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216-003
Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 01/11/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230111 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PBU 05-30 50029222130000 191115 1/2/2023 HALLIBURTON RMT3D PBU 15-07D 50029211660400 215158 12/29/2022 HALLIBURTON RMT3D PBU K-20C 50029225550300 208049 1/2/2023 HALLIBURTON RBT PBU L1-13 50029235630000 216003 1/4/2023 HALLIBURTON RMT3D PBU Z-223 50029237200000 222080 12/22/2022 HALLIBURTON WFL-TMD3D-RMT3D PBU L-112 50029231290000 202229 1/6/2023 READ MemoryRadialCementBondLog Please include current contact information if different from above. By Meredith Guhl at 3:24 pm, Jan 11, 2023 T37435 T37436 T37437 T37438 T37439 T37440 PBU L1-13 50029235630000 216003 1/4/2023 HALLIBURTON RMT3D Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.01.11 15:32:54 -09'00' 5HJJ-DPHV% 2*& )URP $ODVND16&7''60 $ODVND16&7''60#KLOFRUSFRP! 6HQW )ULGD\0D\ $0 7R 5HJJ-DPHV% 2*& '2$$2*&&3UXGKRH%D\ %URRNV3KRHEH/ 2*& &F +HQVRQ-DPHV UREHUWFR\QH#QDERUVFRP 1DWKDQ:KHHOHU +HQVRQ7KRPDV :LOOLDPV:DGH $ODVND16&7''60 6XEMHFW 1DERUV&'53%8/,QLWLDO%23(WHVW $WWDFKPHQWV 1DERUV&'5[OV[ /ŶŝƚŝĂůKW ƚĞƐƚ :ŽŚŶWĞƌů ^ƌ͘ƌŝůůŝŶŐ&ŽƌĞŵĂŶʹEĂďŽƌƐZϮ ZŝŐ;ϵϬϳͿϲϳϬͲϯϬϵϳ WĞƌƐŽŶĂůĞůů;ϵϬϳͿϯϱϱͲϱϴϭϱ ,ηϰϭϲϵ WŽƐŝƚŝŽŶĂů ŵĂŝůůĂƐŬĂE^ͲdͲ^DΛŚŝůĐŽƌƉ͘ĐŽŵ ůƚĞƌŶĂƚĞ͗DĂƌŬ/ŐƚĂŶůŽĐ ,ŝůĐŽƌƉůĂƐŬĂ͕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ll BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:CDR2AC DATE: 5/18/22 Rig Rep.: Rig Phone: (907) 670-3056 Operator: Op. Phone:(907) 670-3097 Rep.: E-Mail Well Name: PTD #22160030 Sundry #321-591 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250 / 3500 Annular:250 / 3500 Valves:250 /3500 MASP:1170 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig P Lower Kelly 0NA PTD On Location P Hazard Sec.P Ball Type 2P Standing Order Posted P Misc.NA Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 2-3/8"P Trip Tank PP Annular Preventer 1 7-1/16" GK FP Pit Level Indicators PP #1 Rams 1 Blind / Shear P Flow Indicator PP #2 Rams 1 2-3/8" Pipe / Slip P Meth Gas Detector PP #3 Rams 1 3" Pipe/ Slip P H2S Gas Detector PP #4 Rams 1 2-3/8" Pipe / Slip P MS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 2-1/16"P Inside Reel valves 1P HCR Valves 2 2-1/16"P Kill Line Valves 1 2-1/16"P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 2 2.0" Piper P Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)2225 P Quantity Test Result 200 psi Attained (sec)16 P No. Valves 12 P Full Pressure Attained (sec)51 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 10 @1990 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:1 Test Time:6.0 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 5/16/22 13:32 Waived By Test Start Date/Time:5/18/2022 16:00 (date) (time)Witness Test Finish Date/Time:5/18/2022 22:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Matt Herrera Nabors Annular Fail / Cycle / Pass R.Coyne / T. Henson Hilcorp J. Perl / T. Kavanagh PBU L1-13 Test Pressure (psi): alaskans-ctd-dsm@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0518_BOP_Nabors_CDR2AC_PBU_L1-13 +LOFRUS1RUWK6ORSH//& 9 9 9 9999 9 9 9 9 9 9 -5HJJ Annular Fail / Cycle / Pass FP +LOFRUS1RUWK6ORSH//&K 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU L1-13 Set Whipstock Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 216-003 50-029-23563-00-00 ADL 028302 & 028303 17216 Conductor Surface Intermediate Liner Liner 8902 80 5166 10709 3342 3178 16961 20" 13-3/8" 9-5/8" 7" 4-1/2" x 3-1/2" 8921 47 - 127 47 - 5212 45 - 10754 10646 - 13988 13828 - 17007 1170 47 - 127 47 - 3806 45 - 6735 6645 - 8858 8729 - 8920 None 2260 4760 5410 7500 / 10530 None 5020 6870 7240 8430 / 10160 13978 - 16933 4-1/2" 12.6#13Cr85 42 - 138348850 - 8921 Structural 4-1/2" HES TNT Perm Packer No SSSV Installed 13740 / 8659 No SSSV Installed Date: Monty Myers Drilling Manager Trevor Hyatt trevor.hyatt@hilcorp.com 777-8396 PRUDHOE BAY, LISBURNE OIL February 15, 2022 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. 11.16.2021 By Samantha Carlisle at 7:12 am, Nov 17, 2021 321-591 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2021.11.16 16:35:11 -09'00' Monty M Myers 1170 BOPE test to 3500 psi. 10-404 DSR-11/17/21MGR29NOV21SFD 11/17/2021dts 11/30/2021 11/30/21Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.11.30 11:25:55 -09'00' RBDMS HEW 12/1/2021 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: November 16, 2021 Re: PBU L1-13 Sundry Request Sundry approval is requested to set a whipstock in L1-13 pre-rig as part of the drilling and completion of the proposed L1-13L1 CTD lateral. Proposed plan for L1-13L1 Producer: Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. E-line will then set a 4-1/2" flow through whipstock. Service coil will mill top frac sleeve to 3.80" ID (potential to do with E-line). See L1-13L1 PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. A single string 3.80" window + 10' of formation will be milled. The well kicks off drilling and lands in the Lisburne formation. The lateral will continue in the Lisburne to TD. Potentially obtain open hole Den/Neu logs before running liner or during the liner run. The proposed sidetrack will be completed with a 3-1/4" x 2-7/8” 13Cr solid/slotted liner. This completion will NOT abandon the parent Lisburne perfs. Pre-Rig Work - (Estimated to start in February 2022): 1. Slickline: Dummy WS drift a. Drift past whipstock setting location 2. Fullbore: CMIT-TxIA to 3,000 psi and MIT-T to 3,000 psi 3. Coil: Mill frac sleeve at 13,978’ MD to 3.80” ID (potential to execute on E-line) 4. E-line: Set 4-1/2” whipstock a. Top of whipstock set at 14,021’ MD (top of window – top of whipstock) b. Oriented 20° ROHS 5. Valve Shop: Pre-CTD Tree Work as necessary Rig Work: x Reference PBU L1-13L1 PTD submitted in concert with this request for full details. x General work scope of Rig work: 1. MIRU and Test BOPE - MASP with gas (0.10 psi/ft) to surface is 1,170 psi a. 24 hour notice for AOGCC witness BOPE test 2. Mill Window 3. Drill Build and Lateral 4. Run Solid/Slotted Liner a. Open hole Den/Neu Logs 5. Freeze Protect and RDMO Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 g completion will NOTpp p abandon the parent Lisburne perfs. Reservoir pore pressure per Trevor Hyatt email 11-29-2021: 2050 psi at 8800' TVD Sundry 321-591 p f whipstock set at 14,021’ MD Separate PTD Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3.0" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 1 Winston, Hugh E (CED) From:Carlisle, Samantha J (CED) Sent:Monday, October 5, 2020 8:16 AM To:Winston, Hugh E (CED) Subject:FW: Cancellation: Sundry #320-043 for L1-13 (PTD 216-003) From: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Sent: Friday, October 2, 2020 8:18 AM To: Abbie Barker <Abbie.Barker@hilcorp.com>; Carlisle, Samantha J (CED) <samantha.carlisle@alaska.gov> Subject: RE: Cancellation: Sundry #320‐043 for L1‐13 (PTD 216‐003) Abbie, I will forward your notification to Samantha Carlisle for AOGCC processing. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907‐793‐1231 Office 907‐223‐3605 Cell CONFIDENTIALITY NOTICE: This e‐mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e‐mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907‐793‐1231 ) or (Melvin.Rixse@alaska.gov). From: Abbie Barker <Abbie.Barker@hilcorp.com> Sent: Thursday, October 1, 2020 8:00 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; Kirsty Schultz <Kirsten.Schultz@hilcorp.com>; Travis Smith ‐ (C) <Travis.Smith@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Bo York <byork@hilcorp.com> Subject: Cancellation: Sundry #320‐043 for L1‐13 (PTD 216‐003) Good Afternoon Mel, Upon review, HNS will not be executing any of the work covered by Sundry #320‐043 before the sundry expires. This sundry covered prep work for a CTD lateral and was approved by the Commission on January 1, 2020. Please cancel Sundry #320‐043. Keep the associated PTD (#220‐014) active pending HNS plan forward. Thank you, Abbie Abbie Barker Regulatory Tech, Prudhoe Bay West Team Hilcorp Alaska Email: Abbie.Barker@hilcorp.com 2 Cell: (907)351‐2459 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Sean Mclaughlin Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU L1-13 Permit to Drill Number: 216-003 Sundry Number: 320-043 Dear Mr. Mclaughlin: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the 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, . Price Chair 2 DATED this J0j day of January, 2020. RBDMST��JAN 3 12020 .LJ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 JAN 2 4 2020 tr7$ 14 3o Zo 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Ope .iio Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change ApfprBv@YfF a EK" Plug for Rednil ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other Set Whipstock 0 ' 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development p - 5. Permit to Dnll Number: 216-003 ' 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number. 50-029-23563-00-00 - 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No Z PBU L7-13 9. Property Designation (Lease Number): 10, Field/Pools: ADL0283028028303 - PRUDHOE BAY. LISBURNE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 17216 • 8902 16961 8921 1774 None None Casing Length Size MD TVD Burst Collapse Structural Conductor so 20" 47-127 47-127 Surface 5166 13-3/8" 47-5212 47-3806 5020 2260 Intermediate 10709 9-5/8" 1 45-10754 1 45-6735 6870 4760 Liner 3342 7" 10645 - 13988 fifi45 - 8856 7240 5410 Liner 3176 4-112" x 3-1/2" 13828 - 17007 8729-8920 8430/10160 7500 / 10530 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13978 - 16933 850 - 8921 8850-8921 4-1 /2" 12.6# 13Cr85 42-13834 Packers and SSSV Type: 4-1/2" HES TNT Perm Packer Packers and SSSV MD (ft) and TVD (it): 13740 18658 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 9 Wellbore Schematic p 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development EI Service ❑ 14. Estimated Date for Commencing Operations: March 1, 2020 15. Well after proposed work: /S}atus Oil ¢ 112WINJ ❑ WDSPL ❑ Suspended ig�'l" 16. Verbal Approval: Date: y� GAS ❑ t WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Mclaughlin, Sean M be deviated from without prior written approval. Contact Email: Sean.McLaughlin@bp.com Authorized Name: Mclaughlin, Sean M Contact Phone: +1 907 223-6784 Authorized Title: Engine ng Team Le - CTD Authorized Signature: Date: G t 'L d COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 0 — Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: ❑ ff JAN 312020 Post Initial Injection MIT Req'd? Yes No ❑J/ RBDMS Spacing Exception Required? Yes ❑ No (Y Subsequent Form Required APPROVED BYTHE 20 Approved by: COMMISSIONER COMMISSION Date. UU - ORIGINAL /k" v, WZPUbmit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate 7+P To: Alaska Oil & Gas Conservation Commission UNVTW From: Sean McLaughlin by CTD Engineer Date: January 23, 2020 Re: L1-13 Sundry Approval Sundry approval is requested to set a whipstock in the L1-13 wellbore as part of the drilling and completion of the proposed L1 -13L1 CTD lateral Parent well, 1-1-13, is a horizontal in the Lisburne. Motherbore production characteristics suggest well is not connected to a large area (or very weakly connected) as the well cycles due to low PI. An add lateral will increase the amount of rock accessed in the area and add productivity as well as maintain parent well production. Proposed plan: Drill a through tubing sidetrack/lateral with CDR2 Drilling rig around April 2020. A frac sleeve will be milled and whipstock set as part of the pre -rig work. CRD2 will mill a 3.80" window in the 4-1/2" liner and drill a Lisburne target to -15,715' MD. A 3-1/4" x2-7/8" L-80 slotted liner completion will be run. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. CTD Drill and Complete L1 -13L1 Program: Start Date: April 2020 Pre -Rig Work scheduled to begin March 2020 1 S Drift for 4-1/2" Mono -Bore Whipstock to deviation. Set DGLV. 2 E Mill Frac sleeve 13,978' MD to 3.80". Set 4-1/2" Mo ore Whipstock top at 14,027' MD. 3 V Pre CTD Tree Work Rig Work: 1. MIRU and test BOPE. Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 1,774 2. Mill 3.80" window plus 10' of rathole. Swap the well to 8.5-9.5 ppg drilling fluid 3. PU drilling BHA with GR/Resistivity 4. Drill 4.25" hole to TD at -15,715' MD 5. Run 3-1/4" x 2-7/8" L-80 slotted liner. 6. Freeze protect well, RDMO Post Rig: V 1. V: Tree work as necessary 2. C: Acid stimulation to increase PI (if necessary) Sean McLaughlin CG.C.—% S CTD Engineer J 223-6784 CC: Well File Joe Lastufka Irk= I.NV WELLHEAD = FMC 11 ACTUATOR - - BAKERC 3.92" OKB. ELEV 60.05' 14223' REF E -EV = _ _ _ . _ 60.05' 4-1/2' BF. B_EV = _ 15.48' 20" X 30" 127' KOP= 576' ZCORD, 4-1/2' Max Angle = 102° @ 14655' 91.5#, A-53, 4-12" ... _.--- DatumI MD= llatum ND= - 14128' 6900' D=19.124' 4-112" 15487' 3.92" 4 13-3/8" CSG, 68#, L-80 HY 0563/BTq D = 12.415' 621 3.92' TOP OF CMT (06/tv16) -7603' 4-1/2' Minimum ID = 3.813" @2201' 2 4-12" 4-1/2" HES X NIPPLE I TOP OF LNR 10646' = 8.681' TBG, 12.6#, 13CR-85 VAMTOP, I -j 13634' bpf, D- 3.8" 95 17"L 26#, L1 VAM TOP, 13988' .0383 bpf. D=6.276" PERFORATION SUMMARY REF LOG: ANGLEAT TOP PERF: 90` @ 16879 Note: Refer to Production DB for historical perf data SQE SPF INTERVAL Opn/Sgz SHOT SOZ 2' 6 16875-16905 1 O 10/04/16 4-12" HES SWELL PACKERS NO SIZE TOP DEPTH MM D 11 4-1/2' 14033' 3.92" 10 4-12" 14223' 3.92' 9 4-1/2' 14470' 3.92' 8 4-112' 14755' 3.92" 7 4-1/2' 15025' 3.92" 6 4-12" 15244' 3.92' 5 4-112" 15487' 3.92" 4 4-112' 15626' 3.92' 3 4-1/2' 15848' 3.92" 2 4-12" 16498' 3.92" 1 4-12' 1 16764' 1 3.92" .0150 bpf, 1)=3.92" LW 9.2#, L-80 TCµ .0087 bpf, D - 1 16961' 1 Ll -13 CHROME TBG&LNR 'MNOTES: WELL � S. 14 70'2"@ 1443f4• 2201' 4-12' HES X NP, D = 3.813' GAS LFT MANTYIF S 7" BKR FRD LTPw RACK SLV & XLOCK HGR D = 6.20' 112" HES X NP, D = 3.813') X 4-712' FDS TNT PKR D= 1/2' HES X NP, D = 3.813" 13826' 7-X5-BKR FBiaEZXPLTPw/TIEBACKSLV& BKR FLf7(LOCK HGR, D = 4.30' 13834' 4-1/2"WLEG, D=3.958' ELMD TT NOT LOGGED 13862' S' X 4-12' XO BDSFfJG, D = 3.91' 4-1/2" FRAC PORT SLEEVES NO DEPTH SEATSZ. STI MD I ND I DEV TYPE VLV I LATCHI PORT165124,17 0720/16 11 14089' 3.037" 5 5626 4005 64 MSX' DOME RK 16 0720116 9 14626 2.857' 5.630' 0720/16 8 MMX'DOMERK 2.767' 5.630' 16 0720/16 7 15200' 2.677' 5.630" 0720116 6 MMG DOME RK 16 0720116 5 15539 2.497' 5.630' 0720/16 4 MMG DMY BK 0 0720116 3 16267 2.332" 5.630" 0720(16 2 MMC SO BK 24 7" BKR FRD LTPw RACK SLV & XLOCK HGR D = 6.20' 112" HES X NP, D = 3.813') X 4-712' FDS TNT PKR D= 1/2' HES X NP, D = 3.813" 13826' 7-X5-BKR FBiaEZXPLTPw/TIEBACKSLV& BKR FLf7(LOCK HGR, D = 4.30' 13834' 4-1/2"WLEG, D=3.958' ELMD TT NOT LOGGED 13862' S' X 4-12' XO BDSFfJG, D = 3.91' 4-1/2" FRAC PORT SLEEVES NO DEPTH SEATSZ. ACTUALS¢E OIC DOTE 12 13978' 3.137" 5.630' 1020/16 0720/16 11 14089' 3.037" 5.630" 08/22116 0720(16 10 14338' 2.947' 5.630" 0720116 9 14626 2.857' 5.630' 0720/16 8 14888' 2.767' 5.630' 0720/16 7 15200' 2.677' 5.630" 0720116 6 15418' 2.587" 5.630" 0720116 5 15539 2.497' 5.630' 0720/16 4 15711' 2.412' 5.630' 0720116 3 16267 2.332" 5.630" 0720(16 2 1666-Z 2252' 5.630" 0720116 7 1 16933' 1 3.75' 1 5.630" 0720/16 DATE RLV BY COWANTS DATE REV BY 0OMMI3ffS 0725116 P-272 IMTTALCOMPLEnON 10112116 TFA/JMD PEW FRAC PORT (10104116) 0728116 JMD DR -G FD CORRECTIONS 1020/16 ZV/JMD GLV GO (10116/16) 08/02116 BGIJMD FINALODEAPPROVAL 0&/30/17 ZV/AD GLVGO(08/24/17) 08/22116 JNJJMD LVDATED REF & BF E LEV 0920116 JPK/JMD GLV d0 (09/14116) 0928/16 WJMD GLV GO(0926/16) SLB FLOWTI-FRU CRC I X 3-1/2' XO. D = 2.992" WB1: L1-13 1437MT Nb: '2160030 API Nb: 50-029-23563-00 SEC. 1, T11 R 141� 2542' FSL & 2478' FE. BP F tploration (Alae ka) 3.87" I Minimum ID = 3.813" @ 2201' 4-1/2" HES X NIPPLE TBG, 12.6#, 13CR-85 VAM TOP, 13834' 3pf, D - 3.958" 7" LNR, 26#, L-80 VAM TOP, 13988- .0383 bpf. D = 6.276" BKR TOP OF 3-1/4' X 2-7/8" LNR000 1 14027' 1 4-Z' LNR, 13.5#, 13CR-85 HYD 521, 16973' .0150 bpf, D = 3.92" L-80 TCII, .0087 bpf, D = 2.992" I17007' m 13828• ("X 5" BKR HRD-E ZXP LTP w /TIEBACK SLV & BKR FLDCLOCK HGR, D = 4.30" 13834' 4-1/2" WLEG, ID= 3.958" -tELMO TT NOT LOGGED 13862' 5" X 4-1/2" XO BUSHNG. D = 3.91' 1-13.70" DEPLOYSLV, D = 3.00" MILLOUT WINDOW (1-143 LI) —' - L -Ea 14131 3-1/4" LNR, 6.6#4aGR-05 TCII, .0079 bpr, D = 2.85" 14V 1' 3-1/4" X 2-7/8" XO. D = 2.377" TD LNR, 6.5#, 43BItm85 STL, I 15715' f, ID = 2.441" DATE __ _G�L FMC PROPOSED � 1 13AD= P-272 INITIAL COMPLETION OR= BA_KERC 09/05/19 SAFETYNOTES: WELL ANGLE>70° 14308'*** GEV = _ ____ _" _ -60A5' L1CHROME TBG &LNR *"•MAX DLS:14.2° @ 14434' V = FR _ 60.05' - ..... 15.48' __.. _- -576' 20" X 30" 127'e 2201' 4-1/2" HES X NIP, ID = 3.813" INS COND, = 91.5#• A-53, GAS LFT MANDRBS D = --- D=19124" ST MD ND DEV TYPE VLV LATCH PORI DATE Datum TVD = 8900' 5 5626 4005 64 Mv1C DOME RK 16 08/24/17 L-B0HVD563/BTC, ID= 12.415' 5212' 4 9928 6099 45 MMG DOME RK 16 08/24/17' 3 11662 7241 64 MIVIG DOME RK 16 08/24/17 TOP CMT (06/12/16) -7503' 2 12731 7849 38 M G OMY BK 0 07/22/16 1 13471 8441 36 M G SO BK 24 08/24/17 10646' 9-5/8" X 7" BKR HRD LTP w /TIEBACK SLV & TOP OF LNR 10646' BKR FLEXLOCK HGR D = 620" WHIPSTOCK (06/23/16) 10754' 9-5/8" CSG, 47#, L-80 VAM TOP, D = 8.681" 12199' 13712' 4-1/2" HES X NIP• D = 3.813" Minimum ID = 3.813" @ 2201' 4-1/2" HES X NIPPLE TBG, 12.6#, 13CR-85 VAM TOP, 13834' 3pf, D - 3.958" 7" LNR, 26#, L-80 VAM TOP, 13988- .0383 bpf. D = 6.276" BKR TOP OF 3-1/4' X 2-7/8" LNR000 1 14027' 1 4-Z' LNR, 13.5#, 13CR-85 HYD 521, 16973' .0150 bpf, D = 3.92" L-80 TCII, .0087 bpf, D = 2.992" I17007' m 13828• ("X 5" BKR HRD-E ZXP LTP w /TIEBACK SLV & BKR FLDCLOCK HGR, D = 4.30" 13834' 4-1/2" WLEG, ID= 3.958" -tELMO TT NOT LOGGED 13862' 5" X 4-1/2" XO BUSHNG. D = 3.91' 1-13.70" DEPLOYSLV, D = 3.00" MILLOUT WINDOW (1-143 LI) —' - L -Ea 14131 3-1/4" LNR, 6.6#4aGR-05 TCII, .0079 bpr, D = 2.85" 14V 1' 3-1/4" X 2-7/8" XO. D = 2.377" TD LNR, 6.5#, 43BItm85 STL, I 15715' f, ID = 2.441" DATE REV BY COMMENTS DATE REV BY COMMENTS 07/251116 P-272 INITIAL COMPLETION --L-L- CTD MULTI -LAT (1-1-13 Lt) 09/05/19 JMD BULTPROPOSED 17 FLOW - PRUDHOE BAY UNf! WELL: Lt -13L1 PERMIT No: '2160030,' API No: 50-020-23563-00 (60) BP Exploration (Alaska) li1V V NELLHEAD= FMC PROPOSED LHEF ELEV = 69.05' SBF. -EL 154A' K� cW = 576' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 90" @ 16875' Note: Refer to Production DB for historical Derf data 4-1/2" FRAC PORT SLEEVES NO DEPTH SEATSZ. JACTLAL SIZE O/C DATE 12 13978' 3.137" 5.630" CTD MULTI-LAT(L1-13L1) 07/20/16 11 14089' 3.037" 5.630" 8 07/20/16 10 14338' 2.947" 5.630" 15025' 07/20/16 9 14626' 2.857" 5.630" 5 07/20/16 8 14888' 2.767" 5.630" 15626' 07/20/16 7 15200' 2.677" 5.630" 2 07/20/16 6 15418' 2.587" 5.630" 16764' 07/20/16 5 1553V 2.497" 5.630" 07/20/16 4 15711' 2.412" 5.630" 07/20/16 3 16262' 2.332" 5.630" 07/20/16 2 16662' 2.252" 5.630" 07/20/16 1 1 16933' 3.75" 1 5.630" 07/20/16 Ll -13 SAFETY NOTES: WELL ANGLE > 70° @ 14308'-** L 1 CHROME TBG & LNR ***MAX DLS: 14.2° @ 14434' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/25/16 P-272 INITIAL COMPLETION 3.92" _/ / 4-1/2" CTD MULTI-LAT(L1-13L1) 3.92" 09/05/19 JMD BUILTPROPOSED 3.92" 8 4-1/2" 14755' 3.92" 7 4-1/2" 15025' 3.92" 6 4-1/2" 15244' 3.92" 4-1/2" FES SWELL PACKERS NO SIZE TOP DEPTH MIN ID 11 4-1/2" 14033' 3.92" 10 4-1/2" 14223' 3.92" 9 4-1/2" 14470' 3.92" 8 4-1/2" 14755' 3.92" 7 4-1/2" 15025' 3.92" 6 4-1/2" 15244' 3.92" 5 4-112" 15487' 3.92" 4 4-1/2" 15626' 3.92" 3 4-112" 15848' 3.92" 2 4-1/2" 16498' 3.92" 1 4-112" 16764' 3.92" PRUDHOE BAYUNR WELL: 1-1-131-1 PERMIT' No: '2160030,' API No: 50-029-23563-00 (60) SP Exploration (Alaska) • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISIN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well ® Re-enter Susp Well 0 Other:OA Well Lock Treatment m 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 216-003 3. Address: P.O.Box 196612 Anchorage, Development m Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-23563-00-00 7. Property Designation(Lease Number): ADL 0028303 8. Well Name and Number: PRUDHOE BAY UN LIS L1-13 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,LISBURNE OIL q 11.Present Well Condition Summary: C E121/01E7 l d6y Total Depth: measured 17216 feet Plugs measured feet iiiwww�i�Vv C true vertical 8902 feet Junk measured feet MA+ 9 2017E i~'6� Effective Depth: measured 16961 feet Packer measured 13740 feet true vertical 8921 feet Packer true vertical 8659 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor Surface 5166 13-3/8"68#L-80 47-5212 47-3806 5020 2260 Intermediate 10709 9-5/8"47#L-80 45-10754 45-6735 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr85 42-13834 42-8734 Packers and SSSV(type,measured and 4-1/2"HES TNT Perm Packer 13740 8659 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): At Surface scAtatW 12017 Treatment descriptions including volumes used and final pressure: G� NOVY 0 2 Gallons Well Lock,2 Gallons MuSol,3800 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 337 2940 22 2050 554 Subsequent to operation: 1030 12678 0 2050 670 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development II Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ ❑ WAG 0 GINJ 0 SUSP ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-090 Authorized Name: Sauve,Mark A Contact Name: Sauve,Mark A Authorized Title: GPMA/Lisburn ad PE Contact Email: Mark.Sauve@bp.com Authorized Signature: r'�.-"?'- L z...--- Date:.5777(1 Contact Phone: +1 907 564 4660 Form 10-404 Revised 04/2017 ✓1/77- 6) 1` I7, x 47 RB DMS ��MAY 1 6 2017 ���/// /// Submit Original Only RECEIVE® MAY 0 9 2017 AOGCC Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary May 9, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Well Lock Treatment of the OA on L1-13, PTD # 216-003. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • m CI 0 0 0 0 co cc... 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N N CO • • II o� � ( E ci - O a) o_ _c = U N > O \ L U a) �m — J eL < O L Q ✓ ) O II L C M 3 O 7 Q i J Y o E sz Cfn o • o co . ~ • Z a) • 5 } iC2 LL e0 Q • m < W = ai O a 0 = Q a, = = -d • II U) II !n > • 111) E U (0 'I c\ Y -ci > Cn Y cn fn N 0 II U 0 L o O )) C 2 N- O N N N TREE rr,.- CMI VVB_LHEAD= RC • L 1 -1 3 S NOTES: WELL ANGLE>70°@ 14308'"° ACTUATOR= BA KER C CHROME TBG& LNR***MAX DLS:142°@ 14434' OKB ELEV= 60.05' REF ELW= 60.05' H - -) 4, 4: * 1421:TC 1--14-112-1-Es X NP ID=3.813-] BF.ELEV= 15.48' 20'X 30" 127' ' i , _) • KOP= 576' INS(OM), . * Max Angie= 102° (';', 14655' 915#,A-53, GAS LFT MANDRELS Datum1/0= 14125 13 19.124" ST AC TVD DEV TYPE VLV LATCH FORT DATE ' = Datum TVD= 8900' 5 5626 4005 64 MAG DOME RK 16 10/16/16 - 4 9928 6099 45 kt/IG SO RK 20 10/16/16 13-3/8°CSG,68#,L-80 HY C663/STC,ID=12.415" 6212' 1 L 3 11662 7241 64 MG [MY BK 0 07r22/16 TOP oF ChtfT(06/12/16) -7503' . '''. 2 12731 7849 38 WIG DMY Bl< 0 07/22/16 Minimum ID = 3.813" @ 2201' . .1 Pi 1 13471 8441 36 MMG OW BK 0 07/22/16 L. 1.41 4-1/2" I-1ES X NIPPLE f .IN '4 k 10646 -9-5/8-X 7"BKR HRD LTP w TIEBACK SLV& TOP OF LW 10646' L j ...... ...,s BKR FLEKLOCK HGR,ID=6.20" 19-5/8"WHIPSTOCK(06/23/16) it 10754' i Co 4 01 4 t5 p4%4 CSG,47#,L-80 VAMTOP,D=8.681' -H 12199' J I ;$ h p',.... 13712' -14-1/2"FES X NP.ID=3813° 13740' __Ffrc 4-112-FES TNT PKR D=3.870" :rt4 1 13817' --L4-1/7'HES X NIP,ID=3.813' 4-1/2"TBG, 12.6#,13CR-85 VAM TOP, .--[ 13834' .0152 bpf,ID-3.958" , 014 l'rliS 13828' -7"X 5"BKR I-RD-E ZXP LTP w ITEBACX SLV& da. BKR FLEXLOCK HGR,ID=4.30" 7"LNR,26#,L-80 VAM TOP, 13988' I'L 10 k 13834' -14-1/2"VIA_EG,0=3.958" .0383 bpf.D=6_276" ei •*-- h4 1 I I _i--18_ 5D TT NOT LOGGED PERFORATION SLIKRAAR'Y mini it ____13862' H 'X 4-1/2'XO BUSHIVG,ID=3.91' REF LOG: P:41 C.. A 111•111 4-1/2° FRAC PORT SLEEVES NGLE AT TOP F 90'EW @ 16875' eNINUMMIlc, Note:Refer to Production DB for historical pert data .... ...... MD DEPTH SEAT SZ. ACTUAL SIZE 0/C DATE SPF INITER'VAL Opn/Sqz SHOT SQZ 12 13978' 3137" 5.630" 07/20/16 2" 6 16875-16905 0 10/04116 oz.1.111C.4 11 14089' 3.037" 5.630' 07/20/16 10 14338' 2947' 5.630' 07/20/16 4-1/2"FES SWELL PACKERS foi oz. 9 14626' 2857" 5.630" 07/20/16 NO SIZE TOP 0133TH SAN D 8 14888' 2.767" 5.630° 07/20/16 11 4-1/2" 14033' 3.92" ' 7 15200' 2.677' 5.630" 07/20/16 sC4 1.:•,•• 10 4-1/2' 14223' 3.92" 6 15418' 2.587' 5.630' 07/20/16 9 4-1/2' 14470' 3.92° 5 15539' 2.497" 5.630" 07/20/16 /CA III 4 8 4-1/2" 14755 3.92" IC 111111 4 15711' 2.412° 5_630" 07/20/16 7 4-1/2" 15025' 3.92" 3 16262' 2.332" 5.630" 07/20/16 Pr411 prq 6 4-1/2" 15244' 3 92' 2 16662' 2.252° 5.630" 07/20/16 5 4-1/2" 15487' 3.92" 1 16933' 3.75' 5.630' 07/20/16 IN 1.7.4 4 4-1/2" 15626' 3.92' 3 4-1/2" 15848' 3.92' 2 4-1/2' 16498' 3.92° [ 16847' ]-14-1/2°HY 0521 SI-FT TOOL VHRIF1CATXIN SUB,D=3.87"i 1 4-1/2" 16764' 3.92' 143TO H 16961' 16961' H4-112'SLB FLOW-THRU CRC VALVE,ID=1.220' 4-1/2"LNR,13.5#,13CR-85 WO 521, - 16973' a sing .0150 bpf,ID=3.92" 16973' H1/2'X 3-1/2'X0,D=2.992' 3-1/2"LNR,9.2#,L-80 Tat.0087 bpf,ID=2.992° H 17007' ] kW DATE REV BY CONA34TS 1 DATE Re/BY COMMENTS 1 PRUDHOE BAY UHT 07/25116 P-272 IMTIAL COMPLETION 10/12/16 TFA/JM) PAF FRAC PORT(10/04/16) mai_ L1-13 07/28/16 JM) DRLG HO CORRECTIONS 10/20/16 ZWJP.13 GLV C/0(10/16/16) -, PERMT ND: '2160030 08/02/16 BG/JM) FINAL ODE APPROVAL AFT No: 50-029-23563-00 08/22/16 ..INJJM) UPDATED FEF&BF ET_EV SEC. 1,T11N, 14E,2542'FSL&2478'FEL 09/20/16 JFK/J1.13 GLV 010(09/14116) 09/28/16 NW/JMD GLV 010(09126/16) - BP Exploration(Alaska) • o o • O < < < < • N J J J J • O O A j M (OXY Z '� • O O n W < - p M C M (O f0 00 J 0 N 0)I J J J O J O J O J O J m W • O o 7 , � . 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Q a)� a)V I - o a) U Ua < a� o m Q it it Q M J J J Q W it N it ml a' J N J N MI a' co c W it U1 co ;moa Novi , u1 u)I covi O aEco) a) 1 ii Ic) 7 1 7a O I2 J Z c (0 Z co a) oW0,-.7.Z a co a o ' Z W 3 a CO J J J J I m E, m J — L-12 2 W O ocn� @tna p m a }aNo Q a� p as 21 J E Z I m c co 0 ui ui Lai ui o p m @ j�1 ai J hi ai�I N ui iil p YI ni p"o N p "o c LL it a LL t LE aln 0 I p -�2 ca iLL2 it LL2_ iLL2 et p1- it 0 N oa N oa •- O ocp Po Po v oca o7 o1 PO' PO 11 CO PO o o aS • w 0 a)m O to• 0 0p Oa Oo M W OJ Oa N 00 O0 O N O O W O Im 0J U) a) m I N N (N O p I._ I._ I o p 2 -icy) < u) oJ(0 UJco m 0 o) o o) 0Q oa vU1a N on' o"- a N oa OQ o 1y o N J _N a) I5 N N m _N _ 0W a) 0 m IL Q 0 WAIN W N-N W W Q W Q W Q NM M2 W - o) M2 M2 Wo) M2 N 2 W -0 M6 rz 0 z o 0 m co m m co co co co co co m co co m L o 0 0 0 0 0 0 0 0 0 0 0 0 0 W 2 N N N N N N N N N N N N N N O N N N N N N CO M ri a o.O ca 0 co �4- El- W W U m o ', Q 0 V M O co 0 W W O @ N co N. r O co o I N J Q co CLm 0) Co O co Lo g O O O M O oTr O c a U M r U 0 J r M N r Q ct J nn 0. N 1 J (0 5 z_ o 2 N W Q m N r- o 1 CO I m • 0 Q a ° , °' Q c a 0 Z o N co d U E ca as cc; o U Z (n co m a) ca a) a) co a.) co m a) as co a) m a) co a) m m m m m co -o m m m m m m -o m m No 0 0 0 0 0 0 N 0 0 0 0 0 0 N 0 0 a m m m m m m I o m m co o To I o m ) m rn 'rn rn 0) a) a •rn_ 'o) 'o) 'o) o) o) 0) _o o p p p p p p p J 6 p p p b p J p p co > O O 0 0 O O O a) a) a) a) a) a) a) 0 0 o v v v v v v v co m co co co co co co co oLO co co co co co M CO CO CO CO CO CO CO CO CO CO N- r` n N- N- N- r- N. N. n N- N- I r- I N c ,N N N N N N N N N N N N N N N N N .` (0 CI N O � U :.-= U U U U 0 0 0 0 0 0 0 0 0 0 0 0 U C7 O d p p 0 p p 0 0 p 0 0 0 0 0 0 p 0 0 Q a. 2 W W W W W W J W W W W W W J W W 1 • • co . 4:, . . 0 •..- N cm -L3 • M U L.,* U L O O. 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N N N N N N N N N N N N N N N N N N N N '.= co O CV O NII L) U 0 0 0 0 0 0 0 0 0 0 0 0 0 00 0 0 0 0 d 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 F. 0 0 0 0 OQ 0. 2 'IW W W W W W W W W W W W LUW W -1 J W W s • G O C 'O 'O • (,) O g5j m J° f Iiizzz ❑ c p` O 5 ❑ O ❑ O ❑ O c_ c_ c_ c_ - z N O N a O N O N Li: LLI LLI LLI J a -o Z �1 U 2 co 2 co m1 m1 mI mI m U -i Q p1 ❑ �1 p1 ❑ p1 ❑ a)gl 3 00 CD m o0 co it Lii N N U) U) co co co co 1 I I I I a) I "J JF JF JF JF JF JF JF J J J J �I— U O1 ai O 6 O ai O�' ai O ai O 'ai O ai O ai ai ai if) 2 O Z I 1 1'4 1 1 m 1 w Q it = 11= 11 = i Il = it = 11 = LL = IL ) it it Il X ❑ _ @ C 1 E m1 c m1 E E CO (0 D E m1 E ml •E mI E ml E ° •E °- C C x c m1 D E @ O O rn 1:2,1- ..€ O o -o oO a O 'P O -C o P o P o y m m om m fl ,— m 4 0 0 0 o m w E J N M N M O N M y N M N MCI- O N M N M O _N O N O N O N O N M N o Ce Q N W- W- J W ,-❑ E W - J W - W J W 2 W 2 W 2 W 2-c• W .—❑ 0I.0 3 c0 c0 U) co co c0 c0 c0 co CI) (0 c0 Q.... a H U o 0 0 0 0 0 0 0 E E E 0 E in E LU a N N N N N N N N N N N N CO 7 M CO -C-;') M CO CO CO CO CO CO M M U) Z IX 0 LU W 10 0 V m oco Z 41, ° Qreooco N N J 0 0 0. `° acs d C E. o �, co G N _� c"' OcD a VM o r U w 0 J M Q 7. C., - cn a I— J _ y Z 0 to 2 N a) COQ N N M m n c p a) co Cn G co N Q = _ a ° ' m Q o Z E o 0 E U ca Z m m co m co m co co co co m co a) m m m co co m m co co co co co No ❑ ❑ ❑ ❑ O ❑ ❑ ❑ 0 0 0 0 E To �o o m m m m m m m m m o O ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ E GG > WM cooo oo 00CO COC F co co c C O CO CO U) CO co co co c° to co c0 c° W CD N- N- N- N- r N- N- r r N- N- h Z.; N N N N N N N N N N N N d W N C. N d' E E Z •C c N ca 0 D ) Z I- U 0 0 0 0 0 0 0 0 0 0 0 < U tV o0ZE a ❑ ❑ a a a a a a a a a a d Z d w w W W W W W W W W W W • • o o c ce,0 c 7 6 6 o M oNZ >- >- � c)N cv o a T SII Z 0 0) < Ico c co as `I Z L L oo78 m m 2 i U• 0 - J ! Z• O u) t .} c } � w ., Cl IX < ca a 0 u Co13. O U t0 I o> 41) UJ 2 m a O • `„ a it E x a) N W w m rn a 0 m o E 3 co 1 Zc y co Qo• O 0 coV1 -1 a Jw -0 0E iso 0. 0 0 O N a 0 v "' o w c. r U d o J `" O E60 < J O O F N m U ri Z� O I N@=CQNONm I � E LU N = O 0) C w Cl) p m O a) O p D c o Q =a. C �' 0— Co co Q z i : u 0 iiiU 0 M O ca z m 41 coo -- CV -- >- II lb„ Q 00 �J , >. p CO N 'O t0 E o � 0 I' d Tc; N C co 0 o _ > • N d N ▪ CO 0' H `m 0 Co .°2 c e O g o Q o o 0 c c U •• , m -I a) 0 •.a d '� L) a -'o o a Co 0 E 0. • 0 2 o £ m E E 4 a 2 U a 0 0 U p C) I 0 OF • • �yy��,v THE STATE Alaska Oil and Gas "t��i� 9 f Conservation Commission O ALAsKA Sty 333 West Seventh Avenue r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �'' Main: 907.279.1433 OF ALAS*P' Fax: 907.276.7542 www.aogcc.alaska.gov Aras J. Worthington Interventions and Integrity Engineer BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU LIS L1-13 Permit to Drill Number: 216-003 Sundry Number: 317-090 Dear Mr. Worthington: 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, Cath P. Foerster Chair DATED this uuo day of March, 2017. RBDE S AR 2 3 2E7 • STATE OF ALASKA • • ALASKA OIL AND GAS CONSERVATION COMM ON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0• Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other OA Well Lock Sqz Id • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 216-003 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development [JJ' 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-23563-00-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No I1 PRUDHOE BAY UN LIS L1-13 • 9. Property Designation(Lease Number): 10. Field/Pools: RECEIVED ADL 0028303 J' ,a-i oZ.v Z ./..53 2.21-l 7 PRUDHOE BAY,LISBURNE OIL• 11. PRESENT WELL CONDITION SUMMARY FEB 2 3 2017 Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MDL s 24 ist0 17216 • 8902 • 16961 8921 Ap�gJJJ��/1�p� Casing Length Size MD TVD Burst /�ad�11j7N1s� (V Structural Conductor Surface 5166 13-3/8"68#L-80 47-5212 47-3806 5020 2260 Intermediate 10709 9-5/8"47#L-80 45-10754 45-6735 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#13Cr85 13Cr85 42-13834 Packers and SSSV Type: 4-1/2"HES TNT Perm Packer Packers and SSSV MD(ft)and TVD(ft): 13740, 8659.05 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary H Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development El• Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil II • WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Worthington,Aras J be deviated from without prior written approval. Email Aras.Worthington@bp.com Printed Name Worthington,Aras J Title Interventions&Integrity Engineer Signature Phone +1 907 564 4102Date ,//A2^��" COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3 \-1— 090 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance ❑ A_KC 1 !tiI l•` Other: Post Initial Injection MIT Req'd? Yes 0 No IV Spacing Exception Required? Yes 0 No 13 Subsequent Form Required: /(.— ✓fL 4- Approved by:Ctiet7 D p J✓ �� v7i_ 3/i5 /i APPROVED BYTHE COMMISSIONER COMMISSION Date:3-/6, - SS RSDLIS f/' 2 3 2017 ORIGINAL Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate . /�fZ7 ,,"----r.. L. 7 Lli./7 bp • • Well: L1-13 L1-13 OA WeIlLock Squeeze Well Interventions Engineer: Aras Worthington (907) 440-7692 Pad Engineer: Kirsty Schultz (907) 564-5105 History L1-13 is a recent grassroots producer that was drilled by P272. After running the 4-1/2" tubing and setting the production packer, the well failed an MIT-IA. The well passed an MIT-T and the pack off passed an integrity test, indicating IAxOA communication through the 9-5/8" and/or 7" casing. The communication appears to be a few small one way leaks from the IA to OA. E-line ran a LDL indicating leaks at 2883', 2690', 2550', and 2310' MD. The OA was fully cemented by downs ueeze. A follow-up OA squeezecrete job was performed with -2 gallons squeezed to 300 psL A passing MITIA to 2500 psi was performed 9/26/2016. When the well was POP, the OA still evidenced IAxOA communication to gas. A re-squeeze was performed on the OA with WeIlLock to seal off the IAxOA communication, with -1 gallon squeezed away @ -3500 psi but the squeeze was not completed as planned due to runnin _ of cure-time on the Well Lock and having to cut the job short. Subsequent diagnostics indicated there was still IAxOA communication to gas. Current Status The well is currently online without gas-lift and is classified as "Operable" by BP. Gas-lift will not be used on the well until the IAxOA can be successfully repaired. Objective Re-squeeze the OA with Well Lock to seal off IAxOA communication to gas. Procedure 1. ND OA Gate Valve, NU OA Integral. 2. Bleed Annuli, Prep OA, WeIlLock OA top job squeeze to 3500 psi per RPs. <P Z TRS= CNV WEI-LI-EAD= FMC Ll -1 3 SAFETY NOTES: WELL ANGLE>70'@ 14308' '" ACTUATOR- BAKER C CHROME TBG&LNR***MAX DLS:14.2'@ 14434' OKB.ELEV= 60.05' J t ,:- 1 REF ELEV= 60.05' / r • BE ELEV= 15.48' 20"X30" - 127' + I r 2201' _I-I4-1/2••HES x NP,D=3.813' KOP= 576' NSCOND, # y4 - -.,yv1abii`(7lc l{Ak-3 ^' 25 'c' ,tw4-'j j4S Max Angie= 102°@ 14655' 91.54,A-53, GAS LFT MANDRELS Datum MD= 14128' 13=19.124" /At. ST MD TVD DEV TYPE VLV LATCH PORT DATE Datum TVD= 8900' 5 5626 4005 64 MAG DOME RK 16 10/16/16 II 4 9928 6099 45 MAG SO RK 20 10/16/16 [13-3/8'CSG,68#,L-80 HYD563/BTC,D=12.415" - 6212' 3 11662 7241 64 MAC DMY BK 0 07/22/16 �TOP OF CMT(06/12/16} _7603' 2 12731 7849 38 1443 DMY BK 0 07/22/16 ", 1 13471 8441 36 MAG DMY BK 0 07/22/16 Minimum lD =3.813" 2201' - 4-1/2" HES X NIPPLE " 'ili10646' ,-9-5/8'X 7"BKR HRD LIP w/TEBACK SLV& ITOP OF LNR 10646' ) BKR FLEX LOCK HGR ID=6.20" ri 1 1 9-5/8'WFMPSTOCK(06/23/161i 10764' , ,'' N ' 9-5/8"CSG 47#,L-80 VAM TOP,ID=8.681" - 12199' j ` lit 111 lk 13712' I-14-1/2"i- X MP,D=3.813' � ill_ EtPS �� M 13740' -7"X 4112"FSS TNT PKR D=3.870' ► 1381T -I4-1/2"HES X NP,D=3.813' I ill 4-1/2'TBG,12.6#,13CR-86 VAM TOP, 13834' il 0152 bpf,D-3.958' 13828' -f 7'X 5"BKR FORD-E ZXP LTP w/TEBACK SLV& BKR FLED XLOCK HGR, =4.30" 7'LNR 26#,L-80 VAM TOP, 13988' ` 1 13834' 14-1/2'WLEG,D=3.958" I 0383 bpf.D=6.276' 0 2� 1 ( HELM) NOT LOGGED FERFORATION SUM)AARY ■T1 1 13862' He"X 4-1/2"XO BUSHING,D=3.91LI REF LOG: '='_'=' ANGLE AT TOP PERF:90°@ 16875' '-.1,_• 4-1/2"FRAC PORT SLEEVES Note:Refer to Production DB for historical perf data 0.1 NO DEPTH SEAT SZ. ACTUAL SIZE 0/C DATE SIZE SPF INTERVAL Opn/Sqz SHOT SCZ �'� 12 13978' 3.137' 5.630' 07/20/16 2" 6 16875-16905 0 10/04/16 _,7., 11 14089' 3.037" 5.630" 07/20/16 10 14338' 2.947" 5.630" 07/20/16 4-1/2"HES SWELL PACKERS ,_,1111„ 9 14626' 2.857' 5.630" 07/20/16 NO SIZE TOP DEPTH MN D `-i1 8 14888' 2.767" 5.630" 07/20/16 11 4-1/2" 14033' 3.92" 7 15200' 2.677" 5.630" 07/20/16 10 4-1/2' 14223' 3.92" 4 -ic 6 15418' 2.587" 5.630" 07/20/16 9 4-1/2" 14470' 3.92" n1 5 15539' 2.497" 5.630" 07/20/16 8 4-1/2" 14755' 3.92" .-.7...- 4 15711' 2.412' 5-630" 07/20/16 7 4-1/2" 15025' 3.92" 73 16267 2.332" 5.630" 07/20/16 6 4-1/2" 15244' 3.92" �-� 2 16667 2.252' 5-630" 07/20/16 5 4-1/7 15487' 3.92" 1 16933' 3-75" 5.630" 07/20/16 4 4-1/2" 15626' 3.9 �"�_� 2' 3 4-1/2" 15848' 3.92" ._.ill._, 2 4-1/2" 16498' 3.97 •111 ( 16847' 1-(4-112 HYD521 SHFTTOOL V8FICAT1ON SUB,D=3.87" j 1 4-1/2" 16764' 3.92" PBTD -j 16961' ._.lir> 16961' J-4-1/2 SLB FLOW-THRID CRC VALVE,D=1.220" 4-1/2'LNR,13.5#,13CR-85 HYD 521, - 16973' - R1 16973' -4-1/2'X 3-1/2'XO,D=2.992" 0150 bpf,D=3.92" 1.3-.-±1/7_LW,9.24,L-80 TCM,.0087 bpf,D=2.992" 1--j, 17007' J DATE F€V BY CO NIT'S DATE REV BY COM EhITS FRUDHOEBAY UNIT 07/25/16 P-272 INITIAL COMPLETION 10/12)16 TFA/JMD PERF FRAC PORT(10/04/16) WELL: L1-13 07/28/16 JMD DRLG HO CORRECTIONS 10/20/16 ZV/JM) GLV GO(10/16/16) P62MT No: '2160030 08/02/16 BG/JM) FINAL ODE APPROVAL API Nb: 50-029-23563-00 08/22/16 JNUJM) UPDATED FIEF&BF ELEV SEC. 1,T11 N,14E,2542'FSL&2478'FEL 09/20/16 JPK/JWD GLV C/O(09/14/16) 09/28/16 NN/JM)'GLV GO(09/26/16) BP Exploration(Alaska) 2 • • m Q 0 0 0 0 co 0 co CO (0 t N L() O N LO CO CO U Ti; O 0 c 0 0 N I'- "LtN N 3 CD (X) N CD 0 0 m Lo CO I- 6) CS) CO L0 CO - O O CO LO N N CO CO I- co CA CA N- M CO CO CO CO CO H � O � N- LC) CO N N CO CO CO C CO M r-- LO LC) CO N- CD CO E J NN- C)) O) O co 10 O CO CO N- CO - • - r- r r r V co ....12 I I 1 1 I 1 Z VCO CO N N- CO CO C) N "Cr O CO CO V C M� LO LC) O CO O CO c9 co, U U �= J J CO M M Irt N co N *k in co UCt ao N Q. �? 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C0 O O N r N O d- N V (M O C() t() Q CO I- CO O O) CO CO N Cn I- M O N- O c m W Cn O N If) N O N LU CO OO tf) OO OO CA ❑ CO 't Nrtf) t() IC) tf) IC) CO CO CO CO CO W m O cc c J = H O d J d A 0 2 O cn co co co co W CLCe a ° U 2• 000000000000U- 0 % HF- F--- HHHHHHHHHaH a (n (n (A cn (n Cn w U) U) W W U) Q U) 0 1) m 0 m M CO CO CO CO CO CO CO CO CO CO CO CO CO CO O ❑ r r r = = = = = = = = = `- r p cO O O O O O O O O O O O O O W Z o N N N N N N N N N N N N N CV Z W ¢ w w O E N N N N N N N N N N N 0 0 0 Z a W U W pW LIJ W W W ¢ ❑ J I— J J D J a d' W O m ❑ a W —1 J O ¢ 0 W ¢ ¢ a cn ti it co w co a cr a) E M CO M M M M M M M M M M COM 3 = = = = = = = i i = r r r r r r r i LL d U) O N = = = = = r r r r r r r r rcp J O O w a J J J J J J J J J J J J J J < < CO CO LL tL co CO a C< gig STATE OF ALASKA •LASKA OIL AND GAS CONSERVATION COMMISS Revised:Added second OA Squeeze, REPORT OF SUNDRY WELL OPERATIONS Perforate and Acid Stimulate ' 1. Operations Performed Abandon ❑ Plug Perforations Q Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown 0 Suspend ❑ Perforate Q Other Stimulate Q Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well 0 Other:OA Squeeze Q 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 216-003 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-23563-00-00 7. Property Designation(Lease Number): ADL 028302&028303 8. Well Name and Number: PBU L1-13 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: LDL PRUDHOE BAY,LISBURNE OIL w �i 11.Present Well Condition Summary: C EWE D Total Depth: measured 17216 feet Plugs measured None feet ■ ire true vertical 8902 feet Junk measured None feet DEC 15 2016 Effective Depth: measured 16961 feet Packer measured 13740 feet �1 true vertical 8921 feet Packer true vertical 8658 feet ,4®GCC Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20" 47-127 47-127 Surface 5166 13-3/8" 47-5212 47-3806 5020 2260 Intermediate 10709 9-5/8" 45-10754 45-6735 6870 4760 Liner 3342 7" 10646-13988 6645-8858 7240 5410 Liner 3178 4-1/2"x 3-1/2" 13828-17007 8729-8920 8430/10160 7500/10530 Perforation Depth: Measured depth: 13978-16933 feet True vertical depth: 8850-8921 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr85 42-13834 42-8734 Packers and SSSV(type,measured and 4-1/2"HES TNT Perm Packer 13740 8658 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): See Attached Treatment descriptions including volumes used and final pressure: Cement OA with 353 Bbls Class'G'1.16 yield(1709 sx),50 Bbls Class'G'1.19 yield(236 sx)and 1.5 Gallons WellLock. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 2047 9080 100 255 1113 14.Attachments:(required per 20 AAC 25.070.25.071,8 25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ 0 WAG 0 GINJ ❑ SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-415 Contact Worthington,Aras J Email Aras.Worthington@bp.com Printed Name Joe Lastuf a Title Drilling Technologist 1 Signature )fG2 Phone +1 907 564 4091 Date 124151 r 10 T-� Form 10-404 Revised 5/2015 + ` 3/ 2 D / /,7--- ,4 ., ?` 07 RBDMS tiDEC 2 2 2016 Submit Original Only • • 12. Present well condition summary Intervals treated (measured): 16805'— 17007': 3%KCL w/F103 gpt-389 Bbls, 3% KCL w/U67 MuSol —64 Bbls, 28% SXE Acid— 129 Bbls, 20% VDA Acid—30 Bbls, 20% MaxCO3 Acid (fibers added © 120 ppt)—67.5 Bbls. 15667' — 16764': 3%KCL w/F103 gpt— 1088 Bbls, 3% KCL w/U67 MuSol—150 Bbls, 28% SXE Acid — 186 Bbls, 20% VDA Acid—55 Bbls, 20% MaxCO3 Acid (fibers added @ 120 ppt)—61 Bbls. 14796' — 15626': 3%KCL w/F103 gpt— 1011 Bbls, 3% KCL w/U67 MuSol—200 Bbls, 28% SXE Acid —348 Bbls, 20% VDA Acid—143 Bbls, 20% MaxCO3 Acid (fibers added© 120 ppt)—83 Bbls. 13988'— 14755': 3%KCL w/F103 gpt— 1143 Bbls, 3% KCL w/U67 MuSol—213 Bbls, 28% SXE Acid —351 Bbls, 20% VDA Acid—99 Bbls, 20% MaxCO3 Acid (fibers added @ 120 ppt)— 103 Bbls. • i L1-13 Well History ACTIV �^ !1*�, � . , T/I/O = ?/VAC/10. Temp SI. T & IA FL (WIC request). Well has a dry hole tree installed (double gate valves). Well is disconnected from the system, no flow line, well house, grating, scaffolding. Unable to get T FL due to TWC in hole. IA FL near surface. 7/28/2016 Unable to verify dry hole tree valve positions. IA, OA= OTG. 16:10 T/I/O =Vac/Vac/10. Temp = SI. T& IA FLs (E-Line request). No AL. No well house, has drilling scaffolding. TWC pulled and ASV installed. T& IA FLs near surface. 8/4/2016 ASV= C. MV= O. IA, OA= OTG. 04:30 T/I/O= TWC/0/0. RU ASV#02. Pressure test tree 5000 psi (Passed). Pull 4" H TWC 8/4/2016 #294 @108". RDMO. FWP=VAC/0/0. ***Job Complete***. See log for details. T/I/O =Vac/Vac/10. Temp = SI. Assist Eline (LDL). No AL. No well house or flow lines. IA, OA FL near surface. Pressured up to and held 3800 psi on IA while maintaining an 8/4/2016 open bleed on OA. LLR = 1.16 gal/min. Continued on WSR 8-5-16. ***WELL SHUT IN UPON ARRIVAL***(SLB ELINE -ACOUSTIC LDL) INITIAL T/I/O=0/0/0 RIH W/ PDS ACOUSTIC LDL TOOLSTRING (TEMP/CCL/TANDEM LEAKPOINT) (OAL 28', MAX OD 2.125") FOR BASELINE TEMP PASS. TIED INTO TUBING TALLY DATED 22-JULY-16. DHD PUMPED DSL DOWN IA WITH OPEN BLEED ON OA TO OBTAIN LLR OF 1.15 GPM. TBG PRESSURE TRACKED IA VIA GLM#5 SHEAR VALVE (PREVIOUSLY SHEARED) BEGIN DYNAMIC UP PASS FROM 13770' MD WHILE MAINTAINING 3800 PSI ON 8/4/2016 TUBING/IA TAKING RETURNS OUT FROM OA. ***CONTINUED FROM 4-AUG-16***(SLB ELINE -ACOUSTIC LDL) COMPLETE DYNAMIC UP PASS FROM 13770' MD TO 1800' MD WHILE MAINTAINING CONSTANT T/IA PRESSURE OF 3800 PSI DETECTED IA X OA ANOMALIES AT 2883', 2690', 2550'AND 2310'. PERFORMED REPEAT PASSES OVER ANOMALIES. REDUCED IA PRESSURE TO 3000 PSI TO LOG DYNAMIC UP PASS FROM 1800' MD TO SURFACE. ALL PASSES CORRELATED TO TUBING TALLY DATED 22-JULY-16. SEE DHD WSR FOR DETAILS ON FLUIDS. FINAL T/IA/OA= 0/0/0 8/5/2016 ***JOB COMPLETE. WELL SHUT-IN UPON DEPARTURE*** Continued from WSR 8-4-16. T/I/O = 3990/3800/1. Temp = SI. Assist Eline (LDL). No AL. No well house or flow lines. IA, OA FL near surface. Pressured up to and held 3800 psi on IA while maintaining an open bleed on OA. LLR = .958 GPM @ 3800 psi (Pumped 57 gallons of diesel in 60 minutes). Pumped a total of 26 bbl of diesel during LDL. Bled IAP to 0 psi in 20 minutes, (all fluid, 9.9 bbl of returns from IA). E-Line bled TP to 0 psi, OA on Vac. Final WHP's = 8/5/2016 0/ONac. T/I/O=VAC/48NAC. Post Parker 272. Set 4" CIW"H" TWC#432 at 120". TWC LTT Pass. ND DH Tree SV Temp#17 , and ASV#02 . Installed 4" CIW Upper tree serial #120699008-01 . Torqued SSV x MV and THA x MV to API Specs. PT'd tree to 5000 psi =PASS. Pulled TWC#432 at 120". Removed Temp#4 from IA and Temp#30 from OA. Installed tapped blind flange's with jewerly, Torqued to API Specs and PT to 3500 psi. PASS. PT tree cap to 500 psi. PASS ***Job Complete***See Log for Details 8/13/2016 FWP=0/48/0 • • L1-13 Well History 'T/I/O= 35/82/38 Temp= Shut in (new well) Perform Injectivity test on OA. Pumped 100 bbls of ambient diesel in stages to preform injectivity test, see log for details. Bled back -13 bbls diesel. 8/27/2016 FWHP= 73/123/36 Swab, wing, SSV= closed, IA, OA= open to gauge 8/27/2016 T/I/O=vac/104/183 Temp=Sl Circ out for cement job (NEW WELL POST) Pumped 2 bbls 60/40 down IA followed by 302 bbls of 180*crude. Pumped 38 bbls crude down tubing for 8/30/2016 freeze protect. Halliburton pump has well control upon departure. FWHP's=22/3/120. HES Cementing: Job Scope: OA Cement Downsqueeze: MIRU HES cement van and bulk trucks. Pump 10 bbls 50/50 McOH, 186 bbls fresh water mixed w/2 gal/bbl MUSOL- A and 2 gal/bbl SEM-8, 10 bbls Clean Spacer, 75 bbls neat Class"G" cement, 50 bbls Class "G" cement w/ 15 lb/bbl Pressure Seal Aggregate, and 278 bbls neat Class"G" cement. Observe pressure bump of 250 psi after hesitating with aggregate at shoe. Shut down pumps and hesitate/squeeze again to a final pressure of 300 psi. Rig down iron 8/30/2016 from OA, clean out and service OA casing valve. RDMO. ***Job Complete*** T/I/O = 0/0/0. Temp = SI. Squeeze OA(New well post). AL SI @ casing valve (0 psi). Performed draw down test and removed OA jewelry. OA on 12 o'clock position was a wall of cement with a minor amount of soft cement at the bottom of the profile (cleaned out). OA on the 6 o'clock position had valve grease along the top portion of the OA profile leading to a channel around the RH side of the wellhead to about the 4 o'clock position. Filled the channel up with water and used a heater to keep water hot. Rigged up to the opposite side (12 o'clock) and mixed SqueezeCRETE. Pumped -2 cups of SqueezeCRETE into the OA. OA pressured up to 3000 psi. Bumped up 3 times, losing -300 psi in 15 minutes the first two times and holding at 3000 psi the last time (No returns @ the 6 o'clock position). Bled the OAP &cleaned OA opening. Filled OA channed @ the 6 o'clock position w. F-103 & hot water, flushed with fresh water till clean returns were observed (performed twice). Pumped 2 gallons of squeeze crete down the OA @ the 6 o'clock positon to pressure up to 3000 psi. Bumped up 4 times. OAP decreased 5 -600 psi in 15 minutes the first two times, 300 psi the third time and held @ 3000 psi the fourth time. Bled the OAP to 0 psi (1 cup). Cleaned up OA opening & installed 1502 block valves &caps. Applied 500 psi of N2 to the OA. Tags hung. Heater left in wellhouse, door left open. TC x SSV void © 0 psi. Sample left on wellhead. FWPs = 0/0/500. 9/3/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 1700 hrs. T/I/O= SI/0/0. Pre Cement Squeeze. R/D 2" FMC 120 OA valve and N/U 2" intergal 9/3/2016 flanges and block valves. ***Job Complete*** See log. Final WHP's SI/0/0. T/I/O = SSV/0/120. Temp = SI. WHPs (Post OA squeeze). ALP = 0 psi, SI © CV. OAP decreased 80 psi overnight. Temp taken -6" below OA CV at the 6 o'clock position = 72°. Cement sample in WH has not hardened. Heater in WH working properly, WH doors are open. Tree cap = 0 psi. 9/4/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 21:00. T/I/O = SSV/0/200. Temp = SI. WHPs (Post OA squeeze). ALP = 0 psi, SI @ CV. OAP decreased 300 psi overnight. Temp taken -6" below OA CV at the 6 o'clock position = 92*. Cement sample in WH has not hardened. Heater in WH working properly, WH doors are open. Tree cap = 0 psi. 9/4/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 15:00. TWO = SSV/0/180. Temp= SI. WHPs (Post OA squeeze). ALP = 0 psi, SI @ CV. OAP decreased 20 psi overnight. Temp take -6" below OA CV at the 6 o'clock position = 88*. Cement sample in WH is not hard yet. Heater in WH is working properly. WH doors are open. Tree cap bled to 0 psi. 9/5/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 13:50 • • L1-13 Well History T/I/O = SSV/Vac/40. Temp = SI. WHPs (Post OA squeeze). ALP = 0 psi, SI @ CV. OA cemented to surface. OAP decreased 140 psi overnight. Temp taken -6" below OA CV at the 6 o'clock position = 80*. Cement sample in WH is set up on the outside of the sample, still soft in center. Heater in WH is working properly. WH doors are open. 9/6/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 13:50 T/I/O = SSVNac/30. Temp = SI. WHPs (Post OA squeeze). ALP = 0 psi, SI @ CV. OAP decreased 10 psi overnight. Temp take -6" below OA CV at the 6 o'clock position = 68°. Cement sample in WH is not hard yet. Heater in WH is working properly. WH doors are open. Tree cap bled to 0 psi. 9/7/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 04:00 T/I/O = SSV/VAC/O+. Temp = SI. WHPs (post OA squeeze). AL blinded @ CV. Block valve installed in place of OA CV. Heater running in wellhouse. Cement sample on WH no longer liquid. OAP decreased 30 psi in overnight. 9/8/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 00:30 T/I/0 = SSVNac/0. Temp = SI. WHPs (Post OA squeeze). ALP = 0 psi, SI @ CV. OAP decreased 10 psi overnight. Temp take -6" below OA CV at the 6 o'clock position = 68°. Cement sample in WH is hard. Heater in WH is working properly. WH doors are open. Tree cap bled to 0 psi. Crews on location working on instrumentation. 9/8/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 16:30 T/I/O = SSVNac/0. Temp = SI. WHPs (post OA squeeze). AL blinded @ CV. Block valves installed in place of OA CV. Heater is working properly and is aimed to not overheat the well house. Cement sample appears to be solid. 9/9/2016 SV,SSV= C. WV, MV= LOTO'ed. IA, OA= OTG. 16:50 T/I/O = SSVNAC/0+. Temp = SI. WHPs (post OA squeeze). AL blinded @ CV. WHPs unchanged overnight. 9/10/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 04:00 T/I/O=SI/0/0 N/D OA Intregals, N/U front working side OA gate valve Tag#5. FWP's 9/10/2016 SI/0/0 see log for details. T/I/O = SSVNac/0. Temp = SI. Tbg & IA FL (call-in). Unable to obtain Tbg FL due to Master valve being LOTO'ed. IA FL @ -180' (10 bbls). Heater is removed from well 9/10/2016 house. ***WELL S/I ON ARRIVAL*** (new well post) RIGUP, CONT RIH TO PULL B&R 9/13/2016 ***CONT TO 09/14/16 WSR, JOB IN PROGRESS*** (new well post) ***CONT FROM 9/13/16 WSR***(new well post) PULL B&R FROM 13791' SLM / 13817' MD PULL STA#5 RKP-SHEAR VLV© 5604' SLM /5626' MD SET STA# 5 RK-DGLV @ 5604' SLM /5626' MD MIT-IA,1ST 15 MIN 2718 PSI, LOST 45 PSI, 2ND 15 MIN LOST 24 PSI, 3RD 15 MIN LOST 17 PSI, PULL 4-1/2" RHC PLUG BODY FROM SLM 13796'/ 13817' MD ***CONT TO 9/15/16 WSR JOB IN PROGRESS*** (new well post) 9/14/2016 ***CONT FROM 9/14/16 WSR, JOB IN PROGRESS*** (new well post) CONT. POOH W/ PLUG RIGDOWN 9/15/2016 ***WELL S/I ON DEPARTURE, PAD OP NOTIFIED*** (new well post) • • L1-13 Well History T/I/0=500/100/0 SI MIT/Open Hydraulic port (NEW WELL POST) MIT IA to 2631 psi ***PASSED*** Pumped 7.75 bbls DSL down IA to achieve test pressure of 2631 psi. 4th attempt. 15 min loss of 19 psi, 30 min loss of 18 psi, for total loss of 37 psi in 30 mins. Pumped total of 22 bbls DSL down TBG to open Port. See log for Details. IAP bled to 0 psi, bled back approx 6.1 bbls. Tags hung on WV/IA. AFE sign hung on MV***FLUID PACKED WELL*** Valve positions=SV WV SSV closed MV open CVs OTG AL closed 9/16/2016 FWHP=2000/0/0 9/16/2016 Fluid Support dropped Diesel to pump truck T/I/O = SSV/17NAC. Temp = SI. Assist SP (hold back pressure on IA). ALP = 0 psi, AL SI @ casing valve. IA FL @ surface. Pumped 5.9 Bbls of diesel to increase IAP from 17 psi to 2000 psi & held 2000 psi for Halliburton pumpers for 4 hrs. See Halliburton log for pump details. Bled IAP to BT from 1780 psi to 0 psi in 30 min. Monitor for 30 min. IAP unchanged during monitor. Final WHPs = SSV/ONAC. 9/24/2016 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 18:00 HES Pump Unit 9: Job Scope: Close Flow Thru Circulation Valve, Open Frac Port: MIRU HES equipment. Pump 10 bbls 50/50 McOH and 30 bbls 3% KCL for injectivity test, pressure stabilized at 5 bpm at 2900 psi. Drop 1.275" OD dissolvable aluminum ball and pump ball to Flow Thru Circulation Valve with 200 bbls 3% KCL and 5 bbls 50/50 McOH. Ball on seat with 208 bbls away- 50 bbls early. Pressure up to 3800 psi, ball appears to be on seat. Flow Thru Circulation Valve appears to be closed. Cycle pressure from 0 to 5,000 psi 24 times in attempt to open the frac port. Frac port did not open. Well only 9/24/2016 freeze protected at surface with 5 bbls 50/50 McOH. RDMO. Job Complete. Assist SL (New Well Post) Load Fluid, Road to Loc, Spot in equipment, SB for HSL to 9/25/2016 RIH. ***Job continues 09-26-16*** ***WELL S/I ON ARRIVAL*** (new well post) SET 4-1/2" SLIP STOP CATCHER @ 6627' SLM PULLED 1-1/2" DV FROM STA#5 @ 5626' MD SET 1-1/2" CIRC VALVE ON REK LATCH IN STA#5 © 5626' MD 9/25/2016 ***JOB CONT. ON 9/26/16*** **Job continued from 09-25-16 WSR*** Assist SL (New Well Post) MIT IA to 2500 3rd attempt***PASSED*** Pumped 2 bbls meth spear into IA. Pumped 390 bbls crude into IA. taking returns up tbg and out flowline. Pumped 10 bbls crude down flowline for freeze protect. Pumped 7 bbls of crude to achieve test pressure. 1st 15 min IA lost 22 psi, 2nd 15 min IA lost 19 psi. For a total loss of 41 psi in a 30 min test. Bled back 6.7 bbls. AFE sign 9/26/2016 on well/Caution tags hung. FWHP=6/290/0 HSL on well upon departure. ***JOB CONT. FROM 9/25/16***(new well post) LRS CIRCULATED 400 BBLS CRUDE DOWN IA& UP TBG. PULLED 1-1/2" RKP-CIRC VLV FROM STA#5 @ 5626' MD SET 1-1/2" RK-DGLV IN STA#5 @ 5626' MD LRS MIT-IA...PASSED PULLED SS C-SUB FROM 6627' SLM 9/26/2016 ***JOB COMPLETE, WELL LEFT S/I*** HES Pump Unit 9: Job Scope: Open Frac Port: MIRU HES equipment. Tree saver installed in well. Pressure up to 6100 -6300 psi 6 times. Did not open frac port. Shut 9/29/2016 down for the day. Job continued on 9/30/2016. T/I/O = 10/260Nac. Temp = SI. Hold 2500 psi on IA (Assist SP). ALP = 0 psi, SI @ CV. IA FL @ surface. Used 5.4 bbls Diesel to pressure up IA from 260 psi to 2500 psi. Held 2500 psi on IA for SP job. Bled IAP to 0 psi (5.6 bbls). Monitored during RD. IAP increased 60 psi. Final WHPs = 0/60Nac. 9/29/2016 Tree Saver attached to well upon arrival and departure. 17:30. • • L1-13 Well History T/I/O = 30/170Nac. Temp = SI. Hold 3000 psi on IA(Assist SP). ALP = 0 psi, SI @ CV. IA FL @ surface. Used 6.75 bbls Diesel to pressure up IA to 3000 psi. Used another 2 bbls to maintain 3000 psi on IA for duration of job. Bled IAP to 0 psi (8.75 bbls). Monitored during RD. IAP increased 80 psi. Final WHPs = 0/80Nac. 9/30/2016 Tree Saver installed upon arrival and departure. 17:00. HES Pump Unit 9: Job Scope: Open Frac Port: Continued from 9/29/2016. Tree saver installed in well. Pressure up to 6800 psi 8 times. Did not open frac port. Secure well and 9/30/2016 location. Job Complete. CTU#14, 2" CT Job Objective: Depth Log/Tbg Punch MIRU CTU. 10/2/2016 ***In Progress*** CTU#14, 2" CT Job Objective: Depth Log/Tbg Punch 10/2/2016 Spot and RU unit. CTU#14, 2" CT Job Objective: Depth Log/Tbg Punch RU and perform BOP test. 10/3/2016 CTU#14 2.0" CT Job Objective: Depth Log/ Perforate Perform Weekly BOP Test. MU & RIH w/ PDS 2.2" GR/CCL Carrier&2.2" DJN. Circulate safelube while RIH. Stop pumping at 15000'. RIH dry and tag down at 16906'. Pick up clean. Depth seems a little high from the Circ Valve at 16961'. Attempt to jet and tagged same depth and circ pressure spiked up (have down jet nozzle on). From compression log 50fpm. Flag pipe at 16800'. Continue logging 50fpm up to 13350'. 10/3/2016 Pooh. CTU#14 2.0" CT Job Objective: Depth Log/ Perforate Perform Weekly BOP Test. MU & RIH w/ PDS 2.2" GR/CCL Carrier&2.2" DJN. Circulate safelube while RIH. Stop pumping at 15000'. RIH dry and tag down at 16906'. Pick up clean. Depth seems a little high from the Circ Valve at 16961'. Attempt to jet and tagged same depth and circ pressure spiked up (have down jet nozzle on). From compression log 50fpm. Flag pipe at 16800'. Continue logging 50fpm up to 13350'. Pooh. LD logging BHA, failed run, data is bad. MU & RIH w/ PDS 2.2" GR/CCL Carrier& 10/3/2016 2.2" DJN Assist Frac Crew. Circulated 35 bbls to heat diesel transport. ***WSR continued on 10-5- 10/4/2016 16*** CTU#14 2.0" CT Job Objective: Depth Log/Perforate RIH w/ PDS 2.2" GR/CCL Carrier&2.2" DJN. Tag at 16,929 CTM. Log up and repaint flag (Yellow and red) e =16834.6, mech = 16855, PDS = 16834.67'. Log to 13300 @ 40 fpm. POOH to surface. ***In Progress*** 10/4/2016 CTU#14 2.0" CT Job Objective: Depth Log/ Perforate RIH w/ PDS 2.2" GR/CCL Carrier&2.2" DJN. Tag at 16,929 CTM. Log 40fpm and flag pipe at 1634.67'. Continue logging 40fpm up to 13300'. POOH. Receive good PDS data ( +40' Correction ). Corrected Tag was at Slb Circ Valve at 16963'. MU & RIH w/2"x 30' HES MaxForce Perf Gun. Correct Depth at flag, perforate Interval 16875 - 16905. Perform Injectivity Test: 2240 psi at 1 BPM. Pooh. FP Well w/40 bbls 50/50 Meth. Blow reel down w/ N2. Rig Down CTU. 10/4/2016 ***Job Complete*** i L1-13 Well History CTU#14 2.0" CT Job Objective: Depth Log/ Perforate RIH w/ PDS 2.2" GR/CCL Carrier&2.2" DJN. Tag at 16,929 CTM. Log 40fpm and flag pipe at 1634.67'. Continue logging 40fpm up to 13300'. POOH. Receive good PDS data ( + 40' Correction ). Corrected Tag was at Slb Circ Valve at 16963'. MU & RIH w/2"x 30' HES MaxForce Perf Gun. Correct Depth at flag, perforate Interval 16875- 16905. Perform Injectivity Test: 2240 psi at 1 BPM. Pooh. FP Well w/40 bbls 50/50 Meth. 10/4/2016 ***Job Complete*** ***WSR continued from 10-4-16***Assist Frac Crew. Circulated 210 bbls of diesel (250 bbls total) to heat transport to 90*. Heat SLB tanker of diesel to 90****WSR continued on 10/5/2016 10-6-16*** Schlumberger Frac, Job Scope: Multi Stage Acid Stimulation: MIRU SLB frac equipment. Rig up iron, heat diesel transport, test IA PRVs. PT treating iron, function test check valve. Leak found on 3.5"valve on missile manifold -cannot repair on location. Secure 10/5/2016 location. Job Continued on 10/6/2016. ***WSR continued from 10-5-16***Assist Frac Crew. Pumped 3.36 bbls dsl down IA for initial pressure on IA. Maintained 1600-1700 psi on IA with an additional 2.4 bbls diesel. 10/6/2016 ***WSR continued on 10-7-16*** ***SLB Frac Crew*** Job Scope: Pump Multi-Stage Acid Treatment w/fiber diversions targeting Wahoo Zones 6, 5 and 4 «< InterAct Publishing >>> Pump job per design. Pump Matrix injection test using 3% KCL, Pump 3% KCL w/5% U67 MuSol then verious stages of acid using 28% SXE, 20%VDA, 20% MaxCO3 (120 ppt fibers) no diviersion seen on first fiber stage. During second SXE stage entering through perforations at Frac Port#1 area well started to lock up not taking any fluids. Waited for a few minutes and well started to take fluid but would pressure up again. Waited until pressure cure slowed and well began taking fluids at min rate. Re-established injection rate of 1.9 bbl/min @ 3763 psi Flushed wellbore and liner with 3% KCL and freeze protected TBG w/30 bbls of diesel. Secured well for night and called grease crew to service tree. ...Suspend operations for night and continue next day... ***Note: Due to wrong ratios put into software, fluid volumes 10/6/2016 seen in Log and Fluids sections of report are accually 1.5 times more.*** ***WSR continued from 10-6-16***Assist Frac Crew. Pumped 3.93 bbls of diesel down IA to bring IAP to initial pressure of 1400 psi. Pumped an additional 1 bbl diesel down IA to 10/7/2016 maintain 1600-1700 while fracking.***WSR continued on 10-8-16*** ***SLB Frac Crew*** Job Scope: Pump Multi-Stage Acid Treatment w/fiber diversions targeting Wahoo Zones 6, 5 and 4 «< InterAct Publishing >>> Pump job per design. Frac Port#2 shifted and stimulated with varring stages/volumes of 28% SXE, 20%VDA Frac Port#3 shifted and stimulated with varring stages/volumes of 28% SXE, 20% VDA and MaxCO3 150 ppt showed a small response Frac Port#4 shifted and stimulated with varring stages/volumes of 28% SXE, 20%VDA and MaxCO3 150 ppt showed a small response Flushed wellbore with 3% KCL w/F104 and freeze protected to 2500'with diesel. 10/7/2016 ...Suspend operations for night and continue next day... • • L1-13 Well History ***SLB Frac Crew*** Job Scope: Pump Multi-Stage Acid Treatment w/fiber diversions targeting Wahoo Zones 6, 5 and 4 <<< InterAct Publishing >>> Pump job per design. Frac Port#5 shifted and stimulated with varring stages/volumes of 3%KCL, MuSol, 28% SXE, 20%VDA and MaxCO3 150 ppt Frac Port#6 shifted and stimulated with varring stages/volumes of 3%KCL, MuSol, 28% SXE, 20%VDA and MaxCO3 150 ppt Frac Port#7 shifted and stimulated with varring stages/volumes of 3%KCL, MuSol, 28% SXE, 20%VDA and MaxCO3 150 ppt Frac Port#8 shifted and stimulated with varring stages/volumes of 3%KCL, MuSol, 28% SXE, 20%VDA and MaxCO3 150 ppt Flushed wellbore with 3% KCL w/F104 and freeze protected to 2500'with diesel. 10/8/2016 ...Suspend operations for night and continue next day... ***WSR continued from 10-7-16***Assist Frac Crew. Pumped 4.3 bbls diesel down IA for initial pressure on IA. Pumped an additional .5 bbl diesel down IA to maintain 1600 - 1700 10/8/2016 psi. ***WSR continued on 10-9-16*** ***WSR continued from 10-8-16***Assist Frac Crew. Pumped 6.36 bbls diesel down IA to reach backside pressure for frac. Pumped an additional 1.14 bbls diesel down IA during frac to maintain 1600 psi during frac. Bled IA down to 400 psi, rigged off PRV skid, rigged 10/9/2016 up to hardline to freeze protect tbg ***WSR continue on 10-10-16*** ***SLB Frac Crew*** Job Scope: Pump Multi-Stage Acid Treatment w/fiber diversions targeting Wahoo Zones 6, 5 and 4 <<< InterAct Publishing >>> Pump job per design. Frac Port#9 shifted and stimulated with varring stages/volumes of 3%KCL, MuSol, 28% SXE, 20%VDA and MaxCO3 150 ppt Frac Port#10 shifted and stimulated with varring stages/volumes of 3%KCL, MuSol, 28% SXE, 20%VDA and MaxCO3 150 ppt Frac Port#11 shifted and stimulated with varring stages/volumes of 3%KCL, MuSol, 28% SXE, 20% VDA and MaxCO3 150 ppt Frac Port#12 shifted and stimulated with varring stages/volumes of 3%KCL, MuSol, 28% SXE, 20%VDA and MaxCO3 150 ppt Flushed wellbore with 3% KCL Handed over well to LRS to freeze protect. 10/9/2016 ***Job Comoplete***. ***WELL S/I ON ARRIVAL*** (new-well-post) CURRENTLY DRIFTING W/2.25" CENT/SB 10/10/2016 ***CONT ON 10/11/16 WSR*** ***WSR continued from 10-9-16***Assist Frac Crew. Pumped 38 bbls of diesel down the 10/10/2016 tbg to FP. FWHP=788/334/5 SV,WV,SSV=closed IA,OA=OTG ***CONT FROM 10/10/16 WSR, JOB IN PROGRESS*** TAGGED UP @ 13,959' SLM W/2.25" CENT, 1.75" S. BAILER (recovered 1/2 cup of frac sand) RAN BP DUAL SPARTEK GAUGES AS PER ADJUSTED PROCEDURE. (unable to make bottom stop) WINDS ABOVE 30 MPH. MOVE TO WEATHER WSR. 10/11/2016 ***END TICKET, MOVE TO WEATHER WSR*** ***BEGIN TICKET, CONT FROM 10/11/16 WSR*** (new-well-post) SET X-CATCHER IN X NIP @ 13690' SLM (13,712' MD) 10/14/2016 ***CONT TO 10/15/16 WSR, JOB IN PROGRESS*** • L1-13 Well History ***CONT FROM 10/14/16 WSR, JOB IN PROGRESS*** PULLED RK-DGLV FROM ST#4 © 9,915' SLM/9,928' MD. PULLED RK-DGLV FROM ST#5 @ 5,606' SLM/5,626' MD. SET RK-LGLV IN ST#5 @ 5,606' SLM/5,626' MD. THREE FAILING ATTEMPTS TO SET RK-OGLV IN ST#4 @ 9,915' SLM/9,928' MD. RATTLE MANDRELS DOWN TO 13,692' SLM (14,012' MD)ATTEMPT TO FISH VLV 10/15/2016 ***CONT TO 10/15/16 WSR*** ***CONT FROM 10/15/16 WSR, JOB IN PROGRESS*** ATTEMPT TO FISH VALVE FROM CATCHER @ 13692' SLM, W/2-1/2" JD GUTTED, UNSUCCESSFUL KOT W/LIB TO STA#4 @ 9,915' SLM (9,928' MD), PICTURE OF EMPTY POCKET. PULLED 4-1/2"X CATCHER FROM X-NIPPLE @ 13,690' SLM/ 13,712' MD. SET 4-1/2"X-CATCHER IN X-NIPPLE @ 13,690' SLM/ 13,712' MD. SET RK-OGLV IN ST#4 @ 9,915' SLM/9,928' MD. PULLED EMPTY X-CATCHER FROM X-NIPPLE @ 13,690' SLM/ 13,712' MD. 10/16/2016 ***WELL S/I ON DEPARTURE, PAD OP NOTIFIED, JOB COMPLETE*** LRS Test Unit 2. Post Acid Frac Flowback/Test. Rig Up, PT, POP. Continue on WSR 10/18/2016 10/19/16 LRS Test Unit 2. Continue from 10/18/16. Post Acid Frac Flowback/Test. Rig Up, PT, 10/19/2016 POP/flow. Continue on WSR 10/20/16 LRS Test Unit 2. Continue from 10/19/16. Post Acid Frac Flowback/Test. Flow/Trouble 10/20/2016 Shoot Suspected Ice Plug in Tubing. Continue on WSR 10/21/16 T/I/O = 30/2000/370. Temp = SI. TBG & IA FL. (Assist well testers). TBG FL @ 690' (11 bbl), IA FL @ 9928', (sta#4 OGLV, 532 bbl). 10/20/2016 Well Testers in control of WH Valves. 04:00 T/I/O= 2500/2000/225 SI (NEW WELL POST) Pumped a total of 510 bbls of Hot Crude down IA. Pumped 2 bbls of Meth down the TBG before it reached max pressure of 2500 10/20/2016 psi. ***Job continued from 10/20/16 *** Pumped 254 bbls 180*crude and 10 bbls meth down IA. Pumped 170 bbls 180*crude down TBG to clear hydrates. Well Testers on well upon 10/21/2016 departure CVs OTG AL closed FWHP=900/1100/200 LRS Test Unit 2. Continue from 10/20/16. Post Acid Frac Flowback/Test. Flow/Trouble Shoot Suspected Ice Plug in Tubing/LRS Pumping Down IA and Tubing. Continue on 10/21/2016 WSR 10/22/16 LRS Test Unit 2. Continue from 10/21/16. Post Acid Frac Flowback/Test. Flow Well, 10/22/2016 Well Started to U-Tube Gas, SI and Stack Out, Surge Well. Continue on WSR 10/23/16 T/I/O = 2210/2210/770. Temp = SI. TBG & IA FL (Well test call-in). T FL @ 8830'. IA FL @ 9928' (glm#4, OGLV). 10/23/2016 ASRC in control of well. 01:00. LRS Test Unit 2. Continue from 10/22/16. Post Acid Frac Flowback/Test. Stack Out, 10/23/2016 Surge Well, Flow to Tanks. Continue on WSR 10/24/16 T/I/O = 70/820/200. Temp = 60°. TBG & IA FLs (Well Test request). AL SI @ casing valve,ALP = 2200 psi. TBG FL @ 8790'. IA FL @ 9928' (sta#4, S/O). 10/23/2016 ASRC in control of well on departure. 12:00 hrs. LRS Test Unit 2. Continue from 10/23/16. Post Acid Frac Flowback/Test. Flow to Tanks. BD, RD, Move to DS06-15. GLT Casing valve left SI, flagged and tagged due to OA continually pressuring up while IA was being supplied GLT. Discussed with DSO. GLT 10/24/2016 Casing Valve Job Complete on WSR 10/24/16 T/I/0=650/700/460 Temp=S/I (Freeze Protect Tbg for Well Testers) Pumped 2 bbls of meth followed by 38 bbls of crude down Tbg for freeze protect. SV,WV,SSV,AL=closed 10/25/2016 MV=open IA,OA=otg. FP tag hung. FWHPs=150/700/460. DSO notified of well status • L1-13 Well History T/I/O = 650/700/420. RD Ball Catcher& CV, re-install 4"tapped blind on FC. Torque & 10/26/2016 test. See log for details. ***Job Complete*** T/I/O = SSV/700/320. TEMP = SI. PPPOT-IC (PASS) eval. Stung into Test port, 0 plus psi. bled void to 0 psi. Monitored for 10 min, no change in pressure. R/U test equipment to test void. pumped through void, good returns. void would not pressure over 2,200 psi. torque LDS to 450 ft/lb. Pressure void up to 3,500 psi for 30 min test. Loss of(50 psi) in 15 min, Loss of(0 psi) in second 15 min (PASS). Bled void to 11/9/2016 0 psi, R/D test equipment. Injectivity Test (NEW WELL POST) Road to GC1 to load crude, Road to location, 11/10/2016 ***WSR Continued on 11-11-16*** ***WSR Continued from 11-10-16*** T/I/O= 1060/700/300 Temp= S/I Injectivity Test (NEW WELL POST) Pumped 3 bbls meth spear followed with 200 bbls 110*crude to load TBG, Pumped 204 bbls 110*crude down TBG to achieve injectivity SRT, Rates& pressures as follows, .5 bpm @ 800 psi, 1 bpm @ 893 psi, 1.5 bpm @ 1063 psi, 2 bpm @ 1156 psi, 2.5 bpm @ 1463 psi, 3 bpm @ 1654 psi, 3.5 bpm @ 1819 psi, 4 bpm @ 2013 11/11/2016 psi, Valve position @ departure-SV, WV, SSV= Closed, MV= Open, IA& OA= OTG, ******WELL SHUT IN ON ARRIVAL****** DRIFT W/ 2 .50" CENTRALIZER AND 2.50" SAMPLE BAILER TO 14,300 FT SLM DEVIATED OUT ( 70 DEG + - )(RECOVERED 1/2 GALLON OF SAND) 11/11/2016 ***RDMO, DSO WALKED DOWN WELL*** T/I/O = 230/720/570. Temp = SI. T& IA FL (Testers request). ALP = 1960 psi, SI @ CV. OA cemented to surface. T FL @ surface. IA FL @ 9928' (#4 SO, 531 bbls). 11/23/2016 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 16:30. LRS Unit 1. Post Acid Frac Flowback/Test. Inlet Well L1-13, Outlet Well L1-15. ***Started on WSR 11-24-16***Current Well Barrier Inlet&Outlet: SSV, MIRU ***Continue on WSR 11/24/2016 11/25/16*** LRS Unit 1. Post Acid Frac Flowback/Test. Inlet Well L1-13, Outlet Well L1-15. ***Continued from WSR 11-24-16***Current Well Barrier Inlet: SSV Outlet: SSV, RU, PT, 11/25/2016 SB for Shower Trailer, POP Well ***Continue on WSR 11/26/16*** LRS Unit 1. Post Acid Frac Flowback/Test. Inlet Well L1-13, Outlet Well L1-15. ***Continued from WSR 11-25-16*** Current Well Barrier Inlet: Hardline/Separator Outlet: SSV, Flowing Well, Bled down OA multiple times, DSO's OA transmitter was not working correctly, possibly needs calibration pad op made a work order for it. When OA is SI (Normalized) it pressures up over the course of 30-40 mins to >960 PSIG. Bled down and left an open bleed in an attempt to correct the pressuring up. So far not successful, 11/26/2016 continue to actively monitor pressure build up and bleed off as necessary. ***Continue on LRS Unit 1. Post Acid Frac Flowback/Test. Inlet Well L1-13, Outlet Well L1-15. ***Continued from WSR 11-26-16*** Current Well Barrier Inlet: Hardline/Separator Outlet: SSV, Flowing Well, Bleed the down IA 500 psi and OA down to 0 psi. Monitor the 11/27/2016 pressure for any communication ***Continue on WSR 11/28/16*** T/I/O = 1140/260/60. Temp = 76°. WHPs (eval IAxOA). ALP = 2000 psi, SI @ CV. Heater in WH. Ops holding open bleed, SI for 5 min for read. OA cemented to surface. 11/28/2016 T/I/0=770/220/0+, Temp=84*. PPPOT-IC (PASS), eval high OAP. PPPOT-IC: Stung into test port(0 psi). Monitored for 10 min, no change in pressure. Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 0 psi 11/28/2016 in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. • • L1-13 Well History LRS Unit 1. Post Acid Frac Flowback/Test. Inlet Well L1-13, Outlet Well L1-15. ***Continued from WSR 11-27-16***Current Well Barrier Inlet: Hardline/Separator Outlet: SSV, Flowing Well, Bleed the down IA 0 psi and OA down to 0 psi. Monitor the 11/28/2016 pressure for any communication, Start 6 hr test,RDMO ***End WSR 11/28/16*** T/I/O = 740/260/620. Temp = 82°. WHPs (eval IAxOA). ALP = 2000 psi, SI @ CV. TP decreased 80 psi, IAP unchanged and OAP increased 460 psi in 8 hrs. 11/29/2016 SV= C. WV, SSV, MV= 0. IA, OA= OTG. 15:15 T/I/O = 820/260/160. Temp = 82°. WHPs (eval IAxOA). ALP = 2000 psi, SI @ CV. OA bleed SI by DSO @ - 06:00. IAP unchanged, temp increased 6° in 8 hrs. 11/29/2016 SV= C. WV, SSV, MV= 0. IA, OA= OTG. 07:30 640/270/950. Temp= 72°. WHPs (eval IAxOA). LAP = 2260 psi, SI @ CV. OA bled t 0 psi by DSO @ -18:00. 12/3/2016 SV= C. WV, SSV, MV= 0. IA, OA= OTG. 02:30 T/I/O = 610/280/870. Temp = 68°. WHPs (eval IAxOA comm). ALP = 2260 psi, SI @ casing valve. OA bled to 0 psi by DSO on 12/04/16. 12/6/2016 SV= C. WV, SSV, MV= 0. IA, OA= OTG. 22:30 T/I/0=600/250/900. Pre Cement Squeeze. Removed 2" FMC 120 OA valve and N/U Integral flanges and block valves on working and companion OA flanges. ***Job 12/7/2016 Complete*** See log. Final WHP's 600/250/0. T/I/O = 610/240/740. Temp = 68°. WHPs (OA down squeeze prep). AL SI @ CV, ALP = 2240 psi. Installed heater in well house and bled treecap to 0 psi. 12/8/2016 SV= C. WV, SSV, MV= 0. IA, OA= OTG. 15:00 T/I/O = 610/240/440 @ front csv, 220 © back csv. Temp = 64°F, AL S/I at csv, ALP = 2250 psi. Starting head temp = 58°. Job Scope: OA down sqz w/HES WeIlLock. Pumped WeIlLock into OA pressure came up to 1800 psi and leveled off for 1 gallon giving indication of squeezing into micro annulus. Continued pumping until 3000 psi reached after 1.25 gallons of WeIlLock pumped. Watched pressure for 30 min then pressured back up to 3500 psi Continued process going as high as 3800 psi. During process monitored opposite side of OA spool looking for communication with no pressure increase during processs. In last three hours of pumping .25 gallons were pumped. Bled OA and cleaned out VR profile area. Rigged up N2 and put as much pressure as the N2 bottles allowed 1800 psi. Watched for one hour with a total loss of 400 psi. Note: Monitor temperature and pressure every 15minutes for 24 hours. At then end of 24 hours, bleed back N2 OA cap pressure to 800 psi. After the first 24 hours, monitor well once every 12 hours for 6 days to ensure casing is above 40?F. Record temperature reading in AWGRS with a description of the sample in wellhouse and physical condition. e.g. liquid, spongy, hard. . 12/9/2016 ***JOB CONTINUED ON 12/10/15 WSR *** • • L1-13 Well History T/I/O = 610/240/440 @ front csv, 220 @ back csv. Temp =64°F, AL S/I at csv, ALP = 2250 psi. Starting head temp = 58°. Job Scope: OA down sqz w/HES WeIlLock. Pumped WeIlLock into OA pressure came up to 1800 psi and leveled off for 1 gallon giving indication of squeezing into micro annulus. Continued pumping until 3000 psi reached after 1.25 gallons of WeIlLock pumped. Watched pressure for 30 min then pressured back up to 3500 psi Continued process going as high as 3800 psi. During process monitored opposite side of OA spool looking for communication with no pressure increase during processs. In last three hours of pumping .25 gallons were pumped. Bled OA and cleaned out VR profile area. Rigged up N2 and put as much pressure as the N2 bottles allowed 1800 psi. Watched for one hour with a total loss of 400 psi. Note: Monitor temperature and pressure every 15minutes for 24 hours. At then end of 24 hours, bleed back N2 OA cap pressure to 800 psi. After the first 24 hours, monitor well once every 12 hours for 6 days to ensure casing is above 40?F. Record temperature reading in AWGRS with a description of the sample in wellhouse and physical condition. e.g. liquid, spongy, hard. . 12/9/2016 ***JOB CONTINUED ON 12/10/15 WSR *** Cont from WSR 12/9/16. Monitor OAP & OA temp (wellock). Monitor OAP & OA temp for 16 hrs, released by WSL. 12/10/2016 SV= C. WV, SSV, MV= O. IA, OA= OTG.16:30 T/I/O = 640/290/3. Temp = 68°. WHPs (post wellock). ALP = 2260 psi, SI @ CV. TP increased 30 psi, IAP & OAP unchanged. Sample of Wellock on wellhead is not set. 12/11/2016 SV= C. WV, SSV, MV= O. IA, OA= OTG. 17:00. T/I/O = 610/290/3. Temp = 68°. WHPs (post wellock). ALP = 2260 psi, SI @ CV. TP decreased 10 psi, IAP & OAP unchanged. 12/11/2016 SV= C. WV, SSV, MV= O. IA, OA= OTG. 04:00 T/I/O = 640/290/3. Temp = 68°. WHPs (post wellock). ALP = 2260 psi, SI @ CV. TP, IAP& OAP unchanged overnight. Sample of Wellock on wellhead is not set. 12/12/2016 SV= C. WV, SSV, MV= O. IA, OA= OTG. 11:00. TREE= CW i WELLHEAD= FMC 1_1 -13 SAFETY NOTES: WELL ANGLE>70°@ 14308''"' ACTUATOR= BAKERCCHROME TBG&LNR"•MAXDLS:14.2°@14434' OKB.ELEV= 60.05' �, , REF H.EV= 60.05' iN BF.ELEV= 15.48' 20"X30" - 127' `; 2201'�_A--14-1/2'HES X NP,D=3.813" KOP= 576' NS COPD, b. os Max Angle= 102°@ 14655' 91.5#,A-53, GAS LFT MANDRELS Datum ND= 14128' D=19.124" ST MD TVD DEV TYPE VLV LATCH PORT DATE Datum ND= 8900' 5 5626 4005 64 MING DONE RK 16 10/16/16 4 9928 6099 45 MC SO RK 20 10/16/16 13-3/8"CSG,68#,L-80 HY 0563/BTC,D=12.415" -i 5212' 3 11662 7241 64 WAG DW BK 0 07/22/16 TOP OF CMT(06/12/16) -7503' 2 12731 7849 38 MMG DMY BK 0 07/22/16 tle Pk 0 1 13471 8441 36 MMC DMY BK 0 07122/16 Minimum ID = 3.813" @ 2201' 4-112" HES X NIPPLE ;, f' 10646' -9-5/8"X7"BKR HRDLTPw/TACKSLV& TOP OF LNR 10646' L ,, BKR FLEXLOCK HGR,ID=6.20" 9-5/8'WFSTOCK(06/23/16) I 10754' 9-5/8"CSG,47#,L-80 VAM TOP,O=8.681" -{ 12199' • lit 14, Jl V ei IC 13712' -14-1/2"HES X HP D=3.813' rIC *4 13740' _.47'X 4-1/2"HES TNT PKR D=3.870" V 1:41i Pi fik 13817'J-14-1/2"HES X NP,D=3.813' co 11 4-112"TBG,12.6#,13CR-85 VAM TOP, 13834' so IS 0152 bpf,D-3.958' 13828' -j7'X 5"BKR EZXP LTPw/TEBACK SLV& tj D BKR FLEXLOCK HGR, =4.30" 7"LNR,26#,L-80 VAM TOP, H 13988' .0383 bpf.D=6.276' tA .,e► 111 13834' -14-1/2"WLEG,D=3.958' I tAlie H ELM)TT NOT LOGGED 216 PERFORATION SUSMARY �1 BUSHING,13862' - 5"X 4 1/2"XO BUSG D=3.91' REF LOG: '='_'_' ANGLE AT TOP PERF:90°@ 16875' .-'_�.-. 4-1/2" FRAC PORT SLEEVES Note:Refer to Production DB for historical perf data RI NO DB'TH SEAT SZ, ACTUAL SEE 0/C DATE SIZE SPF SI T32VAL Opn/Sqz SHOT SLY 12 13978' 3.137" 5.630" 07/20/16 .1111 2" 6 16875-16905 0 i 10/04/16 1.7:41_0:, 11 14089' 3.037" 5.630" 07/20/16 NMI10 14338' 2.947" 5.630' 07/20/16 4-1/2"HES SWELL PACKS •_ 9 14626' 2.857" 5.630" 07/20/16 NO SIZE TOP DEPTH MN ID - 8 14888' 2.767' 5.630" 07/20/16 11 4-1/2" 14033' 3.92" 7 15200' 2.677" 5.630" 07/20/16 10 4-1/2" 14223' 3.92" .a-.' 6 15418' 2.587" 5.630" 07/20/16 9 4-1/2" 14470' 3.92" 11111111 5 15539' 2.497" 5.630" 07/20/16 8 4-1/2" 14755' 3.92" �-� 4 15711' 2.412" 5.630" 07/20/16 7 4-1/2" 15025' 3.92" 7 3 16267 2.332" 5.630" 07/20/16 6 4-1/2" 15244' 3.92" �_ 2 16667 2.252" 5.630" 07/20/16 5 41/2" 15487' 3.92" 1.7. ,ilill0-, 1 16933' 3.75' 5630' 07/20/16 4 4-1/2" 15626' 3.92" IMO , 2 4-1/2" 16498' 3.92" ,-•, 16847' j-J4-112"HYD521 SI-OFT TOOL VERFICATION SUB,D=3.87" 1 4-1/2" 16764' 3.92' PBTD - 16961' I.:4 .-. H �� 16961' -14-1/2"SLB FLOW-THRU CRC VALVE,D=1.220' 4-1/2"LNR, 13.5#,13CR-85 HYD 521, H 16973' VIM _0150 bpf,D=3.92" 16973'j-14-1/2"X 3-112"XO,D=2.992" Mr 3-1/2"LNR,9.2#,L-80 TCµ.0087 bpf,D=2.992" H t 17007' DATE REV BY CONSENTS DATE REV BY CONSENTS PRUDHOE BAY UNIT 07/25/16 P-272 INTIAL COMPLETION 10/12/16 TFA/JND PERF FRAC PORT(10/04/16) WELL: L1-13 07/28/16 JND DRLG HO CORRECTIONS 10/20/16 ZV/JND GLV C/O(10/16/16) PERMIT No: '2160030 08/02/16 BG/JM) FINAL ODE APPROVAL API Pb: 50-029-23563-00 08/22/16 JNUJND UPDATED REF&BF ELEV SEC. 1,T11N, 14E,2542'FSL&2478'FEL 09/20/16 JPK/JND GLV 00(09/14/16) 09/28/16 MN/JM) GLV CJO(09/26/16) BP Exploration(Alaska) • Link, Liz M (DOA) From: Lastufka,Joseph N <Joseph.Lastufka@bp.com> Sent: Monday, December 05, 2016 9:35 AM To: AOGCC Reporting (DOA sponsored) Subject: POP PBU L1-13/PTD#216-003 Hello, Please reference the following well: Well Name: PBU L1-13 Permit#: 216-003 API #: 50-029-23563-00-00 Date of Test: 11/28/16 Type of Test: IPT(Initial Production Test) Choke Size: 176 Choke Unit: Production Method: Flowing Duration (Hours Tested): 6 Top Reference(Top Perf MD): 13978' Bottom Reference(Bottom Perf MD): 16933' Tubing Flowing (Pressure): 1113 Casing Pressure: 255 Total Test Rate (0, G, W): 512/2270/25 24-Hour Rate (0, G, W): 2047/9080/ 100 Gravity(Oil, API): 24.8 GOR(Gas-Oil Ratio): 4436 This well began Production on Method of Operations on this date: November 27, 2016 1 RBDMS - 6 2016 21 6003 .,P.1 .... ‘.0 „ ; , ; 27680 BAKER R` � #3 PRINT DISTRIBUTION LIST HUGHES Please sign and return one copy of this transmittal form to: COMPANY " '.q" ., n Alaska Inc. BP Exploration(Alaska)Inc. Petrotechnical Data Center,LR2-1 DATA LOGGED \\ /'6/201 Ca WELL NAME L1-13 900 E.Benson Blvd. M.K.BENDER Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE GR-RES-DEN-NEU STK:Image Log BHI DISTRICT Alaska --- LOG DATE July 18,2016 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares(a.bakerhughes.com TODAYS DATE November 1,2016 Revision STATUS Final Replacement: No Details: Rev. Requested by: FIELD I CD/DVD FINAL COMPANY PRELIM FINAL SURVEY REPORT LOGS (las,dlis,PDF,META, ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BO* LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #OF 1-1-(IN I S #OF COPIES -#OF COPIES #OF COPIES 4 4 4 4 4 4 1 BP North Slope. 0 1 1 1 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 1 1 0 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 1 1 1 0 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 0 1 1 1 0 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 I 0 1 1 I 0 Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 6 BP Exploration(Alaska)Inc. 0 0 I 0 I 0 I 0 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 TOTALS FOR THIS PAGE: 0 3 5 5 0 TOTALS FOR ALL PAGES: 0 3 5 5 0 21 6003 0 • 27600 4L-Oklift i. bp wq ®3g,§ 4,0) 6kla r North America - ALASKA - BP Lisburne Lis DS 01 L1-13 L1-13 500292356300 Design: L1-13 Final Survey Report 19 July,2016 vu BAKER HUGHES • 0 b BP / ilk pFinal Survey Report BAKER >' W a s; 4 , HUGHES Company: North America-ALASKA-BP - Local Co-ordinate Reference: Well L1-13 Project: Lisburne TVD Reference: L1-13 Plan @ 60.05usft(PARKER 272) Site: Lis DS 01 MD Reference: L1-13 Plan @ 60.05usft(PARKER 272) Well: L1-13 North Reference: True Wellbore: L1-13 Survey Calculation Method: Minimum Curvature Design: L1-13 Database: EDM RSK-Alaska PROD-ANCP1 Project Lisburne,GPB,GPMA Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site -,,i,, Lis DS 01,TR-11-14 Site Position: Northing: 5,970,246.770 usft Latitude: 70°19'25.721 N From: Map Easting: 683,519.170 usft Longitude: 146°30'42.654 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 1.40° Well L1-13 Well Position +NI-S 0.00 usft Northing: 5,974,893.730 usft Latitude: 70°20'10.172 N +EI-W 0.00 usft Easting: 688,600.880 usft Longitude: 148°28'10.962 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 12.90 usft Wellbore L1-13 Magnetics Model Name Sample Date Declination Dip Angle Field Strength ('1 (°I (nT) BGGM2015 5/15/2016 19.13 81.08 57,538 Design L1-13 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 10,730.05 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) 11 47.15 0.00 0.00 232.40 7/192016 3:43.21PM Page 2 COMPASS 5000.1 Build 81B • • b BP MIA 0 p Final Survey Report BAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well L1-13 Project: Lisburne TVD Reference: L1-13 Plan @ 60.05usft(PARKER 272) Site: Lis DS 01 MD Reference: L1-13 Plan @ 60.05usft(PARKER 272) Well: L1-13 North Reference: True Wellbore: L1-13 Survey Calculation Method: Minimum Curvature Design: L1-13 Database: EDM R5K-Alaska PROD-ANCP1 Survey Program Date 7/19/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 96.00 803.00 Gyrodata Gyro SS 16"(L1-13PB1) GYD-GC-SS Gyrodata gyro single shots 898.56 5,159.13 BH OTK MWD+IFR+MS 16"(Li-13PBi) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 5,237.09 10,730.05 BH OTK MWD+IFR+MS 12-1/4"(L1-13PB MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 10,754.00 10,815.42 Inc+Trend 8-1/2"(L1-13) INC+TREND Inclinometer+known azi trend 10,847.92 13,953.22 BHI OTK MWD+IFR+MS 8-1/2"(L1-13) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 14,022.61 17,182.04 BHI ATK MWD+IFR+MS 6-1/8"(L1-13) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal Survey MD Inc Azi(azimuth) TVD TVDSS NIS EMI Northing Easting DLeg V.Sec (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°Il00usft) (usft) 47.15 0.00 0.00 47.15 -12.90 0.00 0.00 5,974,893.730 688,600.880 0.00 0.00 96.00 0.14 309.99 96.00 35.95 0.04 -0.05 5,974,893.767 688,600.833 0.29 0.01 127.00 0.05 123.91 127.00 66.95 0.06 -0.06 5,974,893.784 688,600.815 0.61 0.02 187.00 0.18 291.67 187.00 126.95 0.08 -0.13 5,974,893.802 688,600.749 0.38 0.06 280.00 0.13 "Wily 3.80 280.00 219.95 0.19 -0.18 5,974,893.917 ::688,600.695 0.29 0.03 373.00 0.22 3 1 .31 373.00 312.95 0.12 0.03 5,974,893.853 688,600.903 0.26 -0.10 428.00 0.17 se •0.30 Horsy 428.00 367.95 -0.04 0.08 5,974,893.697 688,600.964 0.33 -0.04 484.00 0.31 184.30 484.00 423.95 -0.27 0.06 5,974,893.464 688,600.944 0.25 0.12 576.00 1.23 227.12 575.99 515.94 -1.19 -0.69 5,974,892.525 688,600.225 1.11 1.27 617.00 1.89 234.28 616.97 556.92 -1.88 -1.56 5,974,891.809 688,599.371 1.68 2.38 709.00 3.32 237.45 708.88 648.83 -4.20 -5.03 5,974,889.403 688,595.953 1.56 6.55 803.00 4.16 238.83 802.68 742.63 -7.43 -10.25 5,974,886.044 688,590.825 0.90 12.65 898.56 5.91 249.99 897.87 837.82 -10.91 -17.83 5,974,882.377 688,583.326 2.09 20.79 993.40 6.74 253.06 992.13 932.08 -14.20 -27.75 5,974,878.837 688,573.501 0.94 30.65 1,087.96 6.59 254.71 1,086.05 1,026.00 -17.25 -38.29 5,974,875.525 688,563.039 0.26 40.86 1,183.13 7.46 256.43 1,180.50 1,120.45 -20.14 -49.56 5,974,872.353 688,551.842 0.94 51.56 1,277.67 8.54 253.88 1,274.12 1,214.07 -23.53 -62.27 5,974,868.645 688,539.222 1.20 63.69 1,372.06 12.23 249.88 1,366.95 1,306.90 -28.91 -78.40 5,974,862.855 688,523.238 3.98 79.76 7/19/2086 3;43:21PM Page 3 COMPASS 5000.1 Build 81B • • • p BP SFinal Survey Report BAMI KERER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well L1-13 Project: Lisburne TVD Reference: L1-13 Plan©60.05usft(PARKER 272) Site: Lis DS 01 MD Reference: L1-13 Plan @ 60.05usft(PARKER 272) Well: L1-13 North Reference: True Wellbore: L1-13 Survey Calculation Method: Minimum Curvature Design: L1-13 Database: EDM R5K-Alaska PROD-ANCP1 Survey MD Inc Azi(azimuth) TVD TVDSS NIS EIW Northing Easting DLeg V.Sec (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usr) 0100usft) (usft) 1,465.66 13.16 250.46 1,458.26 1,398.21 -35.89 -97.75 5,974,855.397 688,504.070 1.00 99.34 1,559.44 14.93 249.74 1,549.24 1,489.19 -43.64 -119.15 5,974,847.107 688,482.877 1.90 121.03 1 1,655.67 16.05 251.17 1,641.97 1,581.92 -52.23 -143.37 5,974,837.915 688,458.881 1.23 145.46 1,751.62 15.32 251.47 1,734.35 1,674.30 -60.54 -167.94 5,974,828.991 688,434.527 0.77 169.99 1,845.52 15.76 253.04 1,824.81 1,764.76 -68.20 -191.90 5,974,820.729 688,410.769 0.65 193.65 1,941.19 16.27 253.96 1,916.77 1,856.72 -75.69 -217.21 5,974,812.602 688,385.660 0.60 218.27 2,034.13 18.15 254.34 2,005.54 1,945.49 -83.20 -243.66 5,974,804.434 688,359.405 2.03 243.81 2,129.65 19.08 254.75 2,096.07 2,036.02 -91.32 -273.05 5,974,795.576 688,330.232 0.98 272.05 2,225.55 20.42 253.12 2,186.32 2,126.27 -100.30 -304.18 5,974,785.815 688,299.337 1.51 302.20 2,257.45 21.76 252.59 2,216.09 2,156.04 -103.69 -315.15 5,974,782.155 688,288.458 4.24 312.95 2,289.09 23.58 251.34 2,245.28 2,185.23 -107.47 -326.74 5,974,778.085 688,276.965 5.95 324.44 2,319.78 25.61 251.25 2,273.18 2,213.13 -111.56 -338.84 5,974,773.686 688,264.974 6.62 336.53 2,415.30 27.64 Tr‘rooR0.69 �51RA o/2,358.57 2,298.52 -125.53 .T.,5,59:479.30 5,974,758.710 688,224.878 2.14 377.11 2,508.87 29.95 D.71 1032,440.57 2,380.52 -140.42 -421.84 5974742.751 688,182.734 2.47 419.90 2,605.07 34.53 42.58 7 2521.91 2461.86 -156.53 4n,-470.54 5,974,725.428 688,134.450 4.87 468.31 filn2,699.62 38.60 X253.56 "' 2,597.84 2,537.79 -172.90 ,-524.42 5,974,707.702 688,081.003 4.35 520.99 2,794.94 42.93 253.75 2,670.02 2,609.97 -190.41 -584.13 5,974,688.700 688,021.754 4.54 578.98 2,887.67 47.32 252.74 2,735.43 2,675.38 -209.37 -647.03 5,974,668.166 687,959.355 4.80 640.39 2,921.19 49.26 252.04 2,757.73 2,697.68 -216.94 -670.88 5,974,659.997 687,935.705 5.99 663.90 2,954.51 50.09 251.93 2,779.29 2,719.24 -224.80 -695.04 5,974,651.536 687,911.755 2.50 687.83 2,984.17 52.61 252.28 2,797.82 2,737.77 -231.92 -717.08 5,974,643.868 687,889.900 8.55 709.64 3,078.45 56.42 252.68 2,852.53 2,792.48 -255.02 -790.28 5,974,618.936 687,817.313 4.06 781.73 3,173.47 59.80 253.58 2,902.73 2,842.68 -278.41 -867.47 5,974,593.606 687,740.733 3.65 857.16 3,268.40 63.18 253.37 2,948.03 2,887.98 -302.14 -947.43 5,974,567.878 687,661.400 3.57 934.99 3,362.45 63.15 253.58 2,990.49 2,930.44 -326.01 -1,027.89 5,974,541.993 687,581.575 0.20 1,013.30 3,457.19 63.72 252.99 3,032.86 2,972.81 -350.38 -1,109.05 5,974,515.589 687,501.062 0.82 1,092.47 3,551.70 63.68 252.46 3,074.73 3,014.68 -375.54 -1,189.95 5,974,488.404 687,420.820 0.50 1,171.92 7/19/2016 3:43:21PM Page 4 COMPASS 5000.1 Build 818 • s b BP IER pFinal Survey Report BAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well L1-13 Project: Lisburne ND Reference: L1-13 Plan @ 60.05usft(PARKER 272) Site: Lis DS 01 MD Reference: L1-13 Plan @ 60.05usft(PARKER 272) Well: L1-13 North Reference: True Wellbore: Lt-13 Survey Calculation Method: Minimum Curvature Design: L1-13 Database: EDM R5K-Alaska PROD-ANCP1 Survey MD Inc Azi(azimuth) ND TVDSS NIS EJW Northing Easting DLeg V.Sec (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°1100usft) (usft) 3,646.20 63.75 250.16 3,116.58 3,056.53 -402.69 -1,270.20 5,974,459.247 687,341.280 2.18 1,252.07 3,741.12 62.97 249.68 3,159.14 3,099.09 -431.82 -1,349.89 5,974,428.126 687,262.357 0.94 1,332.98 3,835.81 63.18 249.00 3,202.02 3,141.97 -461.61 -1,428.89 5,974,396.363 687,184.140 0.68 1,413.74 3,931.04 65.30 247.53 3,243.41 3,183.36 -493.37 -1,508.54 5,974,362.605 687,105.311 2.62 1,496.23 4,026.07 66.62 247.08 3,282.12 3,222.07 -526.86 -1,588.61 5,974,327.119 687,026.119 1.45 1,580.10 4,120.45 66.30 246.48 3,319.82 3,259.77 -560.97 -1,668.12 5,974,291.019 686,947.490 0.67 1,663.91 4,215.37 65.64 245.95 3,358.47 3,298.42 -595.93 -1,747.45 5,974,254.074 686,869.069 0.86 1,748.10 4,310.14 63.21 246.08 3,399.38 3,339.33 -630.68 -1,825.55 5,974,217.376 686,791.875 2.57 1,831.17 4,405.11 61.98 249.25 3,443.10 3,383.05 -662.73 -1,903.52 5,974,183.381 686,714.745 3.23 1,912.50 4,499.70 64.54 251.86 3,485.66 3,425.61 -690.82 -1,983.16 5,974,153.293 686,635.834 3.66 1,992.74 4,594.62 65.29 252.19 3,525.90 3,465.85 -717.35 -2,064.93 5,974,124.718 686,554.761 0.85 2,073.72 4,689.32 66.30 251.93 3,564.73 3,504.68 -743.96 -2,147.11 5,974,096.056 686,473.288 1.10 2,155.05 4,784.69 66.24 252.27 3,603.11 3,543.06 -770.79 -2,230.19 5,974,067.143 686,390.913 0.33 2,237.25 4,879.48 65.92 y 254.00 3,641.54 3,581.49 -795.93 -2,313.11 5,974,039.929 686,308.660 1.70 2,318.28 4,910.83 65.04 254.14 3,654.56 3,594.51 -803.76 -2,340.53 5,974,031.413 686,281.440 2.84 2,344.79 4,943.08 62.92 254.59 3,668.70 3,608.65 -811.57 -2,368.44 5,974,022.903 686,253.740 6.69 2,371.67 4,973.83 61.23 254.59 3,683.10 3,623.05 -818.79 -2,394.63 5,974,015.028 686,227.739 5.50 2,396.82 5,069.21 58.95 254.25 3,730.66 3,670.61 -840.99 -2,474.27 5,973,990.832 686,148.694 2.41 2,473.46 5,159.13 57.60 254.17 3,777.94 3,717.89 -861.80 -2,547.86 5,973,968.178 686,075.648 1.50 2,544.47 5,237.09 57.18 254.22 3,819.96 3,759.91 -879.69 -2,611.05 5,973,948.709 686,012.934 0.54 2,605.45 5,331.93 59.24 254.37 3,869.92 3,809.87 -901.51 -2,688.65 5,973,924.948 685,935.913 2.18 2,680.24 5,426.99 61.92 254.06 3,916.61 3,856.56 -924.03 -2,768.32 5,973,900.428 685,856.839 2.83 2,757.10 5,521.72 63.98 253.57 3,959.68 3,899.63 -947.55 -2,849.34 5,973,874.881 685,776.443 2.22 2,835.64 5,615.91 64.40 253.05 4,000.69 3,940.64 -971.90 -2,930.56 5,973,848.495 685,695.865 0.67 2,914.85 5,711.26 64.44 253.01 4,041.86 3,981.81 -997.01 -3,012.82 5,973,821.333 685,614.268 0.06 2,995.34 5,805.99 64.35 252.58 4,082.80 4,022.75 -1,022.27 -3,094.42 5,973,794.022 685,533.329 0.42 3,075.41 5,900.89 64.36 251.82 4,123.87 4,063.82 -1,048.43 -3,175.88 5,973,765.831 685,452.562 0.72 3,155.91 7/19/2016 3:43:21PM Page 5 COMPASS 5000.1 Build 81B • • 0b BP / PI Final Survey Report BAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well L1-13 Project: Lisbume ND Reference: L1-13 Plan @ 60.05usft(PARKER 272) Site: Lis DS 01 MD Reference: L1-13 Plan @ 60.05usft(PARKER 272) Well: L1-13 North Reference: True Wellbore: L1-13 Survey Calculation Method: Minimum Curvature Design: L1-13 Database: EDM R5K-Alaska PROD-ANCP1 Survey MD Inc Azi(azimuth) ND TVDSS N/S 61W Northing Easting DLeg V.Sec (usft) (°) (°) (usft) (usft) (use) (usft) (usft) (usft) (°/100usft) (usft) 5,995.28 64.48 251.83 4,164.63 4,104.58 -1,074.98 -3,256.77 5,973,737.251 685,372.370 0.13 3,236.20 6,090.37 64.37 251.37 4,205.68 4,145.63 -1,102.06 -3,338.16 5,973,708.140 685,291.694 0.45 3,317.20 6,184.87 64.34 250.94 4,246.58 4,186.53 -1,129.57 -3,418.78 5,973,678.605 685,211.792 0.41 3,397.87 6,279.79 64.41 251.08 4,287.63 4,227.58 -1,157.42 -3,499.71 5,973,648.731 685,131.596 0.15 3,478.98 6,373.21 64.22 250.45 4,328.12 4,268.07 -1,185.16 -3,579.19 5,973,619.008 685,052.835 0.64 3,558.88 6,468.63 64.46 250.42 4,369.44 4,309.39 -1,213.96 -3,660.24 5,973,588.178 684,972.546 0.25 3,640.66 6,563.35 64.39 250.21 4,410.33 4,350.28 -1,242.74 -3,740.68 5,973,557.386 684,892.854 0.21 3,721.96 6,658.52 64.39 249.99 4,451.47 4,391.42 -1,271.95 -3,821.38 5,973,526.156 684,812.923 0.21 3,803.72 • 6,752.24 64.42 250.16 4,491.95 4,431.90 -1,300.76 -3,900.84 5,973,495.364 684,734.214 0.17 3,884.25 6,846.59 64.42 250.20 4,532.69 4,472.64 -1,329.61 -3,980.90 5,973,464.506 684,654.909 0.04 3,965.29 6,941.99 64.32 249.70 4,573.96 4,513.91 -1,359.10 -4,061.70 5,973,432.997 684,574.881 0.48 4,047.30 7,035.61 64.35 249.73 4,614.51 4,554.46 -1,388.36 -4,140.85 5,973,401.762 684,496.496 0.04 4,127.85 7,131.56 64.40 25012 } 44.656.00 4,595.95 1,418.05 -4222.11 5,973,370.035 684,416.017 0.37 4,210.35 7,225.42 64.40 08 x„., x,+4 4,696.56 4,636.51 -1,446.86 ,301.70 5,973,339.232 684,337.180 0.04 4,290.99 7,319.98 64.38 J 049 4,737.43 4,677.38 -1,475.63 ,381.97 5,973,306.459 684,257.662 0.39 4,372.14 7,414.89 64.47 ''''''''"4151.38 °`"4,778.40 4,718.35 1,503.59 4,462.89 5,973,278.471 684,177.481 0.85 4,453.31 7,509.73 64.38 251.75 4,819.34 4,759.29 -1,530.64 -4,544.05 5,973,249.388 684,097.035 0.36 4,534.12 7,604.22 64.27 251.90 4,860.28 4,800.23 -1,557.21 -4,624.96 5,973,220.800 684,016.822 0.18 4,614.43 7,698.73 63.17 251.77 4,902.13 4,842.08 -1,583.62 -4,705.47 5,973,192.367 683,936.999 1.17 4,694.34 7,794.26 61.65 251.70 4,946.37 4,886.32 -1,610.16 -4,785.87 5,973,163.821 683,857.298 1.59 4,774.23 7,889.43 61.68 252.03 4,991.54 4,931.49 -1,636.23 -4,865.48 5,973,135.756 683,778.377 0.31 4,853.21 7,984.37 61.23 251.94 5,036.91 4,976.86 -1,662.02 -4,944.79 5,973,107.978 683,699.745 0.48 4,931.78 8,079.07 61.18 252.69 5,082.52 5,022.47 -1,687.24 -5,023.86 5,973,080.789 683,621.342 0.70 5,009.81 8,173.82 61.32 253.32 5,128.10 5,068.05 -1,711.52 -5,103.30 5,973,054.520 683,542.540 0.60 5,087.56 8,268.58 61.34 253.27 5,173.56 5,113.51 -1,735.41 -5,182.93 5,973,028.628 683,463.538 0.05 5,165.24 8,363.26 61.47 253.74 5,218.88 5,158.83 -1,759.02 -5,262.64 5,973,003.029 683,384.452 0.46 5,242.79 8,456.39 61.43 254.03 5,263.38 5,203.33 -1,781.72 -5,341.23 5,972,978.354 683,306.461 0.28 5,318.91 7/19/2016 3:43:21PM Page 6 COMPASS 5000.1 Build 81B • 0 0 b BP ®/,.11 pFinal Survey Report BAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well L1-13 Project: Lisburne ND Reference: L1-13 Plan @ 60.05usft(PARKER 272) Site: Lis DS 01 MD Reference: L1-13 Plan @ 60.05usft(PARKER 272) Well: L1-13 North Reference: True Wellbore: L1-13 Survey Calculation Method: Minimum Curvature Design: Ll-13 Database: EDM R5K-Alaska PROD-ANCP1 Survey MD Inc Azi(azimuth) TVD TVDSS NIS EIW Northing Easting DLeg V.Sec (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°I100usft) (usft) 8,551.51 61.44 253.69 5,308.87 5,248.82 -1,804.95 -5,421.48 5,972,953.122 683,226.827 0.31 5,396.66 8,646.43 61.45 253.91 5,354.24 5,294.19 -1,828.21 -5,501.55 5,972,927.857 683,147.379 0.20 5,474.29 8,740.30 61.43 253,32 5,399.12 5,339.07 -1,851.47 -5,580.64 5,972,902.619 683,068.894 0.55 5,551.15 8,836.31 61.19 251.92 5,445.21 5,385.16 -1,876.62 -5,661.02 5,972,875.451 682,989.182 1.30 5,630.18 8,930.80 59.43 250.64 5,492.01 5,431.96 -1,902.96 -5,738.76 5,972,847.170 682,912.134 2.20 5,707.84 9,025.95 57.41 249.71 5,541.84 5,481.79 -1,930.44 -5,815.01 5,972,817.781 682,836.602 2.28 5,785.02 9,120.51 56.66 248.03 5,593.29 5,533.24 -1,959.03 -5,889.01 5,972,787.337 682,763.349 1.69 5,861.10 9,215.50 56.62 246.75 5,645.53 5,585.48 -1,989.53 -5,962.25 5,972,755.006 682,690.905 1.13 5,937.73 9,311.63 54.67 245.73 5,699.78 5,639.73 -2,021.50 -6,034.88 5,972,721.226 682,619.104 2.21 6,014.78 9,406.19 52.49 244.36 5,755.91 5,695.86 -2,053.59 -6,103.87 5,972,687.415 682,550.951 2.58 6,089.02 9,500.80 50.69 244.05 5,814.69 5,754.64 -2,085.84 -6,170.61 5,972,653.492 682,485.041 1.92 6,161.58 9,594.85 49.57 243.28 5,874.98 5,814.93 -2,117.86 -6,235.30 5,972,619.860 682,421.179 1.35 6,232.37 9,689.53 49.37 242.93 5,936.51 5,876.46 -2,150.41 5.,:--6.299.48 5,972,585.706 682,357.843 0.35 6,303.08 9,784.62 47.39 242.39 5.999.66 5,939.61 -2,183.05 -6,362.63 5,972,551 489 682,295.543 2.13 6,373.02 9,879.26 45.97 241.44 6.064.59 6,004.54 -2,215.46 -6,423.37 5,972.517.566 682,235.634 1.67 6,440.93 9,973.64 44.46 - 241.07 6,131.08 6,071.03 ""-2,247.67 -6,482.11 5,972,483.890 682,177.735 1.62 6,507.11 10,068.29 42.62 239.70 6,199.69 6,139.64 -2,279.88 -6,538.79 5,972,450.270 682,121.882 2.18 6,571.67 10,163.46 41.07 238.66 6,270.58 6,210.53 -2,312.40 -6,593.32 5,972,416.392 682,068.195 1.78 6,634.71 10,258.06 39.90 236.50 6,342.54 6,282.49 -2,345.31 -6,645.16 5,972,382.189 682,017.196 1.93 6,695.87 10,352.04 39.89 234.86 6,414.64 6,354.59 -2,379.29 -6,694.94 5,972,346.968 681,968.290 1.12 6,756.05 10,446.97 39.69 232.69 6,487.59 6,427.54 -2,415.19 -6,743.95 5,972,309.853 681,920.207 1.48 6,816.77 10,541.48 37.78 229.50 6,561.31 6,501.26 -2,452.29 -6,789.97 5,972,271.609 681,875.131 2.92 6,875.88 10,635.74 35.46 224.54 6,636.98 6,576.93 -2,490.54 -6,831.12 5,972,232.335 681,834.961 3.99 6,931.82 10,730.05 33.29 219.64 6,714.83 6,654.78 -2,529.98 -6,866.83 5,972,192.010 681,800.255 3.73 6,984.18 TIP 10,754.00 32.93 218.20 6,734.89 6,674.84 -2,540.16 -6,875.05 5,972,181.629 681,792.295 3.61 6,996.90 Top of WS 7/192016 3:43:21PM Page 7 COMPASS 5000.1 Build 818 • • 0 b BP IER p Final Survey Report BAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well L1-13 Project: Lisburne ND Reference: L1-13 Plan @ 60.05usft(PARKER 272) Site: Lis DS 01 MD Reference: L1-13 Plan @ 60.05usft(PARKER 272) Well: L1-13 North Reference: True Wellbore: L1-13 Survey Calculation Method: Minimum Curvature Design: L1-13 Database: EDM R5K-Alaska PROD-ANCP1 Survey MD Inc Azi(azimuth) TVD TVDSS NIS EIV Northing Easting DLeg V.Sec (usft) (°) (°) (ustt) (usft) (usft) (usft) (usft) (usft) ('Il00usft) (usft) 10.771.08 32.94 219.16 6,749.23 6,689.18 -2.547.41 -6,880.85 5,972,174.237 681,786.676 3.06 7,005.92 Bottom of WS 10,815.42 36.16 221.37 6.785.74 6,725.69 -2,566.58 -6,897.12 5,972,154.665 681,770.901 7.79 7,030.50 Interpolated Azimuth 10,847.92 39.83 222.79 6,811.35 6,751.30 -2,581.42 -6,910.53 5,972,139.495 681,757.867 11.61 7,050.18 10,882.34 42.44 224.75 6,837.27 6,777.22 -2,597.76 -6,926.20 5,972,122.766 681,742.616 8.46 7,072.56 10,909.23 43.44 225.11 6,856.96 6,796.91 -2,610.73 -6,939.13 5,972,109.477 681,730.010 3.83 7,090.73 10,942.52 44.69 225.25 6,880.88 6,820.83 -2,627.05 -6,955.56 5,972,092.751 681,714.004 3.77 7,113.70 10,974.01 45.94 226.66 6,903.02 6,842.97 -2,642.61 -6,971.65 5,972,076.790 681,698.307 5.09 7,135.94 11,004.39 47.60 226.69 6,923.83 6,863.78 -2,657.80 -6,987.75 5,972,061.204 681,682.593 5.46 7,157.97 11,037.48 50.16 226.11 6,945.59 6,885.54 -2,674.99 -7,005.80 5,972,043.566 681,664.984 7.85 7,182.75 11,068.42 52.60 226.52 6,964.90 6,904.85 -2,691.68 -7,023.28 5,972,026.438 681,647.929 7.95 7,206.79 11,099.33 54.30 227.18 6,983.31 6,923.26 -2,708.66 -7,041.40 5,972,009.009 681,630.247 5.76 7,231.50 11,132.62 56.29 15 6.72 0 7,00226 6,942.21 -2.726.99 7,061 72 I 5,971,990.179 681,610.393 7.08 7,258.79 11,164.45 58.40 ' '.56 z '701944 6,959.39 -2,744.34 17082.14 g 5,971,972.324 681,590.415 8.22 7,285.55 11,194.61 60.35 ... .. x231.59 -n 77,034.80 6,974.75 -2,760.64 7,102.33 u 5,971,955.519 681,570.642 7.10 7,311.50 11,226.42 62.22 232.64 7,050.08 6,990.03 -2,777.77 -7,124.35 5,971,937.843 681,549.063 6.55 7,339.39 11,258.08 63.88 233.78 7,064.43 7,004.38 -2,794.67 -7,146.95 5,971,920.382 681,526.895 6.15 7,367.61 11,289.62 64.39 234.62 7,078.19 7,018.14 -2,811.27 -7,169.97 5,971,903.208 681,504.303 2.89 7,395.97 11,384.60 64.20 234.72 7,119.39 7,059.34 -2,860.76 -7,239.79 5,971,851.981 681,435.754 0.22 7,481.49 11,477.18 63.82 234.87 7,159.96 7,099.91 -2,908.73 -7,307.79 5,971,802.314 681,368.990 0.44 7,564.63 11,576.03 63.79 235.25 7,203.59 7,143.54 -2,959.53 -7,380.50 5,971,749.706 681,297.585 0.35 7,653.23 11,672.43 63.85 235.79 7,246.12 7,186.07 -3,008.51 -7,451.81 5,971,698.956 681,227.531 0.51 7,739.62 11,767.16 63.95 236.81 7,287.80 7,227.75 -3,055.71 -7,522.58 5,971,649.994 681,157.971 0.97 7,824.49 11,862.52 63.85 236.61 7,329.75 7,269.70 -3,102.71 -7,594.16 5,971,601.208 681,087.597 0.22 7,909.88 11,956.46 63.92 237.23 7,371.10 7,311.05 -3,148.75 -7,664.84 5,971,553.410 681,018.104 0.60 7,993.97 12,052.01 63.88 236.82 7,413.14 7,353.09 -3,195.45 -7,736.83 5,971,504.915 -680,947.322 0.39 8,079.50 7/19/2016 3:43:21 PM Page 8 COMPASS 5000.1 Build 815 • i C.) b BP IER P Final Survey Report BAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well L1-13 Project: Lisburne TVD Reference: L1-13 Plan @ 60.O5usft(PARKER 272) Site: Lis DS 01 MD Reference: L1-13 Plan @ 60.05usk(PARKER 272) Well: L1-13 North Reference: True Wellbore: L1-13 Survey Calculation Method: Minimum Curvature Design: L1-13 Database: EDM R5K-Alaska PROD-ANCP1 Survey MD Inc Azi(azimuth) TVD TVDSS WS EIW Northing Easting DLeg V.Sec (usft) (°) O (usft) (usft) (usft) (usft) (usft) (usft) (°I100usft) (usft) 12,084.82 62.77 236.66 7.427.87 7,367.82 -3,211.53 -7,761.34 5,971,488226 680,923.220 3.41 8,108.73 12,118.44 60.80 235.36 7,443.76 7,383.71 -3,228.09 -7,785.90 5,971,471.056 680,899.083 6.78 8,138.29 12,146.09 59.28 234.98 7,457.57 7,397.52 -3,241.77 -7,805.57 5,971,456.886 680,879.771 5.62 8,162.22 12,178.31 57.19 233.88 7,474.53 7,414.48 -3,257.70 -7,827.85 5,971,440.400 680,857.898 7.11 8,189.59 12,211.05 55.44 233.12 7,492.69 7,432.64 -3,273.90 -7,849.75 5,971,423.653 680,836.414 5.68 8,216.83 12,240.69 54.06 232.51 7,509.80 7,449.75 -3,288.53 -7,869.03 5,971,408.546 680,817.505 4.95 8,241.03 12,335.26 51.55 231.49 7,566.96 7,506.91 -3,334.90 -7,928.40 5,971,360.704 680,759.329 2.79 8,316.36 12,431.01 48.72 229.53 7,628.33 7,568.28 -3,381.60 -7,985.12 5,971,312.587 680,703.802 3.35 8,389.80 12,526.08 44.79 226.76 7,693.46 7,633.41 -3,427.75 -8,036.72 5,971,265.156 680,653.384 4.65 8,458.84 12,620.68 40.76 223.56 7,762.89 7,702.84 -3,472.99 -8,082.30 5,971,218.796 680,608.958 4.84 8,522.55 12,714.62 37.83 218.61 7,835.60 7,775.55 -3,517.74 -8,121.43 5,971,173.075 680,570.971 4.57 8,580.85 12,809.24 37.88 213.51 7,910.33 7,850.28 -3,564.65 -8,155.58 5,971,125.328 680,538.011 3.31 8,636.53 12,905.04 36.95 209.60 7.986.43 7,926.38 -3.614.21 -8,186.04 5,971,075 014 hp1S410X8.804 2.66 8,690.91 12,999.63 36.72 209.48 8,062.14 8,002.09 -3,663.55 -8,214.00 5,971,024.993 "'6.680,482.097 0.25 8,743.17 13,094.34 36.39 208.65 8,138.22 8,078.17 -3,712.85 -8,241.41 5,970,975,019 680,455.942 0.63 8,794.96 13,189.03 36.68 207.20 8,214.30 8,154.25 -3,762,66 -8,267.80 5,970,924.569 680,430.810 0.96 8,846.26 13,282.96 36.78 206.18 8,289.58 8,229.53 -3,812.84 -8,293.03 5,970,873.766 680,406.851 0.66 8,896.87 13,376.76 36.03 205.25 8,365.08 8,305.03 -3,863.00 -8,317.19 5,970,823.024 680,383.964 0.99 8,946.61 13,465.12 35.97 204.74 8,436.56 8,376.51 -3,910.07 -8,339.13 5,970,775.418 680,363.211 0.35 8,992.72 13,564.75 36.01 204.83 8,517.18 8,457.13 -3,963.22 -8,363.68 5,970,721.667 680,340.013 0.07 9,044.60 13,661.75 36.36 204.87 8,595.47 8,535.42 -4,015.19 -8,387.74 5,970,669.115 680,317.262 0.36 9,095.37 13,755.67 36.32 204.84 8,671.12 8,611.07 -4,065.69 -8,411.14 5,970,618.046 680,295.148 0.05 9,144.72 13,851.88 36.32 205.28 8,748.64 8,688.59 -4,117.31 -8,435.27 5,970,565.839 680,272.318 0.27 9,195.34 13,946.24 36.21 206.84 8,824.72 8,764.67 -4,167.45 -8,459.79 5,970,515.103 680,249.070 0.98 9,245.35 13,953.22 36.15 206.92 8,830.36 8,770.31 -4,171.12 -8,461.66 5,970,511.382 680,247.301 1.09 9,249.07 14,022.61 38.90 206.16 8,885.38 8,825.33 -4,208.93 -8,480.53 5,970,473.110 680,229.383 4.02 9,287.10 14,055.20 42.58 207.89 8,910.07 8,850.02 -4,227.87 -8,490.20 5,970,453.937 680,220.191 11.81 9,306.31 7/19/2016 3:43:21PM Page 9 COMPASS 5000.1 Build 81B • ilk BP riri za..,) by Final Survey Report BAKER 0. HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well L1-13 Project: Lisburne TVD Reference: L1-13 Plan @ 60.05usft(PARKER 272) Site: Lis DS 01 MD Reference: L1-13 Plan @ 60.05usft(PARKER 272) Well: L1-13 North Reference: True Wellbore: L1-13 Survey Calculation Method: Minimum Curvature Design: L1-13 Database: EDM R5K-Alaska PROD-ANCP1 Survey MD Inc Azi(azimuth) ND NDSS NIS E/W Northing Easting DLeg V.Sec (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°/100usft) (usft) 14.086.52 46.64 206.02 8,932.37 8,872.32 -4,247.48 -8,500.16 5,970,434.088 680,210.732 13.62 9,326.16 14,118.00 49.52 205.59 8,953.39 8,893.34 -4,268.56 -8,510.35 5,970,412.754 680,201.072 9.20 9,347.11 14,149.37 53.33 207.64 8,972.95 8,912.90 -4,290.48 -8,521.35 5,970,390.571 680,190.633 13.18 9,369.19 14,181.41 57.42 205.33 8,991.16 8,931.11 -4,314.07 -8,533.09 5,970,366.688 680,179.488 14.08 9,392.89 14,213.55 61.68 205.59 9,007.44 8,947.39 -4,339.08 -8,545.00 5,970,341.388 680,168.213 13.27 9,417.58 14,245.28 64.78 203.82 9,021.73 8,961.68 -4,364.82 -8,556.83 5,970,315.366 680,157.032 10.97 9,442.66 14,275.97 67.49 203.69 9,034.15 8,974.10 -4,390.50 -8,568.14 5,970,289.405 680,146.377 8.84 9,467.29 14,307.55 70.79 203.48 9,045.39 8,985.34 -4,417.55 -8,579.94 5,970,262.077 680,135.257 10.47 9,493.14 14,339.36 74.11 203.19 9,054.98 8,994.93 -4,445.39 -8,591.95 5,970,233.940 680,123.950 10.47 9,519.65 14,370.48 77.78 203.18 9,062.54 9,002.49 -4,473.14 -8,603.83 5,970,205.906 680,112.769 11.79 9,545.99 14,402.48 81.66 202.00 9,068.25 9,008.20 -4,502.20 -8,615.93 5,970,176.548 680,101.414 12.66 9,573.30 14,433.95 86.11 201.72 9,071.60 9,011.55 -4,531.23 -8,627.57 5,970,147.232 680,090.501 14.17 9,600.25 14,464.11 90.29 201.48 9,072.55 9,012.50 -4.559.26 -8,638.67 5,970,118.942 680,080.115 13.88 9,626.14 z:. ;»:i 14,497.41 94.96 202.13 9,071.i 071. 9,010.97 -4,590.13 .8,651.02 5,970,087.766 680,068.544 14.16 9,654.76 9kl'a> 14,528.87 98.37 202.75 9 067 9,007.32 4,619.01 '4,662.95 5,970,058.600 680,057.350 11.01 9,681,83 14,559.87 101.86 201.92 '°'"'9,061. 9,001.88 -4,647.23 -8,674.54 5,970,030.095 680,046.467 11.56 9,708.24 14,591.94 102.21 201.89 9,055.24 8,995.19 -4,676.33 -8,686.24 5,970,000.711 680,035.502 1.10 9,735.26 14,654.59 102.41 200.64 9,041.88 8,981.83 -4,733.38 -8,708.44 5,969,943.134 680,014.745 1.98 9,787.66 14,748.87 102.28 198.32 9,021.72 8,961.67 -4,820.20 -8,739.15 5,969,855.573 679,986.230 2.41 9,864.96 14,782.02 102.28 195.32 9,014.67 8,954.62 -4,851.20 -8,748.53 5,969,824.347 679,977.641 8.84 9,891.30 14,813.74 102.38 194.40 9,007.90 8,947.85 -4,881.15 -8,756.47 5,969,794.207 679,970.450 2.85 9,915.87 14,845.07 102.34 193.03 9,001.19 8,941.14 -4,910.88 -8,763.73 5,969,764.305 679,963.945 4.27 9,939.76 14,876.84 102.28 192.77 8,994.42 8,934.37 -4,941.14 -8,770.66 5,969,733.886 679,957.779 0.82 9,963.71 14,940.18 102.41 192.69 8,980.87 8,920.82 -5,001.49 -8,784.29 5,969,673.211 679,945.667 0.24 10,011.34 15,034.48 102.25 196.46 8,960.73 8,900.68 -5,090.63 -8,807.47 5,969,583.519 679,924.738 3.91 10,084.09 15,128.11 102.34 196.27 8,940.79 8,880.74 -5,178.41 -8,833.25 5,969,495.128 679,901.179 0.22 10,158.07 15,223.96 102.32 198.13 8,920.32 8,860.27 -5,267.86 -8,860.94 5,969,405.018 679,875.751 1.90 10,234.59 7/19/2016 3:43:21PM Page 10 COMPASS 5000.1 Build 818 • • 0 b BP /ER p Final Survey Report BAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well L1-13 Project: Lisburne TVD Reference: L1-13 Plan @ 60.05usft(PARKER 272) Site: Lis DS 01 MD Reference: L1-13 Plan @ 60.05usft(PARKER 272) Well: L1-13 North Reference: True Wellbore: L1-13 Survey Calculation Method: Minimum Curvature Design: L1-13 Database: EDM R5K-Alaska PROD-ANCP1 [Survey MD Inc Azi(azimuth) TVD TVDSS NIS EIW Northing Easting DLeg V.Sec (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°I100usft) (usft) 15.318.18 102.28 197.08 8,900.25 8,840.20 -5,355.60 -8,888.78 5,969,316.607 679,850.125 1.09 10,310.18 15,382.41 102.25 196.24 8,886.61 8,826.56 -5,415.73 -8,906.77 5,969,256.048 679,833.650 1.28 10,361.13 15,412.73 102.25 195.92 8,880.17 8,820.12 -5,444.20 -8,914.98 5,969,227.382 679,826.163 1.03 10,385.00 15,445.43 101.13 195.68 8,873.55 8,813.50 -5,475.01 -8,923.70 5,969,196.363 679,818.222 3.50 10,410.71 15,476.97 98.94 195.61 8,868.05 8,808.00 -5,504.92 -8,932.07 5,969,166.258 679,810.602 6.95 10,435.59 15,507.64 98.20 196A3 8,863.48 8,803.43 -5,534.07 -8,940.44 5,969,136.910 679,802.969 3.58 10,460.00 15,539.73 96.17 196.19 8,859.47 8,799.42 -5,564.62 -8,949.38 5,969,106.141 679,794.800 6.37 10,485.73 15,571.27 93.99 196.76 8,856.68 8,796.63 -5,594.75 -8,958.29 5,969,075.804 679,786.652 7.14 10,511.17 15,602.09 91.48 197.00 8,855.20 8,795.15 -5,624.20 -8,967.23 5,969,046.134 679,778.456 8.18 10,536.22 15,634.39 88.73 196.93 8,855.15 8,795.10 -5,655.09 -8,976.65 5,969,015.017 679,769.814 8.52 10,562.54 15,666.73 86.91 198.46 8,856.38 8,796.33 -5,685.88 -8,986.48 5,968,983.996 679,760.770 7.35 10,589.10 15,696.95 85.86 198.36 8,858.28 8,798.23 -5,714.49 -8,996.00 5,968,955.152 679,751.969 3.49 10,614.11 15,728.33 83.81 198.67 8,861.11 8,801.06 -5.744.13 2. -9,005.92 5,968 925.280 679,742.794 6.61 10,640.05 15,760.80 83.69 198.87 8.864.64 8,804.59 -5.774.69 -9,016.31 5,968,894.470 679,733.181 0.72 10,666.93 15,792.03 83.78 198.69 8,868.05 8,808.00 -5,804.08 -9,026.30 5,968,864.839 679,723.930 0.64 10,692.78 15,886.60 83.97 - 200.32 8,878.14 8,818.09 5,892.71 -9,057.70 5,968,775.452 679,694.776 1.73 10,771.73 15,981.30 82.65 200.08 8,889.17 8,829.12 -5,980.98 -9,090.18 5,968,686.400 679,664.531 1.42 10,851.32 16,075.78 83.69 199.91 8,900.41 8,840.36 -6,069.13 -9,122.25 5,968,597.473 679,634.683 1.12 10,930.52 16,169.94 84.28 197.98 8,910.28 8,850.23 -6,157.70 -9,152.65 5,968,508.177 679,606.523 2.13 11,008.64 16,264.84 85.02 197.34 8,919.12 8,859.07 -6,247.73 -9,181.31 5,968,417.457 679,580.134 1.03 11,086.28 16,360.23 88.21 197.25 8,924.76 8,864.71 -6,338.64 -9,209.62 5,968,325.873 679,554.126 3,35 11,164.17 16,455.06 91.82 198.73 8,924.73 8,864.68 -6,428.81 -9,238.90 5,968,234.994 679,527.122 4.11 11,242.40 16,549.49 90.22 201.21 8,923.05 8,863.00 -6,517.54 -9,271.15 5,968,145.489 679,497.123 3.13 11,322.08 16,643.87 90.24 202.52 8,922.67 8,862.62 -6,605.13 -9,306.29 5,968,057.050 679,464.191 1.39 11,403.37 16,738.12 90.46 201.07 8,922.09 8,862.04 -6,692.64 -9,341.29 5,967,968.694 679,431.412 1.56 11,484.48 16,833.29 90.19 198.35 8,921.55 8,861.50 -6,782.22 -9,373.38 5,967,878.336 679,401.584 2.87 11,564.57 16,928.47 90.15 196.03 8,921.27 8,861.22 -6,873.14 -9,401.51 5,967,786.741 679,375.753 2.44 11,642.33 7/19/2016 3:43:21PM Page 11 COMPASS 5000.1 Build 810 • • .. 0 b BP V&1 pFinal Survey Report BAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well L1-13 Project: Lisburne ND Reference: L1-13 Plan @ 60.05usft(PARKER 272) Site: Lis DS 01 MD Reference: L1-13 Plan @ 60.05usft(PARKER 272) Well: L1-13 North Reference: True Wellbore: L1-13 Survey Calculation Method: Minimum Curvature Design: L1-13 Database: EDM R5K-Alaska PROD-ANCP1 Survey MD Inc Azi(azimuth) ND TVDSS N/S EIW Northing Fasting DLeg V.Sec (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°(100usft) (usft) 17,023.15 91.63 196.69 8,919.80 8,859.75 -6,963.98 -9,428.17 5,967,695.272 679,351.383 1.71 11,718.88 17,118.18 95.06 196.57 8,914.26 8,854.21 -7,054.86 -9,455.32 5,967,603.738 679,326.532 3.61 11,795.84 17,182.04 98.12 196.96 8,906.93 8,846.88 -7,115.60 -9,473.61 5,967,542.566 679,309.771 4.83 11,847.39 17,216.00 98.12 196.96 8,902.13 8,842.08 -7,147.75 -9,483.42 5,967,510 174 679,300 776 0.00 11,874.78 Projection to TD Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 13,988.00 8,858.19 TLSB DOLOMITE 12,113.00 7,441.12 CM1 MUDSTONE 13,809.00 8,714.09 KAVIK SHALE 13,162.00 8,192.61 SHUBLIK Carbonate 10,507.00 6,534.19 CM3 MUDSTONE °' ! 4 .='x`>a.w5 x r----- 4''''''r Iv Annotations Measured Vertical Local Coordinates Depth Depth +N/-S vE/-W (usft) (usft) (usft) (usft) Comment 10,730.05 6,714.83 -2,529.98 -6,866.83 TIP 10,754.00 6,734.89 -2,540.16 -6,875.05 Top of WS 10,771.08 6,749.23 -2,547.41 -6,880.85 Bottom of WS 10,815.42 6,785.74 -2,566.58 -6,897.12 Interpolated Azimuth 17,216.00 8,902.13 -7,147.75 -9,483.42 Projection to TD Approved By: Yosha Ragbirsingh Survey Manager Baker Hughes 7/19/2016 3:43:21PM Page 12 COMPASS 5000.1 Build 818 ',,;:411%,;',0 3 parr,+ i r. Ay .i RECEIVVI 2 1 6 0 0 3 27681 BAKER NOV 0 3 iM PRINT DISTRIBUTION LIST HUGHES A OOOO Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc. BP Exploration(Alaska)Inc. Petrotechnical Data Center,LR2-1 DATA LOGGED ti./4C/201Gr WELL NAME L1-13 PB1 900 E.Benson Blvd. K BENDER Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE GR-RES-DEN-NEU BHI DISTRICT Alaska --- LOG DATE July 18,2016 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizaresbakerhughes.com TODAYS DATE November 2,2016 Revision STATUS Final Replacement: No Details: Rev. 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H F- > > C i a �o-! — { $ — u j < illt U > V ‹, W > a, 'E o ', o �tyy C O O -4 W W V Eel N \ 4, E U ' L W N ` I oa tn y > U pl V W 0 > c:: e \ o as 4g Z a '6 8t0 m O r - - W Q aM ,. Z ` ria r 4W W Z j U OD X N O .-- O a 00O �:, O `/ 1 0 w * O O Q Y \,j W Q1 mawLU o E a cu 3aT co to x 0 a 0 Q O CL O �D O m I. co N N O ) C m O N in O 01 co C vi o co C In aJ L•az ce CO c c. a CO EL.Li in al E a to c oo CLD � 4., d8 al g - a o � gp e1, Q 7 E aci scc 2 _ 0_ n E re.. -J J E z a) -a U Cl. Q p w �n }, �n O t .iP U 0 co ',7 W, a o cop L1 � f Ft a s ° m STATE OF ALASKA IIIPASKA OIL AND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well RI Re-enter Susp Well 0 Other:OA Squeeze l 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 216-003 3. Address: P.O.Box 196612 Anchorage, Development I1 Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-23563-00-00 7. Property Designation(Lease Number): ADL 028302&028303 8. Well Name and Number: L1-13 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: LDL PRUDHOE BAY,LISBURNE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 17216 feet Plugs measured None feetS true vertical 8902 feet Junk measured None feet E P 0 2016 Effective Depth: measured 16961 feet Packer measured 13740 feet AOGCCtrue vertical 8921 feet Packer true vertical 8658 feet Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20" 47-127 47-127 Surface 5166 13-3/8" 47-5212 47-3806 5020 2260 Intermediate 10709 9-5/8" 45-10754 45-6735 6870 4760 Liner 3342 7" 10646-13988 6645-8858 7240 5410 Liner 3178 4-1/2"x 3-1/2" 13828-17007 8729-8920 8430/10160 7500/10530 Perforation Depth: Measured depth: 13978 16933 feet True vertical depth: 8850-8921 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr85 42-13834 42-8734 Packers and SSSV(type,measured and 4-1/2"HES TNT Perm Packer 13740 8658 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: Cement OA with 353 Bbls Class'G'1.16 yield(1709 sx)and 50 Bbls Class'G'1.19 yield(236 sx) 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development IJ Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil RI Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-415 Contact Hibbert,Michael Email Michael.Hibbert@BP.com Printed Name Joe Lastufk Title Drilling Technologist //�� Signature Phone +1 907 564 4351 Date q/ /j b Form 10404 Revised 5/2015 1/1—I 1 d HI/ RBDMS SEP 2 2 2016Submit Original Only (O/O/fib • • L1-13 Well History CTIVITYDATE '' • T/I/O = ?NAC/10. Temp SI. T & IA FL (WIC request). Well has a dry hole tree installed (double gate valves). Well is disconnected from the system, no flow line, well house, grating, scaffolding. Unable to get T FL due to TWC in hole. IA FL near surface. 7/28/2016 Unable to verify dry hole tree valve positions. IA, OA= OTG. 16:10 T/I/O =Vac/Vac/10. Temp = SI. T& IA FLs (E-Line request). No AL. No well house, has drilling scaffolding. TWC pulled and ASV installed. T& IA FLs near surface. 8/4/2016 ASV= C. MV= O. IA, OA= OTG. 04:30 T/I/O= TWC/0/0. RU ASV#02. Pressure test tree 5000 psi (Passed). Pull 4" H TWC#294 8/4/2016 @108". RDMO. FWP=VAC/0/0. ***Job Complete***. See log for details. T/I/O =VacNac/10. Temp = SI. Assist Eline (LDL). No AL. No well house or flow lines. IA, OA FL near surface. Pressured up to and held 3800 psi on IA while maintaining an open 8/4/2016 bleed on OA. LLR = 1.16 gal/min. Continued on WSR 8-5-16. ***WELL SHUT IN UPON ARRIVAL*** (SLB ELINE -ACOUSTIC LDL) INITIAL T/I/O=0/0/0 RIH W/ PDS ACOUSTIC LDL TOOLSTRING (TEMP/CCL/TANDEM LEAKPOINT) (OAL 28', MAX OD 2.125") FOR BASELINE TEMP PASS. TIED INTO TUBING TALLY DATED 22-JULY-16. DHD PUMPED DSL DOWN IA WITH OPEN BLEED ON OA TO OBTAIN LLR OF 1.15 GPM. TBG PRESSURE TRACKED IA VIA GLM #5 SHEAR VALVE (PREVIOUSLY SHEARED) BEGIN DYNAMIC UP PASS FROM 13770' MD WHILE MAINTAINING 3800 PSI ON TUBING/IA TAKING RETURNS OUT FROM OA. 8/4/2016 ***JOB CONTINUED ON 5-AUG-16*** ***CONTINUED FROM 4-AUG-16*** (SLB ELINE-ACOUSTIC LDL) COMPLETE DYNAMIC UP PASS FROM 13770' MD TO 1800' MD WHILE MAINTAINING CONSTANT T/IA PRESSURE OF 3800 PSI DETECTED IA X OA ANOMALIES AT 2883', 2690', 2550'AND 2310'. PERFORMED REPEAT PASSES OVER ANOMALIES. REDUCED IA PRESSURE TO 3000 PSI TO LOG DYNAMIC UP PASS FROM 1800' MD TO SURFACE. ALL PASSES CORRELATED TO TUBING TALLY DATED 22-JULY-16. SEE DHD WSR FOR DETAILS ON FLUIDS. FINAL T/IA/OA= 0/0/0 8/5/2016 ***JOB COMPLETE. WELL SHUT-IN UPON DEPARTURE*** Continued from WSR 8-4-16. T/I/O = 3990/3800/1. Temp = SI. Assist Eline (LDL). No AL. No well house or flow lines. IA, OA FL near surface. Pressured up to and held 3800 psi on IA while maintaining an open bleed on OA. LLR = .958 GPM @ 3800 psi (Pumped 57 gallons of diesel in 60 minutes). Pumped a total of 26 bbl of diesel during LDL. Bled IAP to 0 psi in 20 minutes, (all fluid, 9.9 bbl of returns from IA). E-Line bled TP to 0 psi, OA on Vac. Final WHP's= 0/ONac. 8/5/2016 E-LINE in Control of WH valves. 03:50 T/I/O=VAC/48NAC. Post Parker 272. Set 4" CIW"H" TWC#432 at 120". TWC LTT Pass. ND DH Tree SV Temp#17 , and ASV#02 . Installed 4" CIW Upper tree serial#120699008- 01 . Torqued SSV x MV and THA x MV to API Specs. PT'd tree to 5000 psi =PASS. Pulled TWC#432 at 120". Removed Temp#4 from IA and Temp#30 from OA. Installed tapped blind flange's with jewerly, Torqued to API Specs and PT to 3500 psi. PASS. PT tree cap to 500 psi. PASS ***Job Complete***See Log for Details FWP=0/48/0 8/13/2016 AOGCC test required within 5 days of POP. • • L1-13 Well History T/I/O= 35/82/38 Temp= Shut in (new well) Perform Injectivity test on OA. Pumped 100 bbls of ambient diesel in stages to preform injectivity test, see log for details. Bled back-13 bbls diesel. 8/27/2016 FWHP= 73/123/36 Swab, wing, SSV= closed, IA, OA= open to gauge 8/27/2016 T/I/O=vac/104/183 Temp=Sl Circ out for cement job (NEW WELL POST) Pumped 2 bbls 60/40 down IA followed by 302 bbls of 180*crude. Pumped 38 bbls crude down tubing for 8/30/2016 freeze protect. Halliburton pump has well control upon departure. FWHP's=22/3/120. HES Cementing: Job Scope: OA Cement Downsqueeze: MIRU HES cement van and bulk trucks. Pump 10 bbls 50/50 McOH, 186 bbls fresh water mixed w/2 gal/bbl MUSOL-A and 2 gal/bbl SEM-8, 10 bbls Clean Spacer, 75 bbls neat Class "G"cement, 50 bbls Class "G" cement w/ 15 Ib/bbl Pressure Seal Aggregate, and 278 bbls neat Class "G" cement. Observe pressure bump of 250 psi after hesitating with aggregate at shoe. Shut down pumps and hesitate/squeeze again to a final pressure of 300 psi. Rig down iron from OA, clean out and 8/30/2016 service OA casing valve. RDMO. ***Job Complete*** T/I/O = 0/0/0. Temp = SI. Squeeze OA(New well post). AL SI ©casing valve (0 psi). Performed draw down test and removed OA jewelry. OA on 12 o'clock position was a wall of cement with a minor amount of soft cement at the bottom of the profile (cleaned out). OA on the 6 o'clock position had valve grease along the top portion of the OA profile leading to a channel around the RH side of the wellhead to about the 4 o'clock position. Filled the channel up with water and used a heater to keep water hot. Rigged up to the opposite side (12 o'clock) and mixed SqueezeCRETE. Pumped -2 cups of SqueezeCRETE into the OA. OA pressured up to 3000 psi. Bumped up 3 times, losing -V300 psi in 15 minutes the first two times and holding at 3000 psi the last time (No returns @ the 6 o'clock position). Bled the OAP &cleaned OA opening. Filled OA channed @ the 6 o'clock position w. F-103 & hot water, flushed with fresh water till clean returns were observed (performed twice). Pumped 2 gallons of squeeze crete down the OA @ the 6 o'clock positon to pressure up to 3000 psi. Bumped up 4 times. OAP decreased 5 -600 psi in 15 minutes the first two times, 300 psi the third time and held @ 3000 psi the fourth time. Bled the OAP to 0 psi (1 cup). Cleaned up OA opening & installed 1502 block valves &caps. Applied 500 psi of N2 to the OA. Tags hung. Heater left in wellhouse, door left open. TC x SSV void @ 0 psi. Sample left on wellhead. FWPs = 0/0/500. 9/3/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 1700 hrs. T/I/O= SI/0/0. Pre Cement Squeeze. R/D 2" FMC 120 OA valve and N/U 2" intergal flanges 9/3/2016 and block valves. ***Job Complete***See log. Final WHP's SI/0/0. T/I/O = SSV/0/120. Temp = SI. WHPs (Post OA squeeze). ALP = 0 psi, SI @ CV. OAP decreased 80 psi overnight. Temp taken -6" below OA CV at the 6 o'clock position = 72°. Cement sample in WH has not hardened. Heater in WH working properly, WH doors are open. Tree cap = 0 psi. 9/4/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 21:00. T/I/O = SSV/0/200. Temp = SI. WHPs (Post OA squeeze). ALP = 0 psi, SI @ CV. OAP decreased 300 psi overnight. Temp taken -6" below OA CV at the 6 o'clock position = 92*. Cement sample in WH has not hardened. Heater in WH working properly, WH doors are open. Tree cap = 0 psi. 9/4/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 15:00. T/I/O = SSV/0/180. Temp = SI. WHPs (Post OA squeeze). ALP = 0 psi, SI @ CV. OAP decreased 20 psi overnight. Temp take -6" below OA CV at the 6 o'clock position = 88*. Cement sample in WH is not hard yet. Heater in WH is working properly. WH doors are open. Tree cap bled to 0 psi. 9/5/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 13:50 • r L1-13 Well History T/I/O = SSVNac/40. Temp = SI. WHPs (Post OA squeeze). ALP = 0 psi, SI @ CV. OA cemented to surface. OAP decreased 140 psi overnight. Temp taken -6" below OA CV at the 6 o'clock position = 80*. Cement sample in WH is set up on the outside of the sample, still soft in center. Heater in WH is working properly. WH doors are open. 9/6/2016 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 13:50 T/I/O = SSVNac/30. Temp= SI. WHPs (Post OA squeeze). ALP = 0 psi, SI @ CV. OAP decreased 10 psi overnight. Temp take -6" below OA CV at the 6 o'clock position = 68°. Cement sample in WH is not hard yet. Heater in WH is working properly. WH doors are open. Tree cap bled to 0 psi. 9/7/2016 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 04:00 T/I/O = SSVNAC/0+. Temp = SI. WHPs (post OA squeeze). AL blinded @ CV. Block valve installed in place of OA CV. Heater running in wellhouse. Cement sample on WH no longer liquid. OAP decreased 30 psi in overnight. 9/8/2016 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 00:30 T/I/O = SSVNac/0. Temp = SI. WHPs (Post OA squeeze). ALP = 0 psi, SI @ CV. OAP decreased 10 psi overnight. Temp take -6" below OA CV at the 6 o'clock position = 68°. Cement sample in WH is hard. Heater in WH is working properly. WH doors are open. Tree cap bled to 0 psi. Crews on location working on instrumentation. 9/8/2016 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 16:30 TWO = SSVNac/0. Temp= SI. WHPs (post OA squeeze). AL blinded @ CV. Block valves installed in place of OA CV. Heater is working properly and is aimed to not overheat the well house. Cement sample appears to be solid. 9/9/2016 SV,SSV= C. WV, MV= LOTO'ed. IA, OA= OTG. 16:50 T/I/O = SSVNAC/0+. Temp= SI. WHPs (post OA squeeze). AL blinded @ CV. WHPs unchanged overnight. 9/10/2016 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 04:00 T/1/0=S1/0/0 N/D OA Intregals, N/U front working side OA gate valve Tag#5. FWP's SI/0/0 9/10/2016 see log for details. T/I/O = SSVNac/0. Temp = SI. Tbg & IA FL (call-in). Unable to obtain Tbg FL due to Master valve being LOTO'ed. IA FL @ -180' (10 bbls). Heater is removed from well house. 9/10/2016 PULL B&R FROM 13791' SLM / 13817' MD PULL STA#5 RKP-SHEAR VLV @ 5604' SLM/5626' MD SET STA#5 RK-DGLV @ 5604' SLM /5626' MD MIT-IA,1ST 15 MIN 2718 PSI, LOST 45 PSI, 2ND 15 MIN LOST 24 PSI, 3RD 15 MIN LOST 17 PSI, 9/14/2016 PULL 4-1/2" RHC PLUG BODY FROM SLM 13796'/ 13817' MD CONT. POOH W/ PLUG 9/15/2016 RIGDOWN T/I/0=500/100/0 SI MIT/Open Hydraulic port (NEW WELL POST) MIT IA to 2631 psi ***PASSED*** Pumped 7.75 bbls DSL down IA to achieve test pressure of 2631 psi. 4th attempt. 15 min loss of 19 psi, 30 min loss of 18 psi, for total loss of 37 psi in 30 mins. Pumped total of 22 bbls DSL down TBG to open Port. See log for Details. IAP bled to 0 psi, bled back approx 6.1 bbls. Tags hung on WV/IA. AFE sign hung on MV***FLUID PACKED WELL*** Valve positions=SV WV SSV closed MV open CVs OTG AL closed 9/16/2016 FWHP=2000/0/0 T TREE= Ciw WELLHEAD= FMC L 1 -13 s• - NOTES: WELL ANGLE>70°@ 14308'*** ACTUATOR= BAKER C CHROME TBG&LNR MAX DLS:14.2@ 14434' OKB.ELEV= • 60.05' I REF ELEV= 60.05' BF.ELEV= 15.48' 20"X30" - 127' +-�__, 2201' -{4-1/2"HES X X .D=3.813" KOP= 576' NS COND, ndIN Max Angle= 102°@ 14655' 91.5#,A-53, GAS LFT MANDRELS Datum MD= 14128 D=19.124" ST MD TVD DEV TYPE VLV LATCH FORT DATE Datum TVD= 8900 5 5626 4005 64 MIG OCR-1 RKP - 07/22/16 4 9928 6099 45 MIG DMY RK 0 07/22/16 13-3/8"CSG,68#,L-80 Fit'D563/BTC,D=12.415• 6212' � 3 11662 7241 64 MG DMY BK 0 07/22/16 I'OP OF CMT(06112!16) -7603' ' !• 2 12731 7849 38 MMG MAY BK 0 07/22/16 Minimum ID = 3.813" a@ 2201' N ; 1 13471 8441 36 MG DMY BK 0 07/22/16 4-1/2" HES X NIPPLE 10646' I-9-5/8"X r BKR FRO LTP w/TIEBACK SLV& TOP OF LNR 10646' ••4 L BKR FLEXLOCK . P �`4� HGR,D=6.20" 9-5/8"WH �'PSTOCK(06/23/16) �- 10764' r 9-5/8"CSG,47#,L-80 VAM TOP,D=8.681" H 12199' • P. IC 0 13712' 1-14-1/2'I-ES X NP,D=3.813' rl ea "'.%iN 13740'J_d 7"X 4-1/2"HES TNT PKR,D=3.870" 13817' -j4112"F♦ESXNP,13=3.813 qv r .41 hi •. 13828' -7"X 5"BKR FSE ZXP LTP w/TIEBACK SLV& ID.: BKR FLEXLOCK HGR,D=4.30" 4-1/2"TBG,12.6#,13CR 85 VAM TOP -1 13$34' 1r 13834' -�4 112"WLEG,D=3.958' 0152 bpf,D-3.958" � ..4 r ( I �► BAD--IHTT NOT LOGGED ' .r 13862' --I5"X 4-112"XO BUSHING,D=3.91' 7"LNR 26#,L-80 VAM TOP, - 13988' w .a_. 0383 bpf.D=6.276• -AIL, 4-1/2" FRAC PORT SLEEVES 11111 NO DEPTH SEAT SZ. ACTUAL SEE 0/C DATE `-' • 12 13978' 3.137" 5.630" 07/20/16 4-1/2"HES SWELL PACKERS Min 11 14089' 3.037" 5.630' 07/20/16 NO SEE TOP DEPTH MND 1. _1 10 14338' 2.947' 5.630" 07/20/16 11 4-1/2" 14033' 3.92" Ifni 9 14626' 2857" 5.630" 07/20/16 10 4-1/2" 14223' 3.92" IC.1 -'=' 9 4-1/2" 14470' 3.92" 118 14888' 2.767" 5.630" 07/20/16 7 15200' 2.677" 5.630" 07/20/16 8 4-1/2" 14755' 3.92" in-'' 6 15418' 2.587" 5.630" 07/20/16 7 41/2" 15025' 3.92" 11111 5 15539' 2.497" 5.630" 07/20/16 6 4-112" 15244' 3.92' _'=' 4 15711 2.412" 5.630" 07/20/16 5 4-112" 15487' 3.92" E1111 3 16262' 2.332" 5.630" 07/20/16 4 4-1/2" 15626' 3.92" ._4_10_4 2 16667 2.252" 5.630" 07120/16 3 4-1/2" 15848' 3.92" 1 16933' 3.75" 5.630" 07/20/16 2 4-1/2" 16498' 3.92" v.:.Nil...7.: 1 4-1/2" 16764' 3.92' R■ M-E-1 16847' H4-1/2"HYD521 SHIFT TOOL VBZFICATION SUB,D=3.87" PBTD 16961' •_. .I.:;1�� 16961'--14-112"SLB FLOW-TI-RU CRC VALVE,D=1.220"J 4-1/2"LNR,13.5#,13CR-85 HYD 521, -1 16973' Mi' .0150 bpf,ID=3.92" 16973' -41/2"X 3-112"XO,D=2.992• 91, 3-1/2"LAR 9.2#,L-80 TCI,.0087 bpf,D=2.992" H 17007' lat DATE REV BY COMA:NTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/25/16 P-272 INITIAL COMPLETION WELL: L1-13 07/28/16 JMD DRLG HO CORRECTIONS PERMIT No: '2160030 08/02/16 BG/JMD FINAL ODEAPPROVAL API No: 50-029-23563-00 08/22/16 JNL/JM ) UPDATED REF&BF ELEV SEC. 1,T11N,14E,2542'FSL&2478'FEL BP Exploration(Alaska) 2�Ca• -00 3 WELL LOG TRANSMITTAL DATA LOGGED PROACTIVE DIAGNOSTIC SERVICES, INC. 0 n,L1201 M.K.BENDER To: AOGCC LIVED Makana Bender '�•• 333 W. 7th Ave SEP0 8 alb Suite 100 (907)Anchorage,793-1225ska 99501 AOGCC RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Merion Kendall LR2-1 900 Benson Blvd. Anchorage, AK 99508 gancpdc(c bp.com and ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 04-Aug-16 L1-13 BL /CD 50-029-23563-00 2) Signed : P2val241.42,(4_,(17) � Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(5 MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\BP_Transmit.docx r STATE OF ALASKA AUG 2 3 2016 OIL AND GAS CONSERVATION COMMIWEL•LASKAMPLETION OR RECOMPLETION REPOWAND LOG //•�� �aa� 1 a. Well Status: Oil I71 ` Gas El SPLUG 0 Other 0 Abandoned 0 Suspended 0 lb.W I�I CI�SsG`� "'• 20AAC 25.105 20AAC 25.110 P Development ® Exploratory 0 GINJ ❑ WINJ 0 WAG ❑ WDSPL 0 No.of Completions: One • Service 0 Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 7/25/2016 • 216-003 • 3. Address: 7. Date Spudded: 15' API Number: P.O.Box 196612 Anchorage,AK 99519-6612 5/28/2016 • 50-029-23563-00-00 ' 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 7/17/2016 • PBU L1-13 ' Surface: 2541'FSL,2801'FEL,Sec.01,T11N,R14E,UM • 9 Ref Elevations KB 60.05 - 17. Field/Pool(s): Top of Productive Interval: 1665'FNL,721'FEL,Sec.10,T11N,R14E,UM GL 12.9 • BF 15.48 • PRUDHOE BAY,LISBURNE OIL Total Depth: 4612'FNL,1728'FEL,Sec.10,T11N,R14E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: • 16961'/8921' • ADL 028302&028303 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 688601 • y- 5974894 • Zone - ASP 4 • - 17216'/8902' • 84-62 TPI: x- 680232 y- 5970480 Zone - ASP 4 12. SSSV Depth(MD"/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 679300 y- 5967510 Zone - ASP 4 None 1780'/1760' 5. Directional or Inclination Survey: Yes ® (attached) No 0 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 MC 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,MWD/GR/RES,MWD/GR/RES/NEU/DEN,USIT,LDL 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECORD AMOUNT FT. PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# A-53 47' 127' 47' 127' 42" 260 sx Arctic Set(Approx.) 13-3/8" 68# L-80 47' 5212' 47' 3806' 16" 2793 sx LiteCrete,312 sx Class'G' 9-5/8" 47# L-80 45' 10754' 45' 6735' 12-1/4" 1451 sx LiteCrete,219 sx Class'G' 7" 26# L-80 10646' 13988' 6645' 8858' 8-1/2" 422 sx Class'G',960 sx Class'G' tIR 4-1/2"x 13.5#/ 13Cr85/ 13828' 17007' 8730' 8920' 6.1/8" Uncemented Sliding Sleeves w/Swell Packers 3-1/2" 9.2# L-80 24. Open to production or injection? Yes El No 0 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MDTTV Size and Number): 4-1/2"12.6#13Cr85 13834' 13740'/8658' 4-1/2"Sliding Frac Sleeves w/swell packers 13978' 8850' 14089' 8934' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 14338' 9055' 14626' 9048' COMNLE)i ON Was hydraulic fracturing used during completion? Yes 0 No 0 14888' 8992' DATE 1 Per 20 MC 25.283(i)(2)attach electronic and printed 15200' 8925' information 15418' 8879' 15539' 8860' VERIFIED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 15711' 8859' 16262' 8919' L. 2763' Freeze Protect w/190 Bbls Diesel 16662' 8923' 16933' 8921' 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period ...► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press 24 Hour Rate ...♦ Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only v-rz r0/i2ltb /0(0/4 RBDMS u-- AUG 2 9 2016 '41:'''f x=14. �C 28. CORE DATA • Conventional Core(s) Yes ❑ No 0 • Sidewall Cores Yes ❑ No l , If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Permafrost-Top 47' 47' Well Tested? Yes ❑ No I • Permafrost-Base 1827' 1807' If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 14011' 8876 separate sheets to this form,if needed,and submit detailed test information per 20 MC 25.071. Ugnu 7580' 4850' West Sak 10007' 6155' Colville Mudstone 10507' 6534' HRZ 12695' 7820' LCU/Kingak 12947' 8020' Sag River 13099' 8142' Shublik A 13162' 8193' Shublik B 13192' 8217' Shublik C 13208' 8230' Sadlerochit-Zone 4 13230' 8247' CGL-Zone 3 13362' 8353' Base of CGL-Zone 2C 13417' 8398' Zone 2B 13509' 8472' Zone 2A 13656' 8591' Zone 1B 13704' 8829' TDF-Zone l A 13756' 8671' Base of Sadlerochit-Kavik 13809' 8714' Lisburne-Wahoo 7 13992' 8861' WAHOO 6 14011' 8876' Wahoo 5 14155' 8976' Wahoo 4 14313' 9047' Wahoo 5(Invert) 14804' 9010' Wahoo 6 15158' 8934' Kavik(Fault) 17027' 8920' • Formation at total depth: Kavik(Fault) 17027' 8920' 31. List of Attachments: Summary of Daily Drilling Reports,LOT/FIT Summary,As-Built,Surveys,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. Contact: Gorham,Bradley M Email: Bradley.Gorham@bp.com Printed Name: Joe Lastuf Title: Drilling Technologist Signature: Phone: +1 907 564 4091 Date:j// 2?//J , /\ INSTRUCTIONS / General:This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1 a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1 b.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 MC 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 MC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only r TREE= . WEILIEAD= RAC • L1 -13 s.NOTES: WELL ANGLE>70'@ 14308'*** ACTUATOR= BA :' C CHROME TBG&LNR***MAX DLS:142°@ 14434' OKB.B_EV= 60.05' 7. igg REf REV= 60.05 0 0 lige 2201' -14-1/2"HES X NP,0=3.813' BF.ELEV= 15.48' 20'X 30" MEM 0 KOP= 576' LIS GOND, 0 0 0 0. GAS LFT MA0CRELS Max Angle= 102'(11114655- 91.54,A-53, ST AU TVD DEV TY PE VLV LATCH PORT DATE Detum PM= 14128' 1)= 19,124" CetumTV D= 8900' 13-3/8"CSG.6ais,L-80 HY D563A3TC,ID= 12.415' 6212' IM 5 5626 4005 64 AMC DCR-1 RKP - 07/22/16 4 9928 6099 45 MAC CMY RK 0 07/22/16 3 11662 7241 64 DAG DMY BK 0 07/22/16 . _ . TOP OF cMT(06/12/16) - -7603' ig ii, 2 12731 7849 38 114/G DMY BK 0 07/22/16 1 13471 8441 36 MM(3 DAV BK 0 07/22/16 Minimum ID = 3.813" @ 2201' 0 0 4-1/2" HES X NIPPLE .0 0 Re PS I 1 ri 10646' -9-5/8"X 7"BKR KR)LTP w/TEBACK SLV 8 56 IP TOP OF LNR 10646' ix L. J qg BKR FLEXLOCK HGR,ID=6.20' 0 0 'II ,-le 104 lig 9-5/8"WHIPSTOCK(06/23/16) - 10764' 4 0 ;kJ ig *V Fel 9-5/8'CSG,47#,L-80 VAM TOP,D=8.681" 12199' • ' • N; • .4 EmPrerr = 111 Pi NM i Ss i ki i rm=-14-1/2.FES X NP•13 .813' 3 $ X ?elle 13740' -7'X 4-1/7"I IM TNT PKFR,D=3.870" ,0 IM4 CE4 is ei MO iliSi r- -14-1/2- .,kriS IMEaall ...- ;ge g ie, fe 13828' -7'X 5'BKR i-ORDE 2XP LTP w/i EBACK SLV 8 Ars IP BKR FLEXLOCK HGR,CO=4,30' 0 IP 4-1/2"TBG, 12.6#,13CR-85 VA M TOP, - 13834' .-- -,S MEM-4-1/2'WLEG,13=3.958" I .0152 bpi.0-3 958" 111.0 •71 X t.„ L__ 1-Elmo TT NOT LOGGED lc mini 4, E;: --15'X 4-1/7 XO BUS}-ING,0=3,91'] 7"LNR,26#, L-80 VAM TOP, - 13988' ' ••.-..MEI 0.:::., 4 .0383 bpf D=6.276" Inn mmose 4-1/2" FRAC PORT SLEEVES OWN NO DEPTH SEAT SZ. ACTUAL SIZE 0/C DATE *7-'•IMMI'm, 12 13978' 3.137' 5630' 07/20/16 4-1/2- - S : L PAC v 111111 11 14089' 3.037' 5.630' 07/20/16 -NO SCE TOP DarT1-1 MN ID .i.11.11F:. 11 ' 4-1/2' 14033' 3.92' Ellin 10 14338' 2.947' 5 630' 07/20/16 07/20/16 10 4-1/2' 14223' 3.92' ..--. .-..-. 9 14626' 2.857' 5.630" 8 14888' 2.767' 5.630' 07/20/16 9 4-1/2' 14470' 192' 111111 7 15200' 2.677' 5630' 07/20/16 8 4-1/2' 14755' 3.92' ."--• .17.., 6 15418' 2.587" 5.630' 07/20/16 7 4-1/2" 15025' 3.92" MN 5 15539' 2.497' 5630' 07/20/16 6 4-1/2' 15244' 3.92' /:. .'1". 4 15711' 2.412" 5.630" 07/20/16 5 4-1/2" 15487' 3.92' MIN 3 16262' 2,337 5.630' 07/20/16 4 4-1/2" 15626' 3.92' .7. '11:' 2 16662' 2.257 5630' 07/20/16 3 4-1/2' 15848' 3.92' OTEM 1 16933' 3.75' 5.630" 07/20/16 2 4-1/2' 16498' 3.92' .z. ..7. 1 4-1/2" 16764' 3.92" ..1 ..:.1.111.:. R-1 16847' -14-1/2-HY D521 Si-FT TOOL VE3W1CATION SUB,13=3.87' - FUTD 16961' 16961' -4-1/2-SLB FLOW-V-PU CPC VALVE,D=1.220" j 4-1r2"LNR 13 5#,13CR-851-fY D 521, 16973' 1.-..., 16973' 4-1/2'X 3-1/2'XO,0=2.992" 0150 bpf,D=3 92' mem= 1 W 3-1/2"042,924,L-80 TCI, 0087 bpf.ff..)=2.992" ' 17007' Sr2e DATE REV BY 000/LENTS DATE REV BY COLfANTS PRUDHOE BAY UNfT 07/25/16 P-272 INTIAL COM PLETION WELL L1-13 07/28/16 JM) DRLG HO CORRE-CT1ONS _ FERNT No: '2160030 08/02/16 BG/JM".) FLIAL ODE AFPROVAL _ AR No: 50-029-23563-00 0812206 JNL/JA/f) UPDATED REF&BF ELEV SEC. 1,T11N, 14E,2542'FSL&2478'FEL BP Exploration(Alaska)k a) `u AO 1 t \ T 12 i -r : _r ,b ti .T 11 ly �_ /i LGl' i rsF ti ,, C) i_ -1 I D.S. L-1 - I 2 1 1 31 • 7 ■ 30 6 ?: f? \Is_ ,x# 51'r, >1 I N 28 1 , . 27■ �� I I x `r 23■ 21 IVICINITY MAP F, ll 20 '-•.. N.T.S. 1 / / 1 I 1 1, ,Us. 1 ,��,s OFX111 1 L1-13 ■14 I �4,,wb ,v,......,,...4 if k. lit ✓ yx>.4.(((Ili /4$ 10 f ...�. .s .76, .op os .s ,0101111," ,d10 IN 8 "c~. ot1y F is arnhart 1 �`���`11 �b� 10200 .. 4** aria iii..a* ± .`�.. 1 'SO 1004- ,to • 2 1 N 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 ODETAILS - ._.. ._ I r — -, r — CCORRECTNS ASAND OF AUiGUST 9, 2016.RE I NOTES: LEGEND 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD27. AS-BUILT CONDUCTOR 2. BASIS OF LOCATION IS D.S. L-1 MONUMENTS L-1 NORTH AND L-1 GRAPHIC SCALE SOUTH. ■ EXISTING WELL 3. BASIS OF ELEVATION IS BP MEAN SEA LEVEL (MSL) DATUM. 0 100 200 40C t 1 4. GEODETIC POSITIONS ARE NAD27. ( IN FEET ) 5. PAD MEAN SCALE FACTOR IS: 0.9999405. 1 inch = 200 ft. 6. DATE OF SURVEY: JANUARY 29, 2016, AUGUST 9, 2016. 7. REFERENCE FIELD BOOK: NS16-06 PGS. 01-04, NS16-38, PGS 25-26. LOCATED WITHIN PROTRACTED SECTION 1, T. 11 N., R. 14 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION BASE NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS FLANGE ELEV. L1-13 Y=5,974,893.73 N= 4,948.83 70'20'10.172" 70.3361589' 12 9' 2,541' FSL 15.48' X= 688,600.88 E=4,789.33 _ 148'28'10.962" 148.4697116' 2,801' FEL DRAWN: JACOBS CNcKro ' 0p i, KLEIN 1 30 16 0 DRAWING _.- FRB15 DSU 02 shrLr. „,�'G LISBURNE D.S. L-1 Cl I$/10/�e AWED BASE FLANGE e�e++Asron OK 1J ICAtL, AS—BUILT CONDUCTOR LOCA11ON 00 it/30,18 ISSUED FOR INFORMAIIQN. JJ OK 1” = 200' WELL L1-13 1 OF 1 k,j. DA IL 12._41':)' BY 41.9i_ • BP AMERICA LOT/ FIT Summary Well Name: L1-13PB1 Surface Leak Off Test Test Test Depth Test Depth AMW Pressure Pressure EMW Date Type (TMD-Ft) (TVD-Ft) (ppg) (psi) (BHP) (psi) (ppg) 06/14/16 FIT 12,199.00 7,976.00 10.50 464.00 4,814.55 11.62 Page 1 of 1 0 • BP AMERICA r LOT/ FIT Summary ,,7 � , Well Name: L1-13 Surface Leak Off Test Test Test Depth Test Depth AMW Pressure Pressure EMW Date Type (TMD-Ft) (TVD-Ft) (ppg) (psi) (BHP) (psi) (ppg) 06/05/16 LOT 5,212.00 3,807.00 9.60 751.00 2,649.56 13.40 06/23/16 FIT 10,771.00 6,749.00 10.50 422.00 4,103.28 11.70 07/06/16 FIT 13,988.00 8,858.00 8.60 500.00 4,457.35 9.69 Page 1 of 1 • • North America-ALASKA-BP Page 1 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisbume Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 5/26/2016 18:00 - 20:00 2.00 MOB P PRE BEGIN DON EVENT WITH PARKER RIG 272 AT 18:00 ON 5/26/16 GENERAL RIG DOWN OPERATIONS ON P1-122: -LOWER PIPE SKATE,SKID CATTLE CHUTE AND SKID RIG FLOOR. -COMPLETE MAST LOWERING CHECKLIST 20:00 - 20:30 0.50 MOB P PRE LOWER MAST -FINAL HOOKLOAD PRIOR TO LANDING ON STAND=380 KLBS 20:30 - 22:00 1.50 MOB P PRE GENERAL RIG DOWN OPERATIONS ON P1-122: -ELECTRICIAN DISCONNECTS INTERCONNECTS WARMUP TIRES AND PREPARE TO SPLIT (MODULES 22:00 - 00:00 2.00 MOB P PRE (SPLIT MODULES AND PULL OFF P1-122 i-PULL UTILITY&MUD MODULES AWAY FROM DRILL MODULE AND STAGE ON PM1 -REMOVE DUMMY WELLHOUSE OF P1-122 WITH LOADER. 5/27/2016 00:00 - 05:30 5.50 MOB P PRE MOVE RIG FROM PM1 TO LISBURNE 1 DRILLSITE -5.4 MILE MOVE FROM PM1 TO L1 -ARRIVE ON L1 DRILLSITE AND 4:30 AND LINE UP MODULES FOR SPOTTING OVER L1-13. I -NO ISSUES WITH ROAD CONDITIONS OR OTHER ASSOCIATED WAITING. 05:30 - 08:30 3.00 MOB P PRE SPOT MODULES OVER L1-13 CONDUCTOR. -RIG MATS SET IN FRONT IN OF L1-13 AND DUMMY WELLHOUSE WAS SET OVER CONDUCTOR PRIOR TO RIG MOVE WELLWORK TRANSFER PERMIT OPEN WITH DRILLSITE OPERATOR. -PERMIT TO DRILL,PAD DATA SHEET, SUMMARY OF HAZARDS,AND STANDING ORDERS POSTED IN DOG HOUSE -CONFIRM LANDING RING HAS BEEN WELDED ON CONDUCTOR -6"PUMP LINERS INSTALLED IN BOTH MUD PUMPS -CONFIRM AC SCAN FOR WPO4C COMPLETED ON 5/20/16(WITHIN PAST 30 DAYS) -PRESPUD MEETING COMPLETED WITH [ANCHORAGE TEAM 5/23/16 08:30 - 10:30 2.00 MOB P PRE RIG UP INTERCONNECTS. INSTALL ROOFTOP TRANSITIONS. RAISE DRIVING CABS. 10:30 - 11:00 0.50 MOB P PRE RAISE MAST -535 KLBS HOOKLOAD OFF STAND 11:00 - 12:00 1.00 MOB I P PRE SKID RIG FLOOR AND CATTLE CHUTE. RAISE PIPE CAT. INSTALL ROOFTOP WALKWAYS. ACCEPT PARKER RIG 272 AT 12:00 ON 5/27/16 Printed 8/8/2016 11119:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 2 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisbume Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 17:00 5.00 RIGU P PRE I GENERAL RIG UP OPERATIONS 1-TAKE ON 8.6PPG-51°F MAXDRIL MUD -MD TOTCO REP ON LOCATION TO CALIBRATE PIT AND FLOW SENSORS -BRIDLE DOWN,HOOK UP TOP DRIVE AND CALIBRATE BLOCKS -INSTALL NEW 9-5/8"MOUSE HOLES NEAR OFFLINE ST-80(TO ALLOW FOR MAKING UP LARGER BHAS OFFLINE) RIG UP FLUID INTERCONNECTS -SPOT CUTTINGS BOX. -SECURE RIG STAIRS AND LANDINGS 17:00 - 00:00 7.00 RIGU P PRE NIPPLE UP 21-1/4"2000 HYDRIL DIVERTER SYSTEM AND LOW PRESSURE RISERS INSTALL BALL VALVES ON CONDUCTOR 4" OUTLETS 1-CHANGEOUT SAVER SUB ON TOP DRIVE TO NC-50 -CONTINUE TO TAKE ON MAXDRIL MUD PICKUP 4 STANDS 5"HWDP AND 6 STANDS I5"DP WITH OFFLINE EQUIPMENT. -HOLD PRESPUD MEETINGS AND TABLETOP D3 DIVERTER/RIG EVACUATION DRILLS WITH HUNDLEYAND MASSIE CREWS 5/28/2016 00:00 - 02:30 2.50 RIGU P PRE I NIPPLE UP 21-1/4"2000 HYDRIL DIVERTER SYSTEM AND LOW PRESSURE RISERS -INSTALL FLOW RISER AND TURNBUCKLES -COMPLETE PICKING UP 4 STANDS 5"HWDP AND 6 STANDS 5"DP WITH OFFLINE EQUIPMENT. 02:30 - 07:00 4.50 RIGU P PRE FINAL PREPARATIONS FOR SPUD -RUN IN HOLE WITH STAND OF 5"DRILLPIPE (NO TAG IN CONDUCTOR DOWN TO 90'MD) I-CALIBRATE BLOCK HEIGHT WITH BAKER GENERAL HOUSEKEEPING PRIOR TO SPUD. -MOVE IN AND RIG UP SPERRY E-LINE UNIT AND GYRODATA DIVERTER FUNCTION TEST ON 5"DP -KNIFE VALVE OPENS IN 28 SEC,ANNULAR CLOSES IN 39 SEC I-FUNCTION TEST ACCUMULATOR UNIT -SEE ATTACHED AOGCC REPORT 07:00 - 08:30 1.50 RIGU P PRE MAKEUP BASIC 16"DRILLING ASSEMBLY FROM SURFACE TO 50'MD 1-NEW 16"HUGHES VM-3 ROLLER CONE -1.8°8"BENT HOUSING MUD MOTOR WITH SOLID FLOAT -UBHO SUB,HWDP,NO DRILL COLLARS 08:30 - 09:30 1.00 RIGU P PRE RUN IN HOLE WITH BASIC 16"DRILLING ASSEMBLY FROM BHA AT 50'MD TO BASE OF CONDUCTOR AT 127'MD -NO SIGN OF FILL OR ICE IN CONDUCTOR -FILL SYSTEM AND CHECK FOR LEAKS. -PRESSURE TEST SURFACE MUD SYSTEM to 4000 PSI(LEAKTIGHT) -TAKE INITIAL GYRO SURVEY IN !CONDUCTOR Printed 8/8/2016 11:19:42AM "Al!depths reported in Drillers Depths* • North America-ALASKA-BP • Page 3 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 09:30 - 15:30 6.00 DRILL P SURF SPUD L1-13 AT 09:30 ON 5/28/16 ✓ DIRECTIONAL DRILL 16"SURFACE HOLE FROM BASE OF 20"CONDUCTOR AT 127'MD TO 512'MD. -150 FPH INSTANTANEOUS ROP -500 GPM,500-600 PSI ON BOTTOM,500 PSI OFF BOTTOM,60 RPM,170 BIT RPM,3-5 KFT-LBS TORQUE ON BOTTOM,2 KFT-LBS OFF BOTTOM,5-7 KLBS WOB -WIPE UP 30'WITH FULL PUMP RATE,RUN DOWN WITH NO PUMPS AT EACH CONNECTION. NO FILL ISSUES -GYRO SURVEY EVERY STAND WITH BIT ON BOTTOM. MINIMAL LOSSES TO FORMATION WHILE DRILLING AHEAD(-67 BBLS DURING GRAVELS IN INTERVAL) -MW IN/OUT=8.6 PPG 15:30 - 17:00 1.50 DRILL P SURF PULL OUT OF HOLE WITH 16"DRILLING ASSEMBLY FROM 512'MD TO SURFACE PULL FIRST STAND WITH FULL PUMP RATE; 500 GPM,535 PSI -RACK BACK HWDP,PULL OUT OF HOLE TO BIT AND INSPECT(GRADE BIT 1-0-IN GUAGE) -FLOWCHECK WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM(STATIC) -NO HOLE ISSUES PULLING ON ELEVATORS -INITIAL PICKUP WEIGHT OFF BOTTOM (PUMPS OFF)= 56 KLBS 17:00 - 20:00 3.00 DRILL P SURF MAKEUP AND RUN IN HOLE WITH 16" DRILLING ASSEMBLY FROM SURFACE TO BOTTOM AT 512'MD(END OF DRILL COLLARS AT 404'MD). -SAME 16"HUGHES VM-3 BIT -1.8°8"BENT HOUSING MUD MOTOR WITH SOLID FLOAT DIR,VSS,GR,UBHO SUB -NO SIGN OF FILL ON BOTTOM Printed 8/8/2016 11:19:42AM *AII depths reported in Drillers Depths* SNorth America-ALASKA-BP S Page 4 Of 87 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 00:00 4.00 DRILL P SURF DIRECTIONAL DRILL 16"SURFACE HOLE FROM 512'MD TO 715'MD/TVD AT MIDNIGHT (239'IN 4 HRS=60 FPH WITH CONNECTIONS). -100-125 FPH INSTANTANEOUS ROP SLIDING, 150-175 FPH INSTANTANEOUS ROP ROTATING -550-600 GPM,1025-1350 PSI ON BOTTOM, 950-1050 PSI OFF BOTTOM,60 RPM WHEN ROTATING,192 BIT RPM,3-5 KFT-LBS TORQUE ON BOTTOM,2 KFT-LBS TORQUE OFF,20-25 KLBS WOB -WIPE UP 30'WITH FULL PUMP RATE,RUN DOWN WITH NO PUMPS AT EACH CONNECTION. NO FILL ISSUES -GYRO SURVEY EVERY STAND WITH BIT ON BOTTOM. MWD SURVEYS CLEAN AT 525'MD SURVEY DEPTH,BUT NOT MATCHING GYRO SURVEY AZIMUTH -MINIMAL LOSSES TO FORMATION WHILE DRILLING AHEAD -MW IN/OUT=8.7 PPG,TEMP=62°F,72 YP, '45 LSRYP -PICKUP WEIGHT AT 715'MD=95 KLBS, SLACKOFF=93 KLBS,ROTATING=95 KLBS TOTALACTUAL DRILLING HOURS OVER PAST 24 HRS=6,ROTATING=4.7 HRS, SLIDING=1.3 HRS,JARS=2.1 HRS -BEGAN DIRECTIONAL WORK AT 512'MD, OFFICIAL KOP=576'MD/TVD(>1°INC) 5/29/2016 00:00 - 06:00 6.00 DRILL P SURF DIRECTIONAL DRILL 16"SURFACE HOLE FROM 715'MD AT MIDNIGHT TO 1153'MD(438' IN 6 HRS=73 FPH WITH CONNECTIONS). -50-100 FPH INSTANTANEOUS ROP SLIDING, 150-175 FPH INSTANTANEOUS ROP ROTATING -600 GPM,1350-1450 PSI ON BOTTOM, 1100-1150 PSI OFF BOTTOM,60 RPM WHEN ROTATING,192 BIT RPM,3-5 KFT-LBS TORQUE ON BOTTOM,2 KFT-LBS TORQUE OFF,25-28 KLBS WOB -WIPE UP 30'WITH FULL PUMP RATE,RUN DOWN WITH NO PUMPS AT EACH CONNECTION. NO FILL ISSUES -GYRO SURVEY EVERY STAND WITH BIT ON BOTTOM TO 965'MD BIT DEPTH. MWD SURVEYS AFTER. -MINIMAL LOSSES TO FORMATION WHILE DRILLING AHEAD -MW IN/OUT=8.7 PPG -MATCHING GYRO/MWD SURVEYS: 617'MD, 709'MD,803'MD. RELEASE GYRO AT 04:00 (965'MD BIT DEPTH) -6'ABOVE AND 3'LEFT OF PLAN AT 900'MD. NO ISSUES WITH DIRECTIONAL WORK SO FAR. Printed 8/8/2016 11:19:42AM `AII depths reported in Drillers Depths' • North America-ALASKA-BP • Page 5 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 ; End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 12:00 6.00 DRILL P SURF DIRECTIONAL DRILL 16"SURFACE HOLE FROM 1153'MD TO 1684'MD(531'IN 6 HRS= 89 FPH WITH CONNECTIONS). -100-150 FPH INSTANTANEOUS ROP SLIDING, 150 FPH INSTANTANEOUS ROP ROTATING -650 GPM,1550-1750 PSI ON BOTTOM, 1350-1400 PSI OFF BOTTOM,60 RPM WHEN }ROTATING,203 BIT RPM,5-6 KFT-LBS TORQUE ON BOTTOM,2-3 KFT-LBS TORQUE OFF,30-38 KLBS WOB -BACKREAM 10'AND SURVEY EACH I CONNECTION -MINIMAL LOSSES TO FORMATION WHILE DRILLING AHEAD -MW IN/OUT=8.8 PPG -DIFFICULTY ACHEIVING BUILD RATES BEGINS AT-1100'MD 12:00 - 16:00 4.00 DRILL P SURF DIRECTIONAL DRILL 16"SURFACE HOLE FROM 1684'MD TO 2003'MD,1976'TVD(319' IN 4 HRS=80FPH WITH CONNECTIONS). -100-150 FPH INSTANTANEOUS ROP SLIDING, I 200 FPH INSTANTANEOUS ROP ROTATING 1-650 GPM,1700-1850 PSI ON BOTTOM, 1500-1550 PSI OFF BOTTOM,60 RPM WHEN ROTATING,203 BIT RPM,5-6 KFT-LBS TORQUE ON BOTTOM,2-3 KFT-LBS TORQUE OFF,35-38 KLBS WOB -BACKREAM 10'AND SURVEY EACH CONNECTION I -MINIMAL LOSSES TO FORMATION WHILE DRILLING AHEAD I -MW IN/OUT=8.9 PPG I I -DIFFICULTY ACHIEVING REQUIRED BUILD I RATES;DOGLEGS RANGE FROM 1-3°/100', -8°BEHIND PLANNED INCLINATION OF 24°AT 1 ' 1945'MD. 62'BELOW PLAN,11'RIGHT OF PLAN. SLIDE DRILLING-75'OF STANDS FOR MAJORITY OF THE DAY. -PICKUP WEIGHT AT 2003'MD=130 KLBS, j I SLACKOFF=112 KLBS,ROTATING=120 KLBS '-TOTALACTUAL DRILLING HOURS OVER PAST 24 HRS=10.7,ROTATING=2.5 HRS, i I SLIDING=8.2 HRS,JARS=12.8 HRS -BPERM PICKED OFF ROP INCREASE AT 1848'MD,1827'TVD 16:00 - 18:30 2.50 DRILL P SURF I PLANNED SHORT TRIP: PULL OUT OF THE HOLE WITH 16"DRILLING ASSEMBLY FROM 2003'MD TO BHA AT 774'MD I-FLOWCHECK WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM(STATIC) -PUMP FIRST THREE STANDS OUT OF THE HOLE;650 GPM,1400 PSI,1 STAND PER 20 I MIN,2 BOTTOMS UP(MOSTLY SAND IN RETURNS). -INITIAL PICKUP WEIGHT PUMPS OFF=123 ! IKLBS -NO HOLE ISSUES DURING TRIP AND NO SIGNS OF SWABBING Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Pages of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:30 - 20:00 1.50 DRILL P SURF PLANNED SHORT TRIP: RACK BACK HWDP AND DRILL COLLARS. PICKUP TO INSPECT BIT. -PLUG INTO MWD TOOL ON RIG FLOOR AND DOWNLOAD DATA. -GRADE BIT 6 ON INNER CUTTERS,4 ON OUTER CUTTERS,IN GAUGE,SEE ATTACHED 'PHOTOS -STABILIZERS PARTIALLY BALLED UP WITH (CLAY 20:00 - 21:30 1.50 DRILL P SURF PLANNED SHORT TRIP: RUN BACK IN HOLE WITH 16"DRILLING ASSEMBLY FROM SURFACE TO BHAAT 773'MD -FLOWCHECK WELL PRIOR TO RUN IN HOLE (STATIC) 21:30 - 00:00 2.50 DRILL P SURF PLANNED SHORT TRIP: RUN IN HOLE WITH 16"DRILLING ASSEMBLY FROM BHAAT 773' MD TO BOTTOM AT 2003'MD. WASH FINAL STAND DOWN. NO HOLE ISSUES 5/30/2016 00:00 - 06:00 6.00 DRILL P SURF DIRECTIONAL DRILL 16"SURFACE HOLE FROM 2003'MD AT MIDNIGHT TO 2570'MD (567'IN 6 HRS=95 FPH WITH CONNECTIONS). -250 FPH FPH INSTANTANEOUS ROP SLIDING,250 FPH INSTANTANEOUS ROP ROTATING -575 GPM,1350-1450 PSI ON BOTTOM, 1200-1250 PSI OFF BOTTOM,60 RPM WHEN ROTATING,203 BIT RPM,7-8.5 KFT-LBS TORQUE ON BOTTOM,5-6 KFT-LBS TORQUE OFF,5-10 KLBS WOB -BACKREAM 10'AND SURVEY EACH CONNECTION -MINIMAL LOSSES TO FORMATION WHILE DRILLING AHEAD -MW IN/OUT=8.9 PPG,BEGIN THINNING BACK MUD BELOW BPERM PER WELL PROGRAM -DIFFICULTY ACHIEVING BUILD RATES UP UNTIL-2200'MD,THEN GET 5.5°/100'DL. -DIRECTIONAL SUMMARY AT 2320'MD SURVEY DEPTH: 8°BEHIND ON INC,120' BELOW PLAN,24'RIGHT OF PLAN,NO ISSUES ON TRAVELLING CYLINDER 06:00 - 12:00 6.00 DRILL P SURF DIRECTIONAL DRILL 16"SURFACE HOLE FROM 2570'MD TO 3179'MD(609'IN 6 HRS= 102 FPH WITH CONNECTIONS). -250 FPH FPH INSTANTANEOUS ROP SLIDING/ROTATING -650 GPM,1750-2000 PSI ON BOTTOM, 1600-1650 PSI OFF BOTTOM,60 RPM WHEN ROTATING,203 BIT RPM,9-10 KFT-LBS TORQUE ON BOTTOM,6-7 KFT-LBS TORQUE OFF,15-30 KLBS WOB -WIPE 10'UP WITH PUMPS,NO PUMPS DOWN AND SURVEY EACH CONNECTION -MINIMAL LOSSES TO FORMATION WHILE DRILLING AHEAD -MW IN/OUT=9.1 PPG Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 7 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 18:00 6.00 DRILL P SURF DIRECTIONAL DRILL 16"SURFACE HOLE FROM 3179'MD TO 3660'MD(481'IN 6 HRS= 80 FPH WITH CONNECTIONS). -150-275 FPH FPH INSTANTANEOUS ROP SLIDING/ROTATING -650 GPM,1850-2050 PSI ON BOTTOM, 1650-1750 PSI OFF BOTTOM,60 RPM WHEN ROTATING,203 BIT RPM,12-16 KFT-LBS TORQUE ON BOTTOM,8-10 KFT-LBS TORQUE OFF,10-40 KLBS WOB -WIPE 10'-20'UP WITH PUMPS,NO PUMPS DOWN AND SURVEY EACH CONNECTION MINIMAL LOSSES TO FORMATION WHILE DRILLING AHEAD -MW IN/OUT=8.9 PPG 18:00 - 00:00 6.00 DRILL P SURF DIRECTIONAL DRILL 16"SURFACE HOLE FROM 3660'MD TO 4269'MD,3393'TVD(609' 'IN 6 HRS=95 FPH WITH CONNECTIONS). 150-250 FPH FPH INSTANTANEOUS ROP SLIDING/ROTATING -650 GPM,1750-2050 PSI ON BOTTOM, 1750-1800 PSI OFF BOTTOM,60 RPM WHEN ROTATING,203 BIT RPM,12-16 KFT-LBS 'TORQUE ON BOTTOM,8-10 KFT-LBS TORQUE OFF,10-18 KLBS WOB -WIPE 30'UP WITH PUMPS,NO PUMPS DOWN AND SURVEY EACH CONNECTION -MINIMAL LOSSES TO FORMATION WHILE DRILLING AHEAD -MW IN/OUT=9.0 PPG -ACTUAL DRILLING HRS OVER PAST 24=15.1 HRS,ROTATING=6.1 HRS,SLIDING=9 HRS, JARS=27.1 HRS -PICKUP WEIGHT AT 4269'MD=162 KLBS, SLACKOFF=100 KLBS,ROTATING=123 KLBS -COMPLETE RIG SERVICE AT MIDNIGHT CONNECTION 5/31/2016 00:00 - 07:00 7.00 DRILL P SURF DIRECTIONAL DRILL 16"SURFACE HOLE FROM 4269'MD AT MIDNIGHT TO 4860'MD (591'IN 7 HRS=84 FPH WITH CONNECTIONS). -150-200 FPH INSTANTANEOUS ROP SLIDING/ROTATING -650 GPM,1900-2050 PSI ON BOTTOM,1800 PSI OFF BOTTOM,60 RPM WHEN ROTATING, 203 BIT RPM,14-16 KFT-LBS TORQUE ON BOTTOM,12-14 KFT-LBS TORQUE OFF,10-20 KLBS WOB -WIPE 30'UP WITH PUMPS,NO PUMPS DOWN AND SURVEY EACH CONNECTION MINIMAL LOSSES TO FORMATION WHILE DRILLING AHEAD -MW IN/OUT=9.1 PPG -DIFFERENTIALLY STUCK AFTER MAKING CONNECTION at 4269'MD. FREE PIPE ON UPSTROKE WHILE WORKING 50KLBS DOWN AND 110 KLBS OVER -DIRECTIONAL SUMMARY AT 4405'MD: 122' BELOW PLAN,3'LEFT OF PLAN,SAILING AT -63°INC,WORKING BACK TOWARDS PLAN Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths` • North America-ALASKA-BP • Page 8 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) ' (usft) 07:00 - 11:00 4.00 DRILL N DPRB 4,860.00 SURF UNPLANNED CIRCULATING AND WIPER TRIP: CIRCULATE HOLE CLEAN AND CONDITION MUD TO AVOID DIFFERENTIAL STICKING -REGULARLY OBSERVE DIFFERENTIAL STICKING AFTER MAKING CONNECTIONS. DECISION TO CIRCULATE TO CONDITION MUD AND BACKREAM OUT-5 STANDS TO CHECK HOLE CONDITIONS. CIRCULATE 650-875 GPM,1750-2950 PSI,60 RPM,203-253 TOTAL BIT RPM,14-15 KFT-LBS TORQUE,RECIPROCATING FULL STAND. SIMULATE CONNECTION AFTER CIRCULATING(FAIL,STILL OBSERVING DIFFERENTIAL STICKING). 11:00 - 13:30 2.50 DRILL N DPRB 4,860.00 SURF !UNPLANNED CIRCULATING AND WIPER TRIP: j BACKREAM OUT OF HOLE FROM 4860'MD TO 4232'MD;750 GPM,2300-2500 PSI,60 RPM, 225 TOTAL BIT RPM,15-17 KFT-LBS TORQUE. CONTINUE TO OBSERVE DIFFERENTIAL STICKING ON SEVERAL CONNECTIONS AT 4740'MD AND 4636'MD BIT DEPTHS. -LOWER MUD FILTRATE FROM 12 TO 7. APPEARS TO REDUCE DIFFERENTIAL STICKING AT END OF WIPER TRIP. 13:30 - 14:30 1.00 DRILL N DPRB 4,860.00 SURF UNPLANNED CIRCULATING AND WIPER TRIP: RUN IN HOLE WITH 16"DRILLING ASSEMBLY ION ELEVATORS. NO HOLE ISSUES. SIMULATE CONNECTION PRIOR TO RESUMING DRILLING(PASS WITH NO STICKING). Printed 8/8/2016 11:19:42AM *AII depths reported in Drillers Depths* 410 North America-ALASKA BP • Page 9 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:30 - 20:30 6.00 DRILL P SURF DIRECTIONAL DRILL 16"SURFACE HOLE FROM 4860'MD TO HOLE SECTION TD AT 5222'MD,3812'TVD(362'IN 6 HRS=60 FPH WITH CONNECTIONS). 150 FPH INSTANTANEOUS ROP SLIDING/ROTATING -650-750 GPM,ON BOTTOM: 2100-2300 PSI AT 650 GPM,2700-2850 PSI AT 750 GPM,OFF BOTTOM: 1950 PSIAT 650 GPM,2600 PSI AT 750 GPM,60 RPM WHEN ROTATING,203-225 BIT RPM,13-15 KFT-LBS TORQUE ON BOTTOM,11-12 KFT-LBS TORQUE OFF,15-40 KLBS WOB -WIPE 10-30'UP WITH PUMPS,NO PUMPS DOWN AND SURVEY EACH CONNECTION MINIMAL LOSSES TO FORMATION WHILE DRILLING AHEAD -MW IN/OUT=9.1 PPG,YIELD PT=40 -17:00-18:00: RACK BACK STAND AND TAKE 30'SURVEYS AFTER GETTING 5°DOGLEG AT 4950'MD ACTUAL TOTAL DRILLING HOURS FOR DAILY 'REPORT: 7.7 HRS,ROTATING=5.9 HRS, SLIDING=1.8 HRS -PICKUP WEIGHT=186 KLBS,SLACKOFF= 100 KLBS,ROTATING=130 KLBS -FINAL DIRECTIONAL SUMMARY AT 5159'MD SURVEY DEPTH: 58°INC,254°AZI,100' BELOW PLAN,8'RIGHT OF PLAN PLANNED 13-3/8"SURFACE CASING SET DEPTH=5212'MD,3806'TVD(10'OF PLANNED RATHOLE) -462'MD,217'TVD INTO SHALE AT BASE OF SV4 -92'MD,50'TVD ABOVE SAND AT PROJECTED TOP OF SV3(5304'MD,3856' TVD) 20:30 00:00 3.50 DRILL P SURF PLANNED WIPER TRIP: COMPLETE CIRCULATING HOLE CLEAN WITH TOTAL OF 3 BOTTOMS UP WHILE BACKREAMING OUT OF THE HOLE SLOWLY FROM TD AT 5222'MD TO 4750'MD AT MIDNIGHT. -650-750 GPM,1950-2350 PSI,60 RPM, 203-225 TOTAL BIT RPM,14-15 KFT-LBS TORQUE -SHAKERS HAVE DIFFICULTY HANDLING GREATER THAN 750 GPM WITH THICK MUD RETURNS AT START OF CIRCULATING -RACK BACK ONE STAND PER 20 MIN(285 FPH) 6/1/2016 00:00 - 01:30 1.50 DRILL P SURF PLANNED WIPER TRIP: COMPLETE CIRCULATING HOLE CLEAN WITH TOTAL OF 3 BOTTOMS UP WHILE BACKREAMING OUT OF THE HOLE SLOWLY FROM 4750'MD TO 4500' MD -850 GPM,2800-2900 PSI,60 RPM,247 TOTAL BIT RPM,13-16 KFT-LBS TORQUE -RACK BACK ONE STAND PER 20 MIN(285 FPH) Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 10 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisbume I Site:Lis DS 01 Rig Name/No.:PARKER 272 ! Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs I Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:30 - 08:00 6.50 DRILL P SURF PLANNED WIPER TRIP: PULL OUT OF HOLE WITH 16"DRILLING ASSEMBLY FROM 4500' MD TO 1815'MD -FLOWCHECK WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM(STATIC) -PULLING SPEED ON ELEVATORS=40 FPM -BACKREAM 3995'-3800'MD DUE TO CONSISTENT 50 KLBS OVERPULLS;650 GPM, 1850 PSI,500 FPH,60 RPM,15 KFT-LBS TORQUE -BACKREAM 2800'MD TO 2500'MD DUE TO CONSISTENT 50 KLBS OVERPULLS;650 GPM, 1700 PSI,500 FPH,60 RPM,5-7 KFT-LBS TORQUE,1'BOTTOMS UP -INITIAL PICKUP WEIGHT AT 4500'MD=187 KLBS 08:00 - 11:30 3.50 DRILL P SURF PLANNED WIPER TRIP: RUN IN HOLE WITH 16"DRILLING ASSEMBLY ON ELEVATORS FROM TOP OF WIPER TRIP AT 1815'MD TO HOLE SECTION TD AT 5222'MD. -40-60 FPM RUNNING SPEED -INITIAL SLACKOFF WEIGHT=110 KLBS, FINAL=100 KLBS MINOR DRAG ISSUES OBSERVED ATA FEW DEPTHS. WIPE THROUGH EACH ONE,NO ISSUES. -FILL PIPE EVERY 2000'MD -WASH FINAL STAND DOWN; 170-400 GPM, 600-1050 PSI. NO FILL OBSERVED ON BOTTOM 11:30 - 16:00 4.50 DRILL P SURF CIRCULATE HOLE CLEAN AT SURFACE HOLE TD WITH 3.5 BOTTOMS UP WHILE BACKREAMING SLOWLY OUT OF THE HOLE FROM 5222'MD TO 4469'MD. -900 GPM,3225 PSI INITIAL,3050 PSI FINAL, 60 RPM,14-15 KLBS TORQUE. -RACK BACK 1 STAND PER 20 MIN. -MW IN/OUT=9.1 PPG 16:00 - 19:30 3.50 DRILL P SURF PULL OUT OF THE HOLE WITH 16"DRILLING ASSEMBLY FROM 4469'MD TO BHA AT 773' MD,RACKING BACK 5"DRILLPIPE. -FLOWCHECK WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM(STATIC) -50 FPM PULLING SPEED -NO HOLE ISSUES AND NO SIGNS OF SWABBING -INITIAL PU WEIGHT AT 4469'MD=187 KLBS 19:30 - 00:00 4.50 DRILL P SURF RACK BACK HWDP AND FLEX COLLARS. LAYDOWN 16"DRILLING ASSEMBLY. -PLUG INTO MWD TOOLS ON RIG FLOOR TO DOWNLOAD DATA AND VERIFY TOOLS(PIPE BARN TOO CONGESTED) -GRADE BIT 2 ON INNER TEETH,1 ON OUTER,IN GAUGE STABILIZERS AND BIT COVERED IN CLAY. UPPER 14-1/2"STABILIZER 35'BACK FROM BIT 1.25"UNDERGAUGE. -CLEAN AND CLEAR RIG FLOOR Printed 8/8/2016 11.19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 11 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 6/2/2016 00:00 - 02:00 2.00 CASING P SURF RIG UP TO RUN 13-3/8"SURFACE CASING WITH DOYON CASING SERVICES -8-1/2'BAIL EXTENSIONS,320T VOLANT 7.0 CRT,DOUBLE STACK TONGS(TO MAKEUP HANGER AT END OF RUN),350T SPIDER CASING SLIPS HOLD PJSM WITH RIG TEAM FOR RUNNING PIPE. CONFIRM PIPE COUNT IN PIPE BARN AND PROPER HANDLING EQUIPMENT. 02:00 - 19:00 17.00 CASING P SURF MAKEUP AND RUN IN HOLE WITH 13-3/8",68#, L-80,BTC/HYD563 SURFACE CASING FROM SURFACE TO PLANNED SET DEPTH AT 5212' MD. WASH DOWN LANDING JOINT WITH 5 BPM;450 PSI. -BAKERLOK SHOE TRACK AND CHECK FLOATS(PASS) -RUN WEATHERFORD DIAMONDBACK REAMER FLOAT SHOE,OD=15-1/2" -HYDRIL563 PIPE RUN FROM SURFACE TO 2111'MD TO USE UP INVENTORY ON SLOPE INSTALL TORQUE RINGS IN BTC JOINTS TO INCREASE TORQUE RATING TO 73,590 FT-LBS -APPLY BEST-O-LIFE 2000 THREAD DOPE AND MAKEUP BTC CONNECTIONS WITH VOLANT TOOL TO MARK(21,000 FT-LBS) -APPLY JET LUBE SEAL GUARD AND TORQUE HYD563 CONNECTIONS TO 25 KFT-LBS. -40 FPM RUNNING SPEED -FILL PIPE EVERY JOINT WITH VOLANT. -BREAK CIRCULATION EVERY 10TH JOINT WITH 5 BPM FOR 5 MIN FROM SURFACE TO 1000'MD. -NO CIRCULATION THROUGH LOWER PERMAFROST FROM 1000'MD TO 1860'MD BASE OF PERMAFROST -BREAK CIRCULATION EVERY 10TH JOINT WITH 5 BPM FOR 5 MIN FROM 1860'MD TO SET DEPTH AT 5212'MD -RUN 15-3/4"STRAIGHT BLADE RIGID CENTRALIZER LOCKED DOWN 5'FROM SHOE ON JOINT#1,LOCKED DOWN IN MIDDLE OF JOINT#2 AND FREE FLOATING EVERY JOINT WITH STOP RING 5'FROM PIN FOR HANDLING PURPOSES ON JOINTS C,1-71& 80-128(123 TOTAL CENTRALIZERS,124 STOP RINGS) -OBSERVE SIGNIFICANT DRAG FROM 2300' MD TO SET DEPTH. SUCCESSFULLY WORK THROUGH WITH—50-60 KLBS DOWN WEIGHT. -CIRCULATE ONE BOTTOMS UP AT 3500'MD DUE TO INCREASING DRAG TREND. -FINAL PICKUP WEIGHT=375 KBS(PUMPS OFF),SLACKOFF=90 KLBS(PUMPS OFF). -PUSH AWAY TOTAL OF 168 BBLS DURING CASING RUN. -FINAL EXCEL TALLY ATTACHED Printed 8/8/2016 11:19:42AM "All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 12 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 it Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:00 - 00:00 5.00 CASING P SURF STAGE UP PUMPS. CIRCULATE HOLE CLEAN AND CONDITION MUD WITH 8 TOTAL BOTTOMS UP(2.5 SURFACE TO SURFACE VOLUMES). 10 BPM CEMENTING RATE,INITIAL CIRC PRESSURE=350 PSI,FINAL CIRC PRESSURE =450 PSI -CIRCULATE UNTIL SHAKERS ARE CLEAN, CUT MUD YIELD POINT FROM TO<19 GOING IN MW IN/OUT=9.1 PPG -RECIPROCATE 15'STROKES AT 1000 FPH -NEGLIGIBLE LOSSES WHILE CIRCULATING -INITIAL PU/SO WEIGHTS(PUMPS ON)= 320/140 KLBS,FINAL PU/SO(PUMPS ON)= 345/105 KLBS -MIRU SLB CEMENTERS. PRESSURE TEST LINES WITH WATER TO 250 PSI LOWAND 4000 PSI HIGH FOR FIVE MIN EACH (LEAKTIGHT CRITERIA,PASS). HOLD PJSM FOR CEMENTING WITH RIG TEAM. BATCH UP 100 BBLS MUD PUSH. '-NOTE: CIRCULATING AND CONDITIONING COMPLETED ON 6/3/16 AT 01:00 PUMP STAGE UP: 3 BPM=475 PSI 5 BPM=450 PSI 6 BPM=450 PSI 7 BPM=415 PSI 8 BPM=385 PSI 9 BPM=375 PSI 10 BPM=350 PSI 6/3/2016 00:00 01:00 1.00 CASING P SURF COMPLETE CIRCULATING HOLE CLEAN AND CONDITION MUD FOR CEMENTING -SEE DETAILS OF CIRCULATING IN LAST TIME ENTRY ON 6/2/16 REPORT. Printed 8/8/2016 11:19:42AM *AII depths reported in Drillers Depths* North America-ALASKA-BP • Page 13 oP 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:00 - 06:00 5.00 CEMT P SURF CEMENT 13-3/8",68#,L-80,BTC/HYD563 SURFACE CASING AS FOLLOWS: -SLB PUMP 100 BBLS OF 10.0 PPG MUDPUSH II SPACER @ 5 BPM,200 PSI DISENGAGE VOLANTTOOLAND LAUNCH BOTTOM PLUG. VISUALLY INSPECT BURST DISC AFTER PUSHING DOWN WITH PLUG LAUNCHING TOOL(INTACT) -SLB PUMP 950 BBLS,2792 SACKS OF 11.0 PPG LITECRETE LEAD CEMENT(YIELD=1.91 CUFT/SACK)@ 5.0 BPM;ICP=200 PSI,FCP= 200 PSI,EXCESS VOLUME 350%IN THE PERMAFROST AND 40%BELOW THE PERMAFROST OBSERVE BOTTOM PLUG LAND AT 745 BBLS AWAY INTO LEAD(-24 BBLS EARLY). BURST DISC WITH 400 PSI DIFFERENTIAL AS EXPECTED AFTER 55 BBLS OF COMPRESSION. -RECIPROCATE PIPE 15'STROKES WHILE PUMPING LEAD CEMENT. PARK ON LANDING RING WHEN BATCHING UP TAIL CEMENT. 'UNABLE TO FREE PIPE WITH 100 KLBS OVERPULL WHEN BEGINNING TO PUMP TAIL. -SLB PUMP 65 BBLS,315 SACKS OF 15.8 PPG CLASS G TAIL(YIELD=1.17 CUFT/SACK)@ 5 BPM;340 PSI,EXCESS VOLUME 40% -DISENGAGE VOLANT CRT AND LAUNCH TOP PLUG -SLB KICK OUT PLUG WITH 10 BBLS FRESH WATER PERFORM DISPLACEMENT WITH RIG PUMPS AND 9.1 PPG MAXDRIL-N MUD PER SLB CADE -650 BBLS DISPLACED AT 10 BPM:ICP 400 PSI,FCP 1100 PSI -100 BBLS DISPLACED AT 7 BPM:ICP 870 PSI, FCP 920 PSI -REDUCE RATE TO 2 BPM PRIOR TO PLUG BUMP:FINAL CIRCULATING PRESSURE 740 PSI -BUMP PLUG AND INCREASE PRESSURE TO 1300 PSI. HOLD FOR FIVE MIN. BLEED OFF AND CHECK FLOATS-GOOD -TOTAL DISPLACEMENT VOLUME BY RIG& SLB=769 BBLS(7484 STROKES CALCULATES TO 97%PUMP EFFICIENCY) -325 BBLS 11.0 PPG CEMENT RETURNED TO SURACE(CALCULATED ACTUAL PERMAFROST EXCESS=-90%) -TOTAL LOSSES DURING JOB:115 BBLS -CEMENT IN PLACE AT 06:00 -500 PSI COMPRESSIVE STRENGTH IN TAIL CEMENT AT 23:00 ON 6/3/2016 SIMOPS: PRESSURE TEST CHOKE MANIFOLD OFFLINE TO 250 PSI LOW AND 4000 PSI HIGH FOR FIVE MIN EACH(ALL PASSING TESTS) Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 14 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan l 60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase j Description of Operations (hr) (usft) 06:00 - 09:00 3.00 CASING P SURF RIG DOWN AFTER RUNNING CASING AND CEMENTING. -BACKOUT AND LAYDOWN LANDING JOINT -DRAIN CEMENT FROM STACK INTO WELL I CELLAR AND EMPTY CELLAR WITH SUPERSUCKER. -SEND OUT 350T SPIDER SLIPS,VOLANT TOOL,SIDE DOOR ELEVATORS AND BAIL EXTENSIONS FLUSH STACK AND DIVERTER ANNULAR PREVENTER WITH CONTAM PILLS -FOUR BOLT LOW PRESSURE RISERS AND RIG DOWN DIVERTER OUTLET LINE 09:00 - 13:30 4.50 DIVRTR P SURF NIPPLE DOWN DIVERTER SYSTEM. -SET ANNULAR PREVENTER ON TRAVELLING CART IN BOP DECK. SEND KNIFE VALVE'T' OUTSIDE. -NIPPLE DOWN RISER TO CONDUCTER ADAPTER"SPEED HEAD" -CLEANOUT FLOWBOX UNDER RIG FLOOR WITH SUPERSUCKER 13:30 - 15:30 2.00 WHSUR P SURF SET AND NIPPLE UP FMC GEN 5 WELLHEAD+ 13-5/8"5K TUBING SPOOL WITH FMC REP. ALIGN ANNULUS OUTLETS FACING FRONT TO BACK WHEN LOOKING AT FROM CENTER OF DRILLSITE. -INSTALL DOUBLE ANNULUS WORKING VALVES ON IA AND OA. -SINGLE GATE VALVE WITH NEEDLE VALVE ON NON-WORKING IA OUTLET -COMPANION FLANGE WITH BLEEDER WITH VR PLUG ON NON-WORKING OA OUTLET 15:30 - 17:00 1.50 WHSUR P SURF FMC REP ON LOCATION TO TEST CASING HEAD SEALS TO 250 PSI LOW FOR FIVE MIN AND 800 PSI HIGH FOR 15 MIN(PASSING TESTS,SEE ATTACHED CHART). -SET HIGH PRESSURE RISERS AND ENERGIZE WELLHEAD SEAL PRIOR TO TESTING RIG CREW CHANGE UPPER RAMS FROM 2-7/8"X 5"VBRS TO 9-5/8"CASING RAMS PER OCN#2 17:00 - 21:30 4.50 BOPSUR P SURF NIPPLE UP HIGH PRESSURE RISERS AND BOPE(RENTAL CAMERON STACK DURING RECERTIFICATION OF SHAFFER STACK). MAX ANTICIPATED SURFACE PRESSURE DURING INTERVAL=2430 PSI -13-5/8"5K SHAFFER ANNULAR PREVENTER -9-5/8"5K CAMERON UPPER RAMS -BLIND-SHEAR CAMERON RAMS -MUD CROSS !-3-1/2"X 5-7/8"CAMERON LOWER VARIABLE BORE RAMS 21:30 - 23:00 1.50 BOPSUR P SURF RIG UP TO TEST ROPE. -RUN IN HOLE WITH 5"TEST JOINT. FILL STACK WITH WATER AND PERFORM SHELL TEST TO CHECK FOR LEAKS. Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP Page 15 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To Hrs Task Code I NPT NPT Depth Phase Description of Operations (hr) (usft) 23:00 - 00:00 1.00 BOPSUR P SURF I PRESSURE-FUNCTION TEST BOPE PER BP STANDARDS AND AOGCC REGULATIONS -TEST ANNULAR WITH 5"TEST JOINT TO 250 PSI LOWAND 3500 PSI HIGH FOR FIVE MIN EACH -TEST UPPER RAMS WITH 9-5/8"TEST JOINT TO 250 PSI LOWAND 4000 PSI HIGH FOR FIVE MIN EACH -TEST LOWER RAMS WITH 5"TEST JOINT TO 250 PSI LOW AND 4000 PSI HIGH FOR FIVE MIN EACH -CHOKE MANIFOLD TESTED OFFLINE EARLIER IN DAY RESULTED IN ONLY FIVE BOP TESTS REMAINING FOR THIS TIME INTERVAL. -NO FAILURES,SEE ATTACHED DOCUMENTATION -AOGCC WITNESS WAIVED BY ;REPRESENTATIVE JEFF JONES -NOTE: TESTING COMPLETED AT 02:00 ON 6/4/16 6/4/2016 00:00 - 02:00 2.00 BOPSUR P SURF 'COMPLETE BOPE TESTING -SEE DETAILS OF TEST ON FINAL TIME -ENTRY OF 6/3/16 REPORT. 02:00 - 03:00 1.00 BOPSUR P SURF RIG DOWN AFTER TESTING. 03:00 - 03:30 0.50 WHSUR P SURF INSTALL WEAR RING,ID=12-1/2",AND TORQUE LOCKDOWN SCREWS TO 400 FT-LBS 03:30 - 05:00 1.50 CASING R SURF PRESSURE TEST 13-3/8"SURFACE CASING TO 250 PSI LOW FOR FIVE MIN AND 3500 PSI HIGH FOR 30 MIN AGAINST BLIND RAMS. -PASSING TEST PER BP 10-45 CRITERIA -PUMP IN VOLUME=10.5 BBLS=BLEED BACK VOLUME=ACCEPTABLE -APPROVAL TO PROCEED GRANTED BY WSUP,DOCUMENTS ATTACHED -LOSE 10 PSI IN FIRST 15 MIN AND 5 PSI IN ,SECOND 15 MIN TEST AGAINST OUTER OAAND IA WORKING ANNULUS VALVES 05:00 - 05:30 0.50 CASING P SURF HOLD MR WITH RIG TEAM TO DISCUSS SURFACE HOLE LEARNINGS. PRE-JOB SAFETY MEETING TO REVIEW PLAN FORWARD&UPCOMING HAZARDS FOR 12-1/4"INTI DRILLING SECTION. 05:30 06:00 0.50 CASING P SURF RIG DOWN AFTER CASING TEST Printed 8/8/2016 11 19:42AM `AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 16 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 10:00 4.00 CASING P SURF MAKEUP AND RUN IN HOLE WITH 12-1/4" ROTARY STEERABLE(RSS)DRILLING ASSEMBLY FROM SURFACE TO 1098' OVERALL LENGTH -FLOWCHECK WELL PRIOR TO RUNNING IN HOLE(STATIC) -BHA WEIGHT=102 KLBS,40 KLBS ABOVE JARS,62 KLBS BELOW JARS -NEW SECURITY 12-1/4"MM65M PDC,SERIAL #12492220 -9-1/2"AUTOTRAK ROTARY STEERABLE WITH NEAR BIT INC,GR/RES/PWD/DIRNSS (8-1/4"ONTRAK),JARS 844'BEHIND BIT, PORTED FLOAT INSTALL 12-1/4"GAUGE HOLE GHOST REAMERS AT 1092'AND 2049'BACK FROM THE BIT INSTALL NOV BLACK BOXES TO RECORD DOWNHOLE STICK-SLIP DATAAT 165'AND '2045'BACK FROM THE BIT -PLUG INTO MWD ON RIG FLOOR TO VERIFY TOOLS. SHALLOW HOLE TEST AT 1100'MD (PASS). 10:00 - 12:00 2.00 CASING P SURF -RUN IN HOLE WITH 12-1/4"RSS DRILLING ASSEMBLY ON 5"DRILLPIPE FROM BHAAT 1098'MD TO 4615'MD -1.15FF PIPE DOPE ON 5"DRILLPIPE,MU TORQUE=37KFT-LBS -200 FPM TRIPPING SPEED 12.00 - 13:30 1.50 CASING P SURF SLIP AND CUT 51',6 WRAPS OF 1-3/8"DRILL LINE '-1191 TON-MILES 13:30 - 16:30 3.00 CASING P SURF PERFORM KWT,STRIPPING AND WELL KILL DRILLS WITH MASSIE CREW. HOLD MR AFTER DRILLS TO DISCUSS LEARNINGS AND WORK SAFE PROCEDURE UPDATES. 16:30 - 17:00 0.50 CASING P SURF SERVICE AND LUBRICATE RIG 17:00 - 18:30 ' 1.50 CASING P SURF WASH DOWN WITH 12-1/4"RSS DRILLING ASSEMBLY FROM 4615'MD TO 5126'MD. TAG I PLUGS ON DEPTH. TAG CEMENT STRINGERS AND CLEANOUT CEMENT FROM 5104'MD(22' ABOVE FLOAT COLLAR). -RECORD SLOW PUMP RATES -720 GPM,2050 PSI,30-50 FPM -FILL PIPE EVERY 20 STANDS 18:30 - 21:30 3.00 DRILL P SURF DRILL UP CEMENT PLUGS AND HARD CEMENT IN SHOE TRACK FROM FLOAT COLLAR AT 5126'MD TO 5202'MD(10'ABOVE SHOE AT 5212'MD. -DRILL PLUGS WITH 3-8 KLBS WOB,50-60 RPM,15 KFT-LBS TORQUE,600 GPM,1400 PSI -DRILL HARD CEMENT WITH 5 KLBS WOB, 850 GPM,2700 PSI,65 RPM,15 KFT-LBS TORQUE,150 FPH -MW IN/OUT=9.2 PPG -2:15 TO DRILL CEMENT PLUGS PER WEATHERFORD PROCEDURE Printed 8/8/2016 11:19:42AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP . Page 17 of 97 Operation Summary Report Common Wet Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:30 - 23:00 1.50 CASING P SURF DISPLACE WELL FROM 9.2 PPG MAXDRIL-N TO NEW 9.6 PPG LSND -900 GPM,2150 PSI ICP,2235 PSI FCP, RECIPROCATE 20'STROKES,65 RPM,16 KFT-LBS INITIAL TORQUE,11 KFT-LBS FINAL TORQUE -OVERDISPLACE BY ONLY-25 BBLS TO GET CLEAN RETURNS -PUMP 35 BBL 8.33 PPG FRESH WATER AND 35 BBL 9.6 PPG LSND HI-VIS SPACERS AHEAD OF NEW MUD -FLOWCHECK WELL FOR 10 MIN AFTER DISPLACEMENT(STATIC) -RECORD NEW SLOW CIRCULATING RATES 23:00 - 00:00 1.00 DRILL P SURF DRILL UP FINAL 10'OF SHOE TRACKAND WEATHERFORD REAMER FLOAT SHOE FROM 5202'MD TO 5212'MD. -5 KLBS WOB,850 GPM,1975 PSI,65-100 RPM,11-15 KFT-LBS TORQUE -40 MINUTES TO DRILL UP REAMER SHOE 6/5/2016 00:00 - 00:30 0.50 CASING P „ SURF DRILL 10'RATHOLE+20'OF NEW FORMATION BEYOND SURFACE HOLE TD FROM 5222'MD TO 5242'MD MONITOR WELL FOR 10 MIN OUTSIDE 13-3/8"SHOE(STATIC) -850 GPM,1960 PSI,100 RPM, 11K-12K TQ 00:30 - 01:30 1.00 CASING P SURF CIRCULATE BOTTOMS-UP INSIDE 13-3/8" SHOE PRIOR TO LOT -1000 GPM,2580 PSI,10 RPM,10-11K TQ -RECIPROCATE PIPE 30' -PUMP 40 BBL EP-MUD LUBE SWEEP -CONFIRM MW IN=MW OUT=9.6 PPG MONITOR WELL FOR 10 MIN(STATIC) 01:30 03:00 1.50 DRILL P SURF PERFORM LOTTO 13.3 PPG EMW -13-3/8"CASING SHOE AT 5212'MD/3807' TVD,MW=9.6 PPG -PUMP AT 1 BPM TO PRESSURE BREAKOVER AND HOLD FOR 10 MIN -SEE ATTACHED CHART(BBL IN=9.4,BBL OUT=1.7) -DISCUSS RESULTS WITH ODE AND AGREE WITH 751 PSI LEAKOFF PRESSURE(13.39 PPG EMW) -EXCEEDS MINIMUM 25 BBL KICK TOLERANCE REQUIREMENT OF 11.52 PPG EMW 03:00 - 03:30 0.50 DRILL P SURF OBTAIN INITIAL ECD BENCHMARK READINGS AT 1000 GPM,2670 PSI -ECD=9.94 PPG ATO RPM ECD=10.0 PPG AT 150 RPM -DOWNLINK TO RSS Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* North America-ALASKA-BP Page 18 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:30 - 06:00 2.50 DRILL P INTI DIRECTIONAL DRILL 12-1/4"INTI HOLE FROM 5242'MD TO 5470'MD(228'IN 2.5 HRS=91 FPH WITH CONNECTIONS) -INSTANTANEOUS ROP=150 FPH(MAX PER PROGRAM) -900-1000 GPM,2300-2670 PSI,120 RPM,13 KFT-LBS TQ,10 KLBS WOB -PU 196K,SO 90K,ROT 135K -MW IN/OUT=9.6 PPG -ECD:CALC=10.0 PPG,ACTUAL=10.0 PPG -SURVEY EVERY STAND FOR DLS UNDER 5° NO LOSSES WHILE DRILLING AHEAD -LOG 13-3/8"CASING SHOE AT 5213'MD(NO DEPTH CORRECTION MADE TO TALLY SET DEPTH AT 5212'MD) ACTIVATE NOV SOFT-SPEED PROGRAM EVERY OTHER STAND AS PART OF EXPERIMENT WITH NOV BLACK BOXES TO DETERMINE EFFECTIVENESS OF SOFTWARE IN MANAGING STICK-SLIP. CLEAN MWD SURVEY AT 5237'MD SURVEY DEPTH(WITHIN 100'OF PREVIOUS SURVEY DEPTH IN SURFACE SECTION) SV3 AT 5285'MD,3846'TVD,10'HIGH 06:00 - 12:00 6.00 DRILL P INTI DIRECTIONAL DRILL 12-1/4"INTI HOLE FROM 5470'MD TO 6330'MD THROUGH SV FORMATIONS(860'IN 6 HRS=143 FPH WITH CONNECTIONS) -1000 GPM,2850-3225 PSI ON/OFF BOTTOM, 150 RPM,11-13 KFT-LBS TQ ON BOTTOM, 12-15K FT-LBS OFF,12-18 KLBS WOB MW IN/OUT=9.7 PPG,YP=25,FILTRATE= 5.8,1.5%LUBRICANTS -ECD:CALC=10.0 PPG,ACTUAL=10.0-10.5 PPG -SURVEY EVERY STAND,NO BACKREAMING AT CONNECTIONS -NO LOSSES WHILE DRILLING AHEAD -ACTIVATE NOV SOFT-SPEED PROGRAM EVERY OTHER STAND AS PART OF EXPERIMENT WITH NOV BLACK BOXES TO DETERMINE EFFECTIVENESS OF SOFTWARE IN MANAGING STICK-SLIP. SWEEPS: -5850'MD: 35 BBL WEIGHTED(1.5PPG OVER) -75%INCREASE IN RETURNS -6319'MD: 35 BBL WEIGHTED(1.5PPG OVER) -100%INCREASE IN RETURNS SV2 AT 5640'MD,4011'TVD,2'HIGH Printed 8/8/2016 11:19:42AM *AII depths reported in Drillers Depths* III • North America-ALASKA BP • Page 19 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM 'Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 18:00 6.00 , DRILL P INTI DIRECTIONAL DRILL 12-1/4"INTI HOLE FROM 6330'MD TO 7077'MD THROUGH SV FORMATIONS(74T IN 6 HRS=125 FPH WITH 'CONNECTIONS) 1000 GPM,3175-3300 PSI ON/OFF BOTTOM, 150 RPM,14-15 KFT-LBS TQ ON BOTTOM, 12-14K FT-LBS OFF,14-20 KLBS WOB -MW IN/OUT=9.7 PPG,YP=25,FILTRATE= 5.4,1.5%LUBRICANTS -ECD:CALC=10.0 PPG,ACTUAL=10.3-10.4 PPG -SURVEY EVERY STAND,NO BACKREAMING AT CONNECTIONS -NO LOSSES WHILE DRILLING AHEAD -ACTIVATE NOV SOFT-SPEED PROGRAM EVERY OTHER STAND AS PART OF EXPERIMENT WITH NOV BLACK BOXES TO DETERMINE EFFECTIVENESS OF SOFTWARE IN MANAGING STICK-SLIP. 'SWEEPS: -6804'MD: 35 BBL WEIGHTED(1.5PPG OVER) '-100%INCREASE IN RETURNS SV1 AT 6509'MD,4387'TVD,1'LOW Printed 8/8/2016 11:19:42AM `AIL depths reported in Drillers Depths* • North America-ALASKA-BP • Page 20 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:00 - 00:00 6.00 DRILL P INTI DIRECTIONAL DRILL 12-1/4"INTI HOLE FROM 7077'MD TO 7763'MD THROUGH SV AND UGNU FORMATIONS(747'IN 6 HRS=125 FPH WITH CONNECTIONS) -1000 GPM,3300-3500 PSI ON/OFF BOTTOM, 150 RPM,15-19 KFT-LBS TQ ON BOTTOM, 12-14K FT-LBS OFF,14-20 KLBS WOB -PICKUP WEIGHT AT 7763'MD=232 KLBS, SLACKOFF=120 KLBS,ROTATING=145 KLBS -MW IN/OUT=9.7 PPG,YP=25,FILTRATE= 5.7,1.5%LUBRICANTS -ECD:CALC=10.2 PPG,ACTUAL=10.3-10.5 PPG -SURVEY EVERY STAND,NO BACKREAMING AT CONNECTIONS -NO LOSSES WHILE DRILLING AHEAD -ACTIVATE NOV SOFT-SPEED PROGRAM EVERY OTHER STAND AS PART OF EXPERIMENT WITH NOV BLACK BOXES TO DETERMINE EFFECTIVENESS OF SOFTWARE IN MANAGING STICK-SLIP. SOFTSPEED GENERALLY APPEARS TO SMOOTH OUT ERRATIC TORQUE WHEN UTILIZED(5.4%STICK-SLIP WHEN ACTIVE VS 23.3%WHEN INACTIVE,SEE ATTACHED NOV REPORT) -HEAVY COAL RETURNS AT SHAKERS WHEN DRILLING THROUGH TOP OF UGNU -ACTUAL DRILLING HOURS FOR PAST 24 HOURS ON REPORT=13.5 -DIRECTIONAL SUMMARY AT 7699'MD: 0' ABOVE/BELOW PLAN,14'LEFT OF PLAN -HOLD UNANNOUNCED D2(KICK WHILE DRILLING)DRILL AND AAR WITH MASSIE CREW SWEEPS: -7363'MD: 35 BBL WEIGHTED(1_5PPG OVER) -100%INCREASE IN RETURNS UG4 AT 7580'MD,4849'TVD,17'LOW UG4AAT 7660'MD,4884'TVD,22'LOW Printed 8/8/2016 11:19:42AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 21 of 97 A Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisbume Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 6/6/2016 00:00 - 01:30 1.50 DRILL P INTI I DIRECTIONAL DRILL 12-1/4"INTI HOLE FROM 7763'MD TO 7937'MD,THROUGH UGNU 1 FORMATIONS(174'IN 1.5 HRS=116 FPH WITH CONNECTIONS) -1000 GPM,3500-3550 PSI ON/OFF BOTTOM, 1150 RPM,16-21 KFT-LBS TO ON BOTTOM, 14-15K FT-LBS OFF,14-18 KLBS WOB -MW IN/OUT=9.7 PPG,YP=24,FILTRATE= 5.2,1.5%LUBRICANTS -ECD:CALC=10.2 PPG,ACTUAL=10.5 PPG -SURVEY EVERY STAND,NO BACKREAMING AT CONNECTIONS I-NO LOSSES WHILE DRILLING AHEAD -ACTIVATE NOV SOFT-SPEED PROGRAM EVERY OTHER STAND AS PART OF EXPERIMENT WITH NOV BLACK BOXES TO DETERMINE EFFECTIVENESS OF SOFTWARE IN MANAGING STICK-SLIP. 7937'MD-OBSERVE ERRATIC PUMP PRESSURE+SEVERAL STANDS OF DETERIORATING PU/SO/TQ TRENDS. FLOWCHECK WELL(STATIC). 30 KLBS OVERPULLAND NO ROTATION POSSIBLE WHEN TRYING TO RESUME DRILLING. II DE N CSO TO RACK STAND BACK AND CIRCULATE HOLE CLEAN. SWEEPS: -7834'MD: 35 BBL WEIGHTED(1.5PPG OVER) -150%INCREASE IN RETURNS. SWEEP RETURNED-1000 STROKES EARLY. 01:30 - 05:00 3.50 DRILL P INTI CIRCULATE HOLE CLEAN WITH 1.5 BOTTOMS UP. -1000 GPM,3575 PSI,150 RPM,11-15 KFT-LBS TQ,RECIPROCATING FULL STAND 600 FPH -PUMP 35 BBL LO-VIS,35 BBL WEIGHTED SWEEP WITH MINIMAL RETURNS AT SHAKERS. -ECD CLEANHOLE=10.2 PPG,ACTUAL 10.4 PPG INITIAL-10.2 PPG FINAL Printed 8/8/2016 11.19.42AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 22 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:00 - 09:00 4.00 DRILL P INTI DIRECTIONAL DRILL 12-1/4"INTI HOLE FROM 7937'MD TO 8354'MD,THROUGH UGNU FORMATIONS(417'IN 4 HRS=104 FPH WITH CONNECTIONS) 1000 GPM,3450-3500 PSI ON/OFF BOTTOM, 150 RPM,15-21 KFT-LBS TQ ON BOTTOM,17 KFT-LBS OFF,10-20 KLBS WOB -MW IN/OUT=9.7 PPG,YP=29,FILTRATE= 5.4,1.5%LUBRICANTS -ECD:CALC=10.2 PPG,ACTUAL=10.3 PPG -SURVEY EVERY STAND,NO BACKREAMING AT CONNECTIONS NO LOSSES WHILE DRILLING AHEAD -ACTIVATE NOV SOFT-SPEED PROGRAM EVERY OTHER STAND AS PART OF EXPERIMENT WITH NOV BLACK BOXES TO DETERMINE EFFECTIVENESS OF SOFTWARE IN MANAGING STICK-SLIP. -175 PSI INSTANTANEOUS PUMP PRESSURE DROP OBSERVED AT 7940'MD;NO ISSUES 'WITH SURFACE EQUIPMENT '8354'MD-OBSERVE HIGH TORQUE AND TIGHT HOLE SIGNS WHILE ON BOTTOM DRILLING. DECISION TO CIRCULATE BOTTOMS UP. SWEEPS: -7936'MD: 35 BBLS LO-VIS/WEIGHTED SWEEPS WITH 100%INCREASE IN CUTTINGS AT SHAKERS,30 BBLS EARLY UG3 AT 8099'MD,5092'TVD,27'LOW 09:00 - 11:00 2.00 DRILL P INTI CIRCULATE HOLE CLEAN WITH 2 BOTTOMS UP -1000 GPM,3400 PSI,130 RPM,17-21 KFT-BS TQ,RECIPROCATE 30'STROKES -ECD CLEANHOLE=ACTUAL=10.2 PPG Printed 8/8/2016 11:19:42AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP Page 23 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:00 - 18:00 7.00 DRILL P INTI DIRECTIONAL DRILL 12-1/4"INTI HOLE FROM 8354'MD TO 8916'MD,THROUGH UGNU FORMATIONS(562'IN 7 HRS=80 FPH WITH CONNECTIONS) -150 FPH INSTANTANEOUS ROP -1000 GPM,3400-3675 PSI ON/OFF BOTTOM, 130-170 RPM WITH SOFT-SPEED,17-24 KFT-LBS TQ ON BOTTOM,16 KFT-LBS OFF, 15-20 KLBS WOB ' -MW IN/OUT=9.7 PPG,YP=29,FILTRATE= 5,1.5%LUBRICANTS -ECD:CALC=10.2 PPG,ACTUAL=10.3-10.4 PPG -SURVEY EVERY STAND,NO BACKREAMING AT CONNECTIONS -NO LOSSES WHILE DRILLING AHEAD -NOV SOFT SPEED ON 100%OF DRILLING TO 'CONTROL STICK-SLIP THROUGH SURFACE RPM ADJUSTMENTS ' -1/2"PIECES OF COAL IN RETURNS AT SHAKERS THROUGHOUT INTERVAL SWEEPS: 8425'MD: 35 BBLS LO-VIS/HI-VIS SWEEPS 'WITH 75%INCREASE IN CUTTINGS AT SHAKERS,35 BBLS EARLY 18:00 - 00:00 6.00 DRILL P INTI DIRECTIONAL DRILL 12-1/4"INTI HOLE FROM 8916'MD TO 9322'MD,5705'TVD THROUGH I UGNU FORMATIONS(406'IN 6 HRS=68 FPH WITH CONNECTIONS) -50-150 FPH INSTANTANEOUS ROP -1000 GPM,3700-3825 PSI ON/OFF BOTTOM, 120 RPM,18-23 KFT-LBS TQ ON BOTTOM,20 KFT-LBS OFF,14-22 KLBS WOB -MW IN/OUT=9.7 PPG,YP=30,FILTRATE= 5.1,1.5%LUBRICANTS -ECD:CALC=10.2 PPG,ACTUAL=10.3-10.4 PPG -PICKUP WEIGHT AT MIDNIGHT=263 KLBS, SLACKOFF=130 KLBS,ROTATING=162 KLBS -SURVEY EVERY STAND,NO BACKREAMING AT CONNECTIONS -NO LOSSES WHILE DRILLING AHEAD -BEGIN 2°/100'DROP AND LEFT TURN PER DIRECTIONAL PLAN AT 8800'MD -NOV SOFT SPEED ON 100%OF DRILLING TO CONTROL STICK-SLIP THROUGH SURFACE RPM ADJUSTMENTS -ACTUAL DRILLING HOURS FOR PAST 24 HOURS ON REPORT=14 -DIRECTIONAL SUMMARY AT 9311'MD: 15' BELOW PLAN,10 LEFT OF PLAN SWEEPS: -8973'MD: 35 BBLS 1.5PPG OVER WEIGHTED SWEEP WITH 100%INCREASE IN CUTTINGS AT SHAKERS,60 BBLS EARLY -9261'MD: 35 BBLS 1.5PPG OVER WEIGHTED SWEEP WITH 100%INCREASE IN CUTTINGS AT SHAKERS Printed 8/8/2016 11:19:42AM *AII depths reported in Drillers Depths° NorthAmerica-ALASKA-BP • Page24of97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 6/7/2016 00:00 - 06:00 6.00 DRILL P INTI DIRECTIONAL DRILL 12-1/4"INTI HOLE FROM 9322'MD TO 9825'MD,THROUGH UGNU FORMATIONS(503'IN 6 HRS=84 FPH WITH CONNECTIONS) -150 FPH INSTANTANEOUS ROP(MAX PER PROGRAM) -1000 GPM,3980-4000 PSI ON/OFF BOTTOM, 120 RPM,21-26 KFT-LBS TQ ON BOTTOM, 19-24 KFT-LBS OFF,8-17 KLBS WOB -MW IN/OUT=9.7 PPG,YP=30,FILTRATE= 4.7,1.5%LUBRICANTS -ECD:CALC=10.2 PPG,ACTUAL=10.4-10.5 PPG -SURVEY EVERY STAND,NO BACKREAMING AT CONNECTIONS NO LOSSES WHILE DRILLING AHEAD -NOV SOFT SPEED ON 100%OF DRILLING TO CONTROL STICK-SLIP THROUGH SURFACE RPM ADJUSTMENTS SWEEPS: -9634'MD: 35 BBL WEIGHTED(1.5PPG OVER) 100%INCREASE IN RETURNS. SWEEP RETURNED-300 STROKES EARLY. 06:00 - 12:00 6.00 DRILL P INTI DIRECTIONAL DRILL 12-1/4"INTI HOLE FROM 9825'MD TO 10320'MD,THROUGH UGNU/WS /CM FORMATIONS(495'IN 6 HRS=83 FPH WITH CONNECTIONS) -120-150 FPH INSTANTANEOUS ROP(LIMIT FOR ECD) -900 GPM,3725-3740 PSI ON/OFF BOTTOM, 120 RPM,23-26 KFT-LBS TQ ON BOTTOM, 17-25 KFT-LBS OFF,10-20 KLBS WOB -MW IN/OUT=10.5 PPG,YP=27,FILTRATE= 5.1,1.5%LUBRICANTS -ECD:CALC=10.2-11.0 PPG,ACTUAL= 10.5-11.1 PPG -SURVEY EVERY STAND,NO BACKREAMING AT CONNECTIONS -NO LOSSES WHILE DRILLING AHEAD -NOV SOFT SPEED ON 100%OF DRILLING TO CONTROL STICK-SLIP THROUGH SURFACE RPM ADJUSTMENTS WEIGHT UP TO 10.5 PPG PRIOR TO CM3 Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* North America-ALASKA-BP • Page 25 of 97 Operation Summary Report Common Wet Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 18:00 6.00 DRILL P INTI DIRECTIONAL DRILL 12-1/4"INTI HOLE FROM 10320'MD TO 10622'MD,THROUGH CM FORMATIONS(302'IN 6 HRS=50 FPH WITH CONNECTIONS) -50-100 FPH INSTANTANEOUS ROP(LIMIT FOR ECD) -900 GPM,3780 PSI ON/OFF BOTTOM,120 RPM,25-29 KFT-LBS TQ ON BOTTOM,19-28 KFT-LBS OFF,10-20 KLBS WOB -MW IN/OUT=10.5 PPG,YP=24,FILTRATE= 5.1,1.5%LUBRICANTS ECD:CALC=11.0 PPG,ACTUAL=11.0 PPG -SURVEY EVERY STAND,NO BACKREAMING AT CONNECTIONS NO LOSSES WHILE DRILLING AHEAD -NOV SOFT SPEED ON 100%OF DRILLING TO CONTROL STICK-SLIP THROUGH SURFACE RPM ADJUSTMENTS SWEEPS: -10406'MD: 70 BBL WEIGHTED(1.5PPG OVER)-100%INCREASE IN RETURNS. 18:00 - 00:00 6.00 DRILL P INTI DIRECTIONAL DRILL 12-1/4"INTI HOLE FROM 10622'MD TO 11057'MD,THROUGH CM FORMATIONS(435'IN 6 HRS=73 FPH WITH CONNECTIONS) -100 FPH INSTANTANEOUS ROP(LIMIT FOR ECD) -900 GPM,3830 PSI ON/OFF BOTTOM,120 RPM,26 KFT-LBS TQ ON BOTTOM,24 KFT-LBS OFF,20 KLBS WOB -MW IN/OUT=10.5 PPG,YP=23,FILTRATE= 5.4,1.5%LUBRICANTS -ECD:CALC=10.95 PPG,ACTUAL=11.0 PPG -PICKUP WEIGHT AT MIDNIGHT=295 KLBS, SLACKOFF=148 KLBS SURVEY EVERY STAND,NO BACKREAMING AT CONNECTIONS -NO LOSSES WHILE DRILLING AHEAD -NOV SOFT SPEED ON 100%OF DRILLING TO CONTROL STICK-SLIP THROUGH SURFACE RPM ADJUSTMENTS SWEEPS: -10678'MD: 70 BBL WEIGHTED(1.5PPG OVER)-100%INCREASE IN RETURNS. ACTUAL DRILLING HOURS FOR PAST 24 HOURS ON REPORT=17.9 HR DIRECTIONAL SUMMARY AT 11014'MD: 9' BELOW PLAN,3'RIGHT OF PLAN Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 26 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 6/8/2016 00:00 - 06:00 6.00 DRILL P INTI DIRECTIONAL DRILL 12-1/4"INTI HOLE FROM 11057'MD TO 11325'MD,THROUGH CM FORMATIONS(268'IN 6 HRS=45 FPH WITH CONNECTIONS) -70-100 FPH INSTANTANEOUS ROP 900 GPM,3880 PSI,100 RPM(REDUCE DUE TO HIGH TQ),25-30 KFT-LBS TO ON BOTTOM, 17 KLBS WOB -MW IN/OUT=10.5 PPG,YP=26,FILTRATE= 5.3,1.5%LUBRICANTS -ECD:CALC=10.95 PPG,ACTUAL=11.05 PPG -SURVEY EVERY STAND,NO BACKREAMING AT CONNECTIONS -NO LOSSES WHILE DRILLING AHEAD -NOV SOFT SPEED ON 100%OF DRILLING TO CONTROL STICK-SLIP THROUGH SURFACE RPM ADJUSTMENTS SWEEPS: -11115'MD: 70 BBL WEIGHTED(1.5PPG OVER)-100%INCREASE IN RETURNS. INCORPORATE BLACK PRODUCT SPIKE FLUID PRIOR TO THRZ 06:00 - 12:00 6.00 DRILL P INTI DIRECTIONAL DRILL 12-1/4"INTI HOLE FROM 11325'MD TO 11610'MD,THROUGH CM FORMATIONS(285'IN 6 HRS=48 FPH WITH CONNECTIONS) -70-100 FPH INSTANTANEOUS ROP -900 GPM,4000 PSI,120 RPM,25-28 KFT-LBS TQ ON BOTTOM,18-20 KLBS WOB -MW IN/OUT=10.5/10.6 PPG,YP=26, FILTRATE=3.9,2.0%LUBRICANTS -ECD:CALC=10.96 PPG,ACTUAL=11.05 PPG -SURVEY EVERY STAND,BACKREAMING 15' AT CONNECTIONS -NO LOSSES WHILE DRILLING AHEAD -NOV SOFT SPEED ON FOR MOST OF DRILLING TO CONTROL STICK-SLIP THROUGH SURFACE RPM ADJUSTMENTS INCORPORATE BLACK PRODUCT SPIKE FLUID PRIOR TO THRZ Printed 8/8/2016 11:19:42AM 'All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 27 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 17:30 5.50 DRILL P INTI DIRECTIONAL DRILL 12-1/4"INTI HOLE FROM 11610'MD TO 11904'MD,THROUGH CM FORMATIONS(294'IN 5.5 HRS=53 FPH WITH CONNECTIONS) -70-100 FPH INSTANTANEOUS ROP -900 GPM,4020 PSI,120 RPM,22-25 KFT-LBS TQ ON BOTTOM,9 KLBS WOB -MW IN/OUT=10.5 PPG,YP=25,FILTRATE= 3.0,2.25%LUBRICANTS ECD:CALC=10.95 PPG,ACTUAL=11.06 PPG -SURVEY EVERY STAND,BACKREAMING 15' AT CONNECTIONS -NO LOSSES WHILE DRILLING AHEAD -NOV SOFT SPEED ON FOR MOST OF DRILLING TO CONTROL STICK-SLIP THROUGH SURFACE RPM ADJUSTMENTS SWEEPS: -11652'MD: 70 BBL WEIGHTED(1.5PPG OVER)-50%INCREASE IN RETURNS. INCORPORATE BLACK PRODUCT SPIKE FLUID PRIOR TO THRZ 17:30 - 18:00 0.50 DRILL P INTI i SERVICE TOP DRIVE AND RIG FLOOR EQUIPMENT 18:00 - 00:00 6.00 DRILL P INTI DIRECTIONAL DRILL 12-1/4"INTI HOLE FROM 11904'MD TO TD AT 12210'MD,THROUGH CM AND THRZ FORMATIONS(306'IN 6 HRS=51 !FPH WITH CONNECTIONS) I-70-100 FPH INSTANTANEOUS ROP -880 GPM,4000 PSI,120 RPM,24 KFT-LBS TQ ON BOTTOM,14 KLBS WOB -MW IN/OUT=10.5 PPG,YP=25,FILTRATE= 2.9,2.25%LUBRICANTS -ECD:CALC=10.95 PPG,ACTUAL=10.9 PPG -SURVEY EVERY STAND,BACKREAMING 15' AT CONNECTIONS -NO LOSSES WHILE DRILLING AHEAD -NOV SOFT SPEED ON 100%OF DRILLING TO CONTROL STICK-SLIP THROUGH SURFACE RPM ADJUSTMENTS -TD HOLE SECTION 146'TVD BELOW THRZ PER CASING PICK PROGRAM SWEEPS: -11950'MD: 70 BBL WEIGHTED(1.5PPG OVER)-100%INCREASE IN RETURNS. Printed 8/8/2016 11:19:42AM *AII depths reported in Drillers Depths* 0 North America-ALASKA-BP • Page 28 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 6/9/2016 00:00 06:30 6.50 DRILL P INTI CIRCULATE HOLE CLEAN AT INTI TD(12210' MD)PRIOR TO PERFORMING WIPER TRIP -5X BOTTOMS UP,1680 BBLS FOR BOTTOMS UP -880 GPM,3935 PSI -120 RPM,20 KFT-LBS TORQUE -RECIPROCATE PIPE AT 13.5'FT/MIN -STAND BACK ONE STAND AFTER EACH BOTTOMS UP -INITIAL/FINAL ECD=11.0 PPG/10.85 PPG I INITIAL PU WEIGHT OFF BOTTOM:315K PUMPED 2 SWEEPS: -70 BBL 12.2 PPG WEIGHTED-50% I INCREASE IN RETURNS j-70 BBL 12.2 PPG WEIGHTED-MINIMAL INCREASE IN RETURNS i 06:30 - 08:30 2.00 DRILL P INTI PULL OUT OF HOLE FOR PLANNED WIPER TRIP FROM 12004'MD TO 11531'MD -MONITOR WELL FOR 10 MIN(STATIC) -ATTEMPT TO PULL ON ELEVATORS, I ENCOUNTER MULTIPLE TIGHT HOLE SPOTS IAFTER 11749'MD(30K-50K OVER) BACKREAM OUT OF HOLE,STAGING PUMPS TO 750 GPM,3050 PSI,100 RPM,18K TQ 08:30 09:00 0.50 DRILL 1 P INTI PULL OUT OF HOLE ON ELEVATORS FROM � 11531'MD TO 11057'MD PU 310K,SO 176KAT 11342'MD 09:00 - 10:30 1.50 1 DRILL P INTI CIRCULATE BOTTOMS UP TO CLEAN WELLBORE -850 GPM,3580 PSI,100 RPM,16K TQ -RECIPROCATE ONE STAND 10:30 - 11:30 1.00 DRILL P INTI j PULL OUT OF HOLE ON ELEVATORS FROM 11057'MD TO 10490'MD -PU 280K,SO 145KAT 10584'MD } -TIGHT HOLE AT 10490'MD(30K OVER) 11:30 - 12:30 1.00 DRILL P INTI CIRCULATE BOTTOMS UP TO CLEAN WELLBORE -850 GPM,3440 PSI,100 RPM,15K TQ T — + -RECIPROCATE 90'AT 500 FPH 12:30 - 15:00 2.50 DRILL P INTI BACKREAM OUT OF HOLE FROM 10490'MD TO 9922'MD -MONITOR WELL FOR 10 MIN(STATIC) -STAGE PUMPS/ROTARY TO 866 GPM,3600 I I PSI,100 RPM,17K TQ TIGHT HOLE AT 9443'MD,8700'MD,7935'MD 15:00 - 18:00 3.00 DRILL P INTI 'PULL OUT OF HOLE ON ELEVATORS FROM I 9922'MD TO 7742'MD -TIGHT HOLE AT 7940'MD,7840'MD 18:00 19:30 1.50 DRILL P INTI I BACKREAM OUT OF HOLE FROM 7742'MD TO 7174'MD -STAGE PUMPS/ROTARY TO 866 GPM,3200 PSI,100 RPM,15K TQ Printed 8/8/2016 11:19:42AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 29 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) • 19:30 - 22:00 2.50 DRILL P INTI CIRCULATE BOTTOMS UP 4X WITH UPPER GHOST REAMER INSIDE CASING SHOE • -866 GPM,3200 PSI,100 RPM,10K TQ -RECIPROCATE 90'AT 500 FPH -HOLE UNLOADED LOTS OF COAL UPON FIRST TWO BOTTOMS-UP -PUMP 70 BBL WEIGHTED SWEEP:150% INCREASE IN CUTTINGS RETURNS -ATTEMPT TO PULL ONE STAND ON ELEVATORS,INDICATIONS OF DRAGGING CUTTINGS UP HOLE WITH 50K-60K OVERPULLAFTER PULLING 70' -CONTACT ODE AND AGREE TO PULL BIT TO • CASING SHOE DUE TO HIGH CUTTINGS RETURNS AND SUSPECTED CUTTINGS BEDS CREW PERFORMS STOP THE JOB DRILL 22:00 - 00:00 2.00 DRILL P INTI BACKREAM OUT OF HOLE FROM 7174'MD TO 6417'MD -STAGE PUMPS/ROTARY TO 866 GPM,2980 PSI,100 RPM,10K TQ PU 182K,SO 115K AT 6417'MD 6/10/2016 00:00 - 00:30 0.50 DRILL P INTI l BACKREAM OUT OF HOLE FROM 6417'MD TO I 16223'MD -STAGE PUMPS/ROTARY TO 866 GPM,2880 PSI,100 RPM,9K TQ 00:30 - 01:30 1.00 DRILL P INTI J PULL ON ELEVATORS FROM 6223'MD TO 5174'MD(BIT INSIDE 13-3/8"CASING SHOE) -NO HOLE ISSUES 01:30 - 03:30 2.00 DRILL P INTI J CIRCULATE HOLE CLEAN WITH 3X BOTTOMS UP WITH BIT INSIDE CASING SHOE -950 GPM,3100 PSI,100 RPM,6K TQ •-RECIPROCATE 90'AT 1000 FPH -HOLE UNLOADED FINE COAL/CUTTINGS AFTER FIRST BU,DID NOT CLEAN UP UNTIL 2.5X BU 03:30 - 08:30 5.00 DRILL P INTI RUN IN HOLE ON ELEVATORS FROM 5174'MD TO 12210'MD -MONITOR WELL FOR 10 MIN PRIOR TO RUNNING IN THE HOLE:STATIC -FILL PIPE EVERY 2000'MD -PU 330K,SO 165K AT 12099'MD -WASH AND REAM DOWN LAST 150'TO TD -420 GPM,1245 PSI,80 RPM,18-21K FT-LBS TORQUE -NO FILL NOTED ON BOTTOM 08:30 - 14:30 6.00 DRILL P INTI CIRCULATE HOLE CLEAN AT INTI TD(12210' MD)PRIOR TO PULLING OUT OF THE HOLE -5X BOTTOMS UP,1680 BBLS FOR BOTTOMS UP -SIGNIFICANT COAL IN FIRST BU,HOLE CLEANED UPAFTER4 BU -880 GPM,4050 PSI -100 RPM,18 KFT-LBS TORQUE • -RECIPROCATE PIPE AT 13.5'FT/MIN -STAND BACK ONE STAND EVERY 30 MIN -INITIAL PU WEIGHT OFF BOTTOM:340K PUMPED 1 SWEEP: -70 BBL 12.2 PPG WEIGHTED-20% INCREASE IN RETURNS Printed 8/8/2016 11:19:42AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 30 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:30 - 21:00 6.50 DRILL P INTI PULL OUT OF THE HOLE ON ELEVATORS FROM 11700'MD TO BHA AT 1097'MD -MONITOR WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM;STATIC -PU 330K,SO 170KAT 11700'MD -MONITOR THE WELL FOR 10 MIN AT 13-3/8" SHOE;5 BPH STATIC LOSS RATE -LAY DOWN UPPER GHOST REAMER; -5/8"UNDER GAUGE WITH SIGNIFICANT WEAR. -SEE ATTACHED PHOTOS. -MONITOR WELL FOR 10 MIN;5 BPH STATIC LOSS RATE 21:00 - 23:00 2.00 DRILL P INTI PULL AND LAY DOWN BHA FROM 1097'MD -LOWER GHOST REAMER 1/16"UNDER GAUGE; -SIGNIFICANT DAMAGE TO LEADING EDGE OF BLADES -SEE ATTACHED PHOTOS -DULL BIT GRADE:3-3-BT-T-X-I-WT- TD 23:00 23:30 0.50 BOPSUR P INTI FUNCTION PERFORM WEEKLY BOPE FUNCTEST 23:30 - 00:00 0.50 CASING P INTI [CLEAN AND CLEAR RIG FLOOR 6/11/2016 00:00 - 01:00 1.00 WHSUR P INTI MAKE UP RUNNING TOOL AND PULL WEAR RING CONTINUE TO REMOVE BHA COMPONENTS -- —_.- - FROM RIG FLOOR 01:00 - 03:00 2.00 CASING P INTI RIG UP TO RUN 9-5/8",47#/FT,L-80,VAMTOP CASING STRING MOBILIZE CASING RUNNING EQUIPMENT TO RIG FLOOR -RIG UP VOLANT CRT TOOL -INSTALL 8'BAIL EXTENSIONS AND 350 TON SIDE DOOR ELEVATORS i-RIG UP SINGLE STACK TONGS AND TORQUE [TURN EQUIPMENT -RIG UP 350 TON SPIDERS -RIG UP FILL UP HOSE -INSTALL 3'PUP ON BOTTOM OF LANDING JOINT -FUNCTION TEST UPPER 9-5/8"FIXED PIPE [RAMS Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* North America-ALASKA-BP • Page 31 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:00 - 00:00 21.00 CASING P INTI RUN 290 JOINTS OF 9-5/8",47#,L-80,VAMTOP CASING FROM SURFACE TO 9559'MD(JT# 228)AT MIDNIGHT -BAKERLOK SHOE TRACK CONNECTIONS W/ BTC CONNECTIONS MADE UP TO THE MARK -CHECK FLOATS;GOOD -USE JET LUBE SEAL GUARD PIPE DOPE ON VAMTOP CONNECTIONS -TORQUE TURN VAMTOP CONNECTIONS TO 15,900 FT-LBS -RUN 12"VOLANT SPIRAL BLADE !CENTRALIZER LOCKED DOWN 5'FROM SHOE ON JOINT A,LOCKED DOWN MID JOINT BAND FREE FLOATING EVERY JOINT WITH STOP RING 5'FROM PIN FOR HANDLING PURPOSES ON JOINTS C&1-162(165 TOTAL CENTRALIZERS,166 STOP RINGS) '-RUNNING SPEEDS:140 FPM(SURFACE- 4000'MD),90 FPM(4000'MD-8000'MD),50 FPM(8000'MD-TD) -FILL CASING ON THE FLY -TOP OFF WITH VOLANT EVERY 10TH JOINT 'TO 13-3/8"SHOE CIRCULATE 1X BU AT 13-3/8"CASING SHOE, 'STAGE PUMPS TO 10 BPM,306 PSI -BREAK CIRCULATION EVERY 5TH JOINT WITH 7 BPM FOR 5 MIN FROM SHOE TO BASE UGNU -START PUSHING FLUID AWAY AT-9300'MD, OBSERVE 12 BBL UNDERDISPLACEMENT FOR 5 JOINTS AT 9472'MD -SLOWLY STAGE PUMPS TO CIRCULATE ONE BOTTOMS-UP 10 JOINTS ABOVE WEST SAK 2 DUE TO OBSERVED FLUID LOSSES AND PLACE NEW MUD ON BACKSIDE(AS OF MIDNIGHT) -AVERAGE 13 JT/HR WITH CIRCULATION EVERY 5 JOINTS Printed 8/8/2016 11.19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP Page 32 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 6/12/2016 00:00 - 08:30 8.50 CASING P INTI RUN 290 JOINTS OF 9-5/8",47#,L-80,VAMTOP INTI CASING FROM 9559'MD(JT#228)AT MIDNIGHT TO PLANNED SET DEPTH AT 12199' MD/7976'TVD I-USE JET LUBE SEAL GUARD PIPE DOPE ON VAMTOP CONNECTIONS -TORQUE TURN VAMTOP CONNECTIONS TO 15,900 FT-LBS -RUNNING SPEEDS:50 FPM(8000'MD-TD) -FILL CASING ON THE FLY '-COMPLETE ONE BOTTOMS-UP CIRCULATION 10 JOINTS ABOVE WEST SAK 2 DUE TO OBSERVED FLUID LOSSES AND PLACE NEW MUD ON BACKSIDE(IN LIEU OF PLANNED FULL BOTTOMS UP CIRCULATION BY WEST SAK 1),STAGE TO 7 BPM,400 PSI -OBSERVE 15K-20K LESS DRAG AFTER BOTTOMS-UP -BREAK CIRCULATION EVERY 10TH JOINT WITH 7 BPM FOR 5 MIN FROM BASE UGNU TO TOP HRZ -PUSH AWAY 7 BBL FOR 10 JOINTS,-15 BPH LOSSES WHILE CIRCULATING NO CIRCULATION THROUGH HRZ -MAKE UP LANDING JOINT TO 9-5/8"FLUTED HANGER JOINT AND WASH DOWN TO LAND ON RING -NO HOLE ISSUES,RUN IN HOLE CLEAN -AVERAGE 10 JT/HR WITH STAGE UP CIRCULATION EVERY 10 JOINTS(WEST SAK 1 TO TD) -AVERAGE 10 JT/HR FOR ENTIRE RUN (INCLUDING SHOE TRACK&ALL CIRCULATIONS) -PICK UP WEIGHT AT 11,917'MD=498 KLBS (AT 2 BPM). -UNABLE TO BREAK OVER AT TO PULLED TO 500 KLBS(AT 2 BPM),SLACKOFF=205 KLBS (AT 2 BPM) -PUSH AWAY ATOTAL OF 90 BBLS DURING CASING RUN -FINAL EXCEL TALLY ATTACHED Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 33 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:30 14:00 5.50 CEMT P INTI STAGE UP PUMPS TO CIRCULATE HOLE CLEAN AND CONDITION MUD WITH 2.5 TOTAL BOTTOMS UP(2 BU AT FULL RATE) -7 BPM CEMENTING RATE(THROUGH CEMENT LINES),INITIAL CIRC PRESSURE= 650 PSI,FINAL CIRC PRESSURE=610 PSI -CIRCULATE UNTIL SHAKERS ARE CLEAN, CUT MUD YIELD POINT TO<18 -MW IN/OUT=10.5 PPG -NO RECIPROCATION,STUCK ON RING LOST 46 BBL WHILE CIRCULATING -MIRU SLB CEMENTERS. PRESSURE TEST LINES TO 250 PSI LOWAND 4000 PSI HIGH FOR FIVE MIN EACH. HOLD PJSM. PUMP STAGE UP: 2 BPM=380 PSI,8% 3 BPM=425 PSI,10% 4 BPM=460 PSI,10% 5 BPM=440 PSI, 11% 6 BPM=450 PSI,13% 7 BPM=475 PSI,14% 7.5 BPM=490 PSI,14% Printed 8/8/2016 11:19:42AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 34 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 18:30 4.50 CEMT P INTI CEMENT 9-5/8",47#,L-80,VAMTOP INTI CASING AS FOLLOWS: -NO RECIPROCATION THROUGHOUT JOB, STUCK ON RING i-SLB PUMP 70 BBLS OF 11.0 PPG MUDPUSH II SPACER @ 5 BPM,430 PSI -DISENGAGE VOLANT CRT AND LAUNCH BOTTOM PLUG -SLB PUMP 465.4 BBLS,1451 SACKS OF 11.5 PPG LITECRETE LEAD CEMENT(YIELD=1.8 CUFT/SACK)@ 6.8 BPM:ICP=600 PSI,FCP= 475 PSI,EXCESS VOLUME 40% -SLB PUMP 45.7 BBLS,219 SACKS OF 15.8 i PPG CLASS G TAIL(YIELD=1.17 CUFT/SACK) @ 6 BPM:390 PSI,EXCESS VOLUME 40% -DISENGAGE VOLANT CRT AND LAUNCH TOP PLUG I-SLB KICK OUT PLUG WITH 10 BBLS FRESH 11WATER -PERFORM DISPLACEMENT WITH RIG PUMPS AND 10.5 PPG LSND MUD PER SLB CADE -865 BBLS DISPLACED AT 7 BPM:ICP 295 PSI, FCP 1060 PSI -OBSERVE BOTTOM PLUG LAND AT 386 BBL DISPLACED,DISK BURST AT 800 PSI I-REDUCE RATE TO 2 BPM PRIOR TO PLUG BUMP:FINAL CIRCULATING PRESSURE 720 PSI -BUMP PLUG AND INCREASE PRESSURE TO 1300 PSI. HOLD FOR FIVE MIN. BLEED OFF AND CHECK FLOATS-GOOD -TOTAL DISPLACEMENT VOLUME BY RIG& SLB=887.2 BBLS(8728 STROKES CALCULATES TO 96%PUMP EFFICIENCY) -TOTAL LOSSES AFTER CEMENT EXIT SHOE: 95 BBL -TOTAL LOSSES DURING JOB:126 BBLS -CEMENT IN PLACE AT 18:27 -23:48 HRS TO 500 PSI COMPRESSIVE !STRENGTH IN LEAD CEMENT _ 18:30 - 19:30 1.00 CASING P INTI RIG DOWN CASING EQUIPMENT -BREAKAND LAY DOWN LANDING JOINT -RIG DOWN TONGS,BAIL EXTENSIONS& VOLANT CRT -CLEAN AND CLEAR RIG FLOOR 19:30 - 20:00 0.50 CASING P INTI SERVICE TOP DRIVE AND RIG FLOOR EQUIPMENT 20:00 - 21:30 1.50 WHSUR P INTI SET AND TEST 9-5/8"PACKOFF PER FMC REP -250 PSI LOW FOR 5 MIN AND 4500 PSI HIGH FOR 15 MIN -PASSING TEST,SEE ATTACHED CHART -DISCUSSED TEST AND RECEIVED ATP FROM ACTING WSUP 21:30 - 22:00 0.50 WHSUR P INTI ESTABLISH INJECTION DOWN 13-3/8"x 9-5/8" ANNULUS -INJECT 10.5 PPG LSND INTO OA -BREAKOVER PRESSURE AT 950 PSI, PUMPED 5 BBL AWAY -PUMP 2 BBL INTO OA EVERY HOUR Printed 8/8/2016 11:19.42AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 35 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:00 - 23:00 1.00 BOPSUR P INTI RIG UP BOPE TEST EQUIPMENT AND CHANGE UPPER RAMS TO 2-7/8"X 5"VBR -BARRIERS TO BREAK CONTAINMENT: CLOSED BLIND RAMS&KWF -SET TEST PLUG 23:00 - 00:00 1.00 BOPSUR P INTI TEST BOPE AFTER CHANGING UPPER RAMS TO 250 PSI LOW/4000 PSI HIGH FOR 5 MIN EACH ' -TEST WITH 5"AND 4"TEST JOINTS TEST ANNULAR PREVENTER TO 3500 PSI HIGH 6/13/2016 00:00 - 01:30 ' 1.50 BOPSUR P INTI TEST BOPE AFTER CHANGING UPPER PIPE 1 RAMS TO 250 PSI LOW/4000 PSI HIGH FOR 5 MIN EACH I -TEST WITH 5"AND 4"TEST JOINTS I-TESTANNULAR PREVENTER TO 3500 PSI 'HIGH ' -ALL TESTS PASSED,SEE ATTACHED CHART 01:30 - 02:30 1.00 BOPSUR P INTI RIG DOWN BOPE TEST EQUIPMENT -PULL TEST PLUG AND LAY DOWN TEST 'JOINT ' .-INSTALL WEAR RING,ID=8.625" I SIMOPS:CONTINUE TO MAINTAIN INJECTION ' DOWN THE OA FOR FREEZE PROTECT,2 _ BBLS EVERY HOUR 02:30 - 04:30 2.00 DRILL P INTI MAKE UP 8-1/2"INTERMEDIATE 2 DRILLING BHA TO 804'MD -PICK UP AUTOTRAK,ONTRAK,AND BCPM -PLUG IN AND VERIFY TOOLS -MAKE UP SECURITY 8-1/2"MM65D BIT SIMOPS:CONTINUE TO MAINTAIN INJECTION ' DOWN THE OA FOR FREEZE PROTECT,2 BBLS EVERY HOUR 04:30 05.00 0.50 DRILL P1 I INTI RUN IN THE HOLE WITH 8-1/2"INTERMEDIATE 2 DRILLING BHA FROM 805'MD TO 1276'MD ON 4"DRILL PIPE. 05:00 05:30 0.50 DRILL P , INT1 PERFORM SHALLOW HOLE TEST ON MWD 05:30 - 10:30 5.00 DRILL I P INTI CONTINUE TO RUN IN THE HOLE WITH 8-1/2" INTERMEDIATE 2 DRILLING BHA FROM 1276' MD TO 10560'MD ON 4"AND 5"DRILL PIPE -FILL PIPE EVERY 2000'MD -PU 194K;SO 220KAT 10100'MD -TAPERED DRILL STRING;3972'OF 4"DRILL PIPE. i I SIMOPS:CONTINUE TO MAINTAIN INJECTION DOWN THE OA FOR FREEZE PROTECT,2 j BBLS EVERY HOUR 10:30 - 12:30 2.00 DRILL P I INTI UNANNOUNCED D1,KICK WHILE TRIPPING DRILLAND MR WITH ALL HANDS -AFTER WELL SECURED HELD A TABLE TOP STRIPPING DRILL WITH CREW -HELD AAR ON DRILLING 12-1/4"HOLE SECTION WITH CREW -HELD PRE-SPUD MEETING WITH CREW ON DRILLING 8-1/2"HOLE SECTION Printed 8/8/2016 11:19:42AM *AII depths reported in Drillers Depths* • North.America-ALASKA-BP • Page 36ot97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60 05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 1230 - 14:00 1.50 DRILL P INTI SLIP AND CUT DRILL LINE -CUT 72'OF DRILL LINE -SERVICE TOP DRIVE AND RIG FLOOR EQUIPMENT -CALIBRATE BLOCK HEIGHTS WITH BAKER MWD. SIMOPS:FREEZE PROTECT OA 14:00 - 15:00 1.00 DRILL P INTI CONTINUE TO RUN IN THE HOLE WITH 8-1/2" DRILLING ASS'Y -FROM 10560'MD TO 11887'MD ON ELEVATORS -WASH DOWN FROM 11887'MD TO 12107'MD -300 GPM AT 335 PSI SIMOPS:FREEZE PROTECT OA 15:00 - 18:00 3.00 DRILL P ' INT1 PRESSURE TEST 9-5/8",47 LB/FT,L-80 INTERMEDIATE 1 CASING TO 250 PSI LOW FOR 5 MIN/4000 PSI HIGH FOR 30 MIN. -CIRCULATE AND PURGE AIR FROM SYSTEM PRESSURE SENSATOR FAILED ON FIRST ATTEMPT;REPAIR SENSATOR AND RE-TEST PASSING TEST PER BP 10-45 CRITERIA -PUMP IN VOLUME=12.3 BBLS,BLEED BACK VOLUME=12.3 BBLS APPROVAL TO PROCEED GRANTED BY WSUP,DOCUMENTS ATTACHED -LOST 30 PSI IN FIRST 15 MIN AND 11 PSI IN SECOND 15 MIN 18:00 - 22:30 4.50 DRILL P INT1 SIN ATTEMPT TO DRILL CEMENT AND PLUGS IN SHOE TRACK AT 12107'MD UNABLE TO ROTATE PIPE WITH SURFACE TORQUE LIMIT SET AT 18K FT-LBS. INCREASED SURFACE TORQUE LIMIT TO 24K FT-LBS,AND WORK PIPE AT 0-50 RPM. BUILD AND PUMP TWO 35 BBL 5%EP MUD LUBE SWEEPS AND INCREASE MUD SYSTEM LUBES FROM 2.25%TO 3% -550 GPM,2810 PSI -WORKING PIPE WITH 20-30'OF STROKE -TORQUE DECREASED TO 16-18K FT-LBS AFTER SECOND SWEEP -PIECES OF TOP CEMENT PLUG ACROSS SHAKERS AT 1.5 BOTTOMS UP WHILE PUMPING LUBE SWEEPS SIMOPS:FREEZE PROTECT OA -66 BBLS OF 14.0 PPG LSND INJECTED AHEAD OF DIESEL THROUGHOUT DAY TO MAINTAIN INJECTION AND PROVIDE OVERBALANCE FOR DIESEL AT 1-2 BPM, 900-950 PSI. -132 BBLS OF 6.8 PPG DIESEL INJECTED DOWN THE OA TO FREEZE TO 2200'MD AT 1-2 BPM,900-1000 PSI. -TOTAL VOLUME INJECTED(10.5 PPG LSND, 14.0 PPG LSND,6.8 PPG DIESEL)=223 BBLS Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 37 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan@60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:30 - 00:00 1.50 DRILL P INTI DRILL PLUGS,FLOAT EQUIPMENT AT 12107' MD -50 RPM,18-22K FT-LBS TORQUE -450 GPM,2350 PSI -8-10K WEIGHT ON BIT -CONTINUE TO RECOVER PIECES OF TOP CEMENT PLUG AT SHAKERS 6/14/2016 00:00 - 01:00 1.00 DRILL P INTI CONTINUE TO DRILL PLUGS,FLOAT EQUIPMENT AND CEMENT FROM 12107'MD TO 12189'MD-10'FROM 9-5/8"CASING SHOE. -50 RPM,18-22K FT-LBS TORQUE -450 GPM,2350 PSI -8-16K WEIGHT ON BIT TO DRILL OUT BOTTOM PLUG AND FLOAT COLLAR -5-8K WEIGHT ON BIT TO DRILL OUT CEMENT IN SHOE TRACK -MUD WIEGHT 10.5 IN/OUT RECOVER PIECES OF BOTTOM CEMENT PLUG AT SHAKERS 01:00 - 02:30 1.50 DRILL P INTI CIRCULATE HOLE CLEAN AND TREAT CONTAMINATED MUD -540 GPM,3150 PSI -50 RPM,18-23.5K FT-LBS TORQUE -TORQUE INCREASING AS HOLE CLEANED UP 02:30 - 03:30 1.00 DRILL P r INTI ATTEMPT TO DRILL CEMENT AND SHOE AT 12189'MD UNABLE TO ROTATE PIPE WITH SURFACE TORQUE LIMIT SET AT 24K FT-LBS MUD CHECK REVEALED THAT LUBE CONCENTRATION HAD DROPPED TO 2% WHILE TREATING CONTAMINATION BUILD AND PUMP 35 BBL 5%EP MUD LUBE SWEEP AND INCREASE MUD SYSTEM LUBES BACK TO 3% -550 GPM,3170 PSI -WORKING PIPE WITH 20-30'OF STROKE -TORQUE DECREASED TO 19-21K FT-LBS WITH EP MUD LUBE SWEEP IN SYSTEM -CONTINUE TO ADD LUBES TO GET MUD SYSTEM UP TO 3% 03:30 - 04:30 1.00 DRILL P INTI DRILL CEMENT,SHOE AND 10'OF NEW FORMATION FROM 12189'MD TO 12230'MD -50-80 RPM,18-24K FT-LBS TORQUE -550 GPM,3320 PSI -8-10K WEIGHT ON BIT -MUD WIEGHT 10.5 IN/OUT -CONTINUE TO ADD LUBES TO MUD SYSTEM TO INCREASE TOTAL CONCENTRATION TO 3%. 04:30 - 05:30 1.00 DRILL P INTI CIRCULATE HOLE CLEAN PRIOR TO PERFORMING FIT -550 GPM,3240 PSI -50 RPM,19-21K FT-LBS TORQUE -MONITOR WELL FOR 10 MIN-STATIC Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* North America-ALASKA-BP • Page 38 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:30 06:30 1.00 DRILL P INTI PERFORM FIT TO 11.6 PPG EMW AT 9-5/8" CASING SHOE(12199'MD,7976'TVD) -MUD WEIGHT IN/OUT=10.5 PPG -PUMP AT 1/2 BPM TO 464 PSI -SEE ATTACHED CHART(BBL IN=3.0,BBL OUT=2.0) -DISCUSS RESULTS WITH ODE AND RECIEVE ATP 06:30 15:00 8.50 DRILL P INT2 DIRECTIONAL DRILL 8-1/2"INT2 HOLE FROM 12230'MD TO 12526'MD(305'IN 8.5 HRS=91 FPH WITH CONNECTIONS) -550 GPM,3250-3295 PSI, 110 RPM,22-24 KFT-LBS TQ,8-15 KLBS WOB -PU 265K,SO 164K,ROT 191K -MW IN/OUT=10.5 PPG -ECD:CALC=11.3 PPG,ACTUAL=11.5 PPG -SURVEY EVERY-45' -NO BACKREAMING AT CONNECTIONS -LOST 50%OF RETURNS AT 12500'MD -LOST ALL RETURNS AT 12526'MD 15:00 - 00:00 9.00 LCR N DPRB 12,526.00 INT2 LOST ALL RETURNS AT 12526'MD -NOTIFY ODE AND ANCHORAGE TEAM -PUMP 35 BBL,40 PPB AT 12526'MD -250 GPM;835 PSI -NO CHANGE IN LOSSES -PICK UP 100'ABOVE SHOE TO 12070'MD -STATIC LOSS RATE=25 BPH -DYNAMIC LOSS RATE AT 5 BPM=5 BPM BARIOD MUD PLANT BUILDING MUD DISCUSS PLAN FORWARD WITH ODE -PUMP 80 BBL,40 PPB DRILL AHEAD LCM PILL -5 BPM;625 PSI UNTIL PILL AT BIT -REDUCED RATE TO 2 BPM;240 PSI UNTIL PILL CLEARED BIT -MINIMAL RETURNS WHILE PUMPING(NOT ENOUGH FLOW TO REGISTER ON FLOW PADDLE) -LET DRILL AHEAD PILL SOAK FOR 15 MIN; STATIC LOSS RATE 10 BPH DISCUSS WITH ODE AND PROCEED WITH PLAN FORWARD TO PUMP ANOTHER 80 BBL PILL. -PUMP 80 BBL,40 PPB DRILL AHEAD LCM PILL -5 BPM;655 PSI UNTIL PILL AT BIT -REDUCED RATE TO 2 BPM;240 PSI UNTIL PILL CLEARED BIT -MINIMAL RETURNS WHILE PUMPING(NOT ENOUGH FLOW TO REGISTER ON FLOW PADDLE) -LET DRILL AHEAD PILL SOAK FOR 15 MIN; NO CHANGE IN STATIC LOSS RATE(10 BPH) 1201 BBL TOTAL LOSSES. Printed 8/8/2016 11:19:42AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 39 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 , End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisbume Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 6/15/2016 00:00 - 01:30 1.50 LCR -1-N DPRB 12,515.00 INT2 MONITOR WELL AT 12070'MD TO DETERMINE STATIC LOSS RATE -AVERAGE STATIC LOSS RATE OF 10 BPH CALL ODE AND DISCUSS PLAN FORWARD. NO CHANGE NOTED IN LOSS RATE AFTER TWO 80 BBL,40 PPB DRILL AHEAD PILLS BUILD A80 BBL,40 PPB DRILL AHEAD LCM PILL -VERIFY DRILL STRING FREE; -PU 267K,SO 167K AT 12070'MD 01:30 - 04:00 2.50 LCR N DPRB 12,515.00 INT2 PUMP 80 BBL,40 PPB DRILL AHEAD LCM PILL -5 BPM;655 PSI UNTIL PILL AT BIT -REDUCED RATE TO 1 BPM;116 PSI UNTIL PILL CLEARED BIT -ANNULUS STAYED FULL WHILE PUMPING AT 5 8PM(NO RETURNS) -FLUID LEVEL IN ANNULUS DROPPED WHILE PUMPING AT 1 BPM; -TOOK 1.5 BBLS TO FILL STACK AFTER AFTER DISPLACING PILL AT 1 BPM. -LET DRILL AHEAD PILL SOAK FOR 15 MIN; STATIC LOSS RATE OF 18 BPH CALL AND DISCUSS WITH ODE. 04:00 - 08:30 4.50 LCR N DPRB 12,515.00 INT2 MONITOR WELL VIA TRIP TANK -TAKE STATIC LOSS RATES EVERY 15 MINUTES:CONSISTENT 18 BPH LOSS RATE 08:30 - 10:00 1.50 LCR N DPRB 12,515.00` INT2 PULL OUT OF THE HOLE ON ELEVATORS FROM 12070'MD TO 9228'MD -PU 265K,SO 168KAT 12070'MD -DISPLACEMENTS INDICATE WELL NO LONGER TAKING FLUID -STOP AND MONITOR THE WELL FOR 10 MIN -STATIC 10:00 - 11:30 1.50 LCR N DPRB 12,515.00 INT2 ESTABLISH LOSS RATES FOR WELL STATIC LOSS RATE=0 BPH -ATTEMPT TO DETERMINE DYNAMIC LOSS RATE -84 GPM,340 PSI-FULL RETURNS STAGE UP PUMPS TO 400 GPM,1565 PSI- FULL RETURNS -STAGE UP PUMPS TO 550 GPM,2620 PSI- FULL RETURNS -VERIFY MWD TOOL PULSING. 11 30 - 14:00 2.50 LCR N DPRB 12,515.00 INT2 RUN IN THE HOLE WITH 8-1/2"INT2 DRILLING ASSY ON ELEVATORS FROM 9228'MD TO 12170'MD -PU 182K,SO 130K AT 9228'MD FILL PIPE EVERY 1000'MD -RUNNING SPEED 65 FPH 14:00 - 15:30 1.50 LCR N DPRB 12,515.00 INT2 CIRCULATE 1X BOTTOMS UP -550 GPM,2953 PSI-FULL RETURNS Printed 8/8/2016 11.19:42AM "All depths reported in Drillers Depths* • North America-ALAS KA-BP Page 40 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:30 - 16:30 1.00 LCR N DPRB 12,515.00 INT2 CONTINUE TO RUN IN THE HOLE WASHING DOWN FROM 12170'MD TO 12315'MD -210 GPM,700 PSI -NOTICE INCREASE IN DRAG WHILE RUNNING STAND INTO KINGAK -SET 20K DOWN AT 12315'MD OBSERVED PUMP PRESSURE INCREASE TO 1150 PSI -WORK TIGHT HOLE FROM 12315'MD TO 12300'MD -PULLED 25 K OVER WITH NO MOVEMENT -PUT 15K TORQUE IN STRING AND PULLED FREE WITH 20 K OVER -LOST ALL RETURNS PULL BACK INTO THE 9-5/8"SHOE AT 12070' MD -REGAINED 80%OF RETURNS ONCE ABOVE THE KINGAK;12277'MD 16:30 - 17:00 0.50 LCR N DPRB 12,515.00 INT2 MONITOR THE WELLAND ESTABLISH LOSS RATES -STATIC LOSS RATE=3 BPH '-DYNAMIC LOSS RATE=6 BPH 17:00 - 23:00 6.00 LCR N DPRB 12,515.00 INT2 PULL OUT OF THE HOLE FROM 12070'MD TO '801'MD ON ELEVATORS -DECISION MADE TO LAY DOWN MWD TOOLS AND RUN IN THE HOLE WITH"DUMB IRON" TO TREAT LOST CIRCULATION. -MONITOR WELL FOR 15 MIN;3 BPH STATIC (LOSS RATE -PU 260K,SO 165K AT 12070'MD -PULLING SPEED FROM 90-210 FPM 23:00 - 23:30 0.50 LCR P 12,515.00 INT2 SERVICE TOP DRIVE AND RIG FLOOR EQUIPMENT 23:30 - 00:00 0.50 LCR N DPRB 12,515.00 INT2 CONTINUE TO PULL OUT OF THE HOLE FROM 801'MD TO 400'MD -MONITOR WELL FOR 15 MIN;2 BBL STATIC LOSS RATE I-PU 72K,SO 72 AT 801'MD TOTAL LOSSES FOR THE DAY=471 BBLS TOTAL LOSSES FOR THE INT2 SECTION= 1672 BBLS 6/16/2016 00:00 - 01:00 1.00 LCR N DPRB 12,515.00 INT2 'STAND BACK 8-1/2"INT2 DRILLING ASS'Y -RACK BACK 3 STANDS OF 5"HWDP AND 1 STAND OF 6"COLLARS PLUG INTO MWD TOOL AND VERIFY DATA -RACK BACK AUTOTRAK,ONTRAKAND BCPM 01:00 - 02:30 1.50 LCR N DPRB 12,515.00 INT2 MAKE UP AND RUN IN THE HOLE WITH BHA #6,DUMB IRON ASS'Y FOR TREATING LOST CIRCULATION TO 947'MD -8-1/2"MILL TOOTH BIT,STABILIZER,(9)6-1/2" DRILL COLLARS,(20)5"HWDP AND JARS 02:30 - 08:30 6.00 LCR N DPRB 12,515.00 INT2 RUN IN THE HOLE ON ELEVATORS WITH BHA #6,DUMB IRON ASS'Y,ON TAPERED DRILL STRING(4"HT-38 x 5"NC50)FROM 947'MD TO 12187'MD -FILL PIPE EVERY 2000'MD -PU 260K,SO 163KAT 12187'MD Printed 8/8/2016 11.19:42AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP 41110 Page 41 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 I Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To Hrs ! Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:30 - 10:00 1.50 LCR N DPRB I 12,515.00 INT2 CIRCULATE 1X BOTTOMS UP AT THE 9-5/8" CASING SHOE -550 GPM;2300 PSI -NO LOSSES NOTED DURING BOTTOMS UP. 10:00 - 13:00 3.00 LCR N DPRB 12,515.00 INT2 WASH AND REAM TO BOTTOM FROM 12187' MD TO 12514'MD -254 GPM,940 PSI,80 RPM,15K FT-LBS TORQUE,15K WOB PU 260K,SO 163K,ROT 201K -MUD WEIGHT IN/OUT 10.5 PPG/10.6 PPG -OBTAIN SLOW PUMP RATES PRIOR TO WASHING DOWN -TAGGED AT 12477'MD BEGAN REAMING DOWN NO DRAG OR OVERPULLS NOTED WHILE WORKING PIPE ON BOTTOM -MINIMAL LOSSES WHILE WASHING DOWN. 13:00 - 17:00 4.00 LCR N DPRB 12,515.00 INT2 DRILL DOWN.TO T2583'MD WITH DUMB IRON ASSY(68'MD OF NEW HOLE) -254 GPM,642 PSI,80 RPM,14K-16K FT-LBS TORQUE,5-18K WOB -INCREASE RATE ON BOTTOM TO 6 BPM, DYNAMIC LOSS RATE INCREASED TO 3 BPM PUMPED 20 BBLS OF 80 PPB LCM "SUPERPILL";FULL RETURNS AFTER PUMPING PILL '-STAGE BACK UP TO DRILLING RATE;1 TO 1.5 BPM LOSS RATE. 17:00 - 18:30 1.50 LCR N DPRB 12,515.00 !N SPOT 30 BBL OF 80 PPB LCM"SUPERPILL"IN OPEN HOLE -2 BPM,235 PSI -PULLING AT 30 FT/MIN TO LAY PILL IN OPEN HOLE -NO LOSSES NOTED -PULL TO THE 9-5/8"SHOE 18:30 - 19:30 1.00 LCR N DPRB 12,515.00 INT2 CIRCULATEABOTTOMSUPATTHE9-5/8" CASING SHOE TO GETANY LCM AROUND BHA OUT OF THE HOLE I-550 GPM,2225 PSI -DYNAMIC LOSSES=0 -MONITOR WELL FOR 15 MIN-STATIC 19:30 - 20:00 0.50 LCR P 12,515.00 INT2 SERVICE TOP DRIVE AND RIG FLOOR EQUIPMENT 20:00 - 00:00 4.00 LCR N DPRB 12,515.00 INT2 PULL OUT OF THE HOLE ON ELEVATORS WITH DUMB IRON ASS'Y FROM 12100'MD TO 3881'MD -MONITOR WELL FOR 15 MIN-STATIC -PU 260K,SO 170K AT 12100'MD TOTAL LOSSES FOR DAY:684 BBLS TOTAL LOSSES FOR INT2 SECTION:2302 BBLS 6/17/2016 00:00 - 01:00 1.00 LCR N DPRB 12,583.00 INT2 CONTINUE TO PULL OUT OF THE HOLE WITH DUMB IRON ASS'Y ON ELEVATORS FROM 3881'MD TO 947'MD -MONITOR THE WELL FOR 15 MIN AT DRILL I,.PIPE CHANGE(5"TO 4")-WELL STATIC PU 110K,SO 91KAT 3881'MD Printed 8/8/2016 11:19:42AM All depths reported in Drillers Depths* North America-ALASKA-BP r Page 42 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project Lisbume Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:00 - 02:30 1.50 LCR N DPRB 12,583.00 INT2 LAY DOWN DUMB IRON ASS'Y FROM 947'MD TO SURFACE -RACK BACK 5"HWDP -LAY DOWN DRILL COLLARS BIT GRADE:2-2-WT-A-E-I-NO-BHA 02:30 - 03:00 0.50 LCR N DPRB 12,583.00 INT2 CLEAN AND CLEAR RIG FLOOR 03:00 - 05:00 . 2.00 WHSUR N DPRB 12,583.00 INT2 PULL WEAR RING AND INSTALL TEST PLUG -RIG UP TO TEST BOPE 05:00 - 09:30 4.50 BOPSUR P INT2 PRESSURE-FUNCTION TEST BOPE PER BP STANDARDS AND AOGCC REGULATIONS -PASSING TEST -TEST ANNULAR WITH 4"TEST JOINT TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH -TEST UPPER 2-7/8"X 5"VBRS WITH 4"AND 5"TEST JOINT TO 250 PSI LOW AND 4000 PSI HIGH FOR FIVE MIN-EACH -TEST LOWER 3-1/2"X 5-7/8"VBRS WITH 4" AND 5"TEST JOINT TO 250 PSI LOW AND 4000 PSI HIGH FOR FIVE MIN EACH -ALL TESTS CHARTED,SEE ATTACHED DOCUMENTATION TEST WITNESSED BY AOGCC -REPRESENTATIVE MATT HERRERA 09:30 - 10:00 0.50 BOPSUR P INT2 RIG DOWN TEST LINES AND EQUIPMENT i-PULL TEST INSTALL 8-5/8"ID WEAR RING ---I CLEAN AND CLEAR RIG FLOOR. 10:00 - 11:00 1.00 DRILL N DPRB 12,583.00 INT2 MAKE UP AND RUN IN THE HOLE WITH BHA #7,8-1/2"INT2 DRILLING ASSY TO 817'MD PU 72K,SO 72K AT 817'MD -SHALLOW HOLE TEST MWD-GOOD TEST. 11:00 - 16:00 5.00 DRILL N DPRB 12,583.00 INT2 RUN IN THE HOLE WITH BHA#7,8-1/2"INT2 DRILLING ASS'Y ON TAPER DRILL STRING(5" x 4")FROM 817'MD TO 12150'MD -FILL PIPE EVERY 2000'MD -RUNNING SPEED 190-90 FPM -PROPER PIPE DISPLACEMENT WHILE RUNNING IN THE HOLE 16:00 - 16:30 0.50 DRILL P 12,583.00 INT2 SERVICE TOP DRIVE AND RIG FLOOR EQUIPMENT 16:30 - 18:00 1.50 DRILL N DPRB 12,583.00 INT2 I CIRCULATE 1X BOTTOMS UP AT THE 9-5/8" CASING SHOE 550 GPM,2760 PSI -DYNAMIC LOSS RATE=0 BPH -STATIC LOSS RATE=0 BPH -MONITOR WELL FOR 10 MIN;STATIC 18:00 - 20:00 2.00 DRILL N DPRB 12,583.00 INT2 WASH AND REAM DOWN FROM 12100'MD TO 112583'MD -400 GPM,2030 PSI 1-10 RPM,12K FT-LBS TORQUE -CIRCULATING FOR 5 MIN PRIOR TO I CONNECTIONS Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* North America-ALASKA-BP . Page 43 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 21:00 1.00 DRILL P 12,583.00 INT2 DIRECTIONAL DRILL 8-1/2"INT2 HOLE FROM 12581'MD TO 12655'MD(72'IN 1 HR) -550 GPM,2840 PSI,110 RPM,12-14 KFT-LBS TQ,10-15 KLBS WOB I-PU 262K,SO 165K,ROT 194K -MW IN/OUT=10.5 PPG -ECD:ACTUAL=11.3 PPG -ACTUAL ROATING TIME=0.9 HRS TAKE SPR BEFORE DRILLING AHEAD LOST ALL RETURNS AT 12655'MD.HAD JUST MADE A CONNECTION AND FINISHED DOWNLINKING TO AUTOTRAK PRIOR TO BEGINING BUILD.AS SOON AS DOWNLINK WAS COMPLETE,LOST ALL RETURNS -NOTIFY ODE OF SITUATION 21:00 - 00:00 3.00 DRILL N DPRB ' 12,583.00 INT2 ATTEMPT TO ESTABLISH LOSS RATES AND OPEN WELL COMMANDER TOOL TO SPOT LCM PILL -DYNAMIC LOSS RATE IN EXCESS OF 600 BPH I-OPEN HCR KILL AND BEGIN FILLING ON THE BACKSIDE AT 6 BPM TO ATTEMPT TO KEEP THE HOLE FULL -RACK BACK 1 STAND OF DRILL PIPE -DROP WELL COMMANDER OPEN/CLOSE BALL AND PUMP DOWAT 3 BPM,220 PSI BALL LANDED ON SEAT AT 795 STKS -PRESSURE UP TO 1000 PSI AND HELD FOR 40 SEC -CONTINUE TO PRESSURE UP,BALL SHEARED AT 1360 PSI -VERIFY COMMANDER OPEN;3 BPM,180 PSI RACK STAND BACK AND DROP WELL COMMANDER BHA SHUT-OFF BALL,PUMP DOWN AT 3 BPM,180 PSI -ATTEMPT TO RECIPROCATE PIPE,PULLED TIGHT AT 12557'MD WORKED TIGHT HOLE WHILE PUMPING DOWN BHA SHUT-OFF BALL FROM 12577'MD TO 12500'MD -PICKED UP SINGLE FROM SHED TO GAIN ROOM TO WORK PIPE AND LEFT IN STRING -SLACKED OFF 20K TO SET JARS AND WORKED UP TO 90K OVER STRING WEIGHT IN 10K INCREMENTS TO GAIN GROUND -CONTINUED TO WORK PIPE UP HOLE IN AN ATTEMPT TO GET ABOVE THE THRZ BEFORE PUMPING LCM TOTAL LOSSES FOR DAY:795 BBLS TOTAL LOSSES FOR INT2 SECTION:3097 BBLS Printed 8/8/2016 11:19:42AM `All depths reported in Drillers Depths* North America-ALASKA-BP • Page 44 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 6/18/2016 00:00 - 01:00 1.00 DRILL N DPRB ! 12,657.00 INT2 CONTINUE TO WORK TIGHT HOLE AND PICK UP TO SHOE TO SPOT LCM PILL -CONTINUE TO WORK TIGHT HOLE FROM 12500'MD TO 12190'MD -SLACK OFF 20K TO COCK JARS AND WORKED UP TO 100K OVER STRING WEIGHT IN 10K INCREMENTS TO GAIN GROUND CONTINUED TO KEEP THE HOLE FULL FILLING ON THE BACKSIDE AT 6 BPM. 01:00 - 03:30 2.50 LCR N DPRB 12,657.00 INT2 SPOT 50 BBL 80 PPB LCM"SUPER PILL" -CIRCULATE 50 BBL PILL DOWN THE DRILL STRING TO THE WELL COMMANDER AT 4 BPM -REDUCE RATE TO 1.5 BPM WHILE PUMPING PILL THROUGH WELL COMMANDER -FULL LOSSES WHILE PUMPING PILL -CONTINUE TO FILL DOWN THE BACKSIDE AT 6 BPM WITHOUT RETURNS -FULL RETURNS WITH 30 BBL OF PILL DISPLACED -CONTINUE TO DISPLACE PILL AT 1.5 BPM- FULL RETURNS MONITOR WELL FOR 10 MIN-STATIC. 03:30 - 04:00 0.50 LCR N DPRB 12,657.00 INT2 PERFORM POST JARRING INSPECTION ON DERRICK.NO ISSUES IDENTIFIED. 04:00 - 12:00 8.00 LCR N DPRB 12,657.00 INT2 MONITORING WELL BY CIRCULATING ACROSS THE TOP-WELL STATIC -TAKE ON FLUID TO PITS,WAITING ON MORE FLUID FROM MUD PLANT -PERFORM RIG MAINTENANCE:CHANGE OUT SAVER SUB,CHANGE OUT CHAIN ON PIPE SKATE. -SLIP AND CUT DRILL LINE;CUT 48'OF LINE -CALIBRATE BLOCK HEIGHT WITH AMPHION AND BAKER MWD 12:00 - 15:30 3.50 LCR N DPRB 12,657.00 INT2 MONITORING WELL BY CIRCULATING ACROSS THE TOP-WELL STATIC -CLOSE WELL COMMANDER.126 BPM,350 PSI PUMP DOWN.1800 PSI VERIFY CLOSE. -TAKE ON FLUID TO PITS,WAITING ON MORE FLUID FROM MUD PLANT -PERFORM RIG MAINTENANCE -10.5 PPG LSND AVAILIBILITY:PITS TOPPED OFF,4 FULL VAC TRUCKS ONSITE,580 BBLS AT BAROID,290 BBLS AT MI SWACO. Printed 8/8/2016 11:19:42AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 45 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:30 - 17:30 2.00 LCR N DPRB 12,657.00 INT2 WASH DOWN FROM 12,180'MD TO 12,657'MD -247 GPM,800-970 PSI TO 12,618'MD 11% FLOW OUT. -15 RPM,8-11KTORQUE TIGHT SPOT AT 12,618'MD.PICK UP 3OFT TO WIPE.WASH BACK DOWN WITHOUT TAGGING UP.PRESSURE FLUCTUATING FROM 850-1300 PSI. -TAG UP ON FILL 2FT OFF BOTTOM.SLOWLY STAGE UP PUMPS TO 444 GPM,ALLOWING PRESSURE TO STABILIZE.14%FLOW OUT. -DOWNLINK TO AUTOTRACK TO OPEN RIBS. -INCREASE FLOW RATE TO MINIMUM DRILLING RATE 500 GPM,2440 PSI.LOSE RETURNS,FLOW OUT AT 0%. -REDUCE RATE TO 450 GPM AND RE-ESTABLISH PARTIAL RETURNS,6%FLOW OUT.DOWNLINK TO CLOSE RIBS. -PUMP 30 BBL DRILL AHEAD PILL.NO RESPONSE. 17:30 - 22:00 4.50 LCR N DPRB 12,657.00 INT2 FUNCTION WELL COMMANDER AND PUMP LCM PILL PUMP OPENING BALL DOWN 124 GPM, 350-400 PSI LAND BALL ON SEAT AND PRESSURE TO 2127 PSI,VERIFY COMMANDER OPEN -PUMP BHA SHUT OFF BALL DOWN 124GPM, 350PSI -PUMP 35 BBL OF 80 PPB LCM PILL,NO STATIC LOSSES. -DROP CLOSE BALL.PUMP 2 BPM, COMPLETE LOSSES.BACKSIDE REMAINING FULL WITHOUT FILLING. -PUMP 30 BBL DRILL AHEAD PILL.NO CHANGE. 22:00 - 23:00 1.00 LCR N DPRB 12,693.00 INT2 DRILL 36FT OF NEW FORMATION TO 12,693' MD AND PUMP OUT OF HOLE TO SHOE NO CHANGE IN LOSSES WHILE DRILLING NEW FORMATION.LARGE 30FT RESISTIVITY SPIKE LOGGED ON RESISTIVITY. -WORKED PIPE AND JARRED WHILE PUMPING OUT OF HOLE AT 12,685'MD AND 12,620'MD. -500 BPH STATIC LOSS RATE AT SHOE 23:00 - 00:00 1.00 LCR N DPRB 12,693.00 INT2 FUNCTION WELL COMMANDER -PUMP OPENING BALL DOWN 124 GPM,350 PSI -LAND BALL ON SEAT 1750 PSI,VERIFY COMMANDER OPEN -PUMP BHA SHUT OFF BALL DOWN 124 GPM, 350 PSI -PERFORM POST JARRING DERRICK INSPECTION.NO ISSUES IDENTIFIED. TOTAL LOSSES FOR DAY:2935 BBLS TOTAL LOSSES FOR INT2 SECTION:6032 BBLS Printed 8/8/2016 11:19:42AM *AII depths reported in Drillers Depths* • North America-ALASKA BP • Page 46 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 6/19/2016 00:00 - 02:30 2.50 LCR N DPRB 12,693.00 INT2 PUMP 110 BBL 80 PPB SUPER PILL THROUGH WELL COMMANDER -DISPLACE AT 4 BPM,205 PSI -CONTINUE TO KEEP THE HOLE FULL ON THE BACKSIDE WITH THE HOLE FILL PUMP -550 BPH STATIC/DYNAMIC LOSS RATE -STATIC LOSS RATE AFTER DISPLACING 110 BBL80 PPB SUPER PILL=185 BPH -CONTINUE TO KEEP THE HOLE FULL ON THE BACKSIDE WITH THE HOLE FILL PUMP BUILD MUD VOLUME,BOTH BARIOD AND MI SWACO MUD PLANTS BUILDING MUD 02:30 - 06:00 3.50 LCR N DPRB 12,693.00 INT2 BUILD AND PUMP 50 BBL 80 PPB SUPER PILL THROUGH THE WELL COMMANDER -DISPLACE AT 4 BPM,205 PSI -CONTINUE TO KEEP THE HOLE FULL ON THE BACKSIDE WITH THE HOLE FILL PUMP -550 BPH STATIC/DYNAMIC LOSS RATE -STATIC LOSS RATE AFTER DISPLACING 50 BBL 80 PPB SUPER PILL=175 BPH CONTINUE TO KEEP THE HOLE FULL ON THE BACKSIDE WITH THE HOLE FILL PUMP -FROM 04:30 TO 05:00 STATIC LOSS RATE SLOWED TO 165 BPH TO 140 BPH CONTINUE TO BUILD MUD VOLUME. BUILD 50 BBL 120 PPB EXTREME SUPER PILL TOTAL LOSSES SINCE MIDNIGHT=1212 BBL 06:00 - 13:00 7.00 LCR N DPRB 12,693.00 INT2 BUILD AND PUMP 50 BBL 120 PPB EXTREME SUPER PILL THROUGH THE WELL ,COMMANDER -DISPLACE AT 4 BPM,210 PSI -CONTINUE TO KEEP THE HOLE FULL ON THE BACKSIDE WITH THE HOLE FILL PUMP -24-72 BPH DYNAMIC/STATIC LOSS RATE WHILE PUMPING PILL -STATIC LOSS RATE AFTER DISPLACING 50 BBL 80 PPB SUPER PILL=72 BPH -CONTINUE TO KEEP THE HOLE FULL ON THE BACKSIDE WITH THE HOLE FILL PUMP CONTINUE TO BUILD MUD VOLUME BUILD 80 BBL 140 PPB SUPER LCM PILL PERFORM RIG MAINTENANCE 13:00 - 15:30 2.50 LCR N DPRB 12,693.00 INT2 PULL 4 STANDS TO 11800'MD BIT DEPTH AND PUMP 80 BBL 140 PPB SUPER LCM PILL -PUMP LCM PILL DOWN STRING AT 4 BPM, 260 PSI -DISPLACE LCM PILL FROM STRING AT 1.5 BPM AT 60 PSI -STATIC LOSS RATE AFTER DISPLACING LCM PILL=0 BPH CONTINUE TO BUILD MUD VOLUME PERFORM RIG MAINTENANCE Printed 8/8/2016 11:19:42AM `AII depths reported in Drillers Depths* • North America-ALASKA BP • Page 47 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:30 - 23:00 7.50 LCR N DPRB 12,693.00 INT2 CONTINUE TO MONITOR WELLAND LOSS RATE -LOSS RATE INCREASED FROM 0 BPH AT 15:30 TO 35 BPH BY 18:30 HRS -STATIC LOSS RATE STEADY AT 35 BPH FROM 15:30 TO 23:00 -CONTINUE TO KEEP THE HOLE FULL ON THE BACKSIDE WITH THE HOLE FILL PUMP CONTINUE TO BUILD MUD VOLUME BUILD 110 BBL 140 PPB SUPER LCM PILL PERFORM RIG MAINTENANCE 23:00 - 23:30 0.50 LCR N DPRB 12,693.00 INT2 STAGE UP PUMPS TO 10 BPM TO ATTEMPT TO CIRCULATE WELL CLEAN FROM 11800'MD -50%RETURNS AT 6 BPM -DYNAMIC LOSS RATE AT 10 BPM=400 BPH -UNABLE TO EFFECTIVELY CLEAN UP ANNULUS -STATIC LOSS RATE=0 BPH FINISH BUILDING 110 BBL 140 PPB SUPER LCM PILL 23:30 - 00:00 0.50 LCR P 12,693.00 INT2 SERVICE TOP DRIVE AND RIG FLOOR EQUIPMENT TOTAL LOSSES FOR DAY:2769 BBLS TOTAL LOSSES FOR INT2 SECTION:8801 BBLS 6/20/2016 00:00 - 05:00 5.00 1 LCR N DPRB 12,693.00 INT2 BUILD AND PUMP 120 BBL 140 PPB SUPER LCM PILL THROUGH THE WELL COMMANDER -STATIC LOSS RATE 10 BPH -PUMP LCM PILL AT 2.5 BPM,140 PSI DISPLACE LCM PILL WITH 10.5 PPG LSNDAT 2.5 BPM,140 PSI REGAIN PARTIAL RETURNS -CLOSE THE ANNULAR AND REDUCE RATE TO 1 BPM,45 PSI -PUMP DOWN THE BACKSIDE AT 1 BPM,45 PSI AND DOWN THE DRILL STRING AT 1 BPM, 45 PSI -SHUT DOWN WITH ALL OF PILL DISPLACED AND 60%INJECTED INTO FORMATION -MONITOR WELL,STATIC LOSS RATE 12 BPH 05:00 - 07:30 2.50 LCR N DPRB 12,693.00 INT2 ATTEMPT TO CLOSE WELL COMMANDER -KEEP THE HOLE FULL WITH THE TRIP TANK; STATIC LOSS RATE=12 BPH -DROP 2.115"OD CLOSING BALLAND PUMP DOWN TO WELL COMMANDER -3 BPM,377 PSI -ATTEMPT TO CLOSE WELL COMMANDER FOLLOWING PRESSURE/HOLD SCHEDULE -WORK PRESSURE UP TO 4300 PSI-NO SUCCESS -BLEED OFF PRESSURE AND REPEAT PRESSURE/HOLD SEQUENCE 2 MORE TIMES -PRESSURE UP TO 4300 PSI EACH TIME WITH NO SUCCESS. Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • North America.-ALASKA-BP Page 48 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:30 - 09:00 1.50 LCR N DPRB 12,693.00 INT2 PULL OUT OF THE HOLE ON ELEVATORS WET FROM 11800'MD TO 9500'MD AT 50-80 FPM -PU 260K,SO 170K AT 11800'MD -KEEP THE HOLE FULL WITH THE TRIP TANK; LOSS RATE 3-5 BPH MORE THAN PIPE DISPLACEMENT 09:00 - 09:30 0.50 LCR N DPRB 12,693.00 INT2 MAKE TWO MORE ATTEMPTS TO CYCLE WELL COMMANDER CLOSED FOLLOWING MI SWACO PROCEDURE -FOLLOW THE PRESSURE/HOLD SEQUENCE UP TO 4300 PSI WITH NO !SUCCESS. 09:30 - 14:30 5.00 LCR N DPRB 12,693.00 INT2 CONTINUE TO PULL OUT OF THE HOLE ON ELEVATORS WET FROM 9500'MD TO 807'MD AT 150-250 FPM PU 110K,SO 92K AT 4792'MD -KEEP THE HOLE FULL WITH THE TRIP TANK; LOSS RATE 25-30 BPH MORE THAN PIPE DISPLACEMENT -MONITOR THE WELL AT THE TOP OF THE BHA;STATIC LOSS RATE=14 BPH 14:30 - 16:30 2.00 LCR N DPRB 12,693.00 INT2 PULL AND LAY DOWN 8-1/2"INT2 DRILLING ASS'Y FROM 807'TO SURFACE -BHA WAS PACKED OFF WITH LCM FROM FLEX COLLARS DOWN TO BIT -BREAK DOWN AND FLUSH ALL BHA COMPONENTS ON RIG FLOOR LAY DOWN BHA TO PIPE SHED -MONITOR WELL FOR 10 MIN;STATIC LOSS RATE=20 BPH 16:30 - 18:00 1.50 LCR N DPRB 12,693.00 INT2 CLEAN AND CLEAR LCM AND MUD FROM RIG FLOOR -30 BPH STATIC LOSS RATE 18:00 - 18:30 0.50 LCR P 12,693.00 INT2 SERVICE TOP DRIVE AND RIG FLOOR EQUIPMENT 18:30 - 19:00 0.50 LCR N DPRB 12,693.00 INT2 MAKE UP 9-5/8"HES EZ DRILL SVB SQUEEZE PACKER AND MECHANICAL SETTING TOOL ON RIG FLOOR -30 BPH STATIC LOSS RATE 19:00 - 00:00 5.00 LCR N DPRB 12,693.00 INT2 RUN IN THE HOLE WITH 9-5/8"EZ DRILL SQUEEZE PACKER ON TAPERED DRILL STRING(4"X 5")TO 5885'MD -RUN IN THE HOLE ON ELEVATORS AT 80 FPM -KEEP THE HOLE FULL WITH THE TRIP TANK; LOSS RATE 15-20 BPH MORE THAN PIPE DISPLACEMENT WHILE RUNNING IN -FILL PIPE EVERY 1000'MD;STAGE UP PUMPS TO 3 BPM AND CIRCULATE FOR 5 MIN -PARTIAL RETURNS WHEN STAGING UP PUMPS -MONITOR WELL AFTER PUMPING AND DETERMINE STATIC LOSS RATE;WELL CONTINUED TO LOSE AT 20 BPH TOTAL LOSSES FOR DAY:890 BBLS TOTAL LOSSES FOR INT2 SECTION:9691 BBLS Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 49 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 6/21/2016 00:00 - 07:00 7.00 LCR N DPRB 12,693.00 INT2 CONTINUE TO RUN IN THE HOLE WITH 9-5/8" EZ DRILL SQUEEZE PACKER FROM 5885'MD TO 12109'MD PLANNED SET DEPTH FOR CEMENT RETAINER. -RUNNING SPEED=60-80 FPM -KEEP THE HOLE FULL WITH THE TRIP TANK; LOSS RATE 5-10 BPH MORE THAN PIPE DISPLACEMENT WHILE RUNNING IN -FILL PIPE EVERY 1000'MD -STAGE UP PUMPS TO 3 BPM AND CIRCULATE FOR 5 MIN EVERY 2000'MD PARTIAL RETURNS WHEN STAGING UP PUMPS -MONITOR WELL AFTER PUMPING AND DETERMINE STATIC LOSS RATE;WELL CONTINUED TO LOSE AT 5-10 BPH -FLOW CHECK WELL AT 7185'MD,8355'MD AND 10425'MD:PIPE DISPLACEMENT STILL LESS THAN CALCULATED BUT MORE THAN PREVIOUS 5 STANDS:WELL CONTINUED TO LOSE AT 2-4 BPH 07:00 - 07:30 0.50 LCR N DPRB 12,693 00 INT2 SET CEMENT RETAINER WITH TOP AT 12109' MD PER HALLIBURTON TOOL REP. -SET DOWN 20KLBS TO CONFIRM SET 07:30 - 11:00 3.50 LCR N DPRB 12,693.00 INT2 CIRCULATE HOLE CLEAN AND CONDITION MUD TO EVEN 10.5 PPG IN/OUT WITH 3 BOTTOMS UP -600 BPM,1900 PSI -MIRU SLB CEMENTERS. HOLD PJSM AND PRESSURE TEST LINES TO 250 PSI LOW AND 4200 PSI HIGH FOR FIVE MIN EACH(PASSING TESTS,PER LEAKTIGHT CRITERIA). 11:00 - 13:00 2.00 LCR N DPRB 12,693.00 INT2 PERFORM OPENHOLE ABANDONMENT SQUEEZE CEMENT JOB AS FOLLOWS: WITH CEMENT RETAINER STINGER UNSTUNG -SLB PUMP 5 BBLS 12 PPG MUDPUSH,2.5 BPM,300 PSI -SLB PUMP 43.5 BBLS 15.8 PPG CLASS G CEMENT,5 BPM,565 PSI ICP,175 PSI FCP -SLB PUMP 5 BBLS 12.0 PPG MUD PUSH, 5BPM,100 PSI -SLB DISPLACE CEMENT TO END OF STINGER WITH 128.5 BBLS 10.5 PPG LSND,5 BPM,225 PSI -WITH CEMENT AT END OF STINGER,STAB INTO CEMENT RETAINER -SLB SQUEEZE 41.5 BBLS CEMENT BELOW CEMENT RETAINER 5 BPM,80 PSI -PICKUP TO PIPE MARK FOR 5.5'ABOVE RETAINER Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 50 of 97 Operation Summary Report Common Well Name L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:00 - 13:30 0.50 LCR N HMAN 12,693.00 INT2 WITH STINGER THOUGHT TO BE UN-STUNG FROM RETAINER -SLB PUMP 7 BBLS 10.5 PPG LSND,5 BPM, 80 PSI -RIG PUMP 42 BBLS 10.5 PPG LSND;540 GPM,2500 PSI. OBSERVE NO RETURNS AND DISCOVER STILL STUNG INTO RETAINER. SHUT DOWN PUMPS. -PICKUP 1'TO COMPLETLY UNSTING FROM CEMENT RETAINER. RESTART PUMPS AND BEGIN TO OBSERVE FULL RETURNS. BEGIN TO CIRCULATE HOLE CLEAN WHILE DISCUSSING RESULTS OF OPENHOLE ABANDONMENT WITH ANCHORAGE TEAM. -550 GPM,1975 PSI FOR 3/4 BOTTOMS UP, NO RECIPROCATION 13:30 14:00 0.50 LCR N HMAN 12,693.00 INT2 STING BACK INTO CEMENT RETAINER AND ESTABLISH INJECTION RATES 2 BPM=100 PSI 3 BPM=180 PSI -4 BPM=280 PSI -5 BPM=420 PSI UNSTING FROM RETAINER AFTER ESTABLISHING RATES AND DISCUSS RESULTS WITH ANCHORAGE TEAM. 14:00 - 15.00 1.00 LCR N HMAN 12,693.00 INT2 APPROXIMATELY 10MIN AFTER UNSTINGING FROM CEMENT RETAINER,RE-STING BACK IN AND ATTEMPT TO ESTABLISH INJECTION RATES. PUMP AT 1 BPM AND PRESSURE UP TO 1322 PSI. SUCCESSFULLY HOLD PRESSURE FOR 50 MIN. 15:00 - 16:30 1.50 LCR N DPRB 12,693.00 INT2 UNSTING FROM CEMENT RETAINER AND RESUME CIRCULATING HOLE CLEAN WITH 2 FULL BOTTOMS UP -550 GPM,1960 PSI 16:30 - 17:30 1.00 LCR N HMAN 12,693.00 INT2 WAITING ON AOGCC APPROVAL OF OPENHOLE ABANDONMENT PLUG AND PLAN FORWARD FROM ANCHORAGE TEAM. 17:30 - 22:00 4.50 LCR N DPRB 12,693.00 INT2 PREPARE FOR L1-13PB1 P&A -RECEIVE PLANS AND AUTHORIZATIONS TO PROCEED FROM ANCHORAGE TEAM& AOGCC FOR BALANCED PLUG AND CONTINUING ON WITH L1-13 SIDETRACK. -CIRCULATE 2 BOTTOMS UP;600 GPM,2225 PSI -SPACEOUT WITH TOOL JOINT AT RIG FLOOR AND END OF CEMENT RETAINER STINGER AT 12104'MD(5'ABOVE CEMENTER RETAINER). RIG UP HEAD PIN AND FOSV ON STUMP. CLOSE ANNULAR PREVENTER AND LINE UP THROUGH MGS. -HOLD PJSM WITH RIG TEAM AND SLB FOR CEMENTING -PRESSURE TEST CEMENTING LINES TO 250 PSI LOW AND 4400 PSI HIGH FOR FIVE MIN EACH(PASSING TESTS PER LEAKTIGHT CRITERIA) -BATCH UP MUD PUSH AND CEMENT. CEMENT WET AT 21:08 -AOGCC REP BOB NOBLE WAIVES STATE'S RIGHT TO WITNESS P&A OPERATIONS Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* North America-ALASKA-BP • Rage 51 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:00 - 23:00 1.00 LCR N DPRB 12,693.00 INT2 LAY IN 500'MD BALANCED PLUG ON TOP OF CEMENT RETAINER AT 12109'MD PER OCN #10 AS FOLLOWS: -WITH ANNULAR PREVENTER SHUT,HOLD 1000 PSI BACKPRESSURE ON WELL DURING CEMENTING OPS. OPEN CHOKE 100%TO RELEASE ALL BACKPRESSURE WHEN MUD PUSH BEGINS TO ROUND CORNER(123 BBLS INTO DISPLACEMENT) -SLB PUMP 8.5 BBLS 11.5 PPG MUD PUSH,3 BPM,1400 PSI -SLB PUMP 36.6 BBLS 15.6 PPG CLASS G CEMENT,5 BPM,1500 PSI ICP,1100 PSI FCP SLB PUMP 1.6 BBLS 11.5 PPG MUD PUSH, 2.5 BPM,835 PSI ICP,700 PSI FCP -SLB DISPLACE WITH 160 BBLS 10.5 PPG LSND AT 5 BPM,1000-1200 PSI WITH BACKPRESSURE,150-300 PSI WITHOUT BACKPRESSURE. SLOW RATE TO 2 BPM,50 PSI ICP,200 PSI FCP FOR FINAL 10 BBLS. TOTAL DISPLACEMENT=170 BBLS(4.5 BBLS I UNDERDISPLACED) -CLOSE FOSV IMMEDIATELY WHEN PUMPS ARE SHUT DOWN. RIG DOWN CEMENT LINE FROM HEAD PIN -OPEN FOSV AND OBSERVE NOTICEABLE SOUND OF U-TUBE BALANCING. -OPEN ANNULAR PREVENTER PRIOR TO PULLING OUT OF HOLE. BREAK OFF HEAD PIN AND FOSV CEMENT IN PLACE AT 22:50. 500 PSI COMPRESSIVE STRENGTH AT 8HR 30MIN (07:20AM ON 6/22/16) FIELD PICK TOC=11609'MD(500'PLUG) 23:00 - 00:00 1.00 LCR N DPRB 12,693.00 INT2 PULL OUT OF HOLE WITH CEMENT RETAINER RUNNING TOOL FROM 12104'MD(5'ABOVE RETAINER"TO"SAFETY"AT 11382'MD(-227' ABOVE ESTIMATED TOC) -PULL AT 5 MIN/STAND -PIPE PULLS DRY -INITIAL PICKUP WEIGHT OFF BOTTOM=245 KLBS TOTAL LOSSES FOR DAY:449 BBLS TOTAL LOSSES FOR INT2 SECTION:10,140 BBLS 6/22/2016 00:00 - 01:30 1.50 LCR N DPRB 12,693.00 INT2 CIRCULATE HOLE CLEAN WITH SURFACE TO SURFACE VOLUME WITH CEMENT RETAINER STINGER AT 11382'MD(-227'ABOVE ESTIMATED TOC) -DROP 5"NERF WIPER BALL -PUMP 30 BBL NUT PLUG SWEEP SURFACE TO SURFACE -NO CEMENT RETURNS UPON BOTTOMS UP -600 GPM,1800 PSI,RECIPROCATING FULL STAND AT 1000 FPH,MW IN/OUT=10.5 PPG -FLOWCHECK WELL FOR 10 MIN PRIOR TO PULLING OUT OF HOLE(STATIC) Printed 8/8/2016 11.19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 52 of 97 Operation Summary Report Common Well Name L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:30 - 07:00 5.50 LCR N DPRB 12,693.00 INT2 PULLOUT OF THE HOLE WITH CEMENT RETAINER RUNNING TOOL FROM 11382'MD TO SURFACE -PUMP DRY JOB PULLING SPEED=265 FPM,NO LIMIT 07:00 - 07:30 0.50 LCR N DPRB 12,693.00 INT2 BREAKDOWN CEMENT RETAINER RUNNING TOOL AND CLEAN RIG FLOOR AFTER TRIPPING 07:30 - 08:30 1.00 LCR N DPRB 12,693.00 INT2 MIRU HALLIBURTON E-LINE 08:30 - 09:30 1.00 LCR N DPRB 12,693.00 I INT2 PRESSURE TEST 9-5/8"CASING CEMENT PLUG TO 250 PSI LOW FOR 5 MIN/3500 PSI HIGH FOR 30 MIN TO CONFIRM ISOLATION FROM ABANDONED WELLBORE BELOW -LOST 26 PSI DURING FIRST 15 MIN,LOST 13 PSI DURING SECOND 15 MIN -BBL IN=11.3 BBL,BBL OUT=11.3 BBL -PASSING TEST PER BP INTEGRITY TESTING CRITERIA,SEE ATTACHED CHART -TEST APPROVED BY WELL SUPT 09:30 - 15:00 5.50 LCR N DPRB I 12,693.00 I INT2 'RUN HES EZSV ON E-LINE AND SET PLUG AT 10777'ELMD -RUN E-LINE THROUGH RIG BOP WITH INTEGRAL LINE WIPER/CUTTER AND NO 'ADDITIONAL PRESSURE CONTROL PER SOP (APPROVED BY WELL SUPT) -MONITOR WELL DISPLACEMENT VIA TRIP TANK -LOG GR/CCLACROSS DESIRED SET DEPTH, SET TOP OF PLUG AT 10777'ELMD(6'ABOVE COLLAR) -POOH AND INSPECT TOOLS TO CONFIRM j GOOD SET j-RIG DOWN E-LINE 15:00 - 16:30 1.50 LCR N DPRB 12,693.00 INT2 PRESSURE TEST EZSV PLUG TO 250 PSI LOW FOR 5 MIN/3500 PSI HIGH FOR 10 MIN -BBL IN=10.2 BBL,BBL OUT=10.2 BBL -PASSING TEST,SEE ATTACHED CHART 16:30 - 18:30 2.00 STWHIP N DPRB 12,693.00 INT2 MAKE UP BAKER 9-5/8"WHIPSTOCK/ MILLING BHA FROM SURFACE TO 955'MD -SCRIBE MWD TO TRAY FACE -WSLAND BAKER REP VERIFY CORRECT SHEAR PINS AND BOLT -SHALLOW HOLE TEST MWD(PASS) 18:30 - 00:00 5.50 LCR N DPRB 12,693.00 INT2 RUN IN HOLE WITH WHIPSTOCK/MILLING ASSEMBLY ON ELEVATORS FROM 955'MD TO 8150'MD -FILL PIPE EVERY 20 STANDS -LIMIT RUNNING SPEED TO 60 FPM FOR 'WHIPSTOCK 6/23/2016 00:00 - 02:30 2.50 STWHIP N DPRB 12,693.00 INT2 RUN IN HOLE WITH 9-5/8"WHIPSTOCK/ MILLING ASSEMBLY ON ELEVATORS FROM 8150'MD AT MIDNIGHT TO 10750'MD FILL PIPE EVERY 20 STANDS -LIMIT RUNNING SPEED TO 60 FPM FOR WHIPSTOCK Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 53 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne I Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/me:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:30 - 04:00 1.50 STWHIP N DPRB 12,693.00 INT2 ORIENTAND SET 9-5/8"BAKER GEN II WHIPSTOCKAT46°ROHS WITH TOP OF SLIDE AT 10754'MD. -BREAK CIRCULATION,RECORD SLOW PUMP RATES,AND ORIENT WHIPSTOCK WITH MWD AT 500 GPM,2200 PSI. WORK TORQUE DOWN TO WHIPSTOCK TO CONFIRM PROPER ALIGNMENT. -RUN IN HOLE WITH WHIPSTOCK AND TAG 1 EZSV ON DEPTH AT 10777'MD. -DO NOT DEFINITIVELY OBSERVE SHEAR OF ANCHOR BOLT OR STARTER MILL BOLT AFTER MULTIPLE ATTEMPTS OF SLACKING OFF IN INCREASING INCREMENTS. EVENTUALLY SLACKOFF WITH 80 KLBS DOWN TO DEFINITIVELY SHEAR ANCHOR AND STARTER MILL BOLTS. -CONFIRM WHIPSTOCK SET AND STARTER MILL SHEARED OFF BY OBSERVING STRING ROTATE FREELY 10'ABOVE WHIPSTOCK SLIDE AND STALL OUT AT TOP OF SLIDE. 04:00 - 20:00 16.00 STWHIP N DPRB 12,693.00 INT2 MILL WINDOW IN 9-5/8"CASING FROM 10754' MD(TOP WINDOW)TO 10771'MD(BOTTOM -WINDOW)AND DRILL 20'OF NEW CM3 FORMATION TO 10791'MD PER OCN#11 -INITIAL MILLING PARAMETERS:500 GPM, 2150 PSI,1-2 KLBS WOB,80-100 RPM,20-21 KFT-LBS -FINAL MILLING PARAMETERS:650 GPM, 3150 PSI,20 KLBS WOB,100 RPM,17 KFT-LBS -ADD LUBES AND VISCOSIFY MUD DOWNHOLE(WAS INITIALLY NEW MUD WITH NO LUBES ORDERED DUE TO PREVIOUS LOSSES) -INITIALLY LIMITED BY HIGH FREE TORQUE, INCREASE LUBE CONCENTRATION TO 2.25% I(INCLUDES 0.25%EP MUDLUBE)WITH SUCCESS -OBSERVE CEMENT AND FORMATION RETURNS DURING MILLING -UPPER WINDOW MILLS FULLY EXITS AT 10789'MD 1-DRIFT WINDOW WITHOUT ISSUE -SEE ATTACHED BAKER MILLING REPORT FOR MORE DETAILS PUMP 40 BBL HI-VIS SWEEP AT 10771'MD AFTER MILLING WINDOW:100%INCREASE IN METAL SHAVINGS 20:00 - 20:30 0.50 STWHIP N DPRB 12,693.00 INT2 CIRCULATE AND CONDITION WELLBORE 'WITH 1.5 BOTTOMS-UP PRIOR TO FIT -600 GPM,2700 PSI -STARTED 1.5X BU CIRCULATION DURING FINAL 3'OF DRILLING TO OPTIMIZE CIRCULATING TIME -PUMP 40 BBL HI-VIS SWEEP AT 10788'MD: NO INCREASE IN METAL RETURNS -CONFIRM MW IN=MW OUT=10.5 PPG Printed 8/8/2016 11:19:42AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP Page 54 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20.30 - 21:00 0.50 STWHIP N DPRB 12,693.00 INT2 PERFORM FIT TO 11.7 PPG EMW -MONITOR WELLBORE INSIDE CASING FOR 10 MIN(STATIC) BOTTOM OF WINDOW AT 10771'MD,6749' ITVD -PRESSURE UP TO 422 PSI WITH 10.5 PPG MUD AND HOLD FOR 10 MIN -1.1 BBL TO PRESSURE UP,1.0 BBL BLED BACK TEST RESULT APPROVED BY ODE,SEE ATTACHED CHART 21:00 - 00:00 3.00 STWHIP N DPRB 12,693.00 INT2 PULL OUT OF HOLE WITH MILLING ASSEMBLY FROM TOP OF WINDOW AT 10754'MD TO 5000'MD AT MIDNIGHT -MONITOR WELLBORE PRIOR TO PULLING OFF-BOTTOM FOR 10 MIN(STATIC) -RECORD SLOW PUMP RATES ON BOTTOM -PUMP DRY JOB 6/24/2016 00:00 - 02:00 2.00 STWHIP N DPRB 12,693.00 INT2 PULL OUT OF HOLE WITH MILLING ASSEMBLY FROM 5000'MD TO BHAAT 951'MD 02:00 - 04:00 2.00 STWHIP N DPRB 12,693.00 INT2 LAY DOWN MILLING BHA FROM 951'MD TO ,SURFACE MONITOR WELLBORE PRIOR TO BHA ACROSS STACK FOR 10 MIN(STATIC) -LAY DOWN 6-1/2"DRILL COLLARS,RACK BACK 5"HWDP -LAY DOWN AND INSPECT MILLS(WINDOW MILL&LOWER MILL=1/8"UNDER-GAUGE, UPPER MILLS=IN-GAUGE) 04:00 - 06:00 2.00 STWHIP N DPRB 12,693.00 INT2 CLEAN AND CLEAR RIG FLOOR AFTER TRIPPING AND FLUSH STACK TO REMOVE ANY METAL DEBRIS AFTER MILLING -PERFORM WEEKLY BOP FUNCTION TEST (FROM LER PANEL). RECORD CLOSING TIMES FOR EACH ELEMENT ON IADC 06:00 - 09:00 3.00 DRILL N DPRB 12,693.00 INT2 MAKE UP 8-1/2"BENT MOTOR DRILLING ASSEMBLY FROM SURFACE TO 833'MD -NEW HCC VM-3 TRI-CONE BIT,0.941 TFA -1.5°AKO ULTRA XTREME MUD MOTOR WITH PORTED FLOAT+DIR/GR/RES/PWDNSS -WELL COMMANDER CIRC SUB -BHAACTUAL BOUYED WEIGHT AT 833'MD= 75 KLBS -SHALLOW HOLE TEST MWD(PASS) 09:00 - 15:00 6.00 DRILL N DPRB 12,693.00 INT2 TRIP IN HOLE WITH 8-1/2"DRILLING ASSEMBLY FROM BHAAT 833'MD TO PREVIOUSLY DRILLED 10791'MD. -4"/5"TAPERED STRING(XO TO 5"AT 4808' BACK FROM BIT) -265 FPM RUNNING SPEED -FILL PIPE EVERY 20 STANDS Printed 8/8/2016 11.19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP S Page 55 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 00:00 9.00 DRILL N DPRB 12,693.00 INT2 DIRECTIONAL DRILL 8-1/2"INT2 HOLE FROM 10791'MD TO 10965'MD,6895'TVD AT MIDNIGHT IN CM FORMATION(174'IN 9 HRS= 19 FPH) -20-40 FPH INSTANTANEOUS ROP SLIDING, 20-40 FPH INSTANTANEOUS ROP ROTATING -450 GPM,2100-2250/2025 PSI ON/OFF BTM, 60 RPM,209 TOTAL BIT RPM,10 KFT-LBS TRQ ON/OFF BTM,20-25 KLBS WOB MW IN/OUT=10.5 PPG,YP=24(INITIAL YP AT START OF DRILLING=31 ACCOUNTED FOR INITIAL HIGH 11.5 PPG ECDS) -ECD CALC CLEANHOLE=11.3 PPG,ACTUAL =11.3-11.4 NO LOSSES TO FORMATION WHILE DRILLING AHEAD -SURVEY EVERY 30'(PLANNED DOGLEGS> 5°/100') -NO BACKREAMING AT CONNECTIONS -PICKUP WEIGHT AT 10965'MD=215, SLACKOFF=151 KLBS,173 KLBS ROTATING -ACTUAL DRILLING HOURS FOR PAST 24 HRS =6 HRS,ROTATING=1.3 HRS,SLIDING=4.7 HRS 14°/100'DLSAT 10847'MD SURVEY- GREATER THAN LISBURNE BASIS OF DESIGN. NOTIFY ODE AND DECISION TO REAM STAND SEVERAL TIMES AND RE-SHOOT SURVEY. NO CHANGE IN SURVEY AFTER REAMING. 6/25/2016 00:00 - 06.00 6.00 DRILL N DPRB 12,693.00 INT2 DIRECTIONAL DRILL 8-1/2"INT2 HOLE FROM 10965'MD AT MIDNIGHT TO 11110'MD IN CM FORMATION(145'IN 6 HRS=24 FPH) -20-50 FPH INSTANTANEOUS ROP SLIDING, 20-50 FPH INSTANTANEOUS ROP ROTATING -500 GPM,2500-2650/2350-2450 PSI ON/OFF BTM,60 RPM,277 TOTAL BIT RPM,10-12/9-11 KFT-LBS TRQ ON/OFF BTM,24-26 -MW IN/OUT=10.5 PPG -ECD CALC CLEANHOLE=11.3 PPG,ACTUAL =11.3 -NO LOSSES TO FORMATION WHILE DRILLING -SURVEY EVERY 30'(PLANNED DOGLEGS> 5°/100') -NO BACKREAMING AT CONNECTIONS Printed 8/8/2016 11:19:42AM 'All depths reported in Drillers Depths' • North America-ALASKA-BP • Page 56 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth 1 Phase Description of Operations (hr) (usft) 06:00 - 15:00 9.00 DRILL N DPRB 12,693.00 INT2 I DIRECTIONAL DRILL 8-1/2"INT2 HOLE FROM 11110'MD TO 11438'MD,END OF BUILD/TURN TO GAIN SEPARATION FROM OLD WELLBORE IN CM FORMATION(328'IN 9 HRS=37 FPH) -20-40 FPH INSTANTANEOUS ROP SLIDING, 40-80 FPH INSTANTANEOUS ROP ROTATING -500 GPM,2600-2700/2400-2450 PSI ON/OFF BTM,60 RPM,225 TOTAL BIT RPM,12-14/12 KFT-LBS TRQ ON/OFF BTM,25-28 KLBS WOB -MW IN/OUT=10.5 PPG, -ECD CALC CLEANHOLE=11.3 PPG,ACTUAL =11.3-11.4 PPG EMW -NO LOSSES TO FORMATION WHILE DRILLING -SURVEY EVERY 30'(PLANNED DOGLEGS> 5°/100') -NO BACKREAMING AT CONNECTIONS 15:00 - 17:00 2.00 DRILL N DPRB 12,693.00 INT2 CIRCULATE HOLE CLEAN WITH 1 BOTTOMS UP -CIRCULATE 40 BBL HI-VIS SWEEP SURFACE TO SURFACE(MINIMAL INCREASE IN RETURNS) 500 GPM,2430 PSI,60 RPM,10-13 KFT-LBS TRQ,RECIPROCATE FULL STAND 1000 FPH 17:00 - 22:00 5.00 DRILL N DPRB 12,693.00 INT2 PULL OUT OF HOLE WITH 8-1/2"DRILLING ASSEMBLY FROM 11439'MD TO BHAAT 833' MD -PULLING SPEED=150-210 FPM -NO ISSUES TRIPPING THROUGH OPENHOLE OR WINDOW. -FLOWCHECK WELL FOR 10 MIN ON BOTTOM AND AT WINDOW(STATIC) -HOLD UNANNOUNCED KICK WHILE TRIPPING DRILL(02:30 CRT)AND AAR. HOLD STOP THE JOB DRILL 22:00 00:00 2.00 DRILL N DPRB 12,693.00 INT2 (LAYDOWN 8-1/2"MOTOR DRILLING ASSEMBLY FROM 833'MD TO SURFACE. -FLOWCHECK WELL FOR 10 MIN PRIOR TO PULLING BHA THROUGH STACK(STATIC). HOLD PJSM FOR LAYING DOWN BHA 6/26/2016 00:00 - 01:00 1.00 DRILL N DPRB 12,693.00 INT2 COMPLETE LAYING DOWN 8-1/2"MOTOR DRILLING ASSEMBLY. CLEAN AND CLEAR RIG FLOOR AFTER TRIPPING. -GRADE MILL TOOTH BIT 3-3-IN GAUGE 01:00 - 03:30 2.50 DRILL N DPRB 12,693.00 INT2 MAKEUP AND RUN IN HOLE WITH 8-1/2"RSS DRILLING ASSEMBLY FROM SURFACE TO 817' 'MD -FLOWCHECK WELL FOR 10 MIN PRIOR TO RUNNING IN HOLE(STATIC) -REBUILD HCC HCC DP606X BIT,0.902 TFA AUTOTRAK ROTARY STEERABLE SYSTEM WITH PORTED FLOAT+NEARBIT INC&GR/DI R/GR/RES/PWDNSS -WELL COMMANDER CIRC SUB -BHAACTUAL BOUYED WEIGHT AT 817'MD= .72 KLBS I-PLUG INTO MWD TOOLS ON SURFACE AND SHALLOW HOLE TEST MWD ON LAST HWDP (PASS) Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 57 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) ..-_.._._- Project:Lisburne Site:Us DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:30 - 11:00 7.50 DRILL N DPRB 12,693.00 INT2 TRIP IN HOLE WITH 8-1/2"RSS DRILLING ASSEMBLY FROM BHA AT 817'MD TO PREVIOUSLY DRILLED 11439'MD. -RUNNING SPEED=265 FPM 11:00 - 18:00 7.00 DRILL N DPRB 12,693.00 INT2 DIRECTIONAL DRILL 8-1/2"INT2 HOLE FROM 11438'MD TO 11861'MD IN CM FORMATION (423'IN 7 HRS=60 FPH WITH CONNECTIONS) -100 FPH INSTANTANEOUS ROP(LIMITED FOR ECD) -450-500 GPM,2250-2350 PSI ON/OFF BTM, 120 RPM,17-18/15-16 KFT-LBS TRQ ON/OFF BTM,12-15 KLBS WOB -ATTEMPTING TO KEEP FLOWRATE AS HIGH AS POSSIBLE WHILE MAINTAINING ECD 'UNDER 11.7 PPG HARDLINE -MW IN/OUT=10.5 PPG,YP=23 -ECD CALC CLEANHOLE=11.3 PPG,ACTUAL =11.4-11.7 PPG EMW -NO LOSSES TO FORMATION WHILE DRILLING AHEAD -SURVEY EVERY STAND -NO BACKREAMING AT CONNECTIONS 18:00 00:00 6.00 DRILL N DPRB 12,693.00 INT2 ,DIRECTIONAL DRILL 8-1/2"INT2 HOLE FROM 11861'MD TO 12158'MD AT MIDNIGHT IN CM FORMATION(297'IN 6 HRS=50 FPH WITH CONNECTIONS) 50-100 FPH INSTANTANEOUS ROP -475-500 GPM,2300-2600 PSI ON/OFF BTM, 150 RPM,16-18/16 KFT-LBS TRQ ON/OFF BTM, 16-18 KLBS WOB -MW IN/OUT=10.5 PPG -ECD CALC CLEANHOLE=11.3 PPG,ACTUAL =11.5-11.6 PPG EMW NO LOSSES TO FORMATION WHILE DRILLING AHEAD -SURVEY EVERY STAND -NO BACKREAMING AT CONNECTIONS 40 BBL 11.5PPG WEIGHTED SWEEP AT 11805' MD(0.2PPG ECD INCREASE WHILE IN ANNULUS)-MINOR INCREASE IN CUTTINGS AT SHAKERS. Printed 8/8/2016 11:19:42AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 58 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 6/27/2016 00:00 - 06:00 6.00 DRILL N DPRB 12,693.00 INT2 DIRECTIONAL DRILL 8-1/2"INT2 HOLE FROM 12158'MD TO 12470'MD IN CM FORMATION (312'IN 6 HRS=52 FPH) -100 FPH INSTANTANEOUS ROP(LIMITED FOR ECD) -500 GPM,2550-2600 PSI ON/OFF BTM,150 RPM,16-18 KFT-LBS TRQ ON/OFF BTM,12-18 KLBS WOB -MW IN/OUT=10.5 PPG -ECD CALC CLEANHOLE=11.3 PPG,ACTUAL I=11.5-11.6 PPG NO BACKREAMING AT CONECTIONS i-SURVEY EVERY 30'WITH>5 DEG DLS (BEGINNING DROP AND LEFT TURN WITH PLANNED 5 DEG DLS) -NO BACKREAMING AT CONNECTIONS ACTIVATE SOFTSPEED SOFTWARE AT 12300' MD(CM1)DUE TO HIGH STICK-SLIP AND ERRATIC TORQUE:STICK-SLIP LEVEL REDUCED FROM 6 TO ZERO 06:00 12:00 6.00 DRILL N DPRB 12,693.00 INT2 DIRECTIONAL DRILL 8-1/2"INT2 HOLE FROM 12470'MD TO 12828'MD IN CM/HRZ !FORMATION(358'IN 6 HRS=60 FPH) 100 FPH INSTANTANEOUS ROP -500 GPM,2500-2650 PSI ON/OFF BTM,150 RPM,20-22/KFT-LBS TRQ ON/OFF BTM,10-14 KLBS WOB -MW IN/OUT=10.5 PPG -ECD CALC CLEANHOLE=11.3 PPG,ACTUAL =11.4-11.6 PPG EMW -NO BACKREAMING AT CONECTIONS -SURVEY EVERY STAND -NO BACKREAMING AT CONNECTIONS 40 BBL HI-VIS SWEEP AT 12400'MD-35 BBL HI-VIS SWEEP WITH 10%INCREASE IN CUTTINGS Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 59 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 20:00 8.00 DRILL N DPRB 12,693.00 INT2 DIRECTIONAL DRILL 8-1/2"INT2 HOLE FROM 12828'MD TO 13321'MD,8320'TVD IN HRZ/KINGAK/SGR/SHU FORMATIONS(493'IN 8 HRS=62 FPH) 100 FPH INSTANTANEOUS ROP -500 GPM,2500-2600 PSI ON/OFF BTM,150 RPM,19-24/18-20 KFT-LBS TRQ ON/OFF BTM, 16-18 KLBS WOB -MW IN/OUT=10.5 PPG -ECD CALC CLEANHOLE=11.3 PPG,ACTUAL =11.3-11.5 PPG EMW SURVEY EVERY STAND -NO BACKREAMING AT CONNECTIONS, EXCEPT FULL STAND AT 13025'MD CONNECTION FOR ECD CONTROL -SHUT OFF ALL PRODUCT MIXING AND WATER ADDITIONS WHILE DRILLING THROUGH SHUBLIK -PICKUP WEIGHT AT 13321'MD=275 KLBS, SLACKOFF=165 KLBS,ROTATING=195 KLBS -ACTUAL DRILLING/ROTATING TIME FOR PAST DAY=16.2 HRS -NO LOSSES TO FORMATION UNTIL 13208' MD ENCOUNTER LOSS ZONE IN SHUBLIK BEGINNING AT 13208'MD(46'MD BELOW SHUBLIK TOP). SHUBLIK FOUND TO BE-28' TVD THICKER ON THIS WELLBORE VERSUS L1-13 PB1 DUE TO POSSIBLE FAULT AND REPEAT OF SECTION -SEE ATTACHED DRAWING OF LOSS ZONE CORRELATION BETWEEN PB1 AND CURRENT WELLBORE -NO SIGNS OF SHUBLIK PHENOMENOM(NO FLOWBACK WITH PUMPS OFF) -13208'-13225'MD: DYNAMIC LOSS RATE= -65 BPH,STATIC LOSS RATE=0 BPH 13225'-13321'MD: DYNAMIC LOSS RATE INCREASES TO MAX RECORDED RATE OF -180 BPH AT 500 GPM -MAKE NOTIFICATIONS TO ANCHORAGE TEAM AND DECISION TO REMDIATE LOSSES WITH WELL COMMANDER CIRC SUB. -PUMP 40 BBL40 PPB DRILLAHEAD PILL AT 13235'MD WHILE DRILLING AHEAD-NO IMPORVEMENT IN LOSS RATE Printed 8/8/2016 11.19:42AM *AII depths reported in Drillers Depths* North America-ALASKA-BP • Page 60 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 00:00 4.00 LCR N DPRB 12,693.00 INT2 WITH BIT ON BOTTOM AT 13321'MD AND WELL COMMANDER AT 13153'MD(55'MD ABOVE START OF LOSSES),ATTEMPT TO REMEDIATE LOSSES AS FOLLOWS: j OPEN WELL COMMANDER AND ISOLATE BHA (1HR 15MIN OF TIME) -PUMP DOWN 2.115"OD BALL WITH 3 BPM, 400 PSI,RECIPROCATING FULL STAND,30 RPM,16-19 KFT-LBS TRQ -LAND BALL ON SEAT AT 44%OF CALCULATED STROKES TO WELL COMMANDER -SHEAR WELL COMMANDER CIRC SUB OPEN AT 1470 PSI -PUMP DOWN 2.063"OD BHA ISOLATION BALLAT 3 BPM,NEW 360 PSI CIRC PRESSURE WITH SAME STROKES TO WELL COMMANDER. PUMP 130 BBL 80 PPB SUPER PILL -RECIPROCATING FULL STAND,30 RPM, '16-19 KFT-LBS TRQ THROUGHOUT PUMPING CIRCULATE PILL DOWN TO WELL COMMANDER AT 5 BPM,700 PSI -PUMP FIRST 15 BBLS OF PILL INTO ANNULUS AT5BPM,700PSI -SLOW RATE TO 2 BPM,300-400 PSI FOR REMAINDER OF 130 BBL PILL 1-DYNAMIC LOSS RATE THROUGH 2 BPM PUMPING=<20 BPH -COMPLETE PILL SPOTTING AT 01:30 ON 6/28/16 NOTE: MINIMUM ECD OBSERVED DURING LOSSES REMEDIAL WORK=11.1 PPG 480 BBLS 10.5 PPG LSND LOST DURING PAST 24 HOURS 480 BBLS TOTAL LOST DURING SIDETRACK Printed 8/8/2016 11:19:42AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 61 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 6/28/2016 00:00 - 01:30 1.50 DRILL N DPRB 12,693.00 INT2 COMPLETE REMEDIATING LOSSES AT 13321' MD AS FOLLOWS: -COMPLETE SPOTTING 130 BBL 80 PPB SUPER LCM PILL IN ANNULUS AT 2 BPM, 300-400 PSI,<20 BPH DYNAMIC LOSS RATE WHILE SPOTTING PILL -WITH ALL OF PILL OUTSIDE WELL COMMANDER,DROP PUMP RATE TO 0.5 BPM (TO PREVENT U-TUBE BACKFLOW INTO WELL COMMANDER)AND ALLOW PILL TO SOAK ON BACKSIDE FOR 15 MIN. -0 BPH STATIC LOSS RATE FOLLOWING 15 MIN WAITING PERIOD CLOSE WELL COMMANDER CIRC SUB -PUMP 2.115"OD BALL DOWN WITH 3 BPM, 360 PSI,0 BPH DYNAMIC LOSS RATE -LAND CLOSING BALL ON SEAT AT 33%OF CALCULATED STROKES TO CIRC SUB -SHEAR WELL COMMANDER CIRC SUB I CLOSED AT 1725 PSI. CONFIRM WITH NEW CIRC PRESSURE OF 400 PSI AT 3 BPM RECORD SLOW PUMP RATES STAGE UP PUMPS TO FULL DRILLING RATE 450 GPM,2200 PSI,0 BPH DYNAMIC LOSS RATE. DECISION TO RESUME DRILLING Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* North America-ALASKA-BP Page 62 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:30 - 06:00 4.50 DRILL P INT2 DIRECTIONAL DRILL 8-1/2"INT2 HOLE FROM 13321'MD TO 13510'MD IN IVISHAK FORMATION (189'IN 4.5 HRS=42 FPH) -100 FPH INSTANTANEOUS ROP -450 GPM,2200 PSI ON/OFF BTM,150 RPM, 27/25-26 KFT-LBS TRQ ON/OFF BTM,10-15 KLBS WOB -MW IN/OUT=10.5 PPG,LUBRICANT CONC.= 2.75% -ECD CALC CLEANHOLE=11.2 PPG,ACTUAL =11.2-11.4 PPG EMW -SURVEY EVERY STAND -ACTIVATE SOFTSPEED SOFTWARE AT 13321'MD IN ATTEMPT TO SMOOTH OUT AND REDUCE TORQUE-NO IMPROVEMENT OBSERVED. TORQUE IS-4-5 KFT-LBS HIGHER THAN BEFORE LOSS ZONE. UNABLE TO HOLD RPM CONSTANT AT 150 RPM DUE TO CONSISTENT 27 KFT-LBS. DYNAMIC LOSS RATES: -13321'-13375'MD(TCGL @ 13362'MD): -150 BPH @ 450 GPM 13375'-13417'MD: 20 BPH @ 450 GPM -CIRCULATING BOTTOMS UP AT 13417'MD: -100 BPH @ 500 GPM -13417'-13510'MD: -50 BPH AT 450 GPM RELAX RIBS ON BAKER AUTOTRAKAT 13417' MD CONNECTION AND CIRCULATE 1X BU IN EFFORT TO REDUCE TORQUE(1 HOUR). -500 GPM,2630 PSI,150 RPM,25-27 KFT-LBS TRQ,RECIPROCATING FULL STAND -NO CHANGE IN TORQUE AFTER CIRCULATING NOTE: RESUME PRODUCTIVE TIME FOR WELL AFTER PASSING 8337'TVD OF L1-13PB1 WELLBORE TOTAL DEPTH 06:00 - 13:00 7.00 DRILL P INT2 DIRECTIONAL DRILL 8-1/2"INT2 HOLE FROM 13510'MD IN IVISHAK FORMATION TO WITHIN KAVIK AT 13835'MD(325'IN 7 HRS=46 FPH) -100 FPH INSTANTANEOUS ROP -450 GPM,2150 PSI ON/OFF BTM,120 RPM, 22/18 KFT-LBS TRQ ON/OFF BTM,10-16 KLBS WOB -MW IN/OUT=10.5 PPG,LUBRICANT CONC.= 3.0% -ECD CALC CLEANHOLE=11.2 PPG,ACTUAL =11.2 PPG EMW -SURVEY EVERY STAND PUMP 40 BBL HI-VIS SWEEP AT 13791'MD: 25%INCREASE OVER BASELINE CUTTING 13:00 - 14:30 1.50 DRILL P INT2 CIRCULATE HOLE CLEAN WITH 1.5 BOTTOMS UP AT TOP OF KAVIK PRIOR TO WIPER TRIP -450 GPM,2100 PSI,120 RPM,20K TQ -RECIPROCATE 30'AT 1000 FPH -DYNAMIC LOSS RATE=60 BPH Printed 8/8/2016 11:19:42AM `AII depths reported in Drillers Depths* North America-ALASKA-BP 411, Page 63 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWi: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:30 - 17:00 2.50 DRILL P INT2 WIPER TRIP(IN ATTEMPT TO REDUCE TORQUE AND ASSESS HOLE CONDITIONS WITH LOSSES): PULL OUT OF THE HOLE WITH 8-1/2"DRILLING ASSEMBLY ON ELEVATORS FROM 13835'MD TO 9-5/8" WINDOWAT 10754'MD NO ISSUES TRIPPING THROUGH OPENHOLE PICKUP WEIGHT OFF BOTTOM=310 KLBS -PULLING SPEED=40-50 FPM 17:00 19:00 2.00 DRILL P INT2 WIPER TRIP: CIRCULATE HOLE CLEAN AT 10754'MD(INSIDE 9-5/8"WINDOW)WITH 2 I BOTTOMS UP -500 GPM,2200 PSI,RECIPROCATING FULL STAND AT 1000 FPH,NO ROTATION '-MW IN/OUT=10.5 PPG,ECD ACTUAL=11.1- 11.2 PPG -NO SIGNIFICANT INCREASE IN CUTTINGS AT SHAKERS -FLOWCHECK WELL AFTER PUMPS OFF (STATIC,0 BPH LOSS RATE) 19:00 - 22:30 3.50 DRILL P INT2 WIPER TRIP: TRIP IN HOLE WITH 8-1/2"RSS DRILLING ASSEMBLY FROM 9-5/8"WINDOW AT 10754'MD TO BOTTOM AT 13835'MD. WASH FINAL 30'DOWN. NO ISSUES PASSING THROUGH WINDOW. -20 KLBS DRAG THROUGH TOP OF CM1. ABLE TO WORK THROUGH WITH NO PUMPS OR ROTARY. -TIGHT HOLE AT 13305'MD(97'BELOW FIRST LOSS ZONE IN SHUBLIK). REAM PAST 2X AT 400 GPM.GAIN BACK-30 KLBS DOWN WEIGHT -TIGHT HOLE AT 13575'MD. REAM THROUGH WITH 400 GPM,1900 PSI,100 RPM,15K TQ -RECORD SLOW PUMP RATES ON BOTTOM 22:30 - 00:00 1.50 DRILL P INT2 DIRECTIONAL DRILL 8-1/2"INT2 HOLE FROM 13835'MD TO 13920'MD IN KAVIK FORMATION (85'IN 1.5 HRS=57 FPH) 100 FPH INSTANTANEOUS ROP -450 GPM,2165 PSI ON/OFF BTM,120 RPM, 22/18 KFT-LBS TRQ ON/OFF BTM,17 KLBS WOB -MW IN/OUT=10.5 PPG,LUBRICANT CONC.= 3.0% -ECD CALC CLEANHOLE=11.2 PPG,ACTUAL =11.2 PPG EMW -SURVEY EVERY STAND -DYNAMIC LOSS RATE=-100 BPH PICKUP WEIGHT AT 13887'MD=290 KLBS, SLACKOFF=175 KLBS,ROTATING=205 KLBS ACTUAL DAILY DRILLING TIME=8.6 HR 921 BBLS 10.5 PPG LSND LOST DURING PAST 24 HOURS 1401 BBLS TOTAL LOST DURING SIDETRACK Printed 8/8/2016 11.19:42AM *AII depths reported in Drillers Depths* 4110 North America-ALASKA-BP S Page 64 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 6/29/2016 00:00 - 01:30 1.50 DRILL P INT2 DIRECTIONAL DRILL 8-1/2"INT2 HOLE FROM 13920'MD TO 13986'MD IN KAVIK FORMATION TOWARD PROGNOSED TD IN TOP LISBURNE PER CASING PICK PROGRAM(66'IN 1.5 HRS =44 FPH) -450 GPM,2160 PSI ON/OFF BTM,120 RPM, 20-21/18 KFT-LBS TRQ ON/OFF BTM,12 KLBS WOB -MW IN/OUT=10.5 PPG,LUBRICANT CONC.= 3.0% -ECD CALC CLEANHOLE=11.2 PPG,ACTUAL !=11.2-11.3 PPG EMW -SURVEY EVERY STAND -DYNAMIC LOSS RATE=-100 BPH -ACTIVATE SOFTSPEED SOFTWARE DUE TO ERRATIC AND HIGH TORQUE:REDUCED TORQUE WITH SUCCESS CASING PICK: -ENSURE POSSUM BELLY AND SHAKER SCREENS CLEAN FOR SAMPLES -SET CONTROL DRILL PARAMETERS AT 75 FPH AND 12K WOB NO INDICATION OF DRILL BREAK OR 'REVERSE DRILL BREAK PRIOR TO MAX ALLOWABLE 140'TVD BELOW TOP KAVIK -DRILL DOWN STAND TO 13983'MD/8854' TVD(140'TVD BELOW TOP KAVIK) -CONTACT TOWN GEO AND ODE.AGREE TO PICK UP SINGLE AND DRILL MAX 3'MD WITH 'SINGLE PRIOR TO CIRCULATING FOR SAMPLES -DRILL 3'MD WITHOUT INDICATION OF TOP LISBURNE,STOP TO CIRCULATE FOR POSSIBLE SAMPLES 01:30 - 03:00 1.50 DRILL P INT2 CIRCULATE 1.5 BOTTOMS UP FOR POSSIBLE LISBURNE SAMPLES -450 GPM,2075 PSI,120 RPM,18K TQ -NO SIGN OF LISBURNE SAMPLES,PLAN TO DRILL ANOTHER 3'MD 03:00 - 03:15 0.25 DRILL P INT2 DIRECTIONAL DRILL 8-1/2"INT2 HOLE FROM 13986'MD TO INT2 HOLE SECTION TD AT 13990'MD/8860'TVD IN TOP LISBURNE PER CASING PICK PROGRAM -SET CONTROL DRILL PARAMETERS AT 75 FPH AND 12K WOB -OBSERVE GOOD REVERSE DRILL BREAK WITH ROP DECREASING TO 25 FPH AT 13988' MD -DRILLAN ADDITIONAL 2'MD FOR ADEQUATE SAMPLES TO TO AT 13990'MD -ACTUAL DRILLING/ROTATING HOURS FOR TOTAL REPORT=1.2 HRS Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 65 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:15 - 06:30 3.25 LCR N DPRB 13,990.00 INT2 CIRCULATE FOR LISBURNE SAMPLES/ REMEDIATE LOST CIRCULATION -450 GPM,2075 PSI,120 RPM,18K TQ, RECIPROCATE FULL STANDS AT 350 FPH -OBSERVE MAJOR LOSSES 10 MIN AFTER TD (LOSSES INITIATE DURING UP-STROKE RECIPROCATION,NO PARAMETERS WERE CHANGED),ECD DROPS FROM 11.2 TO 10.9 PPG EMW -DYNAMIC LOSS RATE AT 450 GPM=350++ BPH -CONTACT TOWN GEO AND AGREE TO NOT ATTEMPT TO CATCH SAMPLES,REDUCE FLOW RATE TO 200 GPM IN ATTEMPT TO REDUCE LOSSES -DYNAMIC LOSS RATE AT 200 GPM=300 BPH,FILLING DOWN BACKSIDE TO KEEP HOLE FULL -CONTACT TOWN TEAM AND DECIDE TO PUMP DRILLAHEAD PILLS,EVALUATE AND 'DECIDE ON PLAN FORWARD FOR ADDITIONAL LOST CIRCULATION REMEDIATION -DECREASE PUMP RATE TO 3 BPM,DYNAMIC •LOSS RATE AT 3 BPM=180 BPH,LOSING -100%OF RETURNS THOUGH HOLE STAYING FULL -SPOT 40 BBL 40 PPB DRILL AHEAD LCM PILL AT 3 BPM,PULL UPHOLE AT 50 FPM AND RACK BACK 2 STANDS FROM 13990'MD TO 13730'MD WHILE SPOTTING PILL -LET PILL SOAK FOR 15 MIN,NEW STATIC LOSS RATE=40 BPH,NEW DYNAMIC LOSS RATE AT 3 BPM=140 BPH 06:30 - 08:00 1.50 LCR N DPRB 13,990.00 INT2 DISCUSS PLAN FORWARD WITH ANCHORAGE TEAM -3 BPM,410 PSI,LOSING-75%OF RETURNS (140 BPH),RECIPROCATING 30',40 RPM, 15-18 KFT-LBS TRQ. NO SIGNS OF HOLE PROBLEMS -LOAD RIG WITH LCM AND BUILD 80 BBL 40 PPB LCM PILL 08:00 - 10:00 2.00 LCR N DPRB 13,990.00 INT2 SPOT 80 BBL 40 PPB"DRILL AHEAD"PILL ON BOTTOM -RUN BACK TO BOTTOM FROM 13730'MD TO 13990'MD -SPOT PILL AT 3 BPM,420 PSI,RACKING BACK STANDS AT 50 FPM FROM 13990'MD TO 13600'MD -FLOWCHECK WELL FOR 10 MIN PRIOR TO LEAVING BOTTOM-WELL ON LOSSES(40 BPH DYNAMIC,24 BPH STATIC) 10:00 13:00 3.00 DRILL P INT2 PULL OUT OF HOLE WITH 8-1/2"RSS DRILLING ASSEMBLY ON ELEVATORS FROM 13600'MD TO ABOVE SHALES AT 12520'MD (THRZ=12695'MD) -INITIAL PICKUP WEIGHT AT 13600'MD=305 KLBS,SLACKOFF=155 KBS -PULLING SPEED=50 FPM -LOSS RATES DECREASE TO 24 BPH AT 3 BPM,0 BPH STATIC Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 66 of 97 Operation Summary Report Common Wet Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:00 - 16:00 3.00 DRILL P INT2 STAGE UP PUMP IN 0.5-1 BPM INCREMENTS TO FULL DRILLING RATE AT 420 GPM AND CIRCULATE 2 BOTTOMS UP -420 GPM,2050 PSI,NO ROTATION, RECIPROCATING 30'STROKES,DYNAMIC LOSS RATE=40 BPH 16:00 - 17:30 1.50 DRILL P INT2 PULL OUT OF HOLE WITH 8-1/2"RSS DRILLING ASSEMBLY ON ELEVATORS FROM 12520'MD TO 9-5/8"WINDOW AT 10754'MD. -PULLING SPEED=50-60 FPM NO ISSUES TRIPPING THROUGH OPENHOLE -PICKUP WEIGHT AT 12520'MD=265 KLBS 17:30 - 18:30 1.00 DRILL P INT2 CUT AND SLIP 72',9 WRAPS OF 1-3/8"DRILL LINE -CUTAT 1856 TON-MILES -MAINTAIN CONTINUOUS HOLE FILL(STATIC) THROUGH MAINTAINENCE -FLOWCHECK WELL FOR 10 MIN AT WINDOW (STATIC) -COMPLETE RIG SERVICE 18:30 - 23:00 ! 4.50 DRILL P INT2 PULL OUT OF HOLE WITH 8-1/2"RSS DRILLING ASSEMBLY ON ELEVATORS FROM 9-5/8"WINDOWAT 10754'MD TO BHA AT 817' MD. PULLING SPEED=90 FPM STATIC LOSS RATE IMPROVED OVER COURSE OF TRIP. NO STATIC LOSS RATE AT SURFACE. -NOTE: DO NOT DROP DRILLPIPE DRIFT DUE TO CONCERNS ABOUT CONSERVING OPERABILITY OF WELL COMMANDER CIRC SUB FOR LOSSES 23:00 - 00:00 1.00 DRILL P INT2 1 RACKBACK HWDP AND LAYDOWN 8-1/2"RSS DRILLING ASSEMBLY FROM 817'MD TO 200' MD AT MIDNIGHT. -FLOWCHECK WELL FOR 10 MIN PRIOR TO PULLING BHA INTO BOP STACK PRESSURE TEST CHOKE MANIFOLD DURING TRIP TO 250 PSI LOWAND 4000 PSI HIGH FOR FIVE MIN EACH(8 TOTAL PASSING TESTS) -BHA LAYDOWN COMPLETED AT 01:30 ON 6/30/16. 6/30/2016 00:00 01:30 1.50 DRILL P INT2 COMPLETE LAYING DOWN 8-1/2"RSS DRILLING ASSEMBLY FROM 200'MD AT MIDNIGHT TO SURFACE -GRADE BIT 2-2-IN GUAGE WITH 7 CHIPPED CUTTERS,SEE ATTACHED PHOTOS Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 67 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date : From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:30 - 04:00 2.50 BOPSUR P INT2 CHANGEOUT UPPER RAMS FROM VBRS TO 7"FIXED RAMS -CLEAN AND CLEAR RIG FLOOR AFTER TRIPPING RIG UP LINER RUNNING TOOLS ON RIG FLOOR DURING RAM SWAP NEW BOP STACK CONFIGURATION(TOP TO BOTTOM): 13-5/8"5K SHAFFER ANNULAR PREVENTER 7"FIXED 5K CAMERON CASING RAMS CAMERON 5K BLIND-SHEAR RAMS MUD CROSS 3-1/2"X 5-7/8"5K CAMERON VARIABLE BORE RAMS BARRIERS FOR BREAKING CONTAINMENT: CLOSED BLIND RAMS -CONSTANT HOLE FILL WITH 10.5 PPG LSND KWF THROUGH MUD CROSS(STATIC LOSS RATE=0 BPH) 04:00 - 05:00 1.00 BOPSUR P INT2 RIG UP TO TEST BOPE -SET TEST PLUG AND MONITOR FOR LEAKS -PAST TEST PLUG WITH OPEN IA VALVE THROUGHOUT TEST. 05:00 - 10:00 5.00 BOPSUR P INT2 PRESSURE-FUNCTION TEST BOPE WITH WATER PER BP STANDARDS AND AOGCC I REGULATIONS NO FAILURES -AOGCC REP LOU GRIMALDI WAIVES STATE'S RIGHT TO WITNESS -TEST ANNULAR WITH 5"TEST JOINT TO 250 PSI LOWAND 3500 PSI HIGH FOR FIVE MIN IEACH -TEST LOWER VBRS WITH 5"TEST JOINT TO 250 PSI LOWAND 4000 PSI HIGH FOR 5 MIN EACH -TEST UPPER CASING RAMS WITH 7"TEST JOINT TO 250 PSI LOW AND 4000 PSI HIGH FOR FIVE MIN EACH -5 TOTAL TESTS DURING THIS INTERVAL BECAUSE CHOKE MANIFOLD TESTED OFFLINE -SEE ATTACHED TEST DOCUMENTATION 10:00 - 10:30 0.50 BOPSUR P INT2 RIG DOWN AFTER TESTING BOPE. SET WEAR RING(ID=8-5/8"). RUN IN AND 1 TORQUE FOUR LOCKDOWN SCREWS TO 450 FT-LBS. 10:30 - 11:30 1.00 CASING P I INT2 RIG UP TO RUN DRILLING LINER Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 68 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:30 - 16:30 5.00 CASING P INT2 MAKEUP AND RUN IN HOLE WITH 7",26",L-80, VAMTOP INT2 DRILLING LINER FROM SURFACE -FLOWCHECK PRIOR TO RUNNING IN HOLE (STATIC) -BAKERLOK SHOE TRACK AND CHECK FLOATS(PASS) -APPLY JET LUBE SEAL GUARD(FF=1.0) AND TORQUE TURN VAMTOP CONNECTIONS TO OPT MU TRQ 11950 FT-LBS RUN 8-1/4"X 7"HYDROFORM CENTRALIZERS ON SHOE TRACK&JOINTS 1-73 WITH STOP RING 5'FROM PIN(76 TOTAL CENTS,78 TOTAL STOP RINGS) FILL LINER EVERY JOINT WITH FILL-UP HOSE -DECREASE RUNNING SPEED FROM 90 FPM TO 60 FPM AT 300'MD TO AVOID PUSHING AWAY FLUID -BOUYED LINER WEIGHT=105 KLBS 16:30 - 18:30 2.00 CASING P INT2 MAKEUP 7"X 9-5/8"BAKER FLEXLOCK LINER HANGER AND HRD ZXP LINER TOP PACKER. CROSS OVER TO DRILLPIPE AND CIRCUALTE ONE LINER VOLUME. -BAKER REP ADD PAL-MIX ON RIG FLOOR -STAGE UP PUMPS TO 5 BPM,330 PSI,NO LOSSES VERIFY NEW HANDLING EQUIPMENT -OVERALL LENGTH OF LINER=3342' 18:30 - 00:00 5.50 CASING P INT2 RUN IN HOLE WITH 7"INT2 LINER ON 5" DRILLPIPE FROM DRILLPIPE CROSSOVER AT 3342'MD TO 8100'MD AT MIDNIGHT -RUNNING SPEED=60 FPM -FILL PIPE EVERY 10 STANDS -CIRCULATE BOTTOMS UP AT 5000'MD;5 BPM,375 PSI,NO LOSSES -CIRCULATE BOTTOMS UP AT 8100'MD;5 BPM,405 PSI,NO LOSSES -NEGLIGIBLE LOSSES TO HOLE WHILE RUNNING PIPE 7/1/2016 00:00 - 07:30 7.50 CASING P INT2 RUN IN HOLE WITH 7"INT2 LINER ON 5" DRILLPIPE FROM 8100'MD AT MIDNIGHT TO 13440'MD -RUNNING SPEED IN CASED HOLE=50 FPM -CIRCULATE 1.5X BU(-415 BBLS)AT 10754' MD,9-5/8"WINDOW;5BPM,500 PSI(PUMP PRESSURE 50 PSI LOWER AFTER BOTTOMS UP) -RUNNING SPEED IN OPENHOLE=50 FPM -CIRCULATE EVERY 5TH STAND DOWN AT 5 BPM FOR 23 BELS(EQUAL TO CLOSED ENDED DISPLACEMENT OF RUNNING IN FIVE STANDS) 06:00 MIRU SLB CEMENTERS AND TRUCKS Printed 8/8/2016 11.19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 69 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisbume Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:30 - 11:00 3.50 CASING P INT2 WORK 7"LINER DOWN THROUGH TIGHT HOLE FROM 13440'MD TO 13502'MD -INITIAL SET DOWN AND INITIATE LOSSES AT 13440'MD(-20'BELOW BASE CONGLOMERATES) -WORK PIPE SLOWLY AND WASH DOWN IN SMALL INCREMENTS,PICKING UP TO CONFIRM FREE PIPE SET DOWN 50 KLBS MAX -WASH DOWN AT 3 BPM,500 PSI,SOME SIGNS OF PACK-OFF -LOSS RATE AT 3 BPM=20-60 BPH 11:00 - 13:30 2.50 CASING P INT2 WASH DOWN WITH 7"LINER FROM 13502'MD TO 13975'MD -WASH DOWN 5-10 FPM TO PREVENT PACK-OFF DUE TO SUSPECTED LCM(2.5 BPM,450 PSI) 13:30 - 23:30 10.00 CASING ' N DPRB ! 13,975.00 INT2 WASH DOWN WITH 7"LINER ON 5"DP FROM 13975'MD TO PLANNED SET DEPTH AT 13988' MD(2'OFF BOTTOM) -PICKUP SINGLE AND BAKER CEMENT HEAD, ESTABLISH CIRCULATION AT 3 BPM -PACK-OFF WHILE WASHING DOWN [THROUGH TIGHT HOLE,MULTIPLE PACK-OFFS WITH INTERMITTENT RETURNS -STOP AND CIRCULATE TO STABILIZE PRESSURES,STAGING VERY SLOWLY UP TO 5 BPM IN 5 GPM INCREMENTS -CIRCULATE A TOTAL OF 2.5 BOTTOMS-UP(8 OPEN-HOLE ANNULUS VOLUMES AT>4.5 IBPM) -NO SIGN OF LCM BACK AT SHAKERS DURING DAY OF CIRCULATING -STABILIZE PRESSURE AT 5 BPM,900 PSI AND WASH TO BOTTOM -TAG TD AT 13990'MD,PICK UP STRETCH PLUS 2'TO SET AS PLANNED AT 13988'MD -FINAL PICKUP WEIGHT=320K,SLACKOFF= 150K(AT 2 BPM) -MUD CONDITIONED FOR CEMENTING,YP= 17 I LOST CIRCULATION WHILE WASHING DOWN TO BOTTOM AT 5 BPM -100%LOSSES AT 5 BPM -LOSS RATE AT 2.5 BPM=180 BPH(FILLING DOWN BACKSIDE) 23:30 00:00 0.50 CASING P INT2 CIRCULATE AT SET DEPTH -WORK TO ESTABLISH FULL CIRCULATION 11-DISCUSS CEMENTING PLAN FORWARD, AGREE TO ASSESS LOSSES AND PROCEED WITH CEMENTING Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • NorthAmerica-ALASKA-BP • Page 7Oofg7 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 7/2/2016 00:00 - 03:30 3.50 CASING P INT2 CIRCULATE AT SET DEPTH TO ASSESS LOST CIRCULATION -RECIPROCATE PIPE STRETCH -PERFORM STAGE UP TO ASSESS LOSS RATES: -2 BPM,310 PSI=FULL LOSSES(120 BPH LOSS) -3 BPM,365 PSI=PARTIAL RETURNS(<180 BPH LOSS) -4 BPM,550 PSI=PARTIAL RETURNS(<240 BPH LOSS) -5 BPM,615 PSI=FULL LOSSES(>300 BPH LOSS) -DISCUSS RESULTS WITH ODE AND AGREE TO PUMP ENTIRE CEMENT JOB AT 4 BPM IN EFFORT TO MAINTAIN SLIGHT RETURNS MIRU SLB CEMENTERS AND HOLD PJSM WITH RIG TEAM FOR PRESSURE TESTING& CEMENTING '-REVIEW PRESSURE CROSSCHECK FILL CEMENT LINES WITH WATER AND PRESSURE TEST TO 250 PSI LOW AND 4500 PSI HIGH FOR 5 MINUTES(LEAKTIGHT CRITERIA PASS) -STATIC LOSS RATE WHILE PRESSURE TESTING=18 BPH 03:30 - 04:30 1.00 CASING P INT2 SET BAKER FLEX-LOCK 7 LINER HANGER -ESTABLISH PARTIAL CIRCULATION AFTER PRESSURE TEST -DROP 1.5"LINER HANGER SETTING BALL AND PUMP TO SEAT AT 3 BPM,370 PSI (INTERMITTENT RETURNS WHILE PUMPING) -LAND BALL ON SEAT AT 139 BBL AWAY(75% OF CALCULATED VALUE),PRESSURE UP TO 2900 PSI TO SET HANGER,SET 50 KLBS ON HANGER TO CONFIRM SET. -PRESSURE UP TO 4200 PSI TO RELEASE RUNNING TOOL AND SHEAR DOBS RUPTURE DISK -BLEED PRESSURE OFF TO 500 PSI AND SEE DOBS TOOL RELEASE BALL AFTER 4.5 MIN WITH PRESSURE DROP -CONFIRM RUNNING TOOL RELEASED WITH 215 KLBS PICKUP WEIGHT(VS.320KLBS WITH LINER ATTACHED) -VERIFIED HANGER SET AT 10646'MD(117' LINER LAP FROM MIDDLE OF WINDOW) Printed 8/8/2016 11:19:42AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP Page 71 of 97 Operation Summary Report Common Well Name L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:30 - 08:00 3.50 CEMT P INT2 CEMENT 7"LINER AS FOLLOWS(OCN#16): -BATCH UP MUD PUSH&CEMENT(30 MIN) -PUMP 30 BBLS OF 12.0 PPG MUDPUSH II SPACER @ 4 BPM,300 PSI -LAUNCH 1.813"PUMP DOWN PLUG(PDP#1) -PUMP 88 BBLS,423 SACKS,OF 15.8 PPG CLASS G TAIL @ 4 BPM,ICP=300 PSI,FCP= 0 PSI,EXCESS VOLUME 50% (YIELD 1.17 CU.FT/S K) '-LAUNCH 2.25"PUMP DOWN PLUG(PDP#2) PERFORM DISPLACEMENT WITH SLB CEMENT TRUCK -KICK OUT PLUGS WITH 10 BBLS OF 8.3 PPG FRESH WATER DISPLACED AT 4 BPM,0 PSI COMPLETE REMAINDER OF DISPLACEMENT WITH 10.5 PPG LSND -PUMP 85 BBLS AT 4 BPM,0 PSI -START TO SLOWDOWN RATE TO 2 BPM. LAND PDP#1 AT PLANNED SLOWDOWN VOLUME OF 85 BBLS(5 BBLS EARLY). LAUNCH LEAD LINER WIPER PLUG WITH 1600 PSI SHEAR PRESSURE -RESUME 4 BPM. PUMP 78 BBLS AT 0 PSI. LOSE MAJORITY OF RETURNS FOR REMAINDER OF JOB AT 126 BBLS AWAY. -SLOW RATE TO 2 BPM 10 BBLS EARLY FOR SECOND PLUG. LAND PDP#2 AND LAUNCH FOLLOW LINER WIPER PLUG WITH 1100 PSI AT 171 BBLS AWAY(4 BBLS EARLY). CORRECT TOTAL PLANNED DISPLACEMENT VOLUMES FOR REMAINDER OF PLUMPING TO REFLECT LATCH. -RESUME 4 BPM,PUMP 39 BBLS AT 0 PSI UNTIL CEMENT ROUNDS CORNER AT 210 BBLS AWAY. OBSERVE LEAD LINER WIPER PLUG LAND AT PROPER 207 BBLS AWAY WITH 600 PSI PRESSURE SPIKE. -AFTER CEMENT ROUNDS CORNER,PUMP 10 BBLS AT 4 MIN,THEN DROP RATE TO 3 BPM FOR 10 BBLS,THEN 2 BPM FOR 10 BBLS, THEN 1 BPM 10 BBLS IN UNSUCCESSFUL ATTEMPT TO BUILD LIFT PRESSURE AND GAIN RETURNS. RESUME 3 BPM FOR 40 BBLS. CATCH PRESSURE UPON RETURN TO 3 BPM AND BUILD LIFT PRESSURE FROM 140 PSI TO 318 PSI. SLOW TO 2 BPM FOR FINAL 10 BBLS,ICP=180 PSI,FCP=345 PSI. LAND FOLLOW LINER WIPER PLUG ON SCHEDULE AT 290.8 BBLS MUD DISPLACEMENT. -OBSERVE PLUG BYPASS. PUMP 1/2 SHOE TRACK WITHOUT PRESSURING UP. TOTAL MUD DISPLACEMENT=292.1 BBLS. -LOSS RATE DURING JOB UNTIL CEMENT ROUNDED CORNER=75%(180 BPH) -DESPITE LIFT PRESSURE OBSERVED AT END OF DISPLACEMENT,ONLY GAIN 3 BBLS IN PITS AFTER CEMENT ROUNDS CORNER (LOST 96%OF RETURNS) -CEMENT IN PLACE AT 07:25 -BLEED OFF PRESSURE TO CEMENTERS AND CHECK FLOATS(PASS) -CALL ANCHORAGE TEAM TO DISCUSS Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP . Page 72 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) RESULTS -FIELD PICK TOC BASED ON 3 BBLS PLACED IN GAGE HOLE ANNULUS=13855'MD(133' HEIGHT) DECIDE NOT TO SET LINER TOP PACKER IN PREPARATION FOR REMEDIAL CEMENT WORK 08:00 - 14:00 6.00 CASING P INT2 PULL OUT OF HOLE WITH LINER RUNNING TOOLS FROM 10646'MD TO SURFACE -MONITOR WELL FOR 10 MIN BEFORE PULLING(STATIC) -LAY DOWN CEMENT HEAD AND SINGLE 14:00 - 15:30 1.50 CASING P INT2 LAY DOWN LINER RUNNING TOOLS -MONITOR WELL FOR 10 MIN BEFORE BHA ACROSS STACK(STATCI LOSS RATE=0 BPH) INSPECT RS PACKOFF ON SURFACE-NO ISSUES 15:30 - 16:00 0.50 BOPSUR P INT2 CHANGE UPPER RAMS FROM 7"FIXED TO 2-7/8"X 5"VARIABLE BORE RAMS -CLEAN AND CLEAR RIG FLOOR WHILE CHANGING RAMS NEW BOP STACK CONFIGURATION(TOP TO BOTTOM): 13-5/8"5K SHAFFER ANNULAR PREVENTER 2-7/8"X 5"5K CAMERON VARIABLE BORE RAMS CAMERON 5K BLIND-SHEAR RAMS MUD CROSS 3-1/2"X 5-7/8"5K CAMERON VARIABLE BORE RAMS BARRIERS FOR BREAKING CONTAINMENT: -CLOSED BLIND RAMS -CONSTANT HOLE FILL WITH 10.5 PPG LSND I KWF THROUGH MUD CROSS(STATIC LOSS RATE=0 BPH) 16:00 - 17:00 1.00 BOPSUR P INT2 RIG UP TO TEST UPPER AND LOWER VBR'S -PULL WEAR RING. SET TEST PLUG AND MONITOR FOR LEAKS PAST TEST PLUG WITH OPEN IA VALVE THROUGHOUT TEST 17:00 - 18:30 1.50 BOPSUR P INT2 TEST BOPE FOLLOWING RAM CHANGE: '-NO FAILURES,SEE ATTACHED CHART -TEST ANNULAR PREVENTER WITH 4"TEST JOINT TO 250 PSI LOWAND 3500 PSI HIGH FOR FIVE MIN EACH -TEST UPPER VBRS WITH 4"AND 5"TEST JOINTS TO 250 PSI LOW AND 4000 PSI HIGH FOR FIVE MIN EACH -TEST LOW VBRS TO 250 PSI LOWAND 4000 PSI HIGH FOR FIVE MIN EACH 18:30 - 19:30 1.00 BOPSUR P INT2 RIG DOWN AFTER BOPE TESTING. SET WEAR RING AND RUN IN/TORQUE 4 LOCKDOWN SCREWS TO 450 FT-LBS,ID= 8-5/8" Printed 8/8/2016 11:19:42AM `All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 73 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:30 - 20:00 0.50 LCR N CEMT 13,990.00 INT2 7"LINER REMEDIAL CEMENT WORK: MAKEUP HES 7",20-29#COMPOSITE BRIDGE PLUG AND RUNNING TOOLS FROM SURFACE TO 8.51'MD -MAKEUP PORTED SUB ABOVE RUNNING TOOLS FOR PIPE FILL AND DRAINING DURING TRIPPING. RUN 2 STANDS OF 4" DRILLPIPE FOR RUNNING INTO TOP OF 7" LINER FLOWCHECK WELL PRIOR TO RUNNING IN HOLE(STATIC) -CONFIRM PROPER SET SCREWS AT RIG FLOOR 20:00 - 00:00 4.00 LCR N CEMT 13,990.00 INT2 7"LINER REMEDIAL CEMENT WORK: RUN IN 'HOLE WITH 7"CBP ON 5"DRILLPIPE FROM SURFACE TO 8500'MD AT MIDNIGHT. RUNNING SPEED=90 KLBS,EASY IN/OUT OF SLIPS 7/3/2016 00:00 - 02:00 I 2.00 LCR N CEMT 13,990.00 INT2 7"LINER REMEDIAL CEMENT WORK: RUN IN HOLE WITH 7"CBP ON 5"DRILLPIPE FROM 8500'MD AT MIDNIGHT TO PLANNED SET DEPTH AT 10741'MD. -RUNNING SPEED=90 KLBS,EASY IN/OUT OF SLIPS -DO NOT OBSERVE LINER TOP WHEN PASSING THROUGH. 4 02:00 - 03:00 1.00 LCR N CEMT 13,990.00 INT2 7"LINER REMEDIAL CEMENT WORK: SET HES 7",20-29#COMPOSITE BRIDGE PLUG AT 10741'MD(TOP OF PLUG)PER HALLIBURTON TOOL REP. -ROTATE TOOL TO RIGHT 25 TURNS TO ENGAGE SLIPS AND SET CBP I-PULL UP IN 15 KLBS INCREMENTS TO SHEAR RUNNING TOOLS OFF PLUG AT 30-40 KLBS OVER -PLUG SET IN THE MIDDLE OF SECOND JOINT DOWN FROM 10646'MD TOP OF LINER -CONFIRM PLUG SET BY SETTING DOWN 5 KLBS ON PLUG 03:00 - 07:00 4.00 LCR N CEMT 13,990.00 INT2 7"LINER REMEDIAL CEMENT WORK: PULL OUT OF THE HOLE WITH 7"BRIDGE PLUG SETTING TOOLS FROM SET DEPTH AT 10741' MD -RECORD SPRS AND FLOWCHECK WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM (STATIC) -PULLING SPEEDS=125-255 FPM 07:00 - 08:00 1.00 LCR N CEMT 13,990.00 INT2 7"LINER REMEDIAL CEMENT WORK: LAYDOWN HES COMPOSITE BRIDGE PLUG RUNNING TOOLS. -CLEAR AND CLEAN RIG FLOOR AFTER TRIPPING. 08:00 - 08:30 0.50 LCR P INT2 SERVICE AND LUBRICATE RIG Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* North America-ALASKA-BP • Page 74 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) ' Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisbume Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To Hrs � Task Code NPT NPT Depth Phase Description of Operations (hr) i (usft) 08:30 - 09:00 0.50 i LCR N CEMT 13,990.00 INT2 7"LINER REMEDIAL CEMENT WORK: MAKEUP BAKER ROTATING DOG SUB AND PORTED CEMENT TOOL FROM SURFACE TO OAL AT 23.42'MD -FLOWCHECK WELL FOR 10 MIN PRIOR TO RUNNING IN HOLE(STATIC) -OFFSET FROM ROTATING DOG SUB TO PUMP DOWN PLUG CATCHER ON END OF TOOL=16.22'MD 09:00 - 14:30 5.50 LCR N CEMT 13,990.00 INT2 7"LINER REMEDIAL CEMENT WORK:TRIP IN HOLE WITH BAKER ROTATING DOG SUB& PORTED CEMENTING TOOL ON ELEVATORS FROM BHAAT 23'MD TO 10634'MD(10' ABOVE 7"LINER TOP) -NO LOSSES WHILE RUN IN HOLE 14:30 - 18:00 1.50 LCR N CEMT 13,990.00 INT2 7"LFNER REMEDIAL CEMENT WORK:MAKEUP CEMENT HEAD AND CIRCULATE -CIRCULATE 1/2 ANNULAR VOLUME AT 10 BPM,1120 PSI AFTER PICKING UP CEMENT I HEAD 16:00 - 16:30 0.50 LCR N CEMT 13,990.00 INT2 7"LINER REMEDIAL CEMENT WORK: CONTINUE IN HOLE FROM 10634'MD TO TAG LINER TOP WITH ROTATING DOG SUB 2' DEEP AT 10648'MD(TALLY SET DEPTH= 10646'MD). 1-PICKUP 3'PAST BREAKOVER(PORTED CEMENTING TOOL STILL INSIDE PBR) -MIRU SLB CEMENTERS. HOLD PJSM AND PRESSURE TEST LINES TO 250 PSI LOW AND 4000 PSI HIGH FOR FIVE MIN EACH(PASSING LEAKTIGHT CRITERIA TESTS) 16:30 - 17:30 1.00 LCR N CEMT 13,990.00 INT2 7"LINER REMEDIAL CEMENT WORK: ESTABLISH INJECTION INTO 7"LINER iANNULUS -CLOSE ANNULAR PREVENTER -1 BPM=640 PSI,2 BPM=790 PSI,3 BPM= 840 PSI,4 BPM=970 PSI,5 BPM=1020 PSI,6 BPM=1190 PSI -INJECT TOTAL OF 60 BBLS OF 10.5 PPG MUD -CONTACT ODE AND AGREE TO 1 DOWNSQUEEZE CEMENT PER PLAN Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 75 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisbume Site:Lis DS 01 Rig Name/No.:PARKER 272 i Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To % Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 1730 - 19:00 1.50 LCR N CEMT 13,990.00 INT2 7"LINER REMEDIAL CEMENT WORK: PERFORM DOWNSQUEEZE INTO 7"LINER ANNULUS AS FOLLOWS: -PUMP 20 BBLS OF 12.0 PPG MUDPUSH SPACER AT 4 BPM,800 PSI -PUMP 200 BBLS,960 SACKS OF 15.8 PPG !CLASS G CEMENT AT 6 BPM,ICP 800 PSI,FCP 310 PSI,EXCESS VOLUME 166%(YIELD 1.17 CU.FT/S K) -VERIFY DRILL PIPE WIPER DART RELEASE I-PUMP 20 BBLS OF 12.0 PPG MUDPUSH SPACER AT 6 BPM,140 PSI DISPLACE WITH 10.5 PPG LSND USING RIG PUMPS 1-165 BBLS DISPLACED AT 5 BPM:ICP 120 PSI, FCP 940 PSI -SHUT DOWN WITH 5 BBL CEMENTAND 20 BBL MUDPUSH REMAINING IN DRILLSTRING, CEMENT IN PLACE AT 19:00 � I SET BAKER 7"X 9-5/8"ZXP LINER TOP PACKER --OPEN ANNULAR PREVENTER AND SLACK-OFF 70 KLBS TO SET LINER TOP PACKER(GOOD INDICATION OF SET) -PICKUP AND ROTATE DOWN AT 20 RPM AND SLACK-OFF 50 KLBS TO VERIFY PACKER SET _ 19:00 - 22:00 3.00 LCR M1t CEMT , 13,990.00 INT2 7"LINER REMEDIAL CEMENT WORK: CIRCULATE HOLE CLEAN WITH PORTED CEMENTING TOOL INSIDE PBR -CIRCULATE 1 BOTTOMS-UP AT 10 BPM,1075 PSI(NO LOSSES) I-STRUNG-OUT CEMENT VERIFIED AT SURFACE -LAY DOWN CEMENT HEAD AND SINGLE -DROP 5"DRILLPIPE WIPER FOAM BALL -CIRCULATE 35 BBL NUT PLUG SWEEP SURFACE TO SURFACE AT 15 BPM,1340 PSI -FLOWCHECK WELL AFTER PUMPS DOWN PRIOR TO PULLING OUT OF THE HOLE (STATIC) 22:00 - 00:00 2.00 LCR N CEMT 13,990.00 INT2 7"LINER REMEDIAL CEMENT WORK PULL OUT OF HOLE WITH BAKER ROTATING DOG SUB AND PORTED CEMENTING TOOLS FROM 7"LINER TOP AT 10646'MD TO 6650'MD AT MIDNIGHT. PULLING SPEED=265 FPM 7/4/2016 00:00 - 02:30 2.50 LCR N CEMT 13,990.00 INT2 7"LINER REMEDIAL CEMENT WORK: PULL OUT OF HOLE WITH BAKER ROTATING DOG SUB AND PORTED CEMENTING TOOLS FROM '6650'MD AT MIDNIGHT TO SURFACE PULLING SPEED=265 FPM 02:30 - 03:30 1.00 LCR N CEMT 13,990.00 INT2 7"LINER REMEDIAL CEMENT WORK: LAYDOWN BAKER CEMENT ASSEMBLY -CONFIRM DOG SUB SHEARED WITH BAKER REP,INDICTING GOOD PACKER SET. Printed 8/8/2016 11:19:42AM "All depths reported in Drillers Depths* North America-ALASKA-BP • Page 76 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:30 - 05:00 1.50 LCR N CEMT 13,990.00 INT2 7"LINER REMEDIAL CEMENT WORK: MAKEUP 6-1/8"CLEANOUT ASSEMBLY FROM SURFACE TO 668'MD -NEW HUGHES 6-1/8"ROLLER CONE STX-1 WITH 3X20 JETS,DUAL BOOT BASKETS,9 STEEL SPIRAL DRILL COLLARS,HYDRAULIC JARS,PORTED FLOAT 05:00 - 09:30 4.50 LCR N CEMT 13,990.00 INT2 7"LINER REMEDIAL CEMENT WORK: RUN IN HOLE WITH 6-1/8"CLEANOUT ASSEMBLY FROM 668'MD TO 10605'MD(41'ABOVE LINER TOP) CROSSOVER FROM 4"DRILLPIPE TO 5" DRILLPIPE AT 8334'MD BACK FROM BIT -RUNNING SPEED=265 FPM -PIPE FILLING THROUGH PORTED FLOAT, BREAK CIRCULATION EVERY 30 STANDS REMEDIAL DOWNSQUEEZE CEMENT AT 500 PSI COMPRESSIVE STRENGTH AT 08:30 09:30 - 10:00 0.50 LCR N CEMT 13,990.00 INT2 I 7"LINER REMEDIAL CEMENT WORK: CIRCULATE 1.5X DRILLPIPE VOLUME AT 10605'MD -9 BPM,1700 PSI 10:00 - 11:30 1.50 LCR N CEMT 13,990.00 INT2 7"LINER REMEDIAL CEMENT WORK: PRESSURE TEST 7"LINER TOP PACKER TO 250 PSI LOW FOR 5 MIN/4000 PSI HIGH FOR • 30 MIN -LOST 24 PSI IN FIRST 15 MIN,LOST 9 PSI IN SECOND 15 MIN -VOLUME PUMPED/RETURNED=10.1 BBL/ 10.1 BBL -PASSING TEST PER BP INTEGRITY TESTING CRITERIA,APPROVED BY ON CALL WELL SUPT 11:30 - 12:00 0.50 LCR N CEMT 13,990.00 INT2 7"LINER REMEDIAL CEMENT WORK: RUN IN HOLE FROM 10605'MD TO TAG HES 7" •COMPOSITE BRIDGE PLUG AT 10741'MD IN TOP OF 7"LINER -RECORD SLOW PUMP RATES 12:00 - 14:00 2.00 LCR N CEMT 13,990.00 INT2 7"LINER REMEDIAL CEMENT WORK: DRILL UP HES COMPOSITE BRIDGE PLUG -275 GPM,1080 PSI,45 RPM,8K TO,8-12 KLBS WOB 14:00 - 15:30 1.50 LCR N CEMT 13,990.00 INT2 7"LINER REMEDIAL CEMENT WORK:RUN IN HOLE WITH 6-1/8"CLEANOUT BHA FROM 10737'MD TO 13730'MD(171'ABOVE LANDING COLLAR) -RUNNING SPEED=120 FPM -FILL PIPE EVERY 2000'MD 15:30 - 17:30 2.00 LCR P INT2 7"LINER REMEDIAL CEMENT WORK: WASH AND REAM DOWN FROM 13730'MD TO 13898' MD(3'ABOVE LANDING COLLAR) -CEMENT STRINGERS AT 13789'MD(112' ABOVE LANDING COLLAR),FIRM TAG AT 13816'MD -DRILL THROUGH FIRM CEMENT(ABLE TO STACK 10 KLBS DOWN)FROM 13816'MD TO 13898'MD;250 GPM,1200 PSI,40 RPM,13K TQ,10 KLBS WOB Printed 8/8/2016 11:19:42AM *AII depths reported in Drillers Depths* North America-ALASKA-BP • Page 77 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:30 - 18:30 1.00 LCR P INT2 7"LINER REMEDIAL CEMENT WORK: CIRCULATE 1.5X DRILLPIPE VOLUME AT 13898'MD -250 GPM,1090 PSI,40 RPM,18K TQ, RECIPROCATE 30'STROKES 18:30 - 19:30 1.00 LCR P INT2 1PRESSURE TEST 7"LINER TO 250 PSI LOW FOR 5 MIN 14000 PSI HIGH FOR 30 MIN '-LOST 25 PSI IN FIRST 15 MIN,LOST 10 PSI IN SECOND 15 MIN -VOLUME PUMPED/RETURNED=12 BBL/12 BBL -PASSING TEST PER BP INTEGRITY TESTING CRITERIA,APPROVED BY ON CALL WELL SUPT,SEE ATTACHED DOCUMENTS - 19:30 - 00:00 I 4.50 LCR P INT2 DRILL OUT PLUGS AND LANDING COLLAR FROM 13900'MD TO 13910'MD AT MIDNIGHT TAG PLUGS ON DEPTH -DIFFICULTY MAKING PROGRESS THROUGH I PLUGS(4.5 TOTAL HRS) -VERY SLOW PROGRESS FOR 6'PAST BASE OF LANDING COLLAR UNTIL BREAKTHROUGH AT 13910'MD -VARY DRILLING PARAMETERS:3-6 BPM, 745-1160 PSI,30-80 RPM,16-20K TQ,10- i 18K WOB 7/5/2016 00:00 - 01:00 1.00 LCR P INT2 7"LINER REMEDIAL CEMENT WORK:DRILL OUT SHOE TRACK FROM 13910'MD TO 13975' MD(13'ABOVE 7"LINER SHOE) HARD CEMENT OBSERVED THROUGHOUT SHOE TRACK -INCREASE FLOWRATE TO 500 GPM,3250 PSI,80 RPM,15-18 KFT-LBS TQ,14-16 KLBS WOB 101:00 - 03:00 2.00 LCR P INT2 7"LINER REMEDIAL CEMENT WORK: CIRCULATE HOLE CLEAN WITH 1.5 BOTTOMS-UP -500 GPM,3250 PSI,80 RPM,18-21K FT-LBS TQ,RECIPROCATE 45'STROKES -CIRCULATE 35 BBL HI-VIS SWEEP SURFACE TO SURFACE-AN INCREASE IN RETURNS (CUTTINGS,LCM,PLUG MATERIAL)WITH INCREASED FLOWRATE AND SWEEP. 03:00 - 08:30 5.50 LCR N CEMT 13,990.00 INT2 7"LINER REMEDIAL CEMENT WORK: PULL OUT OF HOLE WITH 6-1/8"CLEANOUT ASSEMBLY FROM 13975'MD TO BHAAT 668' MD. -PUMP DRY JOB,PULLING SPEED=120-265 FPM -FLOWCHECK WELL PRIOR TO PULLING BHA THROUGH BOP STACK(STATIC). 08:30 - 09:00 0.50 LCR N CEMT 13,990.00 INT2 7"LINER REMEDIAL CEMENT WORK: LAYDOWN 6-1/8"BHA FROM 668'MD TO SURFACE. -RACKBACK DRILL COLLARS AND 4"HWDP. -GRADE BIT 3-1,IN GAUGE -JUNK BASKETS EMPTY 09:00 - 09:30 0.50 LCR N CEMT 13,990 00 INT2 7"LINER REMEDIAL CEMENT WORK:CLEAN AND CLEAR RIG FLOOR Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 78 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 09:30 - 12:30 3.00 LCR N CEMT 13,990.00 INT2 7"LINER REMEDIAL CEMENT WORK:RIG UP SLB E-LINE -HOLD PJSM.VERIFY NO PRESSURE CONTROL REQUIRED. ONLY RIG UP LINE !WIPER WITH INTEGRAL CUTTER(FUNCTION _JEST CUTTER-PASS) 12:30 - 00:00 11.50 LCR N CEMT 13,990.00 INT2 7"LINER REMEDIAL CEMENT WORK: I EVALUATE 7"LINER PRIMARY AND REMEDIAL CEMENT AS FOLLOWS: RUN IN HOLE ON E-LINE WITH IBC-GPIT-MSIP CEMENT EVALUATION TOOLS DIFFICULTY RUNNING IN HOLE BETWEEN -11400'MD AND-12100'MD(SECTION OF MAX WELLBORE INCLINATION AT>60 DEG). WORK DOWN THROUGH SECTION WITH MULTIPLE ATTEMPTS. -LOG PER PROGRAM FROM 13937'MD(PBTD AT 13975'MD)TO 10400'MD(246'ABOVE 7" LINER TOP)AT-30 FPM -MAKE ONE REPEAT PASS -MONITOR WELLAND DISPLACEMENTS VIA TRIP TANK THROUGHOUT THE JOB -PULL OUT OF HOLE WITH LOGGING TOOLS AT MIDNIGHT SIMOPS: -LAY DOWN DRILL COLLARS OFFLINE -OFFLOAD MAJORITY OF LSND MUD AND CLEAN PITS 7/6/2016 00:00 - 01:00 1.00 LCR N CEMT 13 990.00 INT2 7"LINER REMEDIAL CEMENT WORK: COMPLETE EVALUATION OF 7"LINER PRIMARY AND REMEDIAL CEMENT -PULL OUT OF THE HOLE WITH LOGGING TOOLS TO SURFACE 01:00 - 03:00 2.00 LCR N CEMT 13,990.00 INT2 7"LINER REMEDIAL CEMENT WORK: RDMO SLB E-LINE OFFLOAD LOGGING TOOLS -INITIAL RESULTS OF CEMENT EVALUATION SHOW ACCEPTABLE ZONAL ISOLATION -DISCUSS WITH ODE AND AGREE TO PROCEED TO MAKE UP DRILLING BHA 03:00 - 06:00 3.00 DRILL P INT2 MAKE UP 6-1/8"RSS PRODUCTION DRILLING ASSEMBLY FROM SURFACE TO 586'MD -NEW 6-1/8"HYC SKFX613M PDC BIT -HIGH DOG-LEG AUTOTRAK RSS,ONTRAK MWD,COPILOT,SDN,STARTRAK,PORTED FLOAT -NOV MOCS CIRC SUB(202'BACK FROM BIT) 06:00 - 14:00 8.00 DRILL P INT2 RUN IN THE HOLE WITH 6-1/8"DRILLING ASSEMBLY FROM 586'MD TO 13744'MD -INSTALL JARS 4972'BACK FROM BIT -CROSSOVER FROM 4"DP TO 5"DP 8247'MD BACK FROM BIT -FILL PIPE EVERY 2000'MD -SHALLOW TEST MWD TOOLS AT 1163'MD: GOOD TEST -UNNANNOUNCED D1,KICK WHILE TRIPPING DRILLAND AAR WITH CREW.CRT=1 MIN -MONITOR WELL WITH TRIP TANK WHILE RUNNING IN;GOOD DISPLACEMENT -PU 301K;SO 139KAT 13744'MD Printed 8/8/2016 11:19:42AM *AII depths reported in Drillers Depths* North America-ALASKA-BP • Page 79 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) 1 Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) i (usft) 14:00 - 15:00 1.00 DRILL P INT2 SLIP AND CUT 80'OF DRILL LINE -CALIBRATE BLOCK HEIGHTS WITH AMPHION SYSTEM AND BAKER MWD. 15:00 - 15:30 0.50 DRILL P INT2 SERVICE TOP DRIVE,GREASE BLOCKS AND WASHPIPE,AND SERVICE RIG FLOOR EQUIPMENT 15:30 - 16:00 0.50 DRILL P INT2 WASH DOWN FROM 13744'MD TO 13975'MD AND TAG CEMENT WITH 5K -1 BPM;475 PSI 16:00 - 19:00 3.00 DRILL P INT2 'DISPLACE WELL FROM 10.5 PPG LSND TO 8.6 PPG QUICKDRIL-N -50 BBLS SEAWATER FOLLOWED BY 35 BBL HI-VIS SPACER AND 35 BBL EP MUD LUBE SWEEP AHEAD OF 8.6 PPG QUICKDRIL-N -275 GPM;1450-2710 PSI;DISPLACEMENT PRESSURES FOLLOWED TREND MODELED BY BARIOD SPR:13965'MD;8840'TVD MP#1:30/40 SPM;575/740 PSI -MP#2:30/40 SPM;575/735 PSI -PERFORM 30 MIN FLOW CHECK;WELL STATIC. NOTIFIED WOM AND RECEIVE ATP 19:00 - 20:30 1.50 DRILL P INT2 DRILL OUT REMAINDER OF SHOE TRACKAND 20'OF NEW HOLE;FROM 13975'MD TO 14010' MD(8876'TVD) -275 GPM;1355 PSI ON/1385 PSI OFF -40 RPM;11K FT-LBS TORQUE ON,13K FT-LBS TORQUE OFF -10K WOB -PU 275K,SO 150K,ROT 190K -MUD WEIGHT 8.6 PPG IN/OUT FLOW CHECK WELL FOR 15 MIN BEFORE DRILL NEW HOLE:STATIC -PULL BACK TO 7"CASING SHOE AND FLOW CHECK WELL FOR 10 MIN:STATIC 20:30 - 21:30 1.00 DRILL P INT2 CIRCULATE 7"LINER VOLUME 2X -275 GPM;1265 PSI -40 RPM,13K TORQUE _ 121:30 - 22:30 1.00 DRILL P INT2 I RIG UP AND PERFORM FIT -MUD WEIGHT:8.6 PPG,8858'TVD,13988'MD -PUMP 1.8 BBLS TO 500 PSI,BLEED BACK 1.7 BBLS LOT EMW=9.6 PPG --' -CALL AND DISCUSS RESULTS WITH ODE 22:30 - 00:00 1.50 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 14010' MD TO 14060'MD(8917'TVD) -50'IN 1.5 HRS=33 FPH WITH CONNECTIONS AND SURVEYS -INSTANTANEOUS ROP=20-70 FPH -275 GPM,1400 PSI ON,1395 PSI OFF -120 RPM,19K TORQUE ON,18K TORQUE OFF -PU 276K,SO 150K,ROT 192K -SURVEY EVERY-30 FT -ACTUAL ROTATE TIME=1.5 HRS -NO BACKREAMING PRIOR TO CONNECTIONS -MUD WEIGHT:8.6 PPG IN,8.6 PPG OUT -NO LOSSES WHILE DRILLING Printed 8/8/2016 11:19:42AM "All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 80 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) — _ Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) — 7/7/2016 00:00 - 05:00 5.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 14060'MD TO 14120'MD IN LISBURNE FORMATION(60'IN 5 HRS=12 FPH WITH CONNECTIONS) -10-30 FPH INSTANTANEOUS ROP -275 GPM,1400 PSI ON,1390 PSI OFF,30-120 RPM,20K TORQUE ON,20K TORQUE OFF, 1.0-14 KLBS WOB -PU 261K,SO 164K,ROT 192K I-MW IN/OUT=8.6 PPG -NO LOSSES WHILE DRILLING -SURVEY EVERY 30 FT DUE TO>5 DEG DLS -NO BACKREAMING PRIOR TO [CONNECTIONS -HIGH SURFACE TORQUE,UNABLE TO MAINTAIN CONSISTENT 120 RPM:INCREASE OVERALL LUBES TO 2.5% COMPLETE WEEKLY BOP FUNCTION TEST ACTUAL DAILY DRILLING TIME=4.4 HR 05:00 - 06:00 1.00 DRILL N DFAL 14,120.00 PROM- TROUBLESHOOT BHA TOOL FAILURE BCPM DE-SYNC,NO COMMUNICATION WITH -STEERING HEAD -DECIDE TO PULL OUT OF HOLE TO SWAP TOOLS 06:00 - 08:30 2.50 DRILL N DFAL 14,120.00 PROD1 PULL OUT OF HOLE ON ELEVATORS WITH 6-1/8"RSS DRILLING ASSEMBLY FROM 14120' MD TO 10617'MD(ABOVE 7"LINER TOP) -MONITOR WELL FOR 10 MIN BEFORE PULLING OFF BOTTOM(STATIC) -PU 260K,SO 164K ON BOTTOM -PULLING SPEED=90 FPM 08:30 - 10:30 2.00 DRILL N DFAL 14,120.00 PROD1 CIRCULATE HOLE CLEAN WITH 2 BOTTOMS-UP INSIDE 9-5/8"CASING -FUNCTIONED NOV MOCS CIRC TOOL OPEN WITH BALL -635 GPM,2175 PSI -PUMP 40 BBL HI-VIS SWEEP:NO INCREASE IN CUTTINGS RETURNS 1-PUMP 40 BBL 5%EP-MUDLUBE SWEEP TO COAT 9-5/8"CASING -CLOSED NOV MOCS CIRC TOOL 10:30 - 15:00 4.50 DRILL N DFAL 14,120.00 PROD1 PULL OUT OF HOLE ON ELEVATORS WITH •6-1/8"RSS DRILLING ASSEMBLY FROM 10617' MD TO BHAAT 213'MD -PULLING SPEED=200 FPM -MONITOR WELL WITH TRIP TANK:GOOD •DISPLACEMENT 15:00 - 17:30 2.50 DRILL N DFAL 14,120.00 PROD1 LAY DOWN 6-1/8"RSS PRODUCTION DRILLING BHA FROM 213'MD TO SURFACE I-MONITOR WELL FOR 10 MIN BEFORE NON-SHEARABLES CROSSING STACK (STATIC) 1-REMOVE SOURCE AND DOWNLOAD TOOLS TO TROUBLESHOOT FAILURE -HYC SKFX613M GRADE: 2-1-BT-C-X-I-CT-DTF,RING OUT PATTERN STARTED(SEE ATTACHED PICTURES) Printed 8/8/2016 11:19:42AM *AII depths reported in Drillers Depths* 111 • North America-ALASKA-BP Page 81 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) I Start Date:5/26/2016 End Date:7/19/2016 IX30170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. i UWI: Active datum:L1-13 Plan ifp60.05usft(above Mean Sea Level) Date I From-To Hrs I Task Code I NPT NPT Depth Phase Description of Operations (hr) _ I (usft) 17:30 - 20:00 2.50 DRILL N DFAL I 14,120.00 1 PROD1 MAKE UP 6-1/8"RSS PRODUCTION DRILLING BHA FROM SURFACE TO 213'MD -NEW 6-1/8"HDBS MM64D PDC BIT -HIGH DOG-LEG AUTOTRAK RSS,ONTRAK MWD,COPILOT,SDN,STARTRAK,PORTED FLOAT -PLUG IN TOOLS AND INSTALL SOURCE NOV MOCS CIRC SUB(202'BACK FROM BIT)_ 20:00 - 00:00 4.00 DRILL N 1 DFAL 14,120.00 PRODI RUN IN THE HOLE WITH 6-1/8"RSS DRILLING ASSEMBLY FROM 213'MD TO 5792'MD AT MIDNIGHT 1 I-INSTALL JARS 4972'BACK FROM BIT -CROSSOVER FROM 4"DP TO 5"DP 8247' 1 BACK FROM BIT '-SHALLOW TEST MWD TOOLS AT 1160'MD: GOOD TEST -FILL PIPE EVERY 2000'MD -RUNNING SPEED=200-250 FPM MONITOR WELL WITH TRIP TANK:GOOD I I DISPLACEMENT -D1,KICK WHILE TRIPPING DRILL AND AAR: CRT IMIN 30 SEC. 7/8/2016 00:00 - 05:30 5.50 DRILL N DFAL 14,120.00 PROD1 RUN IN THE HOLE WITH 6-1/8"RSS DRILLING 'ASSEMBLY FROM 5792'MD TO 14120'MD -FILL PIPE EVERY 2000'MD -RUNNING SPEED=200 FPM -MONITOR WELL WITH TRIP TANK:GOOD DISPLACEMENT -WASH DOWN FROM 14025'MD TO 14120'MD -MUD WEIGHT:8.6 PPG IN/OUT -SPR:14088'MD;8933'TVD -MP#1:30/40 SPM;550/725 PSI , -MP#2:30/40 SPM;550/725 PSI ASSESS TORQUE AT VARIOUS LOCATIONS WHILE RUN IN HOLE: 10600'MD(ABOVE 7"LINER TOP):80/90 RPM;5K/5.5K FT-LBS TORQUE 11700'MD:80/90 RPM;7K/8K FT-LBS TORQUE I 112700'MD:80/90 RPM;9K/10K FT-LBS ' TORQUE 1 14029'MD:80/90 RPM; 11K/12K FT-LBS TORQUE 05:30 - 12:00 6.50 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 14120'MD TO 14218'MD(9008' ND)IN LISBURNE FORMATION -98'IN 6.5 HRS=15 FPH WITH CONNECTIONS AND SURVEYS -INSTANTANEOUS ROP=20-60 FPH -275 GPM,1490 PSI ON,1457 PSI OFF -100 RPM,18K TORQUE ON,13K TORQUE I OFF I-PU 254K,SO 163K,ROT 197K ' 15K WOB -SURVEY EVERY-30 FT -NO BACKREAMING PRIOR TO CONNECTIONS , 1-MUD WEIGHT:8.6 PPG IN,8.6 PPG OUT -NO LOSSES WHILE DRILLING -INITIATE NOV SOFTSPEED SOFTWARE Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP S Page 82 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. I UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 23:30 ; 11.50 DRILL P i PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 14218'MD TO 14502'MD(9071' TVD)IN LISBURNE FORMATION -284'IN 11.5 HRS=25 FPH WITH CONNECTIONS AND SURVEYS -INSTANTANEOUS ROP=20-60 FPH -275 GPM,1485 PSI ON,1485 PSI OFF 110 RPM,20K TORQUE ON,21K TORQUE OFF PU 256K,SO 164K,ROT 197K -15K WOB -SURVEY EVERY-30 FT -DAILY ROTATE TIME=14.0 HRS -NO BACKREAMING PRIOR TO CONNECTIONS MUD WEIGHT:8.6 PPG IN,8.6 PPG OUT --NO LOSSES WHILE DRILLING -CONTINUE TO UTILIZE NOV SOFTSPEED SOFTWARE SPR:14281'MD;9034'TVD -MP#1:30/40 SPM;575/754 PSI -MP#2:30/40 SPM;576/750 PSI 23:30 - 00:00 0.50 DRILL P PROD1 SERVICE TOP DRIVE,BLOCKS AND WASHPIPE. 7/9/2016 00:00 - 06:00 6.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 14502'MD TO 14649'MD(9043' TVD)IN LISBURNE FORMATION -147'IN 6 HRS=24.5 FPH WITH CONNECTIONS AND SURVEYS -INSTANTANEOUS ROP=10-50 FPH -275 GPM,1505 PSI ON,1505 PSI OFF -120 RPM,21K TORQUE ON,18K TORQUE ,OFF -PU 249K,SO 160K,ROT 193K -15K WOB -SURVEY EVERY-30 FT -NO BACKREAMING PRIOR TO CONNECTIONS -MUD WEIGHT:8.6 PPG IN,8.6 PPG OUT -NO LOSSES WHILE DRILLING -CONTINUE TO UTILIZE NOV SOFTSPEED SOFTWARE -SPR:14499'MD;9070'TVD -MP#1:30/40 SPM;560/740 PSI -MP#2:30/40 SPM;555/745 PSI Printed 8/8/2016 11:19:42AM `AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 83 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 12:00 6.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 14649'MD TO 14860'MD(8998' TVD)IN LISBURNE FORMATION -211'IN 6 HRS=35.2 FPH WITH CONNECTIONS AND SURVEYS -INSTANTANEOUS ROP=15-50 FPH -275 GPM,1580 PSI ON,1560 PSI OFF 120 RPM,21K TORQUE ON,20K TORQUE 'OFF PU 249K,SO 158K,ROT 193K -15KWOB -SURVEY EVERY-90 FT -NO BACKREAMING PRIOR TO CONNECTIONS -MUD WEIGHT:8.6 PPG IN,8.6 PPG OUT -NO LOSSES WHILE DRILLING -CONTINUE TO UTILIZE NOV SOFTSPEED SOFTWARE 12:00 - 00:00 12.00 DRILL P PROD1 DIRECTIONAL DRILL6-1/8"PRODUCTION HOLE FROM 14860'MD TO 15182'MD(8929' TVD)IN LISBURNE FORMATION -322'IN 12 HRS=26.8 FPH WITH 1 CONNECTIONS AND SURVEYS INSTANTANEOUS ROP=10-50 FPH -275 GPM,1780 PSI ON,1670 PSI OFF -120 RPM,21K TORQUE ON,19K TORQUE OFF -PU 249K,SO 156K,ROT 190K -15K WOB -SURVEY EVERY-90 FT -NO BACKREAMING PRIOR TO CONNECTIONS -MUD WEIGHT:8.6 PPG IN,8.6 PPG OUT -NO LOSSES WHILE DRILLING -DAILY ROTATE TIME=19.3 HRS -TURN OFF NOV SOFTSPEED SOFTWARE; 'NO INDICATIONS OF INCREASED STICK SLIP DOWNHOLE SPR:14972'MD;8973'TVD -MP#1:30/40 SPM;600/790 PSI -MP#2:30/40 SPM;600/793 PSI Printed 8/8/2016 11:19:42AM 'All depths reported in Drillers Depths` North America-ALASKA-BP • Page 84 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 7/10/2016 00:00 - 06:00 6.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 15182'MD TO 15419'MD(8879' TVD)IN LISBURNE FORMATION -237'IN 6 HRS=39.5 FPH WITH CONNECTIONS AND SURVEYS -INSTANTANEOUS ROP=20-100 FPH -275 GPM,1750 PSI ON,1650 PSI OFF -120 RPM,21K TORQUE ON,17K TORQUE OFF -PU 254K,SO 159K,ROT 193K 15K WOB -SURVEY EVERY-90 FT -NO BACKREAMING PRIOR TO CONNECTIONS MUD WEIGHT:8.6 PPG IN,8.6 PPG OUT NOT UTILIZING NOV SOFTSPEED SOFTWARE OBSERVED LOSSES WHILE DRILLING: -AT 15198'MD OBSERVED LOSSES OF 11 BPH CONTINUED DRILLING AHEAD AND LOSSES 'HEALED UP BY 15225'MD -LOST 10 BBL TO FORMATION -FROM 15265'TO 15410'LOSS RATE INCREASING FROM 1BPH TO 3 BPH DRILLING BREAK FROM 15293'MD-15314'MD AND FROM 15355'MD-15377'MD -INSTANTANEOUS ROP>100 FPH -WOB8K-10K -SPR:15252'MD;8912'TVD -MP#1:30/40 SPM;635/825 PSI -MP#2:30/40 SPM;637/820 PSI 06:00 - 12:00 6.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 15419'MD TO 15545'MD(8860' TVD)IN LISBURNE FORMATION -126'IN 6 HRS=21 FPH WITH CONNECTIONS AND SURVEYS -INSTANTANEOUS ROP=10-80 FPH -275 GPM,1640 PSI ON,1617 PSI OFF -120 RPM,20K TORQUE ON,17K TORQUE OFF -PU 248K,SO 158K,ROT 195K 15K WOB -SURVEY EVERY-30-90 FT;AS REQUIRED BY DLS -NO BACKREAMING PRIOR TO CONNECTIONS -MUD WEIGHT:8.6 PPG IN,8.6 PPG OUT -NOT UTILIZING NOV SOFTSPEED SOFTWARE -3 BPH LOSS RATE WHILE DRILLING Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 65 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisbume Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 00:00 12.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 15545'MD TO 15826'MD(8872' TVD)IN LISBURNE FORMATION -281'IN 12 HRS=23.4 FPH WITH CONNECTIONS AND SURVEYS -INSTANTANEOUS ROP=10-100 FPH -275 GPM,1650 PSI ON,1645 PSI OFF -120 RPM,19K TORQUE ON,16K TORQUE OFF -PU 261K,SO 159K,ROT 197K !-15KWOB -SURVEY EVERY-30 FT -NO BACKREAMING PRIOR TO CONNECTIONS MUD WEIGHT:8.6 PPG IN,8.6 PPG OUT -NOT UTILIZING NOV SOFTSPEED SOFTWARE -2 BPH LOSS RATE WHILE DRILLING -DAILY ROTATE TIME=20.1 HRS -SPR:15636'MD;8854'TVD -MP#1:30/40 SPM;640/825 PSI -MP#2:30/40 SPM;640/826 PSI 7/11/2016 00:00 - 06:00 6.00 DRILL P I PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 15826'MD TO 15933'MD IN LISBURNE FORMATION -107'IN 6 HRS=18 FPH WITH CONNECTIONS AND SURVEYS -INSTANTANEOUS ROP=10-80 FPH -275 GPM,1625 PSI ON,1600 PSI OFF -120 RPM,20K TORQUE ON,15K TORQUE OFF -PU 260K,SO 162K,ROT 197K -15-18K WOB SURVEY EVERY-30-90 FT AS REQUIRED BY DLS -NO BACKREAMING PRIOR TO CONNECTIONS -MUD WEIGHT:8.7 PPG IN,8.7 PPG OUT NO LOSSES WHILE DRILLING 06:00 - 12:00 6.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 15933'MD TO 16081'MD IN LISBURNE FORMATION -148'IN 6 HRS=25 FPH WITH CONNECTIONS AND SURVEYS -INSTANTANEOUS ROP=15-60 FPH -275 GPM,1725 PSI ON,1685 PSI OFF -120 RPM,20K TORQUE ON,16K TORQUE OFF -PU 259K,SO 163K,ROT 197K -19KWOB -SURVEY EVERY-90 FT -NO BACKREAMING PRIOR TO CONNECTIONS -MUD WEIGHT:8.7 PPG IN,8.7 PPG OUT -NO LOSSES WHILE DRILLING Printed 8/8/2016 11:19:42AM 'All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 86 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) 1 Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne T Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM I Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) I (usft) 12:00 - 18:00 , 6.00 DRILL P I PROD1 1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 16081'MD TO 16179'MD IN 1LISBURNE FORMATION '-98'IN 6 HRS=16 FPH WITH CONNECTIONS l AND SURVEYS -INSTANTANEOUS ROP=15-30 FPH -285 GPM,1720 PSI ON,1710 PSI OFF I 120 RPM,20K TORQUE ON,18K TORQUE OFF PU 261K,SO 161K,ROT 197K 16-20K WOB I -SURVEY EVERY-90 FT -NO BACKREAMING PRIOR TO ii CONNECTIONS -MUD WEIGHT:8.7 PPG IN,8.7 PPG OUT -NO LOSSES WHILE DRILLING 18:00 - 00:00 6.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 16179'MD TO 16319'MD IN 1 LISBURNE FORMATION -140'IN 6 HRS=23 FPH WITH CONNECTIONS AND SURVEYS -INSTANTANEOUS ROP=15-50 FPH 285 GPM,1745 PSI ON,1740 PSI OFF 120 RPM,20K TORQUE ON,17K TORQUE OFF I -PU 263K,SO 159K,ROT 198K -15-18K WOB 1 -SURVEY EVERY-90 FT -NO BACKREAMING PRIOR TO I CONNECTIONS -MUD WEIGHT:8.7 PPG IN,8.7 PPG OUT -NO LOSSES WHILE DRILLING I I TOOL FAILURE AT MIDNIGHT:PULSER NOT TRANSMITTING,INITIATE : TROUBLESHOOTING ACTUAL DAILY DRILLING TIME=20.8 HR _ 7/12/2016 00:00 01:00 1.00 DRILL N DFAL 16,319.00 PROD1 TROUBLESHOOT TOOL FAILURE:PULSER I Ii NOT TRANSMITTING CYCLE TOOLS MULTIPLE TIMES 1 -DOWNLINK TO TURN RIBS OFF AND DRILL 6' I , TO 16325'MD I -UNABLE TO REGAIN PULSER 1 COMMUNICATION -CONTACT ODE,AGREE TO PULL OUT OF i __ HOLE AND DISCUSS CIRC STRATEGY 01:00 - 01:30 0.50 DRILL N DFAL 16,319.00 PROD1 CIRCULATE 2 OPEN-HOLE+7"LINER , ANNULAR VOLUMES -350 GPM,2130 PSI,150 RPM,22K TORQUE, RECIPROCATE 30' 01:30 - 05:30 4.00 DRILL N DFAL 16,319.00 PROD1 PULL OUT OF HOLE ON ELEVATORS WITH 6-1/8"DRILLING ASSEMBLY FROM 16325'MD ITO TOP OF 7"LINER AT 10646'MD -MONITOR WELL PRIOR TO PULLING OFF BOTTOM AND AT 7"LINER SHOE FOR 10 MIN l (STATIC) ' I-PULLING SPEED=45-60 FPM(OPEN-HOLE) -WORK THROUGH TIGHT SPOT AT 14800'MD WITH 40K OVER PU WEIGHT Printed 8/8/2016 11 19:42AM `All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 87 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 • Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM 1 Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth 1 Phase ' Description of Operations (hr) • (usft) 05:30 - 07:30 2.00 DRILL N DFAL 16,319.00 , PROD1 CIRCULATE HOLE CLEAN WITH 2 BOTTOMS UP -DROP ACTIVATION BALLAND OPEN MOCS j TOOL I -PUMP BALL DOWN AT 3 BPM,525 PSI -I AFTER OPENING MOOS TOOL RAISE PUMP 1 RATE TO 650 GPM,2900-2650 PSI FOR 2 BOTTOMS UP -PUMP 35 BBL HIGH VIS SWEEP,MINIMAL 1 1 NCREASE IN CUTTINGS BACKARTA: T SHAKERS 107:30 - 12:00 4.50 1 DRILL N DFAL 16,319.00 PROD1 PULL OUT OF HOLE ON ELEVATORS WITH 1 6-1/8"DRILLING ASSEMBLY FROM TOP OF 7" 1 ; I LINER AT 10646'MD TO TOP OF BHAAT 213' 1 !MD 1 -MONITOR WELL PRIOR TO PULLING BHA INTO STACK FOR 10 MIN(STATIC) • -PULLING SPEED=200-250 FPM(IN CASING) MONITOR WELL WITH TRIP TANK:GOOD DISPLACEMENT 1 -HOLD UNANNOUNCED D1 KICK WHILE TRIPPING DRILL 12:00 - 14:00 2.00 DRILL N DFAL 16,319.00 PROD1 LAY DOWN 6-1/8"RSS PRODUCTION DRILLING BHA FROM 213'MD TO SURFACE 1 I REMOVE SOURCE AND DOWNLOAD TOOLS -HDBS MM64D 6-1/8"BIT GRADE: _1-2-WT-T-X-I-NO-DIF 14:00 - 14:30 0.50 DRILL P PROD1 SERVICE TOP DRIVE AND RIG FLOOR EQUIPMENT 14:30 - 16:30 2.00 DRILL N DFAL , 16,319.00 PROD1 MAKE UP 6-1/8"RSS PRODUCTION DRILLING BHA FROM SURFACE TO 214'MD 1 -NEW 6-1/8"HYCALOG SKFX613M PDC BIT • -AUTOTRAK RSS,ONTRAK MWD,COPILOT, SDN,STARTRAK,PORTED FLOAT -PLUG IN TOOLS AND INSTALL SOURCE 1 I -NOV MOCS CIRC SUB(202'BACK FROM BIT) -MONITOR WELL PRIOR TO RUNNING IN THE HOLE FOR 10 MIN(STATIC) 16:30 - 00:00 7.50 DRILL N DFAL 16,319.00 I PROD1 TRIP IN THE HOLE FROM TOP OF BHAAT 214' MD TO 7"LINER SHOE AT 13988'MD 1-TRIP SPEED=200-250 FPM IN CASED 1HOLE -SHALLOW HOLE TEST DIRECTIONAL TOOLS (PASS) 1-FILL PIPE AND STAGE PUMPS UP TO 275 GPM EVERY 2000'MD SEARCHING FOR POTENTIAL WASHOUT,NO INDICATION OF • WASHOUT OBSERVED ON TRIP IN HOLE -MONITOR WELL WITH TRIP TANK:GOOD DISPLACEMENT 7/13/2016 00:00 - 02:00 2.00 DRILL N DFAL 16,319.00 1 PROD1 TRIP IN THE HOLE FROM 7"LINER SHOE AT 13988'MD TO BOTTOM AT 16325'MD -TRIP SPEED=60-90 FPM IN OPEN HOLE � -NO ISSUES RUNNING IN OPEN HOLE -WASH DOWN LAST STAND -MONITOR WELL WITH TRIP TANK:GOOD DISPLACEMENT Printed 8/8/2016 11:19:42AM `AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 88 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. I UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT I NPT Depth Phase I Description of Operations II (hr) I (usft) 02:00 - 14:00 I 12.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 16325'MD TO 16678'MD IN LISBURNE FORMATION -353'IN 12 HRS=29 FPH WITH CONNECTIONS AND SURVEYS -INSTANTANEOUS ROP=30-40 FPH ' 1 -275 GPM,1720 PSI ' ! 120 RPM,20K TORQUE ON,18K TORQUE OFF PU 274K,SO 145K,ROT 193K -12-15KWOB -SURVEY EVERY-90 FT I I -NO BACKREAMING PRIOR TO CONNECTIONS -MUD WEIGHT:8.7 PPG IN,8.7 PPG OUT -NO LOSSES WHILE DRILLING -DECISION MADE TO PULL TO THE 7"LINER SHOE,HANG OFF DRILL STRING AND TEST BOPE PRIOR TO DRILLING THORUGH PLANNED FAULT AT-16800'MD DUE TO THE ' POTENTIAL OF LOSSES IN FAULT 14:00 - 15:30 , 1.50 DRILL P , PROD1 CIRCULATE BOTTOMS UP --275 GPM,1680 PSI -120 RPM,18K TORQUE -CIRCULATE OUT 30 BBL HIGH VIS SWEEP THAT WAS PUMPED WHILE DRILLING DOWN LAST STAND,MINIMAL INCREASE IN CUTTINGS BACK AT SHAKERS -MONITOR WELL FOR 10 MIN(STATIC) 15:30 - 17:30 2.00 DRILL P PROD1 PULL OUT OF THE HOLE ON ELEVATORS FROM BOTTOM AT 16678'MD 3 TA 1 INSIDE 7"LINER SHOE AT 13650TO'MDSNDS 1 -PU 245K,SO 157K AT 13650'MD -OBSERVED-25K OVER PULL AT 16250'MD AND 13880'MD -MONITOR WELL VIA TRIP TANK=GOOD ,DISPLACEMENT 17:30 - 19:30 2.00 DRILL P PROD1 I CIRCULATE BOTTOMS UP -350 GPM,2125 PSI � -NO INCREASE IN CUTTINGS AT BOTTOMS ' UP 19:30 - 20:00 0.50 DRILL P PROD1 HANG OFF DRILL STRING PICK UP RTTS WITH STORM VALVE PLUG REMOVED � -MAKE UP PORTED SUB ON BOTTOM OF RTTS -INSTALL DRILL PIPE SCREEN IN STUMP AND MAKE UP RTTS -MAKE UP STAND OF DRILL PIPE AND RUN RTTS IN WELL TO 99'MD I -SET RTTS PER HALLIBURTON REP AND RELEASE PU 244K,SO 154K,P272 BLOCK WT 35K -WEIGHT SET ON RTTS=119K 20:00 - 20:30 0.50 DRILL P PROD1 !SERVICE TOPDRIVE AND RIG FLOOR EQUIPMENT Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 89 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:30 - 22:30 2.00 BOPSUR P PROD1 PREPARE TO TEST BOPE -SUCK OUT STACK -PULL WEAR RING -INSTALL TEST PLUG -RIG UP TEST MANIFOLD ON FLOOR -BLEED AIR FROM BOPE -SHELL TEST BOPE 22:30 - 00:00 1.50 BOPSUR P PROD1 PRESSURE TEST BOPE TO 250 PSI LOW AND 4000 PSI HIGH FOR 5 MIN EACH -TEST WITH 4"AND 5"TEST JOINTS -TEST ALARMS,PVT AND FLOW SHOW MONITOR WELL VIA HOLE FILL THROUGH ANNULUS VALVES -NO FAILURES TEST WITNESSED BY AOGCC REP MATT HERRERA 7/14/2016 00:00 - 04:00 4.00 BOPSUR P PROD1 PRESSURE TEST BOPE TO 250 PSI LOW AND 4000 PSI HIGH FOR 5 MIN EACH -TEST WITH 4"AND 5"TEST JOINTS -TEST ALARMS,PVT AND FLOW SHOW -MONITOR WELL VIA HOLE FILL THROUGH ANNULUS VALVES 1-1 FAIL/PASS ON 4-1/2 IF DART VALVE -TEST WITNESSED BY AOGCC REP MATT !HERRERA 04:00 - 04:30 0.50 BOPSUR P PROD1 RIG DOWN TEST EQUIPMENT -RIG DOWN TEST MANIFOLD ON FLOOR -LINE UP WELL CONTROL EQUIPMENT 1-PULL TEST PLUG -SET WEAR BUSHING 04:30 - 05:00 0.50 DRILL P PROD1 PULL RTTS PER HALLIBURTON REP -RUN IN THE HOLE WITH RTTS RUNNING TOOL -SCREW INTO RTTS -PULL RTTS TO RIG FLOOR AND LAY DOWN ELEMENT ON RTTS DAMAGED -METAL FRAGMENT OBSERVED BETWEEN ELEMENT AND RTTS BODY 05:00 - 06:30 1.50 DRILL P PROD1 CUT AND SLIP DRILL LINE -HANG BLOCKS -CUT 57'OF DRILL LINE -UNHANG BLOCKS -RECALIBRATE BLOCK HEIGHT IN AMPHION AND BAKER SYSTEMS MONITOR WELL FOR 10 MIN(STATIC) 06:30 - 08:30 2.00 DRILL P PROD1 TRIP IN THE HOLE ON ELEVATORS FROM 13650'MD TO BOTTOM AT 16678'MD -WASH DOWN LAST STAND WITH 300 GPM, 1880 PSI -PU 257,SO 156KAT 16585'MD -NO ISSUES TRIPPING IN OPEN HOLE Printed 8/8/2016 11:19:42AM `AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 90 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:30 - 10:30 2.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 16678'MD TO 16702'MD IN LISBURNE FORMATION -INSTANTANEOUS ROP=10-20 FPH -275 GPM,1630 PSI -120 RPM,18K TORQUE ON,13K TORQUE OFF -PU 271K,SO 155K,ROT 196K 12-15KWOB MUD WEIGHT:8.7 PPG IN,8.7 PPG OUT I-NO LOSSES WHILE DRILLING -OBSERVE GAS CUT MUD AT BOTTOMS UP AFTER TRIP, CHECK FLOW,WELL NOT FLOWING BUT NOTICE GAS BUBBLING AT I SURFACE,DISCUSS PLAN FORWARD WITH WOS,DECISION MADE TO PRECAUTIONARY SHUT IN THE WELLAND CIRCULATE BOTTOMS UP THROUGH FULL OPEN CHOKE -TRACTION EVENT CREATED 2016-IR-5300402 10:30 - 14:00 3.50 DRILL P PROD1 CLOSE ANNULAR AND LINE UP THROUGH FULL OPEN CHOKE TO MUD GAS SEPARATOR AND CIRCULATE BOTTOMS UP -3 BPM,623 PSI -4 BPM,826 PSI 5 BPM,1145 PSI -MONITOR WELL FOR 10 MIN AT MUD GAS 1 1 SEPARATOR(STATIC) -OBTAIN APPROVAL FROM WOM TO OPEN WELL -MONITOR WELL FOR 10 MIN(STATIC) 14:00 - 00:00 10.00 DRILL P PROD1 [DIRECTIONAL DRILL 6-1/8"PRODUCTION I HOLE FROM 16702'MD TO 16877'MD IN LISBURNE FORMATION -175'IN 10 HRS=17.5 FPH WITH CONNECTIONS AND SURVEYS -INSTANTANEOUS ROP=10-20 FPH -275 GPM,1645 PSI -140 RPM,20K TORQUE ON,14K TORQUE OFF -PU 266K,SO 162K,ROT 194K -15-18KWOB -SURVEY EVERY-90 FT -NO BACKREAMING PRIOR TO CONNECTIONS -MUD WEIGHT:8.7 PPG IN,8.7 PPG OUT NO LOSSES WHILE DRILLING -SERVICE TOPDRIVE AND RIG FLOOR EQUIPMENT Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP Page 31 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:O0AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60 05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 7/15/2016 00:00 - 07:30 7.50 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 16877'MD TO 16920'MD IN LISBURNE FORMATION 43'IN 6 HRS=7.2 FPH -INSTANTANEOUS ROP=5-10 FPH -275 GPM,1580 PSI -120-140 RPM,18K TORQUE ON,16K 'TORQUE OFF -PU 266K,SO 162K,ROT 194K 15-18KWOB -SURVEY EVERY-90 FT -NO BACKREAMING PRIOR TO CONNECTIONS -MUD WEIGHT:8.7 PPG IN,8.7 PPG OUT NO LOSSES WHILE DRILLING OBSERVE SIGNS OF WASHOUT IN DRILL STRING,-150 PSI PRESSURE DROP,LOW TURBINE RPMS,NO SURFACE LEAKS, DECISION MADE TO PULL OUT OF THE HOLE TO LOOK FOR WASHOUT 07:30 - 12:00 4.50 DRILL N DFAL 16 920.00 PROD1 TRIP OUT OF THE HOLE WET TO FIND WASHOUT IN STRING FROM BOTTOM AT 16920'MD TO 7"LINER SHOE AT 13988'MD MONITOR WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM AND AT LINER SHOE (STATIC) -OBSERVE TIGHT SPOT AT 14358'MD WITH 40K OVERPULL,BACK REAM TIGHT SPOT WITH 5BPM,900 PSI,15 RPM 8K TORQUE -OBSERVE WASHOUT AT SURFACE WITH BIT AT 14360'MD -VERIFY PUMP PRESSURES AND TURBINE SPEEDS AT SHOE TO VERIFY NO MORE WASHOUTS -275 GPM,1520 PSI '-DISCUSS PLAN FORWARD WITH ODE, DECISION MADE TO TRIP BACK TO BOTTOM AND RESUME DRILLING 12:00 - 14:00 2.00 DRILL N DFAL 16,920.00 PROD1 TRIP IN THE HOLE FROM 7"LINER SHOE AT 13988'MD TO BOTTOM AT 16920'MD -OBSERVE 30K DRAG AT 15215'MD -PU 270K,SO 150K AT 16870'MD 14:00 - 16:00 2.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 16877'MD TO 16927'MD IN LISBURNE FORMATION -7'IN 2 HRS=3.5 FPH INSTANTANEOUS ROP=3-5 FPH -275 GPM,1680 PSI -120 RPM,17K TORQUE ON,15K TORQUE OFF -PU 266K,SO 162K,ROT 194K 15-18KWOB -MUD WEIGHT:8.7 PPG IN,8.7 PPG OUT -NO LOSSES WHILE DRILLING -DECISION MADE TO MAKE BIT TRIP DUE TO INADEQUATE ROP Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* North America-ALASKA-BP • Page 92 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-01700-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. I UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs I Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:00 - 00:00 I 8.00 I DRILL P j PROD1 PULL OUT OF THE HOLE ON ELEVATORS FROM BOTTOM AT 16927'MD TO 2198'MD -CIRCULATE OPEN HOLE VOLUME 275 GPM, 1610 PSI,80 RPM,13K TORQUE -MONITOR WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM AND AT 7"LINER SHOE(STATIC) OBSERVE 30-40K OVERPULL THROUGH SHALES IN UPPER SECTION OF OPEN HOLE AT-14880'MD,14770'MD,AND 14300'MD -PU 275K,SO 151K PULLING OFF BOTTOM 7/16/2016 00:00 - 01:00 1.00 DRILL P PROD1 PULL OUT OF THE HOLE ON ELEVATORS FROM 2198'MD TO TOP OF BHAAT 214'MD MONITOR WELL FOR 10 MIN PRIOR TO PULLING BHA INTO STACK(STATIC) 01:00 - 04:00 3.00 DRILL P PROD1 STAND BACK BHA FROM 214'MD TO SURFACE -PULL SOURCE -PLUG IN AND DOWNLOAD MWD,COPILOT, AND SPECTRAL RES -CHANGE OUT SPECTRAL RES TOOL -BREAK BIT 6-1/8"HYCALOG SKFX613M BIT GRADE: 2-4-BT-S-X-I-CT-PR -MAKE UP 6-1/8"HDBS MM64D BIT -SET BACK ON FLOOR IN ELEVATORS 04:00 - 04:30 0.50 BOPSUR P PROD1 PREPARE TO TEST ANNULAR -SUCK OUT STACK -PULL AND INSPECT WEAR BUSHING -SET TEST PLUG -FILL STACK AND RIG UP TEST LINES 04:30 - 05:30 1.00 BOPSUR P PROD1 I PRESSURE TEST ANNULAR TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MIN EACH(PASS) -WITNESS WAIVED BYAOGCC REP MATT IHERRERA -RIG DOWN TEST EQUIPMENT 1-PULL TEST PLUG -SET WEAR BUSHING,ID=8-13/16" 05:30 - 06:30 1.00 DRILL P PROD1 RUN IN HOLE WITH BHA TO 214'MD -MONITOR WELL FOR 10 MIN(STATIC) 06:30 - 16:30 10.00 DRILL P PROD1 I TRIP IN THE HOLE ON ELEVATORS FROM 214' MD TO BOTTOM AT 16927'MD -SHALLOW HOLE TEST DIRECTIONAL TOOLS AT 1160'MD,300 GPM,980 PSI(GOOD) FILL EVERY 2000'MD CIRCULATE DP VOLUME AT TOP OF 7" LINER,275 GPM,1270 PSI -CIRCULATE FOR 10 MIN AT 7"LINER SHOE, 275 GPM,1430 PSI -275 GPM,1595 PSI 1-120 RPM,14K TORQUE Printed 8/8/2016 11.19:42AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 93 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:30 - 18:30 2.00 DRILL P PROD1 CIRCULATE BOTTOMS UP 1-CIRCULATE 1/2 BOTTOMS UP,CLOSE I ANNULAR AND LINE UP THROUGH FULL OPEN CHOKE TO MUD GAS SEPARATOR, COMPLETE CIRCULATION WITH ADDITIONAL 100 BBL TO ENSURE TRIP GAS IS CIRCULATED OUT OF THE HOLE PER I AGREED PLAN WITH ODE. -5 BPM,1145 PSI -MONITOR WELL FOR 15 MIN THROUGH MUD GAS SEPARATOR WITH ANNULAR CLOSED (STATIC) -OPEN ANNULAR AND MONITOR WELL FOR 10 MIN(STATIC) -LINE UP WELL CONTROL EQUIPMENT PER STANDING ORDERS HOLD 02/D5 DRILLAND AAR 18:30 - 00:00 5.50 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 16927 MD TO 17042'MD IN LISBURNE FORMATION 115'IN 5.5 HRS=21 FPH WITH CONNECTIONS AND SURVEYS INSTANTANEOUS ROP=20-40 FPH -275 GPM,1645 PSI -140 RPM,22K TORQUE ON,19K TORQUE OFF -PU 270K,SO 154K,ROT 196K -12-16KWOB -SURVEY EVERY-90 FT -NO BACKREAMING PRIOR TO CONNECTIONS -MUD WEIGHT:8.7 PPG IN,8.7 PPG OUT -NO LOSSES WHILE DRILLING -SERVICE TOPDRIVE AND RIG FLOOR EQUIPMENT -SPECTRAL RES INTERMITTENTLY WORKING,DISCUSS PLAN FORWARD WITH ODE,TOWN GEO,AND GEOPHYSICIST, DECISION MADE TO KEEP DRILLING AND MADD PASS ON THE TRIP OUT OF THE HOLE IF NEEDED. Printed 8/8/2016 11 19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 94 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisbume Site:Lis DS 01 Rig Name/No.:PARKER 272 I Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To 1 Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 7/17/2016 '00:00 - 05:00 5.00 DRILL P r PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 17042'MD TO 17216'MD IN LISBURNE FORMATION -174'IN 5 HRS=35 FPH WITH CONNECTIONS AND SURVEYS I-INSTANTANEOUS ROP=20-40 FPH 275 GPM,1580 PSI 140 RPM,22K TORQUE ON,19K TORQUE I OFF -PU 270K,SO 154K,ROT 196K 1-12-16KWOB 1 j I-SURVEY EVERY-90 FT -NO BACKREAMING PRIOR TO CONNECTIONS -MUD WEIGHT:8.7 PPG IN,8.7 PPG OUT -NO LOSSES WHILE DRILLING -OBSERVE SIGNS OF WASHOUT IN DRILL i STRING,-120 PSI PRESSURE DROP WHILE DRILLING LAST STAND,LOW TURBINE RPMS, NO SURFACE LEAKS,DECISION MADE TO • PULL OUT OF THE HOLE TO LOOK FOR WASHOUT 05:00 - 20:00 15.00 DRILL N DFAL I 17,218.00 PROD1 -PULL OUT OF THE HOLE WET TO FIND _ I WASHOUT FROM BOTTOM AT 17216'MD TO TOP OF BHAAT 214'MD I -MONITOR WELL FOR 10 MIN PRIOR TO 1 !PULLING OFF BOTTOM AND AT 7"LINER SHOE(STATIC) -PU 280K,SO 155K PULLING OFF BOTTOM 1-CIRCULATE AT THE TOP OF THE 4"DP,275 GPM,1185 PSI,OBSERVE 50 PSI DROP WITH I i EACH PUMP OVER 15 MIN OF PUMPING WITH LOW TURBINE RPMS -CIRCULATE AT THE JARS AT 4972'MD PRESSURES STABLE AT 275 GPM,1005 PSI -CIRCULATE AT 1100'MD TO SIMULATE SHALLOW HOLE TEST ON THE RUN IN THE HOLE WITH 300 GPM,900 PSI,PRESSURES ! !STABLE BUT-80 PSI LOWER THAN ON THE !TRIP IN THE HOLE 1 I-DISCUSS PLAN FORWARD WITH ODE, DECISION MADE TO PULL TO BHAAND CHANGE OUT MWD COMPONENTS PRIOR TO TRIPPIN IN THE HOLE Printed 8/8/2016 11:19:42AM `AII depths reported in Drillers Depths" North America-ALASKA-BP • Page 95 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60 05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 23:00 3.00 DRILL N DFAL 17,218.00 PROD1 PULL OUT OF THE HOLE WITH BHA FROM 214'MD TO SURFACE -MONITOR WELL FOR 10 MIN PRIOR TO PULLING BHA INTO STACK -UNLOAD SOURCES -CHANGE OUT SDN AND STARTRAK (SPECTRAL RES) -DOWNLOAD AUTOTRAK AND COPILOT -INITIALIZE AUTOTRAK,COPILOT,AND STARTRAK -INSPECT BIT,BIT GRADE: 1-1-NO-A-X-I-NO-P P -NO VISIBLE SIGNS OFA WASHOUT WHILE PULLING OUT OF THE HOLE,DISCUSS PLAN FORWARD WITH ODE,DECISION MADE TO TRIP IN THE HOLE AND CIRCULATE EVERY 2000'MD IN SEARCH OF WASHOUT. 23:00 - 00:00 1.00 DRILL N DFAL 17,218.00 PROD1 TRIP IN THE HOLE FROM THE TOP OF THE BHA AT 214'MD TO 1100'MD -MONITOR WELL FOR 10 MIN(STATIC) -SHALLOW HOLE TEST DIRECTIONAL TOOLS WITH 300 GPM,900 PSI 7/18/2016 00:00 - 06:30 6.50 DRILL N DFAL 17,216.00 PROD1 TRIP IN THE HOLE FROM 1100'MD TO TOP OF LINER AT 10617'MD -FILL PIPE AND PUMP FOR 10 MIN EVERY 2000'MD IN SEARCH FOR WASHOUT -PUMP PRESSURE AT EACH STAGE -2000'MD @ 300 GPM=900 PSI AND STABLE -4000'MD @ 275 GPM=900 PSI,TURBINE SPEED 3597 RPM AND STABLE -6000'MD @ 275 GPM=1000 PSI,TURBINE SPEED 3665 RPM AND STABLE -7000'MD @ 275 GPM=1070 PSI,TURBINE SPEED 3665 RPM AND STABLE -8200'MD @ 275 GPM=1100 PSI,TURBINE SPEED 3550 RPM AND STABLE -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT 06:30 - 08:30 2.00 DRILL P PROD1 CIRCULATE BOTTOMS UP AT 10,617'MD TO CLEAN OFF 7"LINER TOP -300 GPM,1260 PSI -15 RPM,4K TORQUE -RECIPROCATE IN 90'STROKES WHILE CIRCULATING -PUMP 30 BBL HI-VIS SWEEP WITH MINIMAL INCREASE IN CUTTINGS RETURNS -NO INDICATIONS OF WASHOUT WHILE CIRCULATING. **REVIEWING LOGS AND SAMPLES INDICATES KAVIK WAS DRILLED FROM 17,027' -17,216'.DECISION MADE TO CALL PRODUCTION HOLE TD AT 17,216'MD. IIII Printed 8/8/2016 11:19:42AM *AII depths reported in Drillers Depths* North America-ALASKA-BP • Page 96,of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:30 - 12:30 4.00 DRILL P PROD1 COMPLETE WIPER TRIP FROM 10,617'MD TO 17,007'MD -RIH ON ELEVATER WITH 5"DP STANDS -FILL PIPE EVERY 2000' -STOP AT 7"SHOE AND CIRCULATE TO VERIFY TOOLS ARE PROPERLY OPERATING: 275 GPM,1300 PSI @13,931'MD NO INDICATIONS OF WASHOUT WHILE CIRCULATING. -PU 255K,SO 155K @ 15,910'MD -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT 12:30 - 15:30 3.00 DRILL P PROD1 CIRCULATE BOTTOMS UP AND CIRC OUT TRIP GAS PER AGREED PLAN FORWARD -FILL MUD GAS SEPARATOR:13.2 BBLS -AT 3/4 BOTTOMS UP,CLOSE ANNULAR AND CIRCULATE THROUGH FULL OPEN CHOKE TO MUD GAS SEPARATOR,COMPLETE CIRCULATING BOTTOMS UP PLUS AN ADDITIONAL 100 BBLS TO ENSURE TRIP GAS I IS OUT OF HOLE:5 BPM,960 PSI. MONITOR WELL FOR 15 MIN THROUGH MUD GAS SEPARATOR WITH ANNULAR CLOSED (STATIC) -OPEN ANNULAR AND MONITOR WELL FOR 10 MIN(STATIC) -LINE UP WELL CONTROL EQUIPMENT PER STANDING ORDERS OBTAIN SPRS 17,007'MD(8,902'TVD)@ 8.7PPG MW 15:30 - 20:30 5.00 DRILL P PROD1 CIRCULATE SURFACE TO SURFACE,PLUS BOTTOMS UP -275 GPM,1685 PSI -120 RPM,18K TORQUE -RECIPROCATE IN 90'STROKES -PUMP 40 BBL HIGH VIS SWEEP:100% INCREASE IN CUTTINGS RETURNS -OBTAIN SPRS AT 17,007'MD'(8,902'TVD)@ 8.7PPG MW 20:30 - 23:30 3.00 DRILL P PROD1 POOH FROM 17,007'MD TO 12,702'MD -MONITOR WELL FOR 10 MINUTES PRIOR TO PULLING OFF BOTTOM:STATIC -PU 278K,SO 152K AT 17,007'MD -TIGHT HOLE AT 14,880'MD WITH 25K OVERPULL:WIPE CLEAN AND CONTINUE TRIP. -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT SIMOPS:LAY DOWN 25 STANDS OF DRILLPIPE OFFLINE WHILE POOH. 23:30 - 00:00 0.50 DRILL P PROD1 DAILY RIG SERVICE -LUBRICATE RIG.GREASE TOP DRIVE, BLOCKS AND CROWN.ADD OIL TO TOP DRIVE. Printed 8/8/2016 11:19:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP S Page 97 of 97 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:DRL-ONSHORE(DON) Start Date:5/26/2016 End Date:7/19/2016 X3-0170D-C:(13,847,214.00) Project:Lisbume Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. I UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) I (usft) 7/19/2016 00:00 - 01:30 1.50 DRILL I P PROD1 I PULL OUT OF HOLE WITH 6-1/8"DRILLING ASSEMBLY ON ELEVATORS FROM 12,702'MD TO T'LINER TOP @ 10,820'MD,RACKING 1 BACK 4"/5"DRILLPIPE I -PU 180K,SO 134K AT 10,820'MD I MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT PULLING SPEED=100 FPM _ ELECT TO NOT DROP DRILLPIPE DRIFT 01:30 - 03:00 1.50 DRILL P PROD1 I CIRCULATE SURFACE TO SURFACE VOLUME I @ 7"LINER TOP I-DROP BALL AND OPEN MOCS TOOL I(POSITIONED AT TOP OF LINER) I-600 GPM,2640 PSI,20 RPM,5KFT-LBS TRQ, I RECIPROCATE 50'STROKES I-CIRCULATE 40 BBL HI-VIS SWEEP WITH MINIMAL INCREASE 4N CUTTING OBSERVED -MW IN/OUT=8.7 PPG -WELL STATIC WHEN PUMPS OFF i I i I I-PUMP DRY JOB 03:00 - 07:00 4.00 DRILL P ( PROD1 ULL OUT OF HOLE WITH 6-1/8"DRILLING ASSEMBLY ON ELEVATORS FROM TOP OFT' LINER AT 10,820'MD TO 791'MD,RACKING 'BACK 4"/5"DRILLPIPE -MONITOR WELL VIA TRIP TANK:PROPER I DISPLACEMENT -PULLING SPEED=200 FPM INITIAL ISSUES TRIPPING BIT UP THROUGH 7"LINER TOP AT 10646'MD: -30K OVERPULL PULLING THROUGH LINER TOP FIRST PASS -RIH PAST LINER TOP NO ISSUES -20K OVERPULL PULLING THROUGH LINER I TOP SECOND PASS I I -RIH PAST LINER TOP NO WT OBSERVED I -NO OVERPULL PULLING THROUGH LINER TOP THIRD PASS 07:00 - 08:00 1.00 DRILL P PROD1 SLIP AND CUT 10 WRAPS,85'1-3/8"DRILL LINE -INSTALL FOSV IN DRILLSTRING AND PLACE BELOW ROTARY TABLE -1995 TON-MILES -CALIBRATE BLOCKS 08:00 - 09:00 1.00 DRILL P PROD1 j PULL OUT OF HOLE WITH 6-1/8"DRILLING ASSEMBLY ON ELEVATORS FROM 791'MD TO BHAAT 213'MD 09:00 - 10:30 1.50 DRILL P PROD1 LAYDOWN 6-1/8"DRILLING ASSEMBLY FROM 1 BHAAT 213'MD TO SURFACE -NO ISSUES NOTED ON BHA I I -GRADE BIT 1-1-IN GAUGE I -FLOWCHECK WELL FOR 10 MIN PRIOR TO I PULLING BHA INTO BOP STACK(STATIC) 10:30 - 11:00 0.50 I DRILL P PROD1 CLEAN AND CLEAR RIG FLOOR AFTER TRIPPING END DON EVENT AT 11:00 i FINAL DAYS/10K(SPUD TO FINAL BHA LD)= 30.5 Printed 8/8/2016 11:19:42AM *AII depths reported in Drillers Depths* • • North America-ALASKA-BP Page 1 of 10 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:COM-ONSHORE(CON) Start Date:7/19/2016 End Date:7/25/2016 X3-0170D-C:(5,199,685.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 7/19/2016 11:00 - 13:30 2.50 CASING P RUNPRD BEGIN CON EVENT AT 11:00 RIG UP TO RUN 4-1/2"PROD LINER RIG UP DOYON CASING DOUBLE STACK TONGS,FILL UP HOSE,SIDE DOOR ELEVATORS -SERVICE AND LUBRICATE RIG '-HOLD PJSM FOR RUNNING LINER -FINALIZE AND CONFIRM LAYOUT OF COMPLEX LINER ASSEMBLIES IN PIPE BARN 13:30 - 21:00 7.50 CASING P RUNPRD RUN 4-1/2",13.5#,13CR,HYD521 PRODUCTION LINER FROM SURFACE TO OVERALL LENGTH AT 3179'MD -CHECK FLOATS(PASS) -BAKERLOK ALL CONNECTIONS BELOW DEEPEST SWELL PACKER AT 16805'MD -TORQUE TURN AND APPLY JET LUBE SEAL GUARD(FRICTION FACTOR=1.0)TO ALL HYD521 CONNECTIONS -RUNNING SPEED=90 FPM -FILL PIPE EVERY JOINT AND TOP OFF EVERY 10 -RUN FREE FLOATING CENTRALIZERS ON JOINTS 1-59 WITH STOP RINGS 2'FROM PIN AND 10'FROM BOX ON EACH JOINT(59 TOTAL CENTS,118 TOTAL STOP RINGS) 21:00 - 22:00 1.00 CASING P RUNPRD MAKEUP 7"X 4-1/2"BAKER LINER HANGER ASSEMBLY AND XO TO DRILLPIPE AT 3179' MD. BAKER REP ADD PAL-MIX TO TIE BACK RECEPTACLE. CIRCULATE 1 LINER VOLUME (48 BBLS);4 BPM,170 PSI -NO LOSSES WHILE CIRCULATING -WEIGHT OF LINER AFTER CIRCULATING=72 KLBS(TOP DRIVE+BLOCKS=35 KLBS) -RIG DOWN TONGS AND SWAP HANDLING EQUIPMENT ON RIG FLOOR. CONFIRM REMAINDER PIPE COUNT IN PIPE BARN. 22:00 - 00:00 2.00 CASING P RUNPRD RUN IN HOLE WITH 41/2"PROD LINER ON 4" DRILLPIPE STANDS FROM LINER OALAT3179' MD TO 5850'MD AT MIDNIGHT. -RUNNING SPEED=90 FPM -NO LOSSES WHILE RUNNING IN HOLE Printed 8/8/2016 11:20:21AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 2 of 10 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:COM-ONSHORE(CON) Start Date:7/19/2016 End Date:7/25/2016 X3-0170D-C:(5,199,685.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 7/20/2016 00:00 - 10:00 10.00 CASING P RUNPRD RUN 4-1/2",13.5#,13CR,HYD521 PROD LINER ON 4"/5"DRILLPIPE FROM 5850'MD AT MIDNIGHT TO PLANNED SET DEPTH AT 17007' MD(209'OFF BOTTOM) RUNNING SPEED=90 FPM IN CASED HOLE, 50-60 FPM IN OPENHOLE -NO LOSSES WHILE RUNNING IN HOLE NO ISSUES RUNNING PAST 7"LINER TOP AT 10646'MD NO MAJOR ISSUES RUNNING THROUGH OPENHOLE -FILL PIPE EVERY 10 STANDS -FINAL PICKUP WEIGHT=255 KLBS, SLACKOFF=135 KLBS(PARKER 272 BLOCKS +TD=35 KLBS) SEE ATTACHED TALLY 'RECORD TORQUE AND CIRCULATE 1.5 X LINER+DRILLPIPE VOLUMES AT THE 7"SHOE PRIOR TO RUNNING IN OPENHOLE 4.7 BPM,765 PSI 10 RPM=7500 FT-LBS,20 RPM=8-9 'KFT-LBS '4-1/2"LINER TOP AT 13828'MD 4-1/2"LINER PBTD=SLB CIRC VALVE AT 16961'MD 10:00 - 14:00 4.00 CASING P RUNPRD STAGE UP PUMPS AND CIRCULATE BOTTOMS UP TO EVACUATE TRIP GAS FROM WELL (PLANNED) -150 GPM,775 PSI -CIRCULATE 3/4 BOTTOMS UP,THEN SHUT ANNULAR PREVENTER. CIRCULATE REMAINDER OF BOTTOMS UP+1000 STROKES TO CLEAR ALL FREE TRIP GAS FROM WELL. -FLOWCHECK FOR 10 MIN THROUGH MGS (STATIC) -OPEN ANNULAR PREVENTER AND FLOWCHECK WELL FOR 10 MIN AT RIG FLOOR(STATIC) Printed 8/8/2016 11:20:21AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 3 of 10 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:COM-ONSHORE(CON) Start Date:7/19/2016 End Date:7/25/2016 X3-0170D-C:(5,199,685.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 18:00 4.00 CASING N DFAL 17,007.00 RUNPRD UNSUCCESSFULLY ATTEMPT TO SET LINER HANGER AS FOLLOWS: -PUMP 20 BBL HI-VIS PILL -DROP SLB 1.275"DEGRADABLE BALL -PUMP 15 BBL HI-VIS PILL -DISPLACE BALL WITH 175 BBLS 8.7 PPG QUICKDRIL MUD;2.8 BPM,785 PSI 15:15: OBSERVE NEAR INSTANTANEOUS 370 PRESSURE SPIKE AT 175 BBLS AWAY(59 BBLS SHORT OF PLANNED BALL LANDING). SHUT DOWN PUMPS AND OBSERVE PRESSURE DROP FROM 1190 PSI TO 675 IN 4 MIN. -RESUME PUMPING AT 1.5-2 BPM FOR 3 MIN AND BUILD PRESSURE UP TO 2750 PSI,BUT PRESSURE LEVELS OFF AND RETURNS ARE OBSERVED. PUMP 1/2 BBLAT2BPM,2750 PSI. SHUT DOWN PUMPS AND OBSERVE PRESSURE DROP FROM 2750 PSI TO 190 PSI IN 3 MIN. '-RESUME PUMPING AT 3.5 BPM FOR 2 MIN AND BUILD PRESSURE TO 2630 PSI WITH 'RETURNS WHILE PUMP(INDICATING BALL NOT FULLY ON SEAT). SHUT DOWN PUMPS AND OBSERVE PRESSURE DROP FROM 2630 PSI TO 190 PSI IN 3 MIN. -15:40: MAKE NOTIFICATIONS TO ANCHORAGE TEAM -16:30: STAGE UP PUMPS AGAIN TO 3.5 BPM OVER 30,1530 PSI WITH REGULAR RETURNS. SHUT DOWN PUMPS AND OBSERVE PRESSURE DROP FROM 1530 PSI TO 190 PSI IN 2 MIN -17:20: STAGE UP PUMPS AGAIN TO 4 BPM; 1400 PSI OVER 20 MIN WITH REGULAR RETURNS. SHUT DOWN PUMPS AND OBSERVE PRESSURE DROP FROM 1400 PSI TO 190 PSI IN 1.5 MIN. -EXTRA CIRCULATING AMOUNTS TO OVERDISPLACING CALCULATED BALL LANDING VOLUME BY 97 BBLS -DISCUSS INABILITY TO PRESSURE UP BEHIND BALL ON SLB CIRC VALVE BALL SEAT AT 16961'MD WITH ANCHORAGE&RIG TEAMS. DECISION TO SET HANGER USING BAKER'S SECONDARY BALL SEAT IN HGR RUNNING TOOLS. SLICKLINE WILL MAKE DRIFT RUNS TO CONFIRM PATH THROUGH DRILLPIPE TO BALL SEAT IS CLEAR. 18:00 - 21:00 3.00 CASING N DFAL 17,007.00 RUNPRD WAIT ON SLICKLINE UNIT DUE TO LAST MINUTE CALLOUT -MONITOR WELL WITH CONTINUOUS CIRCULATION OVER TOP OF WELL,<5 BPH STATIC LOSS RATE Printed 8/8/2016 11:20.21AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 4 of 10 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:COM-ONSHORE(CON) Start Date:7/19/2016 End Date:7/25/2016 X3-0170D-C:(5,199,685.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan©60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:00 - 00:00 3.00 CASING N DFAL 17,007.00 RUNPRD RIG UP SLICKLINE -BREAK CIRCULATION AT 22:00;1 BPM,445 PSI FOR 3 MIN -MONITOR WELL WITH CONTINUOUS CIRCULATION OVER TOP OF WELL,<5 BPH STATIC LOSS RATE -HOLD PJSM WITH SLICKLINE CREW AND WELLS GROUP WSL -RIG UP COMPLETED AT 1AM ON 7/21/16 7/21/2016 00:00 - 01:00 1.00 CASING N DFAL 17,007.00 RUNPRD COMPLETE RIGGING UP SLICKLINE(0.125" CARBON LINE) -ONLY LINE WIPER WITH INTEGRAL CUTTER REQUIRED(APPROVED BY ACTING WSUP) REVIEW WELL CONTROL RESPONSIBILITIES WITH RIG TEAM -MAKEUP FIRST DRIFT TOOL STRING 01:00 - 04:30 3.50 CASING N DFAL 17,007.00 RUNPRD PERFORM DRIFT RUNS WITH SLICKLINE AS FOLLOWS: -RUN IN HOLE WITH 2.125"WEIGHT BAR DRIFT ASSEMBLY FROM SURFACE TO TAG ROTATING DOG SUB 1.97"NO-GO ON DEPTH AT 13831'MD. CONFIRM TAG 3 TIMES. NO DEPTH CORRECTION REQUIRED. PULL OUT OF HOLE. NO ISSUES TRIPPING IN OR OUT OF DRILLPIPE. -RUN IN HOLE WITH 1.75"TAPERED/FLUTED DRIFT ASSEMBLY FROM SURFACE TO TAG 1.65"BALL SEAT NO-GO ON DEPTH AT 13862' MD. CONFIRM TAG THREE TIMES. PULL OUT OF HOLE. NO ISSUES TRIPPING IN OR OUT OF DRILLPIPE. -SEE AWGRS REPORTS ON 7/20 AND 7/21 FOR DETAILED TOOLSTRINGS,ETC. 04:30 - 05:00 0.50 CASING N DFAL 17,007.00 RUNPRD RIG DOWN SLICKLINE 05:00 - 06:30 1.50 CASING P RUNPRD SET BAKER LINER HANGER,RELEASE RUNNING TOOL AND SET ZXP LINER TOP 1 PACKER AS FOLLOWS: -DROP 1.75"BAKER PHENOLIC BALL PUMP DOWN BALL TO BALL SEAT;3 BPM 710 PSI FOR 100 BBLS,THEN 2 BPM,540 PSI FOR FINAL 25 BBLS -LAND BALL ON SEAT IN LINER HANGER RUNNING TOOLS AT 67%OF CALCULATED STROKES. -PRESSURE UP TO 4000 PSI TO SET HANGER AND RELEASE RUNNING TOOL -PICKUP TO EXPOSE DOG SUB. SET DOWN 50 KLBS TO SET ZXP LINER TOP PACKER. CONFIRM SET WITH 15 RPM,8 KFT-LBS TRQ WHILE SETTING DOWN 50 KLBS 06:30 - 08:00 1.50 CASING P RUNPRD PRESSURE TEST 7"X 4-1/2"LINER TOP PACKER&DP X CSG/LNR ANNULUSTO 250 PSI LOW FOR FIVE MIN AND 4000 PSI HIGH FOR 30 MIN PER BP STANDARDS(PASSING TEST) -TEST AGAINST UPPER RAMS -PUMP 8.7 BBLS TO PRESSURE UP,BLEED BACK 8.7 BBLS LOSE 60 PSI IN FIRST 15 MIN,30 PSI IN iSECOND 15 MIN SEE ATTACHED DOCUMENTATION Printed 8/8/2016 11:20:21AM "All depths reported in Drillers Depths* • North America-ALASKA BP Page 5 oft) Operation Summary Report Common Well Name:L1-13 AFE No Event Type:COM-ONSHORE(CON) Start Date:7/19/2016 End Date:7/25/2016 X3-0170D-C:(5,199,685.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:00 - 10:00 2.00 CASING P : RUNPRD DISPLACE WELL ABOVE TOP OF 4-1/2"LINER FROM 8.7 PPG MUD TO 8.5 PPG KCL -APPLY 850 PSI DOWN DRILLSTRING/LINER WHILE PULLING UP OUT OF LINER TOP. OBSERVE EXPECTED PRESSURE DROP WHILE PULLING UP. -630 GPM,2500-2700 PSI,NO PIPE MOVEMENT FLOWCHECK WELL FOR 10 MIN AFTER SHUTTING DOWN PUMPS PRIOR TO PULLING OFF BOTTOM 10:00 - 15:30 5.50 CASING P RUNPRD PULL OUT OF HOLE WITH BAKER LINER RUNNING TOOLS ON ELEVATORS,RACKING BACK 4"/5"DRILLPIPE FROM TOLAT 13828' MD TO 2100'MD -INITIAL PICKUP WEIGHT OFF BOTTOM=240 KLBS PULLING SPEED=100 FPM 15:30 - 16:00 0.50 CASING P RUNPRD LAYDOWN BAKER LINER HANGER RUNNING TOOLS. CONFIRM SHEARD DOG SUB INDICATING _ GOOD PACKER SET 16:00 - 16:30 0.50 CASING P RUNPRD SERVICE AND LUBRICATE RIG 16:30 - 18:30 2.00 CASING P RUNPRD PULL OUT OF HOLE WITH BAKER LINER RUNNING TOOLS ON ELEVATORS,LAYING DOWN 4"SINGLES FROM 2100'MD TO SURFACE. -AVERAGE 35-40 JOINTS PER HOUR -PULLING SPEED=265 FPM 18:30 - 19:30 1.00 CASING P RUNPRD PULL WEAR RING&PERFORM WEEKLY BOPE FUNCTION TEST 19:30 22:30 3.00 RUNCOM P RUNCMP RIG UP TO RUN 4-1/2"PRODUCTION TUBING -DOYON CASING SERVICES,DOUBLE STACK TONGS WITH TORQUE TURN EQUIPMENT, 4-1/2"YC ELEVATORS,CAVIN AIR SLIPS. -LAYOUT TUBING RUNNING ORDER IN PIPE BARN. CONFIRM PIPE COUNT WITH HES, DRILLER,CASING REP,WSL 22:30 - 00:00 1.50 RUNCOM P RUNCMP RUN 4-1/2",12 6# 13CR,VAMTOP PRODUCTION TUBING FROM SURFACE TO 1500'MD AT MIDNIGHT. -BAKERLOK CONNECTIONS BELOW PACKER -APPLY JET LUBE SEAL GUARD(FRICTION FACTOR=1.0)AND TORQUE TURN VAMTOP CONNECTIONS TO 4440 FT-LBS OPT MU TRQ. H RUNNING SPEED=90 FPM 1 7/22/2016 00:00 - 13:30 13.50 RUNCOM P RUNCMP RUN 4-1/2",12.6#,13CR,VAMTOP PRODUCTION TUBING FROM 1500'MD AT MIDNIGHT TO-7100'MD -APPLY JET LUBE SEAL GUARD(FRICTION FACTOR=1.0)AND TORQUE TURN VAMTOP CONNECTIONS TO 4440 FT-LBS OPT MU TRQ. -RUNNING SPEED=90 FPM -FINAL PICKUP/SLACKOFF WEIGHTS(P272 TOP DRIVE+BLOCKS=35 KLBS)=159/113 KLBS. SIMOPS: LAYDOWN 4"DP STANDS WITH OFFLINE EQUIPMENT Printed 8/8/2016 11:20:21AM *All depths reported in Drillers Depths* • North America-ALASKA-BP 1111 Page 6 of 10 Operation Summary Report Common Wet Name:L1-13 AFE No Event Type:COM-ONSHORE(CON) Start Date:7/19/2016 End Date:7/25/2016 X3-0170D-C:(5,199,685.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:30 15:00 1.50 RUNCOM P RUNCMP SPACEOUT COMPLETION ASSEMBLY AS FOLLOWS: -RUN IN HOLE WITH JOINT#327 AND TAG BOTTOM OF LINER TIE-BACK RECEPTACLE AT 13843'MD(4'DEEPER THAN LINER TALLY PROJECTED DEPTH,WITHIN ACCEPTABLE TOLERANCE) LAYDOWN JOINTS 327,326,325&324. PICKUP 19.77',2.02',9.78'PUPS+JT 324+ HGR AND RUN BACK IN HOLE TO SPACEOUT AND LAND TUBING WITH WLEG 6'IN LINER TOP TIE-BACK RECEPTACLE(13834'MD SET DEPTH IN MIDDLE OF TBR) -NOTE: NO DEPTH CORRECTIONS MADE TO LINER/TBG TALLIES BASED ON 4'DEEPER TAG. TUBING TALLY ADJUSTED TO ACCOUNT FOR SPACEOUT PUPS AND TO SHOW WLEG 'IN MIDDLE OF LINER TOP TBR. SEE EXCEL TALLY FOR ADDITIONAL COMMENTS. FMC VERIFY LANDING HANGER BY !VISUALLY CHECKING THROUGH IA VALVE -CONFIRM LEFTOVER PIPE COUNT IN PIPE BARN. SEE ATTACHED TUBING TALLY 15:00 - 19:00 4.00 RUNCOM P RUNCMP DISPLACE WELL TO NEW 120°8.5PPG CORROSION INHIBITED NACL,BBL IN/OUT AS FOLLOWS: -167 GPM,550-600 PSI -REVERSE IN 213 BBLS OF 8.5 PPG NACL TO BE PLACED IN TUBING AND FROM PACKER TO WLEG IN ANNULUS REVERSE IN 325 BBLS 8.5 PPG CORROSION-INHIBITED NACL TO BE PLACED FROM PACKER TO UPPER GLM IN ANNULUS REVERSE IN 302 BBLS OF 8.5 PPG NACL TO BE PLACED ABOVE UPPER GLM IN ANNULUS -OVERDISPLACE WITH 5 BBLS,THEN LINEUP BACK DOWN TUBING TO PUMP 5 BBLS BACK IN NORMAL DIRECTION TO WASH OFF RHC-M PLUG SEAT. 19:00 - 21:00 2.00 RUNCOM P RUNCMP SET HES 7"X 4-1/2"PERMANENT PRODUCTION PACKER AND TEST TUBING AS FOLLOWS: -DROP 1-7/8"ROLLER STEM BALL AND ROD. ALLOW TO FALL FOR 15 MIN TO RHC-M PLUG PROFILE IN LOWEST X NIPPLE AT 13817'MD -PERFORM PASSING LOW PRESSURE TEST ON TUBING TO 250 PSI FOR FIVE MIN -SET PACKER AT 3000 PSI DURING PRESSURE UP FOR HIGH TEST -PERFORM PASSING HIGH PRESSURE TEST ON TUBING TO 4000 PSI FOR 30 MIN. -60 PSI LOSS IN FIRST 15 MIN,30 PSI LOSS IN SECOND 15 MIN -BLEED TUBING PRESSURE TO 2500 PSI IN PREP FOR IA TEST Printed 8/8/2016 11:20:21AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 7 of 10 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:COM-ONSHORE(CON) Start Date:7/19/2016 End Date:7/25/2016 X3-0170D-C:(5,199,685.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:00 - 00:00 3.00 RUNCOM N DFAL 17,216.00 RUNCMP UNSUCCESSFULLY ATTEMPT TO PRESSURE TEST IA TO 4000 PSI -PERFORM PASSING LOW PRESSURE TEST 'ON IA TO 250 PSI FOR FIVE MIN -PROCEED TO 4000 PSI FOR HIGH TEST. RECORD 250 PSI LOSS IN FIRST 15 MIN AND OBSERVE INCREASING OA PRESSURE DURING MONITORING PERIOD -SHUT-IN IA GATE VALVES TO RE-PRESSURE TEST SURFACE LINES(PASS) -OBSERVE IA LOSE 230 PSI OVER SECOND 20 MIN MONITORING PERIOD,DURING WHICH OA BUILDS 230 PSI -TOUBLESHOOTING CONTINUES ON 7/23/16 7/23/2016 00:00 - 07:00 7.00 RUNCOM N DFAL 17,216.00 RUNCMP TOUBLESHOOT FAILING IA TEST -RE-PRESSURE TEST ISOLATED SURFACE LINES(PASS) -WITH TUBING PRESSURE AT 2500 PSI, ATTEMPT TO PRESSURE TEST IA TO 4000 PSI HIGH(FAIL) -IA LOSSES-10 PSI PER MIN WHILE OA BUILD-10 PSI PER MIN FROM 700 TO 1000 PSI DURING 30 MIN TEST. -BLEED OFF IA FROM 4000 PSI TO 0 PSI. OA BLEEDS FROM 1000 PSI TO 580 PSI WHILE IA BLED OFF,THEN ONLY BLEEDS OFF TO 480 PSI OVER NEXT 1.5 HOURS. CONFIRM DIESEL FLUID IN OA BY TAKING SAMPLE. -FMC REP ON LOCATION TO RETEST 9-5/8" PACKOFF TO CONFIRM NO COMMUNICATION WITH IAAT THAT POINT(PASSING TEST TO 4500 PSI) -PRESSURE UP ON OA WITH DIESEL FROM FREEZE PROTECT PUMP TO1200 PSI. NO PRESSURE RESPONSE OR SIGN OF DIESEL ON IA. -RE-APPLY 2500 PSI ON TUBING. PRESSURE UP IA IN 1000 PSI INCREMENTS TO 4000 PSI. -OBSERVE SAME TREND OF 10 PSI/MIN GAIN ON OAAND 10 PSI/MIN LOSS ON IA DURING 1 HOUR MONITORING PERIOD. ALLOW OA PRESSURE TO BUILD TO 1330 PSI. -BLEED OFF IA FROM 4000 PSI TO 0 PSI. OA BLEEDS FROM 1330 PSI TO 880 PSI IMMEDIATELY,THEN BLEEDS MUCH SLOWER WITH NO SIGNS OF OA COMMUNICATING BACK TO IA. -DISCUSS RESULTS AND PLAN FORWARD WITH ANCHORAGE TEAM. DECISION TO CALLOUT E-LINE UNIT FOR ACOUSTIC LEAK DETECT LOG. SEE ATACHED PRESSURE TESTING CHARTS 07:00 - 12:30 5.50 RUNCOM N DFAL 17,216.00 RUNCMP TROUBLESHOOTING IA/OA COMMUNICATION: WAIT ON E-LINE UNIT AND PDS(LEAK DETECT LOG)TO ARRIVE -LAYDOWN 5"DRILLPIPE STANDS WITH OFFLINE EQUIPMENT -RIG UP DUTCH RISER AND WIRELINE BEAM AT TOOL CRANE IN PREPARATION FOR E-LINE WORK Printed 8/8/2016 11:20:21AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 8 of 10 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:COM-ONSHORE(CON) I Start Date:7/19/2016 1 End Date:7/25/2016 X3-0170D-C:(5,199,685.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: ' Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs j Task I Code NPT NPT Depth Phase Description of Operations (hr) � (usft) 12:30 - 20:30 I 8.00 1 RUNCOM • N 1 DFAL 17,216.00 RUNCMP TROUBLESHOOTING IA/OA COMMUNICATION: RIG UP E-LINE -LOAD TOOLS TO RIG FLOOR AND BUILD TOOLSTRING -FUNCTION TEST TOOLSTRING AND HAVE TO PREP CABLE HEAD -SEE AWGRS REPORT FOR FULL DETAILS OF ALL E-LINE WORK -RIG UP LUBRICATOR FOR APPLYING PRESSURE TO WELLBORE DURING LOGGING. PRESSURE TEST LUBRICATOR TO 1250 PSI LOWAND 3500 PSI HIGH AGAINST BALLAND ROD FOR FIVE MIN EACH 1 (PASSING TESTS PER LEAKTIGHT CRITERIA) 20:30 - 00:00 1 3.50 RUNCOM N DFAL 17,216.00 RUNCMP TROUBLESHOOTING IA/OA COMMUNICATION: PERFORM E-LINE ACOUSTIC LEAK DETECT 1 LOG AS FOLLOWS: -PRESSURE UP TUBING TO 2800 PSI. PRESSURE UP IA TO 4100 PSI. MAINTAIN OA PRESSURE 0-200 PSI BY BLEEDING AS REQUIRED -LOG FROM 5500'ELMD TO 3750'ELMD AT MIDNIGHT WITH PDS ACOUSTIC LEAK I DETECT LOG -LOGGING COMPLETED ON 7/24/16 7/24/2016 00:00 - 10:00 10.00 RUNCOM N DFAL 17.216.00 RUNCMP 'TROUBLESHOOTING IA/OA COMMUNICATION: PERFORM E-LINE ACOUSTIC LEAK DETECT I LOG AS FOLLOWS: 1-PRESSURE UP TUBING TO 2800 PSI. I PRESSURE UP IA TO 4100 PSI. MAINTAIN OA i1 :PRESSURE 0-200 PSI BY BLEEDING AS I REQUIRED I -LOG FROM 3750'ELMD AT MIDNIGHT TO SURFACE WITH PDS ACOUSTIC LEAK DETECT LOG -IDENTIFY LEAKS IN THE 9-5/8"INTI CASING AT 2301'ELMD(JT#237 IN 6.5°/100'DL),2510' ELMD(JT#232 IN 2.5°/100'DL),2676'ELMD(JT •#228 IN 4.5°/100'DL),&2883'ELMD(JT#223 IN 6°/100'DL). ALL FOUR LEAKS ARE WITHIN 3-4' I OF COLLARS ACCORDING TO 9-5/8"CASING I TALLY. CONFIRM EACH LEAK BY MAKING REPEAT I PASSES,3'"STEP-UPS"ACROSS EACH TROUBLE INTERVAL AND BLEEDING OFF I PRESSURE/RE-PRESSURING UP WHILE TOOL ' SITTING ON LEAK DEPTH TO OBSERVE NOISE SIGNAL FADE AND RETURN. I-RUN DOWN TO 10650'ELMD(TOP OF 7" LINER TOP)AND PLAN TO LOG UP TO 6000' I ELMD TO COVER ENTIRE 9-5/8"SECTION OF I IA -WHILE LOGGING UP AT-8000'ELMD,PDS TOOL FAILURE. PULL TOOLS TO SURFACE ' AND TROUBLESHOOT ON LOCATION. NO 1 ISSUES FOUND WITH PDS ACOUSTIC 1 LOGGING TOOL. 10:00 12:00 2.00 RUNCOM N DFAL i 17,216.00 RUNCMP TROUBLESHOOTING IA/OA COMMUNICATION: I RIG DOWN E-LINE+LUBRICATOR+DUTCH RISER. Printed 8/8/2016 11:20:21AM *All depths reported in Drillers Depths` • North America-ALASKA-BP S Page 9 of 10 Operation Summary Report Common Well Name:L1-13 AFE No Event Type:COM-ONSHORE(CON) Start Date:7/19/2016 End Date:7/25/2016 X3-0170D-C:(5,199,685.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:00AM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 12:00 - 13:00 1.00 RUNCOM P RUNCMP PER OCN#22 SHEAR DCR-1 VALVE IN UPPER GLV t 5626'MD I-PRESSURE UP ON TUBING TO 2500 PSI. PRESSURE UP ON IA TO 4000 PSI. BLEED OFF IA AT RAPID RATE TO SHEAR VALVE -CIRCULATE BOTH WAYS THROUGH VALVE TO CONFIRM CIRCULATION;3 BPM,450 PSI 13:00 - 16:00 3.00 RUNCOM P RUNCMP 'FREEZE PROTECT TUBING AND IA TO 2763' MD,2646'TVD(BPERM @ 1848'MD,1827' TVD) -REVERSE IN 190 BBLS 6.8 PPG DIESEL AT 2.5 BPM,200 PSI ICP,400 PSI FCP. 1-ALLOW DIESEL TO U-TUBE FROM IA TO TUBING FOR 1 HOUR -89 PSI OVERBALANCE TO THE LISBURNE AT 8861'TVD(7.8 PPG PORE PRESSURE) 16:00 - 18:00 2.00 WHSUR P RUNCMP SET AND TEST CIW 4"TYPE H TWC -FMC REP DRY ROD TWC PRESSURE TEST FROM ABOVE TO 250 PSI LOWAND 3500 PSI HIGH FOR FIVE MINE EACH(PASSING TESTS) -PRESSURE TEST FROM BELOW TO 1500 PSI PSI ROLLING TEST. WELLBORE HOLDS 1800 [PSI WITH PUMPS OFF FOR 10 MIN(PASSING TESTS) -SEE ATTACHED CHART 18:00 - 21:30 3.50 BOPSUR P RUNCMP NIPPLE DOWN HIGH PRESSURE RISERS AND BOPE -SIMOPS: PUMP 20 BBLS 6.8 PPG DIESEL INTO OA TO RE-FREEZE PROTECT OA DOWN TO 2200'MD AFTER DISPLACING 20 BBLS DIESEL OUT OF OA DURING LEAK DETECT LOG. NO PRESSURE OBSERVED ON IA DURING PUMPING. 21:30 - 00:00 2.50 WHSUR P RUNCMP NIPPLE UP NEW 13-5/8"X 4-1/2"TUBING HEAD ADAPTER AND 4-1/8"DOUBLE MASTER VALVE 5K DRY HOLE TREE. -ORIENT TREE VALVES TO RIGHT 1-COMPLETED ON 7/25/16 7/25/2016 00:00 - 01:30 1.50 WHSUR P RUNCMP 1 COMPLETE NIPPLING UP OF TUBING HEAD ADAPTER AND TREE. -FMC ON LOCATION TO TEST ADAPTER FLANGE TO 250 PSI LOW FOR FIVE MIN AND 4500 PSI HIGH FOR 15 MIN(PASSING TESTS, 1 SEE ATTACHED CHARTS) 1-RIG PRESSURE TESTS DRYHOLE TREE AGAINST TWC WITH DIESEL TO 250 PSI LOW AND 4500 PSI HIGH FOR 5 MIN EACH (PASSING LEAK TIGHT TESTS) -FILL TREE WITH 3 BOTTLES OF DIESEL 911 TO PREVENT FREEZING. Printed 8/8/2016 11:20:21AM *AII depths reported in Drillers Depths* • North America ALASKA-BP • Page 10 of la Operation Summary Report Common Well Name:L1-13 AFE No Event Type:COM-ONSHORE(CON) Start Date:7/19/2016 End Date:7/25/2016 X3-0170D-C:(5,199,685.00) Project:Lisburne Site:Lis DS 01 Rig Name/No.:PARKER 272 Spud Date/Time:5/28/2016 9:30:OOAM Rig Release:7/25/2016 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:L1-13 Plan @60.05usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:30 - 03:00 1.50 WHSUR P RUNCMP CLEAN CELLAR AND SECURE WELLHEAD/TREE. -DOUBLE VALVES LEFT ON ANNULUS OUTLETS(TO BE REMOVED POST RIG) -SECURE EACH ANNULUS WITH QUARTER TURN VALVE,PRESSURE GAUGE,NEEDLE VALVE -ALL TREE/WELLHEAD VALVES LEFT CLOSED TO GAUGES CLOSEOUT WELLWORK TRANSFER PERMIT WITH DS OPERATOR. LEAVE WELLHOUSE SIGN. HANDOVER WELL TO WELLS GROUP FINAL T/I/O=0/0/0 PSI RELEASE PARKER 272 RIG AT 03:00 ON 7/25/16 PERFORMANCE SUMMARY: ACTUAL TOTAL DAYS=59.4,8.7 DAYS BEHIND 50.7 DAY AFE. TOTAL NPT=553.75 HRS(23.1 'DAYS,38.9%) ACTUAL TOTAL SPEND=-$21.55MM, $2.5MM,13%OVER$19.047MM AFE Printed 8/8/2016 11:20:21AM *All depths reported in Drillers Depths* • • im In W II _ 1/410 `W' Q= m a m a a a 0 1 a) CU Ce •— >% L. CD °' m > E i < a m 0—. M co co G) 1 U) J co O O m M N ID t L cn a N o Q ❑ r r N C S to wO Cl) ■. Z JJ JJ L53 a LL °n e.,,,„„,,,„ ,,r 1110 ■ � •• co W co Z Z y MI a �We N uWO go vi o N o ,_ N O �1 NV p O co- CV `- 0 N N U) Mil N N M I- 1` O m N N .- O0 V n. 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Y 674850 I _ -_-- p- —i---- ".--- r '----=--674850 a I Ye P 0 8; 8 5. 8 83 8 8 § 8 83 8SI 83 83 �QQ 88 mommmommommommSmS Sim (ui/tjsn 0SS)SuigpoM a • • 0 WO Post Drilling North America - ALASKA - BP Lisburne Lis DS 01 L1-13 L1-13 L1-13 AOGCC Post Drilling Offset Report 19 July, 2016 r' u BAKER HUGHES AOGCC OFFSET RPORT 10 • BP • Frill t. bp Anticollision Report BAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well L1-13 Project: Lisburne TVD Reference: L1-13 Plan @ 60.05usft(PARKER 272) Reference Site: Lis DS 01 MD Reference: L1-13 Plan @ 60.05usft(PARKER 272) Site Error: 0.Oousft North Reference: True Reference Well: L1-13 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore L1-13 Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: L1-13 Offset TVD Reference: Offset Datum Reference L1-13 Filter type: NO GLOBAL FILTER:Using user defined selection&filtering criteria 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.O0usft Error Surface: Elliptical Conic Survey Program Date 7/19/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 96.00 803.00 Gyrodata Gyro SS 16"(L1-13PB1) GYD-GC-SS Gyrodata gyro single shots 898.56 5,159.13 BH OTK MWD+IFR+MS 16"(L1-13PB1) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 5,237.09 10,730.05 BH OTK MWD+IFR+MS 12-1/4"(L1-13PB MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 10,754.00 10,815.42 Inc+Trend 8-1/2"(L1-13) INC+TREND Inclinometer+known azi trend 10,847.92 13,953.22 BHI OTK MWD+IFR+MS 8-1/2"(L1-13) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 14,022.61 17,182.04 BHI ATK MWD+IFR+MS 6-1/8"(L1-13) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 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) Lis DS 01 L1-01-L1-01-L1-01 1,692.64 1,675.00 333.96 25.45 308.51 Pass-Major Risk L1-01-Plan#119 L1-01A-Plan#119 1,692.64 1,675.00 333.96 25.45 308.51 Pass-Major Risk L1-01-Plan#119 L1-01A-Plan#119 L1-01A 47.15 42.97 359.69 1.22 358.46 Pass-Major Risk L1-02-L1-02-L1-02 902.84 900.00 375.34 13.85 361.49 Pass-Major Risk L1-09-L1-09-L1-09 1,093.13 1,075.00 110.03 16.31 93.72 Pass-Major Risk L1-10-L1-10-L1-10 654.49 650.00 198.89 10.24 188.65 Pass-Major Risk L1-13-L1-13PB1-L1-13PB1 11,036.74 11,050.00 59.83 27.73 39.83 Pass-Major Risk L1-14-L1-14-L1-14 577.96 575.00 177.60 8.71 168.89 Pass-Major Risk L1-15-L1-15-L1-15 607.83 600.00 60.38 10.63 49.75 Pass-Major Risk L1-15-L1-15A-L1-15A 607.83 600.00 60.38 10.63 49.75 Pass-Major Risk L1-15-L1-15A-Plan#20e 607.83 600.00 60.38 10.63 49.75 Pass-Major Risk L1-15-L1-15APB1 -L1-15APB1 607.83 600.00 60.38 10.63 49.75 Pass-Major Risk L1-21-L1-21-L1-21 601.43 600.00 237.78 12.15 225.63 Pass-Major Risk L1-23-L1-23-L1-23 594.54 600.00 299.95 8.53 291.43 Pass-Major Risk L1 27 L1 27 L1 27 575.36 575.00 419.76 10.17 409.59 Pass-Major Risk L1-28-L1-28-L1-28 556.84 550.00 482.63 9.83 472.81 Pass-Major Risk Plan L1-29-Plan L1-29-L1-29 WP04 573.97 575.00 481.22 8.64 472.58 Pass-Major Risk PB DS 15 15-16-15-16B-15-16B 16,581.76 14,700.00 298.51 328.55 94.17 Pass-Major Risk PRUDHOE BAY ST 1 PRUDHOE BAY ST 1-PRUDHOE BAY ST 1-PB 14,714.38 9,025.00 216.68 17,278.79 -17,014.50 FAIL-Major Risk PRUDHOE BAY ST 1-PRUDHOE BAY ST 1 PB1 14,791.38 8,593.00 460.95 11,819.73 -5,461.71 FAIL-Major Risk 7/19/2016 3:54:01PM Page 2 of 3 COMPASS 5000.1 Build 81B AOGCC O. G SE`J REPORT • aaa„� • BP i1 Anticollision Report BAKER .0*,. HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well L1-13 Project: Lisburne TVD Reference: L1-13 Plan @ 60.05usft(PARKER 272) Reference Site: Lis DS 01 MD Reference: L1-13 Plan @ 60.05usft(PARKER 272) Site Error: 0.00usft North Reference: True Reference Well: L1-13 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore L1-13 Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: L1-13 Offset TVD Reference: Offset Datum Reference Depths are relative to L1-13 Plan @ 60.05usft(PARKER Coordinates are relative to:L1-13 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:1.44° Ladder Plot 600— — -- J J J J J - C S'450— ./ i I o as 'i / I A� J li CU f1: I I Cl- (1' 300---- ' c u) i 1 I ro -E > i J U --- .� ;,a J J J O I . /" i4 1 i N 150— --f 1 1 U A. 0 I I I I I I 0 3000 6000 9000 12000 15000 18000 Measured Depth(3000 usft/in) LEGEND i ner L1-14,L1-14,L1-14 V1 -B- L1-27,L1-27,L1-27V1 APlan#119 V2 — L1-15,L1-15,L1-15V1 -$ L1-28,L1-28,L1-28V1 A,Plan#119 L1-01 AVO -j- L1-15,L1-15A,L1-15AV6 —1— Plan L1-29,Plan L1-29,L1-29WP04V2 1 - L1-15,L1-15A,Plan#20e V2 -e- 15-16,15-168,15-16B VO 1 -e- L1-15,L1-15APB1,L1-15APB1 V1 PRUDHOEBAY ST1,PRUDHOEBA) 1 $ L1-21,L1-21,L1-21 V1 PRUDHOEBAY ST1,PRUDHOEBA' 3PB1 VO -e- L1-23,L1-23,L1-23V0 -B- L1-13 7/19/2016 3:54:01PM Page 3 of 3 COMPASS 5000.1 Build 81B AOGCC OFFSET RE?Oo RR . • ca W O- LU O- JO JO D a) CC S O0 CC 2 O0 W O W LLI LU W 0}Nu]LU w NM 0 a < Cd O a < 1 c) • 2 WF- oF ~i ! 2 w o m Z IO Z C o Q Ug o c mU a 0 LU O 0 LU ° N 6 J �' a) ° uXi ma .0 Y m N E E y E y mQ Q O W T LL n Na) a o N a C7 C7 O M U N O O u] _ QO O CO )fp a2 N > N O 0a7 O 3 > N 3 3 N O O O E. 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J W p 0 0 — 2 CI 6 To Z Of t w 0 o LL Co Ern M E -1Qa F 8 z 2- b mw0Omrn I J 0 2 0 a) H = 1y, Q �o d a, 5 t LL' o Z O H w co m Q )n Z Z (n H QQ L r J W Q Q -N-- En m 0" m •H N N c 1— °31— Z a a a) zmzwoo H = m w U3 W U m m O w U U 1= o d 3 HDU' mc0 H Lu LL F2 O = 0 Z 0, w j LL Q 0 0 0 0 m0' W U _, W CO u) Z co Q W (i) 1 Z H JLri > m m Z ' w H H 2 X 0I- 0 0 v c W O J Z W D_ of O 0303-1 CC o) O N isl 0_ Z7-0 w W 0 00 o 0 > z a z z �- Cid, rQ mm H 11.1 o W Z H oo E c0 0 OmOOa > co oa, 2 H O z _ C v M f/) 1HHH0 < o J cn 0 al rn H z o vl 0 0 a) O , V LLI a) J Z O Q Q 'V CSI Z N 'CO a) X H H W mo) 0 ro �, o a v o 0 LL < 7< ''�� '� a .. 3 a m N J z W w m Z m0. 0 0 1 O • H• m ai o c ' 3 ca c7,> > 2 O W ( a H a z 1- c 111 O O > O LL .. 0 67:1 'C H c O_ , J J Q LI a, U LL'w 0 D a E a) Co c 0 w 0 a, w m m W H 0 w 0 H H 0 O D m O m H 2 3 m tr rn H U = OF 7 • •° �aA THE STATE Alaska Oil and Gas 7M OfLASKA Conservation Commission c iti 333 West Seventh Avenue Anchorage, Alaska 99501-3572 QF *M � GOVERNOR BILL WALKER g Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Michael Hibbert Well Interventions Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU L1-13 Permit to Drill Number: 216-003 Sundry Number: 316-415 Dear Mr. Hibbert: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this /t day of August, 2016. RBDMS I,v P, 1 8 2016 IPSTATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMI 101. APPLICATION FOR SUNDRY APPRO 20 MC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 • Operations shutdown 0 Suspend ❑ Perforate ❑ Other Stimulate 0 Pull Tubing 0 Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other OA Squeeze 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 216-003 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development 0 6. API Number: 50-029-23563-00-00 • 99519-6612 Stratigraphic 0 Service ❑ 7. If perforating: 8. Well Name and MI What Regulation or Conservation Order governs well spacing in this pool? I Will planned perforations require a spacing exception? Yes 0 No Id PBU L1-13 . L.® nn C VE D 9. Property Designation(Lease Number): 10. Field/Pools: AUG 09 2016 11.ADL 028302&028303' PRUDHOE BAY,PRESENT WELL CONDITION SUMMARY LISBURNE OIL • .40-1'S /C GC Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 17216 8902 16961 8921 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 47-127 27-127 Surface 5166 13-3/8" 47-5212 47-3806 5020 2260 Intermediate 10709 9-5/8" 45-10754 45-6735 6870 4760 Liner 3342 7" 10646-13988 6645-8858 7240 5410 Liner 3178 4-1/2"x 3-1/2" 13828-17007 8729-8920 8430/10160 7500/10530 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 13978-16933 8850-8921 4-1/2"12.6# 13Cr85 42-13834 Packers and SSSV Type: 4-1/2"HES TNT Perm Packer Packers and SSSV MD(ft)and TVD(ft): 13740/8658 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 • Service 0 14.Estimated Date for Commencing Operations: August 20,2016 15. Well Status after proposed work: Oil 0 • WINJ 0 WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Hibbert,Michael be deviated from without prior written approval. Email Michael.Hibbert@BP.com Printed Name Hibbert,Michael Title Well Interventions Engineer Signature ��� Phone +1 907 564 4351 Date 6N/to COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes 0 No <{ (1t‘43,1%L Spacing Exception Required? Yes 0 No r Subsequent Form Required: /a !/4 b"(' (/ APPROVED BYTHE Cl` Approved by� COMMISSIONER COMMISSION Date:,-/7_/ Vrt $/IS/IJ je RBDMS (,k/ AUG 1 6 1016 , Y7S ORIGINAL 8-:S';( Submit Form and Attachments in Duplicate Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. • •r It 4 Well: L1-13 L1-13 OA Cement Downsqueeze Well Interventions Engineer: Aras Worthington (907) 440-7692 Pad Engineer: Kirsty Schultz (907) 564-5105 Expected Start Date: August 20th 2016 History L1-13 is a recent grassroots producer that was drilled by P272. After running the 4-1/2" tubing and setting the production packer, the well failed an MIT-IA. The well passed an MIT-T and the pack off passed an integrity test, so there is IAxOA communication through the 9-5/8" and/or 7" casing. The communication appears to be a few small one way leaks from the IA to OA. E-line ran a LDL with up/down passes from 6000' MD - surface at 100/30 fpm respectively. Leaks were found at 2883', 2690', 2550', and 2310' MD. During the LDL, the tubing was at 2800 psi, the IA was at 4100 psi, and the OA was <200 psi. A down pass was run to 10700' MD at 100 fpm and an up pass from 10700- 8800' MD at 30 fpm when the tool failed. Because there was missing repeat data and missed logging across the 7", another LDL was run to confirm the condition of the 9-5/8" casing. The proposed plan is to break down the OA shoe and cement the OA to surface to seal the leak from the IA to the OA. Current Status The well is currently classified as "Non Operable" by BP due to the IA x OA communication. The well is currently shut-in until the leak is fixed. Job Economics There are 1.48MMbo estimated to be recovered as a result of getting this well on production. Objective The objective of this job is to cement the OA (13-3/8" x 9-5/8" annulus) to seal-off the IA x OA leak and regain operability of the well. Cement will be pumped down the OA and into formation. The intent is to have cement in the OA from the Surface Casing Shoe to Surface. Post-Job Evaluation ➢ MITIA Long-Term Integrity Monitoring ➢ Daily pressure-monitoring of WHPs • •. Loepp, Victoria T (DOA) From: Gorham, Bradley M <Bradley.Gorham@bp.com> Sent: Thursday,August 11, 2016 9:17 AM To: Loepp,Victoria T(DOA);Worthington,Aras J Cc: Lastufka,Joseph N Subject: RE: PBU L1-13(PTD 216-003) Victoria, The 9-5/8" casing had three passing pressure tests to 4,000 psi prior to the casing failing on the final 4-1/2"tbg x 9-5/8" csg integrity test, which was also to 4,000 psi. As far as what caused the leaks,we are still unsure at this time.We have verified the casing design and had our specialists in Houston confirm that the casing design was sufficient and should not have failed with the load cases that it was exposed to. We are currently further investigating to determine the root cause. Let me know if you have any further questions. Thanks, Brad From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday, August 11, 2016 8:59 AM To: Gorham, Bradley M; Worthington, Aras 3 Subject: PBU L1-13(PTD 216-003) Did the 9-5/8" have a passing pressure test before running the tubing? What could have happened to cause the leaks at ^2500' MD? From: Gorham, Bradley M [mailto:Bradlev.Gorham@bp.com] Sent: Sunday, July 24, 2016 4:37 PM To: Loepp, Victoria T(DOA) Cc: Lastufka, Joseph N Subject: L1-13 Update Victoria, Just wanted to give you an update on the L1-13 well.After running and landing our 4-1/2"completion we set out production packer and achieved a passing tubing integrity test.When the rig attempted to test the IA(9-5/8" csg and 7" liner x 4-1/2"tbg annulus)they were unable to achieve a passing test and there was pressure noted on the OA. After running a leak detection log it appears there are 4 connections in the 9-5/8"casing that are leaking to the OA. The rig team also confirmed that the leak path was one way.They pressured up on the OA and no increased pressure was noted on the IA.The decision was made to move off the well to allow adequate time to develop the best remedial plan for the leaking 9-5/8" casing.The well will not be utilized in any way until we are able to return and complete the remedial work necessary to re-establish the integrity of the casing. If you have any questions don't hesitate to contact Joe or myself. Thanks, Brad ' e \C 5 _ • 7 TREE CIW • WELLHEAD= FMC@SAFETY NOTES:WELL ANGLE>700 1430$'•*' ACTUATOR= BAKER C L 1-13 Current CHROME TBG&LNR***MAX DLS:142°@ 14434' OKB.ELEV= 60.05' ,T." •-r INITIAL.BF.ELEV= 12.9' ' 2201' H4-1Y2'KES X NP,D=3.813' KOP= 576' 20"X30" H 127' Max Angle= 1020©14655' NS '"*'- Datum MD= 14128' 91.5#,A-53, GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH FORT DATE Datum ND= 8900' D=19.124" 5 5626 4005 64 INAICi DCR-1 RKP - 07/22/16 L13-3/8"CSG,684,L-80 HY0563/BTC,0=12.415' 5212' 4 9928 6099 45 MMG Y FEC 0 07/22!16) DM3 11662 7241 64 MAG DMY BK 0 07/22/16 LTOP OF CMT(06/12/18d--t -7603' K 2 12731 7849 38 MAG DMY BK 0 07/22/16 Minimum ID =3.813" @ 2201' y 1 13471 8441 36 MNG DMY BK 0 07/22116 4-1/2" HES X NIPPLE N. ' 10646f1' 9-5/8'X 7"BKR O LTP w/TEBACK SLV& TOP LNR 10646' 1Q-. w BKR FLEXLOCK FIG. D=6.20' ti � RI I ';ii$ 19-5/8"W STOCK(06/23/16) - 10764' N • 19-5/8'CSG,47#,L-80 VAM TOP,D=8.681"[ 2199' LA 13712' -14-1/2"FES XNP,D=3.813", 4 Zit DI i �� i� - 13740' _.7'X 4-112"HES TNT PKR D=3.870' le :141 it 13$17' -14-1/2"HES X(Na,),D=3.813" 1 ap mli . � 13828' -7'X 5'BKR I-FD-E 2XP LTP w/TIEBACK SLV& BKR FLEXLOCK HGR,D=4.30' 4-1/2"TBG,12.6#,13CR-85 VAM TOP, H 13834' - J . 13834' 1-I M4-1/2-' EG,D=3.958' $140.0152 bpf,ID-3.958" ,�1 ,• LIiMD TT NOT LOGO 111111113862' I-15"X 4-1/2'XO BUSHING,D=3.91' I 7'LNR 26#,L-80 VAM TOP, - 13988' _.z. 0383 bpf_a=6.276' _ _" 4-1/2"FRAC PORT SLEEVES NO DEPTH SEAT SZ. ACTUAL S/ZE O/C DATE 4-1/2"HES SWELL PACKERS 11111111112 13978 3.137' 5.630" 07/20/16 11 14089' 3.037" 5.630' 07/20/16 NO SIZE TOP DEPTH MND _'7• 11 4-1/2" 14033' 3.92" MMI 10 14338' 2.947" 5.630" 0720/16 10 _ _ 9 14626' 2.857' 5.630" 07/20/16 4-1/2" 14223' 3.92` ••-•:'.1 1 8 14888' 2.767" 5.630" 07/20/16 9 4-1/2" 14470' 3.92' «1 7 15200' 2.677' 5.630" 07/20/16 8 4-1/2" 14755' 3.92" '7.'-'= 6 15418' 2.587" 5.630" 07/20/16 7 4-1/2" 15025' 3.92" II IN II5 15539' 2.497" 5.630" 07/20/16 6 4112" 15244' 3.92" '='_'=' 4 15711' 2.412' 5.630" 07/20/16 5 4-1/2" 15487' 3.92" Ma3 16262' 2.332' 5.630' 07/20/16 4 4-1/2" 15626' 3.92' in_'' 2 16662' 2.252' 5.630" 07/20/16 3 4112" 15848' 3.92" M 1 16933' 3.75" 5.630" 07/20/16 2 4-1/2" 16498' 3.92' .7. 1 4-1/2' 16764' 3.92" FEZ •_,- ■t■ 16847' H 4-1/2'HY D521 SHFT TOOL VERF1CAT1ON SUB,D=3.87" F81D 16961' - I.•1 16961')-14-1/2"SLB FLOW-Th#2U CRC VALVE,D=1.220 4-1/2"Ltd 13.5#,13CR-$5 HYD 521, H 16973' IN III16973' -I4-1/2'X 3-1/2'XO,0=2.992"J .0150 bpf,a=3.92' 13-1/2"LNR 9.24,L-80 TCI,.0087 bpf,D=2.992" „ 17007' Mie DATE REV BY COMMENTS DATE REV BY COMMENTS PRIJDHOEBAY UNIT 07/25/16 P-272 IMTIAL COMPLETION WELL: L1-13 07/28/16 JM3 DRLG HD CORRECTIONS FEF81T No: -2160030 08/02/16 BG/JM) FINAL ODE APFROVAL AR No: 50-029-23563-00 SEC.1,T11M 14E,2542'FSL 8 2478'FEL BP Exploration(Alaska) 2 41110 • •O T>�= cm, - -- • WELLHEAD= FMC L 1-13 Proposed SAFETY NOTES:WELL ANGLE>70°@ 1444308' ACTUATOR= BAKER CHROME TBG&LNR"MAX DIS:14.2°@ 14434' OKB.ELEV= 60.05' �""' `'1 INITIAL SF.ELEV= 12.9' / Cement in OA from 13-3/8" Shoe to 0 - f KOP= 576' 20"X 3127' 1 I-- ^ Surface Max Angle= 102`@14655' INS COND, Datum MD= 14128' 91.5#,A-53, l. GAS LE f MANUd15 - - ST MD ND DEV TYPE VLV LATCH FORT DATE Datum ND= 8900' D=19.124' 5 5626 4005 64 MAG DCR-1 RKP - 07/22/16 113-3/8'CSG,684,L-80 HYD563/BTC,D=12.415' x,6212' 4 9928 6099 45 MM DMY RK 0 07/22/16 _.. 3 11662 7241 64 MMG DMY BK 0 07/22!16 TOP OF CMT(06/12/16) H -7603' J 7 2 12731 7849 38 MMG DMY BK 0 07/22/16 Minimum ID =3.813" @ 2201' _ , 1 13471 8441 36 MMG DMY BK 0 07/22/16 .1 4-1/2" HES X NIPPLE 1 10646' -9-5/8'X 7"BKR H D LTP w/TIEBACK SLV& TOP OF LNR 10646' , , BKR FLEXLOCK HGR,ID=6.20' i9 518'VSTOCK(06/23/16) H10Tb4' r., ;.;- - R. 1+ L518"CSG,47#,L-80 VAM TOP,D=8.681' 12199' :* k' I !7 1 13717 j-14-112"HES X NP,ID=3.813" A!" ►4 �Fy�� 13740'_-{7"X 4-1/2"HES TNT PKR D=3.870"- �. 13817' -i 4-112"HES X NP,1 =3"813' I 5:74 :4- .4. ' ,."v + t xo,./ 13828' -{7'X 5'BKR H E ZXP LTP w/TEBACK SLV& I BKR FLEXLOCK HGR D=4.30 4-1/2'TBG,12.6#,13CR-85 VAM TOP, H 13834' { ' '#- 13834' H4-112"WLEG,D=3.958' 0152 bpf,D-3.958" �� k apt rr NOT LOGGED.] k "."1 13862' H5'X 4-1/2'XO BUSHING,0=3.91' 7'LINK 26#,L-80 VAM TOP, - 13988' _. _. .0383 bpf.0=6.276' 1.,..41I T 1.,...114-1/2"FRAC PORT SLEEVES ND DEPTH SEAT SZ. ACTUAL SIZE (YC DATE '' 12 13978' 3.137" 5-630" 07/20/16 4-1/2'HES SWELL PACKERS ♦ 11 14089' 3.037' 5.630 07/20/16 NO SIZE TOP DEPTH MW D -' 10 14335 2.947' 5.630 0720/16 11 412' 14033' 3.92" I I 9 14626` 2.85T 5.630 0720/16 10 4-1/2' 14223' 3.92" '' 9 4-1/2' 14470' 3.92" I I 8 14888' 2.767' 5.630 07/20/16 7 15200' 2.677" 5.630 07/20/16 8 4112" 14755' 3.92" 6 15415 2.587' 5.630" 07/20/16 7 412' 15025' 3,92" 5 15539' 2.497" 5.630" 07/20/16 6 4-1/2" 15244' 3.92" C. = 4 15711' 2.412' 5.630" 07/20/16 5 412' 15487' 3.92' M. 3 16267 2.332' 5.630' 0720/16 4 4-1/2' 15626' 3.92" -' 2 16667 2.257 5-630" 0720/16 3 4-1/2' 15848' 3.92' I t 1 16933' 3.75" 5.630" 07/20/16 2 4-1/2" 16498' 3.92' - 1 4-12" 16764' 3.97 ■T■ •Ill 1684T -4-12"HY D521 SHIT TOOL VERFICATION SUB,I)=3.87' PETD H-- 16961' 16961'J--1.4-1/2"SLB FLOW-1142U CRC VALVE D=1.220" 4112'LNR 13.5#,13CR-85 HYD 521, 16973' M�M 0150 bpf,D=3.92' 16973' H 4-112"X 3-112"XO,0=2.992" 13-1/2"LW.9.24.L-80 TCN,.0087 bpf,D=2.992" L 17007' WM DATE I REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/25/16 I P-272 INITIAL COMPLETION WB L: L1-13 07/28/16 JMD DRUG HO CORRECTIONS PERMIT No' '2160030 08/02/16 BG/JMD FINAL ODE APPROVAL AR Pb. 50-029-23563-00 S .1,T11N.14E,2542'FSL.&2478'FEL BP Exploration(Alaska) 3 • • II TREE= C1W WELLFEAD= FMC L1-13 Proposed P&A NOTES'WELL ANGLE>70*@14308'*•* ACTUATOR- BAKER C E TBG&LNR***MAX DLS:142*ft 14434' OKB.ELEV= 60.05' a a °s$''s''X a NTIAL.BF.BEV= 12.9' - ' MA`°kap @e°k4 a. KOP= 576' 20"X30" � 127 ^` ow .fi 2201' 14-1/7 HES x r+#P.D=3.813' 1 .. .. -_._ �'....., te'.&,. .. ' �+� Max Angie= 107©14655 mss . p Cement plug #3 circulated down Datum MD= 14128' 91.5#.A-53, - tubing, through tubing punches @ )ATE Datum TVD= 8900' D-19.124" -1500' MD and up IA to surface /22/166 I1CSG,688,L-80 HY 0563/BTC,D=12.415' -1 6212' [13-3/8" J L 3 11662 7241 64 MMG DMY BK 0 07/22!16 (TCW OF CMT(06/12/16) l-L_-7603' s� 2 12731 7849 38 MAG DMY BK 0 07/22/16 Minimum ID =3.813" (,,cd' 2201' g 1 13471 8441 36 MMG DMY BK 0 07/22/16 4-112" HES X NIPPLE r. ,g Cement plug#2 circulated down a TOP OF LNR 10646' , Z��y„ :, ;> " _�. tubing, through tubing punches A`°`"°"'" '� above packer and up IA �i¢1:, �� ��Pi 9-5/8"WFFSTOCK(06/23/16) -1 10764' 1N Pi 19-5/8"CSG,47#,L-80 VAM TOP,D=8.681"i 12199' ' ilEEMMOREN"..41111E4 p s Iiiieinfe� 13712' I4-1/2"FES X NP,D=3.813-1 /a :"i ';►1. 1 Cement plug#1 pumped FB or laid Y in w/ CT iit Fto ad.6� :i :‘e- i*i. t 13828' -7"X 5"BKR I- D-E ZXP LTP w 1TEBAC K Sty& '4 %i:iiiiMinti 111. y BKR FLEXLOCK HGR,D=4.30" s,' NE]litiglii 4-1/2"TBG,12.6#,13CR-85 VAM TCW, 13834' i liol 13834' H4-112"WLE3G,ID=3.958' .0152 bpf,D-3-958" lainSei- MIi V [ _____�__J-1B_MD TT NOT LOGGED ho , ° 5"X 4-l12"XO BUSS-NG,13=3.91J M T"Lt,26#,L-80 VAM TOP, 13988' • .. %' .0383 bpi.D=6.276' ..Wirg 4-112'FRAC PORT SLEEVES wieoci NO DEPTH SEAT SZ. ACTUAL SIZE CYC DATE _, m ,-. 12 13978' 3.137" 5.630' 07/20/16 4-112'FEB SVlEt3L PACK "m y3 11 14089' 3.037" 5.630" 07/20/16 NO SIZE TOP DEPTH MPJ ID '-' ;" 2' 14033' 3.92" 10 14338' 2.947' 5.630' 07/20/16 11 4-1/7 a 10 4-12' 14223' 3.97 ._ _. 9 14626 2.857" 5.630" 0720!16 PAMNP 8 14888' 2.767" 5.630" 07/20/16 9 4-1/7 14470' 3.97 7 15200' 2.677" 5.630' 0720/16 8 4-12" 14755' 3.97 ', 6 15418' 2,587" 5.630" 07/20/16 7 4112" 15025' 3.97 . 4 5 15539' 2.497" 5.630" 0720/16 e �r 6 412" 15244' 3.97 =�'" 4 15711' 2417 5.630" 07/20/16 5 4-1/2 15487' 3.97 i521:0'13 gi _ 16262' 2.337 5.630" 07/20/16 4 412" 15626' 3.97 /, '` 2 16667 2.257 5.630" 07/20/16 3 4-12" 15848' 3.92" % 1 16933' 3.75" 5.630" 07/20/16 2 4-1/2 16498' 3.97 '-, 1 4-1/7 16764' 3.97 16847' H4-1/7 FK 0521 SF#T TOOL VEIFIC TION SUB,D=3.87 PBTD 16961' - Egagi► 16961' -14-12'SLB FLOW-T1-RU CRC VALVE,D=1.220'J 4-1/7 LNR,13.5#,13CR-85 HYD 521, 16973' - -.._._____ --------_-_--- M M N 16973' 1-1±1/2-/2"x 3-1/7 XO,D=2.992' .0150 bpf,D=3.97 3-1/2"LW,9.2#,L-80 TOt.0087 bpf,13=2.997 j--( 17007' I- DATE REV BY COP4&NTS DATE REV BY COMMENT'S PFIUDfOE BAY UNIT 07125/16 P-272 INTTAL COMPLETION t+1lELL. L1-13 07/28/16 JM) DRLG HO CORRECTIONS FERMT No: '2160030 08/02/16 BG/JMD FINAL ODE APPROVAL API No. 50-029-23563-00 SFC`.1,T11't 14E,2542'FSL&2478'FEL BP Exploration(Alaska) 4 Job Notes 011) • IA x OA communication leakpoints found @ 2883', 2690', 2550', and 2310' MD. • LLRIAxOAis -1 gpm@3800 psi • Injectivity into the OA was established @ 950 psi w/ 10.5 ppg LSND mud on 6/12/2016 • OA was Freeze-protected to 2200' MD w/ 132 bbls diesel @ 1-2 bpm, 900-1000 psi on 6/13/2016 Cement Calculations OA fillup volume of Cement 311 Bbls Total cement to pump 415 Bbls Key Parameters Ppg: 15.8 ppg Class G — Mix on the fly Slurry Temperature: between 80° and 110°F API fluid loss: 40 - 200 cc Thickening Time: Minimum 4 hours Compressive Strength: 2000 psi in 24—48 hours Cement thickening time: Mix on the fly Activity Time(hours) Shearing time,quality control, PJSM 0 Cement displacement 2 Cement contamination 0 Safety 2 Minimum required thickening time: 4 Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 65 0 2:00 65 0 5:30 52 0 10:00 46 0 16:30 42 0 24:00 39 0 Volumes: top volume MD bot MD Size ID bbls/ft. Ft. bbls 12.415" 13-3/8" 68# x 13-3/8"x 9-5/8" annulus 0 5212' x 9-5/8"47# 9.625" 0.0597 5212' 311 5626' (to circulation 9-5/8"47#x 8.681" 9-5/8" x 4-1/2" annulus 0 sleeve) 4-1/2" 12.6# x 4.5" 0.0535 5626' 301 5 • Fullbore/S•ecial Pro'ects 4911) • 1. RU LRS to OA. 2. Using diesel, fill up OA and pressure up the OA until it starts taking fluid and the shoe is broken down. Max OA pressure is 3000 psi. Record the injectivity rate and pressure after the shoe breaks down. Target 3-5 bpm if attainable. NOTE: • Injectivity into the OA was established @ 950 psi w/ 10.5 ppg LSND mud on 6/12/2016 • OA was Freeze-protected to 2200' MD w/ 132 bbls diesel @ 1-2 bpm, 900-1000 psi on 6/13/2016. Slickline 1. Pull DGLV from Station #1 @ 5626' MD and run Circulation Sleeve @ same. 6 Fullbore Cement/Speci- Projects 1. RU LRS to the IA. Pump 300 bbls of hot (180F) crude down the IA through to heat the wellbore prior to the cement squeeze. Max pressure 2500 psi. 2. RU Cementers to the OA. RU in such a way that the OA can be closed in and wash up water diverted upstream of the OA. Mix cement on the fly. Pump the following schedule at maximum rate below 2500 psi treating pressure. ➢ 10 bbls neat MEOH ➢ 150 bbls hot (180 deg) freshwater + surfactant; 2 gal/bbl Surfactant and 2 gal/bbl Mutual Solvent ➢ 10 bbls of 13.5 ppg Mudpush Spacer ➢ 75 bbls of neat cement ➢ 50 bbls of cement with 15-ppb aggregate/pressure-seal ➢ 290 bbls of neat cement + have an additional 65 bbls of cement on hand if no bump is seen when aggregate hits the shoe. No displacement behind cement. Slow rate to -1 bpm as aggregate gets to the casing shoe. (OA volume is 311 bbls, aggregate will be at the shoe @ -321 bbls total cement away/-30 bbls cement left to pump). With 3-5 bbls of cement left to pump open tee just upstream of the OA valve. Before swapping to wash-up water close OA valve so that no water is pumped into/or is allowed to be sucked into the OA. 3. After washing up surface lines, hold open bleed on OA for 1 hour, sniff for LEL's, then ND gate valve and manually clean any residual cement from the valve and VR profile. (See MOC #10083 for specific deviation details allowing for this operation). 4. Grease the OA gate valve to clear of all cement & NU valve. DHD 1. Wait on Cement -3 days. 2. Shoot fluid level on OA to locate TOC. 3. If fluid level is "near surface" then strap TOO to verify actual depth. Special ProjectsNaive Shop 1. ND OA Gate Valve, strap TOC. 2. NU OA Integral. 3. Bleed Annuli, Prep OA, Squeezecrete OA top job to 2500 psi per RP: "Small volume cement squeeze". DHD 4. WOC for 7 days. MITIA to 2500 psi. 7 • • el Loepp, Victoria T (DOA) From: Gorham, Bradley M <Bradley.Gorham@bp.com> Sent: Thursday,August 11, 2016 9:17 AM To: Loepp,Victoria T (DOA);Worthington, Aras J Cc: Lastufka,Joseph N Subject: RE: PBU L1-13(PTD 216-003) Victoria, The 9-5/8" casing had three passing pressure tests to 4,000 psi prior to the casing failing on the final 4-1/2"tbg x 9-5/8" csg integrity test, which was also to 4,000 psi. As far as what caused the leaks, we are still unsure at this time. We have verified the casing design and had our specialists in Houston confirm that the casing design was sufficient and should not have failed with the load cases that it was exposed to. We are currently further investigating to determine the root cause. Let me know if you have any further questions. Thanks, Brad From: Loepp, Victoria T(DOA) [nailto:victoria.loepp@alaska.gov] Sent: Thursday, August 11, 2016 8:59 AM To: Gorham, Bradley M; Worthington, Aras J Subject: PBU L1-13(PTD 216-003) Did the 9-5/8" have a passing pressure test before running the tubing?What could have happened to cause the leaks a 2500' MD? From: Gorham, Bradley M [mailto:Bradley.Gorham@bp.com] Sent: Sunday, July 24, 2016 4:37 PM To: Loepp, Victoria T(DOA) Cc: Lastufka, Joseph N Subject: L1-13 Update Victoria, Just wanted to give you an update on the L1-13 well.After running and landing our 4-1/2" completion we set out production packer and achieved a passing tubing integrity test.When the rig attempted to test the IA(9-5/8" csg and 7" liner x 4-1/2"tbg annulus)they were unable to achieve a passing test and there was pressure noted on the OA. After running a leak detection log it appears there are 4 connections in the 9-5/8" casing that are leaking to the OA. The rig team also confirmed that the leak path was one way.They pressured up on the OA and no increased pressure was noted on the IA.The decision was made to move off the well to allow adequate time to develop the best remedial plan for the leaking 9-5/8" casing.The well will not be utilized in any way until we are able to return and complete the remedial work necessary to re-establish the integrity of the casing. If you have any questions don't hesitate to contact Joe or myself. Thanks, Brad 1 40 PYD 2-I —0O3 Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Thursday,August 11,2016 10:19 AM To: 'Lastufka,Joseph N' Subject: RE: L1-13 (PTD#216-003)Sundry for post rig cement squeeze 30 days after rig release From: Lastufka,Joseph N [mailto:Joseph.Lastufka@ bp.com] Sent:Tuesday, August 09, 2016 1:13 PM To: Loepp,Victoria T(DOA) Subject: L1-13 (PTD# 216-003) Sundry for post rig cement squeeze Victoria, We are preparing a sundry request for L1-13 (PTD#216-003)for Repair Well, OA Squeeze that will be submitted this afternoon. We just moved off the well on 7/25 which would have the Completion Report due 8/24. The Completion Report has not been submitted at this time, would you like to have the 10-407 submitted within the 30 days of rig release or after the cement squeeze (assuming approval)? Please let me know if you have any questions or need additional information. Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 vv.) NI11OU 1C111 111111 BP Exploration AlaskaI900 E. Benson Blvd.IRoom: 788D1Anchorage, AK 1 • 21 6003 WELL LOG 2 7 4 6. 2 TRANSMITTAL PROACTIVE DIACINOSTIC SERVICES, INC. DATA LOGGED/12I/201(p K BENDER To: AOGCC Makana Bender 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Merion Kendall LR2—1 900 Benson Blvd. Anchorage, AK 99508 gancpdcabp.com and ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 23-Jul-16 L1-13 BL /CD 50-029-23563-00 2) Signed : /4A4 O3`4" Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\BP_Transmit.docx ,27 Q 2/G —op3 Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday,July 27,2016 9:56 AM To: 'Gorham, Bradley M' Subject: RE: L1-13 Update(PTD 216-003)Operations Shutdown Brad, When do you plan to return to the well?A 10-403 Operations Shutdown Sundry is required. Thanx, Victoria From: Gorham, Bradley M [mailto:Bradley.Gorham@bp.com] Sent: Sunday, July 24, 2016 4:37 PM To: Loepp, Victoria T(DOA) Cc: Lastufka,Joseph N Subject: L1-13 Update Victoria, Just wanted to give you an update on the L1-13 well.After running and landing our 4-1/2"completion we set out production packer and achieved a passing tubing integrity test.When the rig attempted to test the IA(9-5/8"csg and 7" liner x 4-1/2"tbg annulus)they were unable to achieve a passing test and there was pressure noted on the OA. After running a leak detection log it appears there are 4 connections in the 9-5/8"casing that are leaking to the OA. The rig team also confirmed that the leak path was one way.They pressured up on the OA and no increased pressure was noted on the IA.The decision was made to move off the well to allow adequate time to develop the best remedial plan for the leaking 9-5/8"casing.The well will not be utilized in any way until we are able to return and complete the remedial work necessary to re-establish the integrity of the casing. If you have any questions don't hesitate to contact Joe or myself. Thanks, Brad Brad Gorham BP Exploration (Alaska), Inc. Drilling Engineer W: (907)564-4649 C: (907)223-9529 Bradley.Gorham@bp.com 1 • • Pg(, Regg, James B (DOA) ZiboJsc, From: Murphy,Jay <Jay.Murphy@bp.com> Sent: Friday,July 15, 2016 7:57 AM To: DOA AOGCC Prudhoe Bay Cc: Kilfoyle,Jeffery A; Daniel, Ryan; Allen, Kenneth W; Egbejimba, Uchenna J; Kolstad, Scott R; Mclaughlin, Sean M; Schiavenato, Carlos F; Schneider, Kenneth J;Warren, Abigail M; Sarber, Greg J; Murphy,Jay; Romo, Louis A; Cismoski, Doug A;Isaacson,William 5; Serpa, Lina M Subject: AOGCC BOPE USAGE REPORT for L1-13 on Parker 272 Attachments: Parker 272 BOP Usage Form Well L1-13 07-14-16.docx Thank You, � -rL 11,1.n,": t,^ Jay Murphy —7/4.1 cc GWO-Alaska Well Operations Specialist (. -t cett4-/-69 Office: (907) 659-4618 Cell: (907) 715-9211 Harmony: 2156 Oro 1 • • AOGCC BOPE USAGE REPORT FORM (Well Control event only) Field Superintendent Name: Jay Murphy Wellsite Leader Name: Keith Conatser Contact Number: 907-659-4618 Contact Number:907-685-4802 BP Traction Number: 2016-IR-5300402 Rig Name&Well Pad or Drill Site&Well Name: Parker 272—Drill Site L1 Well 13 Permit To Drill (PTD) Number: 216-003 i Date and Time of Incident: 7-14-2016, 10:15 ✓ Original Scope of Work: Drill new well. Operational Description Leading up to Well Control Event: During the drilling of the production zone and timing of BOPE test date approaching the rig team decided to test BOPE before drilling across a fault so that the well would not be on losses during the testing. Pulled drill string into the casing and hung off string with a RTTS.Tested BOPE with witness of AOGCC representative.After reaching bottom of open hole and drilling ahead a deviation in fluid trends was observed, Crew picked up off bottom and flow checked the well.There was no flow but trip gas bubbled at surface at about the same time the first bottoms up circulation was achieved.Town team was notified and WSL was granted permission to precautionary circulate a bottoms up through the choke manifold. Annular Preventer was closed and well was circulated through the choke and MGS.After bottoms up was achieved well was flow checked and opened after permission from WOM was granted. BOPE Used and Reason: Annular Preventer for precaution to obtain a stable fluid column. Current BOPE test time/date: Completed Biweekly BOPE Test with AOGCC witness at 04:00 on 7/14/2016. With 4"and 5"test joints. Is a BOPE re-test required after use: Yes BOPE Retest time/date and result(WSL to complete as applicable) Will retest Annular Preventer when production hole is drilled and drilling assembly is out of the hole before production liner is ran on or about 7/16/2016 around noon. 1-0-0 2 p4—c a,(2k Plan Forward: Complete drilling well, POOH and test Annular Preventer, Run Liner, Run Completion. r • • STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim.regq(c alaska.gov AOGCC.Inspectors analaska.gov phoebe.brooksalaska.qov Contractor: Parker - Rig No.: 272 - DATE: 7/16/16 Rig Rep.: Jon King Rig Phone: 907-685-4801 Operator: B.P. Op. Phone: 907-685-4802 Rep.: Keith Conaster E-Mail rig272srmgr@parkerdrilling.com Well Name: L1-13 / PTD# 2160030 ✓ Sundry# Operation: Drilling: X Workover: Explor.: Test: Initial: Weekly: Bi-Weekly: Test Pressure(psi): Rams: Annular: 250/3500 Valves: MASP: 2616 MISC.INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. NA Well Sign NA Upper Kelly 0 NA Housekeeping NA Rig NA Lower Kelly 0 NA PTD On Location NA Hazard Sec. NA Ball Type 0 NA Standing Order Posted NA Misc. NA Inside BOP 0 NA FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 13-5/8" P Pit Level Indicators NA NA #1 Rams 1 2 7/8"x 5" NA Flow Indicator NA NA #2 Rams 1 Blind/Shear NA Meth Gas Detector NA NA #3 Rams 1 3-1/2"X 5-7/8" NA H2S Gas Detector NA NA #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln.Valves 1 3-1/8" NA Inside Reel valves 0 NA HCR Valves 2 3-1/8" NA Kill Line Valves 2 3-1/8", 2-1/16" NA Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure(psi) NA CHOKE MANIFOLD: Pressure After Closure(psi) NA Quantity Test Result 200 psi Attained(sec) NA No.Valves 0 NA Full Pressure Attained(sec) NA Manual Chokes 0 NA Blind Switch Covers: All stations Yes Hydraulic Chokes 0 NA Nitgn. Bottles#&psi(Avg.): NA CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 Test Time: 0.5 Hours Repair or replacement of equipment will be made within N/A days. Notify the AOGCC of repairs with written confirmation to:AOGCC.Inspectors@alaska.gov Re-test annular preventor only due to shut in and circulating gas cut mud through the mud gas seperator on full open Remarks: choke.Tested with 4"test jt. Last BOPE test was on 7-14-16 AOGCC Inspection 24 hr Notice Yes Date/Time 7/15/16 4:27pm Waived By Matt Herrera Test Start Date/Time: 7/16/2016 4:30 (date) (time) Witness Test Finish Date/Time: 7/16/2016 5:00 Form 10-424(Revised 11/2015) Annular Test State Form 7-16-2016.xlsx • • p T© 216,- 003 Loepp, Victoria T (DOA) From: Gorham, Bradley M <Bradley.Gorham@bp.com> Sent: Wednesday,July 06,2016 3:53 PM To: Loepp,Victoria T(DOA) Subject: E-mailing: L1-13_C106JUL2016 IBC-MSIP_SCH_Field Print.zip Attachments: L1-13_C1 06JUL2016IBC-MSIP_SCH Field Print.zip Follow Up Flag: Follow up Flag Status: Flagged Victoria, As promised,attached is the cement evaluation log that was run on the L1-13 well yesterday evening. If you have any further questions or comments don't hesitate to contact me. Thanks, Brad Brad Gorham BP Exploration (Alaska), Inc. Drilling Engineer W: (907)564-4649 C: (907)223-9529 Bradley.Gorham@bp.com 1 • I Loepp, Victoria T (DOA) From: Gorham, Bradley M <Bradley.Gorham@bp.com> Sent: Wednesday,July 06, 2016 7:32 AM To: Loepp,Victoria T(DOA) Subject: RE: L1-13 Data and FIT Waiver Request Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thank you for your help and timely response. I will be sure to forward the final log to you as soon as I receive it. Thanks, Brad Original Message----- From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday,July 06,2016 3:54 AM To:Gorham, Bradley M Cc: Loepp,Victoria T(DOA) Subject: Re: L1-13 Data and FIT Waiver Request Bradley, Approval is granted to proceed with the 6-1/8" BHA. If severe or total losses are encountered while drilling out the 7" shoe,a waiver to the performance of the FIT is granted. Please forward the final log when it becomes available. 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W = mR I; U ; I is I. „ . el I I I III O M ! . . aJ 61 i 3 I $ ee e e s S e B s S v m ` L i S 4 Y e S i i 110 • • Loepp, Victoria T (DOA) From: Gorham, Bradley M <Bradley.Gorham@bp.com> Sent: Wednesday,July 06,2016 3:03 AM To: Loepp,Victoria T(DOA) Subject: L1-13 Data and FIT Waiver Request Attachments: L1-13 P272 Morning Report 7-3-16.pdf; 11-13 P272 Morning Report 7-2-16.pdf; L1-13 _IBC_eval final BG.ppt Follow Up Flag: Follow up Flag Status: Flagged Victoria, Please see attached for the following items: - PowerPoint Presentation highlighting IBC log findings and schematic - OpenWells Morning Report from 7-2-16—Initial 7"cement job - OpenWells Morning Report from 7-3-16—Describing the 7"squeeze job I know you requested a full log and we are currently working on that.SIB is having issues with their Software and the re- processing phase.They should have a final log to us sometime this morning and you will receive it as soon as we get a copy.The PowerPoint that is attached shows the key depths in which we have out competent cement isolating our DPZ's as well as a basic wellbore schematic. Please review the above attachments and let me know if we have you approval to proceed with our 6-1/8" BHA.We will be picking up the BHA and running in hole and then displacing from our 10.5 ppg fluid to the 8.6 ppg fluid.We will not drill out our remaining shoe track until we have your full approval. With that approval,as per our discussion earlier this afternoon,we would also like to request a deviation from performing the FIT once we drill out of the 7" liner shoe. During our initial cement job we pumped a total of 85 bbls and were able to lift 3 bbls.While prepping to run our IBC cement evaluation log we drilled out our shoe track to—12'above the float collar.When drilling we found very competent cement in our shoe track leading us to believe we have a good shoe. Considering we were on severe losses right at TD, 13,990' MD,we believe it is highly likely to encounter severe losses upon drilling out of our 7"shoe.We had a very similar scenario last summer on the 11-23 well in which we drilled 11'out of the shoe and went on total losses. If we drill out of our 7"shoe and encounter severe or total losses,do we have AOGCC approval to waive the need to perform a FIT test? Please let me know if you require any other information or 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 1 • • Loepp, Victoria T (DOA) From: Gorham, Bradley M <Bradley.Gorham@bp.com> Sent: Tuesday,July 05,2016 8:56 PM To: Loepp,Victoria T(DOA) Subject L1-13 Update Follow Up Flag: Follow up Flag Status: Flagged Victoria, Just wanted to give you an update on where we are at.They are currently re-logging a couple sections to help with the normalization of the logs. I am told we should have the final logs within 3 hours. I will send you the log as soon as I receive it a long with the other documents you requested. Please let me know if you need me to call you once the logs are sent so we can get approval to proceed prior to picking up the 6-1/8" BHA. Thanks for your time and consideration. Brad Brad Gorham BP Exploration(Alaska), Inc. Drilling Engineer W: (907)564-4649 C: (907)223-9529 Bradley.Gorham@bp.com 1 • Loepp, Victoria T (DOA) From: Gorham, Bradley M <Bradley.Gorham@bp.com> Sent: Monday,July 04, 2016 12:23 PM To: Loepp,Victoria T(DOA) Subject: Re: L1-13 Update Follow Up Flag: Follow up Flag Status: Flagged Victoria, Yesterday we pumped 195 bbls of cement down the backside of our 7" liner.All indications were that we injected the cement into the Lisburne.We just tested our LTP and achieved a passing pressure test.We are currently drilling out the bridge plug and will be performing our 7" liner integrity pressure test. Upon the completion of that test we will be rigging up to run a circumferential log to evaluate the quality of our cement. Once we have evaluated the logs we will contact you to discuss our path forward. Let me know if you have any questions or concerns. Thanks, Brad Gorham 907-223-9529 On Jul 2,2016,at 5:37 PM, Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>wrote: Thanx for the update. Let me know what your remedial plans when you have developed them. Thanx, Victoria Sent from my iPhone On Jul 2, 2016,at 5:02 PM,Gorham, Bradley M<Bradley.Gorham@bp.com>wrote: Victoria, Just wanted to touch base with you regarding the status of 11-13. Last night we performed our cement job and experienced severe losses.As you can imagine,we did not meet our zonal isolation requirements and we are now planning remedial cement work.As this pertains to our potential deviation from performing our 6-1/8"open hole FIT test,we will need to re-convene once we have completed our remedial work and evaluate our options. If you have any further questions or concerns don't hesitate to call me. Thanks, Brad 1 • • Brad Gorham BP Exploration (Alaska), Inc. Drilling Engineer W: (907)564-4649 C: (907)223-9529 Bradley.Gorham@bp.com 2 • . Loepp, Victoria T (DOA) From: Gorham, Bradley M <Bradley.Gorham@bp.com> Sent: Tuesday,June 21,2016 6:58 PM To: Loepp,Victoria T(DOA) Cc: Lastufka,Joseph N Subject: Re: L1-13 Cement Pressure Testing Procedure Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thank you for the approval. I called and left a message on your phone, but I wanted to double check to see if you wanted a representative to witness our balanced cement plug operation?We are planning to conduct this operation this evening. Feel free to give me a call when you get a chance. Thanks, Brad Gorham 907-223-9529 On Jun 20,2016,at 4:08 PM, Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>wrote: Brad, Verbal approval is granted to proceed with the plugback. Please route a sundry as soon as possible. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppaalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793- 1247 or Victoria.Loeoa@alaska.gov From: Lastufka,Joseph N [mailto:Joseph.Lastufka@bp.com] Sent: Monday,June 20, 2016 4:04 PM To: Loepp, Victoria T(DOA) 1 r i Cc: Gorham, Bradley M Subject: FW: L1-13 Cement Pressure Testing Procedure Victoria, Please see the program and let Brad know if you need additional information as I'll be out the rest of the day. Thanks! Joe From: Gorham, Bradley M Sent: Monday,June 20, 2016 4:03 PM To: Lastufka,Joseph N Subject: L1-13 Cement Pressure Testing Procedure Joe, Please see the procedure below for placing and testing our cement plug: 1. Set the bridge plug at 12,124' MD (75' inside the 9-5/8"casing shoe). 2. Move down to set depth and set the bridge plug as per the approved Halliburton procedure.Verify plug set by confirming there are no longer static losses. 3. Circulate 2 x BU. 4. Sting into bridge plug as per approved Halliburton procedure in preparation to squeeze -35 bbls of 15.8 ppg Class G cement through the plug as per approved SLB CADE. 5. Un-sting from the bridge plug and circulate the wellbore clean. 6. Place -25 bbls (350' MD) 15.8 pp class G cement balanced plug on top of bridge plug as per approved SLB CADE. 7. POOH and lay down Mechanical setting tool. 8. Wait until balanced cement plug reaches 500 psi compressive strength. At that point we will pressure test the cement plug/mechanical plug to 3,500 psi. Hydrostatic pressure at the plug depth of 12,124' MD (-7,920' TVD)with a full column of 10.5 ppg mud is equal to 4,324 psi. The combination of the hydrostatic column in conjunction with the pressure test to 3,500 psi test gives us an EMW of 19 ppg. The most likely fracture pressure in the HRZ, where the 9-5/8" casing is set, is 14.3 ppg EMW. If you have any questions or comments don't hesitate to ask. Thanks, Brad Brad Gorham BP Exploration(Alaska), Inc. Drilling Engineer W: (907)564-4649 C: (907)223-9529 Bradley.Gorham@bp.com 2 • • Loepp, Victoria T (DOA) From: Gorham, Bradley M <Bradley.Gorham@bp.com> Sent: Tuesday,June 21, 2016 3:53 PM To: Loepp,Victoria T(DOA) Cc: Allen, Kenneth W Subject: L1-13 Summary of Events and Proposed Plan Forward Attachments: 3128 001.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, Please see the summary of events and the proposed plan forward for L1-13. Summary of Events: 1. Set the bridge plug at 12,109' MD(90' inside the 9-5/8"casing shoe). 2. Successfully pumped and squeezed 43.5 bbls of cement below the bridge plug. (41.5 bbls planned volume, 2 bbls excess that were planned to be circulated out above the bridge plug) 3. At this point,the rig attempted un-sting from the bridge plug,and believed there were in fact un-stung 4. Pumped 42 bbls of mud away while still being stung into the bridge plug 5. Un-stung and circulated the wellbore clean. 6. Stung back into bridge plug to establish injection. Well pressured up to ^'1,350 psi and held solid for—45 min. That pressure is equivalent to 13.7 ppg while the most likely frac gradient in the Ivishak and Sag is 13.2 ppg. Proposed Plan Forward. 1. Place"25 bbls(350' MD) 15.8 pp class G cement balanced plug on top of bridge plug as per approved SLB CADE. 2. POOH and lay down Mechanical setting tool. 3. Wait until balanced cement plug reaches 500 psi compressive strength. At that point we will pressure test the cement plug/mechanical plug to 3,500 psi. Hydrostatic pressure at the plug depth of 12,109' MD (-7,900' ND) with a full column of 10.5 ppg mud is equal to 4,313 psi. The combination of the hydrostatic column in conjunction with the pressure test to 3,500 psi test gives us an EMW of 19 ppg.The most likely fracture pressure in the HRZ,where the 9-5/8"casing is set, is 14.3 ppg EMW. 4. Set bridge plug at 10,700' MD, set WS and sidetrack the well. We will submit a revised PTD once we confirm our new well plan. Please let us know if you have any questions or concerns. Thanks, Brad Brad Gorham BP Exploration (Alaska), Inc. Drilling Engineer W: (907)564-4649 C: (907)223-9529 • • Loepp, Victoria T (DOA) From: Lastufka,Joseph N <Joseph.Lastufka@bp.com> Sent: Monday,June 20, 2016 5:06 PM To: Loepp,Victoria T(DOA) Subject: RE: L1-13 Cement Pressure Testing Procedure Follow Up Flag: Follow up Flag Status: Flagged No problem.We'll send the sundry tomorrow. Are we still required to submit a revised PTD or can we include it all under the"Change of Approved Program" 10-403? Thanks, Joe From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday,June 20, 2016 4:08 PM To: Gorham, Bradley M Cc: Lastufka,Joseph N Subject: RE: L1-13 Cement Pressure Testing Procedure Brad, Verbal approval is granted to proceed with the plugback. Please route a sundry as soon as possible. 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(a�alaska.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.Loeoo@alaska.gov From: Lastufka,Joseph N [mailto:Joseph.Lastufka@bp.com] Sent: Monday, June 20, 2016 4:04 PM To: Loepp, Victoria T(DOA) Cc: Gorham, Bradley M Subject: FW: L1-13 Cement Pressure Testing Procedure 1 • • Victoria, Please see the program and let Brad know if you need additional information as I'll be out the rest of the day. Thanks! Joe From: Gorham, Bradley M Sent: Monday, June 20, 2016 4:03 PM To: Lastufka,Joseph N Subject: L1-13 Cement Pressure Testing Procedure Joe, Please see the procedure below for placing and testing our cement plug: 1. Set the bridge plug at 12,124' MD(75' inside the 9-5/8"casing shoe). 2. Move down to set depth and set the bridge plug as per the approved Halliburton procedure. Verify plug set by confirming there are no longer static losses. 3. Circulate 2 x BU. 4. Sting into bridge plug as per approved Halliburton procedure in preparation to squeeze-35 bbls of 15.8 ppg Class G cement through the plug as per approved SLB CADE. 5. Un-sting from the bridge plug and circulate the wellbore clean. 6. Place -25 bbls (350' MD) 15.8 pp class G cement balanced plug on top of bridge plug as per approved SLB CADE. 7. POOH and lay down Mechanical setting tool. 8. Wait until balanced cement plug reaches 500 psi compressive strength. At that point we will pressure test the cement plug/mechanical plug to 3,500 psi. Hydrostatic pressure at the plug depth of 12,124' MD (-7,920' TVD) with a full column of 10.5 ppg mud is equal to 4,324 psi. The combination of the hydrostatic column in conjunction with the pressure test to 3,500 psi test gives us an EMW of 19 ppg. The most likely fracture pressure in the HRZ, where the 9-5/8"casing is set, is 14.3 ppg EMW. If you have any questions or comments don't hesitate to ask. Thanks, Brad Brad Gorham BP Exploration(Alaska), Inc. Drilling Engineer W: (907)564-4649 C: (907)223-9529 Bradley.Gorham@bp.com 2 • • Loepp. Victoria T (DOA) From: Thompson,Jacob <Jacob.Thompson@BP.com> Sent: Friday,June 03, 2016 9:31 AM To: Loepp,Victoria T(DOA);Allen, Kenneth W Subject: RE: PTD#:216-003 PBU L1-13 Change in BOP Stack Follow Up Flag: Follow up Flag Status: Flagged Victoria, As per our phone conversation BP is requesting to change the upper rams to 9-5/8" fixed bore rams for drilling the 12- 1/4" Intermediate hole to increase efficiency for running the 9-5/8" casing. Below I've edited the operational summary from the permit to drill to illustrate the requested changes. Please note the we have currently completed drilling the surface hole and running and cementing the surface casing(Steps 1-3. c. are complete).The requested change is the highlighted section at Step 3. F.The change to step 3. F. will remove the need to perform step 5.A. If you have any question please feel free to give me a call Thank you, Rig Operations: 1r,_MIRI r-2 A - „ • ■ r - • ■ 1 POOH and L/D BHA. connection.- ■ • .. .. d. R/D cementing equipment and flush and R/D diverter system. . e. N/U FMC 13-5/8"5M New Standard Big Bore wellhead system and test as required. 1 • • f. N/U & pressure test 13-5/8" 5M BOPE (Configured from top to bottom: 13%" Annular Preventer, 2 7/8" x 5 1/2" VBR 9-5/8" Fixed Rams in the upper cavity, Blind/Shear Rams, mud cross and 2-7/8" x 5-1/2" VBR in the lower cavity) >Test rams to 250 psi/4,000 psi with 4"and 5"test joints >Test annular to 250 psi/3,500 psi with 4"test joint 2 S • 4. Drill 12-1/4" Intermediate#1 Hole Section: a. Pick up 5,000'of 4"drill pipe and enough 5"drill pipe to drill the 12-1/4" 1st intermediate hole. b. Test 13-3/8" casing to 250 psi low / 3,500 psi high for 5 minutes low / 30 minutes high after cement reaches a minimum of 500 psi compressive strength. c. Make-up 12-1/4"drilling assembly with MWD/GR/RES/GAB tool string. d. RIH &tag float collar or TOC. Drill out all but 10ft of shoe track and then displace to 9.6 ppg LSND mud. Drill out remainder of shoe track. e. Drill at least 20 ft but no more than 50 ft of new formation for the LOT and CBU. f. Pull inside casing and perform the LOT. g. Drill ahead following the directional plan. Ensure mud weight is increased to 10.5 ppg at least 200' above the CM3. h. Continue drilling to the 9-%" intermediate casing point at 12,223' MD, which is predicted TSGR. CBU as needed for cutting samples to properly identify Sag River boundary. i. At casing point, circulate hole clean &condition the mud as needed. Perform wiper trip to previous casing shoe. j. Run back to bottom, circulate hole clean and condition mud for running 9-5/8" casing. Note cuttings returns and fill on bottom. k. POOH and lay down the BHA. If backreaming is necessary, trip back to TD and POH on elevators for final trip out. 5. Run&Cement 9-5/8" Intermediate/Production Casing: a. = _ ••_ - _ • - - -= b. Run 9-5/8", 47 ppf, L-80, TCII intermediate/production casing. c. Stage pumps up and condition mud for cement job. Cement with 15.8 ppg Class G Tail and 11.5 ppg LiteCrete cement to 6,163' MD(650' TVD above UG4). d. Pressure test casing to 250 psi low/4,000 psi high for 5 minutes low/30 minutes high on plug bump. e. Install casing pack-off and test to 250 psi low / 5,000 psi high for 30 minutes per FMC representative procedures/instructions. f. Confirm that OA is open by pumping small volumes of mud down annulus as soon as possible. g. R/D cementing equipment and flush stack. h. Change rams upper rams to 2-7/8"x 5-1/2"VBR in upper cavity. i. Freeze-protect the 13-3/8"x 9-5/8"annulus, once the cement has reached 500 psi compressive strength. Jacob Thompson 907-854-4377 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, April 05, 2016 10:05 AM To: Jakabosky,Troy Subject: PTD #: 216-003 PBU L1-13 Change in BOP Stack Troy, This change to the BOP stack is approved. Please include this approval with the PTD. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave 3 Anchorage,AK 99501 Work: (907)793-1247 VictorialoeppO.alaska.qov 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-U47 or Victoria.Loerp@alaska.gov From: Jakabosky,Troy [mailto:Troy.Jakabosky(abp.com] Sent:Tuesday,April 05, 2016 9:55 AM To: Loepp,Victoria T(DOA) Subject: RE: PTD #: 216-003 L1-13 Victoria— I sent this change to the PTD to you a couple of weeks ago. I just wanted to make sure you didn't need anything additional? Thanks,Troy From: Jakabosky,Troy Sent: Monday, March 21, 2016 1:38 PM To: victoria.loepp()alaska.gov Subject: PTD #: 216-003 L1-13 Victoria, There has been a change in the BOP stack and ram configuration for well L1-13. I have attached the schematic of the BOP stack that will be used for this well,and included the modified operational summaries below(changes in RED). PTD#: 216-003 Thanks,Troy PTD Drilling Rig Operations: 1. MIRU Parker 272: a. Survey conductor with rig over it to ensure rig is centered over the hole. b. RU diverter system and test. Notify AOGCC 24 hours in advance of test. 2. Drill 16"Surface Hole Section: 4 • • a. Take on 8.7 ppg MAXDRIL-N. b. PU enough 5"drill pipe to drill the surface hole. c. Make-up 16"directional drilling assembly with MWD/GR/UBHO tool string. d. Clean out 20" conductor, spud well and directionally drill surface hole to the base of the permafrost. (Gyro until clean MWD surveys). e. At the base of the permafrost circulate hole clean and condition mud as required. f. Perform wiper trip to the top of the HWDP. g. Drill ahead per directional plan. Ensure minimum mud weight is increased to 9.0 ppg at least 200' before reaching the SV6. h. Drill remainder of surface hole to planned casing point at the base of the SV4. i. Circulate hole clean and condition mud as required. j. Perform wiper trip to base of permafrost. k. Trip back to TD, circulate hole clean and condition mud for running 13-3/8"casing. I. POOH and LD BHA. 3. Run&Cement 13-3/8"Surface Casing: a. Run 13-3/8", 68 ppf, L-80, BTC surface casing with Volant tool. Install Torque rings in each connection. b. Cement with 15.8 ppg Class G tail cement and non-freezing cement to surface. c. Pressure test casing to 3,500 psi for 5 minutes on plug bump. d. RD cementing equipment and flush and RD diverter system. e. NU FMC 13-5/8"5M New Standard Big Bore wellhead system and test as required. f. NU and pressure test 13-5/8" 5M BOPE. (Configured from top to bottom: 13-5/8" annular preventer, 2-7/8" x 5" VBRs in the upper cavity, blind/shear rams, mud cross and 2-7/8"x 5"VBRs in the lower cavity). • Test rams to 250 psi/4,000 psi with 4"and 5"test joints. • Test annular to 250 psi/3,500 psi with 4"test joint. 4. Drill 12-1/4" Intermediate#1 Hole Section: a. PU enough 5"drill pipe to drill the 12-1/4"first intermediate hole. b. Test 13-3/8" casing to 250 psi for 5 minutes / 3,500 psi for 30 minutes after cement reaches a minimum of 500 psi compressive strength. c. MU 12-1/4"drilling assembly with MWD/GR/RES tool string. d. RIH and tag float collar or TOC. Drill out all but 10 ft of shoe track and then displace to 9.6 ppg LSND mud. Drill out remainder of shoe track. 5 • i e. Drill at least 20' but no more than 50'of new formation and CBU. f. Pull inside casing and perform LOT. g. Drill ahead per directional plan. Ensure mud weight is increased to a minimum of 10.5 ppg at least 200' above the CM3. h. Continue drilling to the 9-5/8" intermediate 1 casing point which is at HRZ. CBU as needed for cutting samples to properly identify HRZ. i. At casing point, circulate hole clean and condition mud as needed. j. Perform wiper trip, bringing ghost reamer up to the previous casing shoe. k. Run back to bottom, circulate hole clean and condition mud for running 9-5/8"casing. I. POOH and LD BHA. If backreaming is necessary, trip back to TD and POH on elevators for final trip out. 5. Run and Cement 9-5/8" Intermediate Casing: a. Change rams to 9-5/8" FBRs in upper cavity. Test to 250 psi/4,000 psi. b. Run 9-5/8",47 ppf, L-80, VT intermediate casing. c. Stage pumps up and condition mud for cement job. Cement with 15.8 ppg Class G Tail and 11.5 ppg lead cement. d. Immediately following the plug bump, initiate injection down the OA by pumping 5 bbls of drilling fluid to ensure annulus remains open for freeze protection. Continue to pump 3 - 5 bbls of drilling fluid down the OA every hour until the lead cement reaches 500 psi compressive strength. e. Install casing pack-off and test per FMC representative's procedures/instructions. f. RD cementing equipment and flush stack. g. Change rams to 2-7/8" x 5"VBR in upper cavity.Test to 250 psi/4,000 psi. h. Freeze-protect the 13-3/8"x 9-5/8"annulus once the cement has reached 500 psi compressive strength. 6. Drill 8-1/2" Intermediate#2 Hole Section: a. PU additional 5"drill pipe as required to drill the 8-1/2"second intermediate hole. b. MU 8-1/2"drilling assembly with MWD/GR/RES/GAB tool string. c. Once the lead cement has reached 500 psi compressive strength, pressure test 9-5/8 casing to 4,000 psi for 30 minutes. d. RIH and tag float collar or TOC. Drill out all but 10 ft of shoe track, and then displace to 10.3— 10.5 ppg LSND mud. Drill out remainder of shoe track. e. Drill at least 20' but no more than 50'of new formation and CBU. f. Pull inside casing and perform the FIT. g. Continue drilling to the intermediate 2 casing point at TLSB. CBU as needed for cutting samples to properly identify Lisburne boundary. h. At casing point, circulate hole clean and condition the mud as needed. 6 • i. Perform wiper trip to the previous casing shoe. j. Run back to bottom, circulate hole clean and condition mud for running the 7" liner. k. POOH and lay down the BHA. If backreaming is necessary, trip back to TD and POH on elevators on the final trip. 7. Run and Cement 7" Intermediate/Production Liner: a. Change rams to 7" FBRs rams in the upper cavity. Test to 250 psi/4,000 psi. b. Run 7", 26 ppf, L-80, VAM Top HC intermediate liner with 150' lap into the 9-5/8"casing shoe. c. Stage pumps up and condition mud for cement job. Cement to the TOL with 15.8 ppg Class G cement. d. Set the liner hanger and liner top packer. LD Liner running tool. e. Change rams to 2-7/8"x 5"VBRs in upper cavity. Test to 250 psi/4,000 psi. 8. Drill 6-1/8" Production Hole Section: a. PU enough 4"and 5"drill pipe to drill the 6-1/8" production hole. b. Test 7" liner to 250 psi for 5 minutes 14,000 psi for 30 minutes after cement reaches a minimum of 500 psi compressive strength. c. Make-up 6-1/8"drilling assembly with MWD/GR/RES/NEU/DEN/PEF/Image/Neutron Caliper. d. RIH and tag landing collar or TOC. Displace to 8.5 ppg Flo-Pro SF fluid before drilling the shoe track. e. Perform a 30 min no-flow test with 8.5 ppg fluid. f. Drill at least 20' but no more than 50'of new formation and CBU. g. Pull inside casing and perform the FIT. h. Drill ahead to TD per directional plan and rig site geologist as bit performance allows. POOH to replace bit if required. i. At casing point, circulate hole clean and condition the mud as needed. j. Perform wiper trip to the previous casing shoe. k. Run back to bottom, circulate hole clean and condition mud for running casing. I. POOH, LD excess 4"drill pipe and BHA. 9. Run and Cement 4-1/2" Production Liner: a. Run 4-1/2", 13.5 ppf, 13Cr-85, Hydril 521 production liner with 150 ft lap into the 7" liner shoe. b. Drop toe circulating valve (TCV) ball and set the liner hanger and liner top packer. Displace well to clean seawater above the liner top. c. Pressure test 9-5/8"casing x 7" liner x 4-1/2" liner to 4,000 psi for 30 minutes. d. POOH, LD liner running tool. 7 • • 10. Run 4-112" Completion: a. RU and run a 4-1/2", 12.6 ppf, 13Cr-85, VamTop completion. Space out and land the tubing with the tubing tail inserted into the liner tie back sleeve. Run in lock down screws. b. Displace well to seawater completion fluid through the IA. c. Drop ball and rod with rollers to RHC plug. d. Test tubing to 250 psi for 5 minutes and then set production packer with 4,000 psi. e. Hold 4,000 psi for 30 minutes for tubing pressure test. f. Bleed tubing pressure down to below 2,000 psi. g. Pressure test IA to 250 psi for 5 minutes/4,000 psi for 30 minutes. Bleed down Tubing to 0 psi and shear DCR-1. Pump both ways to confirm shear. h. Pump enough diesel freeze protect fluid into the IA to protect to 2,200 ft TVD on both tubing and IA. i. RU jumper line between tubing and IA to allow diesel to U-tube into tubing. 11. Nipple Down BOPE/Nipple Up Production Tree and Freeze Protect: a. Install TWC and test. Nipple down BOPE. b. N/U the tubing head adapter flange and dry hole tree. c. Test tubing head adapter flange and tree to 250 psi for 5 minutes/5,000 psi d. Install VR plugs in the annulus valves as needed and secure the well. Ensure that both IA and OA are protected by two barriers. 12. Release Rig: a. Rig down and move off location. « File: Cameron Stack(2).pdf» Troy Jakabosky Drilling Engineer bp 900E. Benson Blvd. Cube 748C Anchorage,AK 99508 Office 907.564.4868 Cell 907.632.2609 8 y OF ritk, • • ‘,$)\ \\W/7, A THE STATE Alaska Oil and Gas - tit o f LeesKA Conservation Commission • - ,# 333 West Seventh Avenue " C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �` Main: 907.279.1433 ; ®"ALA Y'P Fax: 907.276.7542 www.aogcc.alaska.gov Ken Allen Drilling Engineer BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU L1-13 BP Exploration(Alaska), Inc. Permit to Drill Number: 216-003 (revised) Surface Location: 2541' FSL, 2801' FEL, SEC. 01, T11N, R14E, UM Bottomhole Location: 4821' FNL, 1797' FEL, SEC. 10, T11N, R14E, UM Dear Mr. Allen: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit supersedes and replaces the permit previously issued for this well dated January 28, 2016. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, „_Daniel T. Seamount, Jr. Commissioner n� DATED this 22 day of June, 2016. STATE OF ALASKA OASKA OIL AND GAS CONSERVATION COMMIS. PERMIT TO DRILL 20 AAC 25.005 REVISED:Bottom Hole Location Changed by more than 500' • 1 a. Type of Work: 1b. Proposed Well Class: Exploratory-Gas 0 Service-WAG 0 Service-Disp 0 1 c.Specify if well is proposed for: Drill RI • Lateral 0 Stratigraphic Test 0 Development-Oil EI 'Service-Winj 0 Single Zone © Coalbed Gas 0 Gas Hydrates 0 Redrill ❑ Reentry 0 Exploratory-Oil 0 Development-Gas 0 Service-Supply 0 Multiple Zone 0 Geothermal 0 Shale Gas 0 2. Operator Name: 5. Bond Blanket RI Single Well ❑ 11. Well Name and Number: BP Exploration(Alaska),Inc Bond No. 29S105380 . PBU L1-13 • 3 Address: 6. Proposed Depth: 12. Field/Pool(s): P.O.Box 196612 Anchorage,AK 99519-6612 MD: 17430' • ND: 8920' • PRUDHOE BAY,LISBURNE OIL 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): ' ADL 028302&028303• Surface: 2541'FSL,2801'FEL,Sec.01,T11N,R14E,UM • 8. Land Use Permit: 13. Approximate spud date: 1627'FNL,723'FEL,Sec.10,T11N,R14E,UM 84-62 May 28,2016 Top of Productive Horizon: Total Depth: 4821'FNL,1797'FEL,Sec.10,T11N,R14E,UM 9. Acres in Property: 2560 14.Distance to Nearest Property: 16500 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above MSL: 61.1-feet 15. Distance to Nearest Well Open to Surface:x- 688601 • y- 5974894 ' Zone - ASP 4 GL Elevation above MSL: 12.9.feet 3 00me Pool: 3400 16. Deviated wells: Kickoff Depth: 500 feet 17. Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 103 degrees Downhole: 3473 ' Surface: 2616 ' 18. Casing Program: Specifications Top-Setting Depth-Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 42 20" 129# A-53 80' Surface Surface 80' 80' 260 sx Arctic Set(Agorox.) 16" 13-3/8" 68# L-80 BTC 5231' Surface Surface 5231' 3717' 2675 sx DeepCreete,312 sx Class' 12-1/4" 9-5/8" 47# L-80 VamTop 12049' Surface Surface 12049' 7981' 1424 sx LiteCrete,218 sx Class'G' 8-1/2" 7" 26# L-80 VamTopHC 3351' 10600' 6562' 13951' 8833' 365 sx Class'G' 6-1/8" 4-1/2" 12.6# 13Cr85 Hydril 521 3629' 13801' 8710' 17430' 8920' Uncemented Sliding Sleeves w/Swell Packers 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural I V D Surface Intermediate JUN 2 2 2016 Production Liner AOGCC Pprfnratinn Ilprth MIl(ft)• I Pprfnratinn rlerth TVf(ft)• 20.Attachments Property Plat 0 BOP Sketch 0 Drilling Programa Time v.Depth Plot 0 Shallow Hazard Analysis 0 Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program El 20 AAC 25.050 requirements II 21.Verbal Approval: Commission Representative: Date 22.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated Contact Gorham,Bradley M from without prior written approval. Email Bradley.Gorham@bp.com Printed Name Ken Allen Title Drilling Supervisor Signature „% Com.... Phone +1 907 564 4366 Date 6/' V/ 6, Commission Use Only Permit to Drill Permit Approval See cover letter for other Number: 216-003 REVISED API Number: 50-029-23563-00-00 Date: 1—21r^.Z.o(C.p requirements: Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed metthhane,gas hydrates,or gas contained in shales: El Other: 0,0E1 133"%t->S't 'E0 Ofd PS% Samples req'd: Yes 0 No lye Mud log req'd: Yes 0 No [d 'Sc1\41.3...1%.14:1/4.147., aa ¢ TZ. V jp 2SOJ pQ/si H2S measures Yes No 0 Directional svy req'd: Yes V No 0 Spacing exception req'd: Yes 0 NoC_l �Lc�,,� �,�� wiA�V� G X000 p g p q� � Inclination-only svy req'd: Yes 0 No Dcit•t - IDis PGS- 20 Nct.1 .03 (i) Post initial injection MIT req'd: Yes 0 No ❑ V.)nowrace. Four ," 1. aea, eft wuu_ isE cevm-vst'T�c'O AFTen. ,n Lwect ceust' .3013 APPROVED BY /‘ 2_A_Ii Approved by: COMMISSIONER THE COMMISSION Date: J �c ORIGINAL Form 10-401 Revised 11/2015 This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit Form and Attachments in Duplicate µ'ml, 6IZ?147 .. _._../.36-aZ bp • • To: Alaska Oil & Gas Conservation Commission From: Troy Jakabosky, ODE Brad Gorham ODE Date: June 22, 2016 Re: L1-13 Permit to Drill i The L1-13 well is scheduled to be drilled by Parker 272 in March 2016. This grassroots well is a producer targeting the Lisburne formation. The planned well is a four string design using a 13-3/8" surface casing, 9-5/8"first intermediate casing, 7" second intermediate liner, and 4-1/2" production liner. The surface casing will be set in the SV4 shale. The first intermediate casing will be set at the top of the HRZ. The second intermediate liner will be set at the top Lisburne, and the production liner will be set will be set at the top Lisburne with the toe of the well extending into the Kavik. The production interval will be completed with a cementless liner, and the well will be acid stimulated and possible fracture stimulated post rig. The maximum anticipated surface pressure from the Lisburne with a full column of gas from TD to surface is 2,481 psi (assumes 7.4 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 will be tested to 4,000 psi and the annular will be tested to 3,500 psi. A detailed operations summary is included with the permit application. In addition to a planned well summary, a directional plan and proposed completion diagram is attached to the permit application. If there are any questions concerning information on L1-13, please do not hesitate - to use the contact information below. Troy Jakabosky Office: (907) 564 4868 Cell: (907) 632 2609 Email: troy.jakabosk ••b• corn Brad Gorham Office: (907) 564-4649 Cell: (907) 223-9529 Email: Bradley.Gorham@bp.com Attachments: L1-13 Wellbore Schematic Directional Plan L1-13 PTD Page 1 6/22/2016 • • Planned Well Summary WWell L1-13 Type Producer _ Object ve et Lisburne Current Status Grass Roots Well Estimated Start Date: 3/25/2016 Time to Complete: 50.2 Days Surface Northing Easting Offsets TRS Location 5,974,893.89 - 688,601.06 2541' FSL/2801.1' FEL - 11N 14E Sec 1 Northing Easting TVDss Offsets TRS T1 5,971,053.2 681,074.6 8,712 1112' FNL/5143' FEL 11N 14E Sec 11 TLSB 5,970,518 680,229 8,775 1627.11' FNL/722.79' FEL 11N 14E Sec 10 TD 5,967466-9 679,776 8800 4366.6' FNL/ 1244.9' FEL 11N 14E Sec 10 BHL 5,967,300 679,237 8,860 4820.59' FNL/ 1796.58' FEL Planned KOP: 500' MD Planned TD: 16,604' MD /8,800' TVD-s 17,430' MD/ 8,860' TVDss . Rig: Parker 272 GL-RT: 47.1 RTE (ref MSL): 61.1 Directional —Baku-wpO2 Baker wp05C KOP: 500' MD -60° in the first intermediate section Maximum Hole Angle: -40.0° -63.5° in the second intermediate section -102.7° in the production section Close Approach Wells: None Survey Program: Surface to 970' MD = GYRO 970' MD to TD = MWD+IFR+MS Nearest Property Line: -16,500' Nearest Well within Pool: -3,400' L1-13 PTD Page 2 6/22/2016 • i Formation Tops & Pore Pressure Estimate (SOR) Estimated Minimum Most Likely Fluid Formation Formation Top Pore Pressure Pore Pressure Type (TVDss) (EMW ppg) (EMW ppg) (for sands) G1 505 8.4 8.4 N/A BPF 1,812 8.4 8.4 N/A SV6 2,425 8.4 8.6 water SV5 3,107 8.4 8.6 water SV4 3,358 8.4 8.6 water SV3 3,796 8.4 8.4 water SV2 3,953 8.4 8.4 water SV1 4,325 8.4 8.4 water UG4 4,772 8.4 9.3 water UG4A 4,802 8.4 9.3 water UG3 5,005 8.4 9.3 water UG1 5,435 8.4 9.3 water UG_MA 5,925 8.4 9.3 water UG_MB1 5,980 8.4 9.3 water UG_MB2 6,031 8.4 9.3 water UG_MC 6,096 8.4 9.3 water WS2 6,066 8.5 9.3 N/A WS1 6,252 8.5 9.3 N/A CM3 6,488 9.8 10.2 possible hydrocarbons CM2 6,904 9.8 10.2 possible hydrocarbons CM1 7,458 9.8 10.2 possible hydrocarbons THRZ 7,789 9.6 10.3 N/A Possible PUT 7,970 7.8 8.3 N/A LCU 7,980 9.6 9.9 N/A TKNG 7,980 9.6 9.9 N/A TSGR 8,065 7.8 8.2 gas TSHU 8,115 7.8 8.1 gas TSAD 8,165 7.1 8.1 gas TCGL 8,265 7.1 8.0 gas BCGL 8,325 7.1 8.0 gas TZ2B 8,359 7.1 8.0 gas TZ2A 8,461 7.1 7.9 gas TZ1 B 8,526 7.1 7.8 gas TDF 8,563 7.1 7.8 gas BSAD/TKVK 8,596 9.8 9.9 N/A KAVIK 8,596 9.8 9.9 N/A TLSB 8712 5.5 7.4 oil L1-13 PTD Page 3 6/22/2016 • • Casing/Tubing Program Hole Liner/ Wt/Ft Grade Conn Length Top Bottom Size Tbg O.D. MD/TVDss MD/TVDss 42" 20" x 34" 129# A-53 - 80' Surface 94' /80' 16" 13-3/8" 68# L-80 BTC 5,231' Surface 5,231' / 3,656' 12-1/4" 9-5/8" 47# L-80 VamTop 12,049' Surface 12,049' /7,920' 1-14(49 -784 1 a(49 ? Qo' 8-1/2" 7" 26# L-80 VamTop HC 106' (150' lap) 13,005'/8,717' 351' 10,600' /6,501 13,951'/8,772' 3 769' 12,845'/8,594' 16,605/8,800' 6-1/8" 4 '/" 12.6# 13Cr-85 Hydril 521 3 629 (150' lap) 17,430' /8,860' I 13,801' /8,649' 12,850' 12,850'/8,597' Tubing 4 1/" 12.6# 13Cr-85 VamTop 13,806' Surface (-'5' into liner TBS) 13,806'/8,652' Mud Program Surface Mud Properties: MMO 16" hole section Depth Interval Density PV YP API FL LSR-YP pH (ppg) (cp) (Ib/100ft2) (2x3-6)rpm Surface - 5,231' MD 8.7—9.4 6-20 35-80 <15 25-60 10 - 11 Intermediate 1 Mud Properties: LSND 12-1/4" hole section Depth Interval Density P ( YP API FL HTHP FL MBT pH (cp) Ib/100ft2) 5,231' MD— 10,187' MD 9.6— 10.0 10-15 20-30 <8 NA <20 8.5 - 9.5 10,187' MD— 11,698' MD': 10.4— 11.0. 10-15 20-30 <8 NA <20 8.5 - 9.5 11,698' MD— 12,049' MD 10.4— 11.0 10-15 20-30 <5 <10 <20 8.5 - 9.5 Intermediate 2 Mud Properties: LSND 8-1/2" hole section Depth Interval Density PV YP API FL HTHP FL MBT pH (ppg) (cp) (Ib/100ft2) ,,,,L.: , iViL. "v,bvv IVi..... 10.2— 10.7 10-15 18-25 <5 <10 <20 8.5—9.5 10,750' MD— 13,951' MD Production Mud Properties: Water Based Polymer Fluid (FloPro) 6-1/8" hole section Depth Interval Density PV YP API FL HTHP FL MBT pH (ppg) (cp) (Ib/100ft2) TD 8.5-9.0 <8 12-20 <12 NA <4 8.5-9.5 13,951' MD Logging Program 16" Surface: Drilling: Dir/GR Open Hole: None Cased Hole: None 12-1/4" Intermediate 1: Sample Catchers—as required by Geology Drilling: Dir/GR/Res Open Hole: None L1-13 PTD Page 4 6/22/2016 • • Cased Hole: None 8-1/2" Intermediate 2: Sample Catchers-as required by Geology Drilling: DIR/GR/GR at bit/Res Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers-as required by Geology Drilling: GR/Res/Neu/Den/Pef/Image/Neutron Caliper Open Hole: None Cased Hole: None Cement Program Casing Size 13-3/8"68#, L-80 BTC,Surface Casing Lead: Open hole volume + 350% excess in permafrost and 40% excess below permafrost Basis: Lead TOC: Target surface Tail: Open hole volume +40% excess + 80 ft shoe track Tail TOC: 500 ft MD above casing shoe Total Cement Spacer -V100 bbls of Viscosified Spacer weighted to -V10.5 ppg (Mud Push II) Volume: Lead 910 bbls, 5109 cuft, 2675 sks of 11.0 ppg DeepCRETE, Yield: 1.91 cuft/sk Tail 64.4 bbls, 362 cuft, 312 sks 15.8 lb/gal Class G- 1.16 cuft/sk Temp BHST 74° F Casing Size 9-5/8"47#, L-80 VamTop, Intermediate Casing Lead: Open hole volume +40% excess Basis: Lead TOC: Target 656 ft MD above SV1 Tail: Open hole volume + 40% excess + 80 ft shoe track Tail TOC: 500 ft MD above casing shoe Total Cement Spacer -50 bbls of Viscosified Spacer weighted to -11.0 ppg (Mud Push II) Volume: Lead 441.2 bbls, 2477 cuft, 1424 sks of 11.5 ppg LiteCRETE, Yield: 1.74 cuft/sk Tail 44.9 bbls, 252 cuft, 218 sks 15.8 lb/gal Class G- 1.16 cuft/sk Temp BHST 135° F Casing Size 7" 26#, L-80 VAM TOP HC, Intermediate Liner Tail: olume+ ;. v. Basis: 1,500' open hole volume Above Sag River+40% excess + 80 ft shoe track Total Cement Spacer -35 bbls of Viscosified Spacer weighted to -12.0 ppg (Mud Push II) Volume: Lead N/A Tail 46.9 bbls, 263 cuft, 225 sks 15.8 lb/gal Class G 1.17 cuft/sk 75.9 bbls, 426.53 cuft, 364.5 Sks 15.8 lb/gal Class G- 1.17 cuft/sk Temp BHST 150° F Casing Size 4-1/2" 13.5#, 13Cr-85 HYD 521 Production liner Basis: Sliding Sleeve/Swell Packer Cementless Completion Total Cement N/A N/A Volume: L1-13 PTD Page 5 6/22/2016 i i Lead N/A Tail N/A Temp N/A L1-13 PTD Page 6 6/22/2016 • • Surface and Anti-Collision Issues Surface Close Proximity: No wells will be affected by the Parker 272 rig shadow. Sub-Surface Pressure Management: Cretaceous: Evaluate that there has been no significant change in injection in LPC-01 and LPC-02 that would impact our pore pressure prediction for this interval. If injection rates have significantly changed in disposal wells, re-assess impact on PPFG. Ivishak: SBHP in one of the following wells, in order of preference, NGI-08, WGI-02, WGI-06. Compare predicted pressure with FFM pressure. If SBHP gives pressure out of range of that which was predicted or FFM range is out of expected pore pressure range, expected pore pressure will need to be modified, and PPFG re-calculated. Lisburne: SBHP in L1-15A. If SBHP gives pressure out of range of that which was predicted, expected pore pressure will need to be modified, and PPFG re-calculated. Anti-Collision: Wp02 Wp05C has wells that fails major risk criteria. PRUDHOE BAY ST1 / PRUDHOE BAY ST1 PB1 has been fully P/A and is fully cemented. 15-16B which will be shut-in at surface prior to drilling the- production interval Hydrogen Sulfide L1-Pad is not considered an H2S site. Recent H2S data from the pad is as follows: Well Name H2S Level Date of Reading #1 Closest SHL Well H2S Level L1-15(Lisburne) 20 ppm 12/17/2014 #2 Closest SHL Well H2S Level L1-09(Lisburne) 50 ppm 4/4/2014 #1 Closest BHL Well H2S Level NGI-08(Ivishak) n/a n/a #2 Closest BHL Well H2S Level 18-11B(Ivishak) 0 ppm 10/1/2014 #3 Closest BHL Well H2S Level WGI-07 n/a n/a (Ivishak) #4 Closest BHL Well H2S Level L1-09(Lisburne) 50 ppm 4/4/2014 Max Recorded H2S on Pad/Facility L1-09(Lisburne) 50 ppm 4/4/2014 Faults Formation Where MD TVDss Throw Direction and Lost Circ Encounter Fault Intersect Intersect Magnitude Uncertainty Potential Fault#1: Lisburne 13,438.0 8,928.0 30-40 SW ±150 Med - High Fault#2: Lisburne 13,895.0 8,919.0 30-40 S ±150 Med - High Fault#3: Lisburne 14,510.0 8,892.0 80-100 N ±150 Med - High Fault#4: Lisburne 15,281.0 8,858.0 35-45 S ±150 Med - High Fault#5. Top of 16,400.0 8,808.0 50-70 S ±150 Med - High Lisburne 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) f/guidance. L1-13 PTD Page 7 6/22/2016 • • Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 4,000 psi, except annular at 3500 psi. BOP test frequency for L1-13 will be 14 days with a function test occurring every 7 days. Except in the event of a significant operational issues that may affect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. Intermediate 1 Interval Maximum anticipated BHP 3,023 psi at the WS1 at 6,252' TVDss (9.3 ppg EMW) Maximum surface pressure 2,398 psi at the WS1 (0.10 psi/ft gas gradient to surface) 25 bbls with 11.52 ppg frac gradient. Kick tolerance Assumes 9.3 ppg pore pressure in the WS1 + 0.5 ppg kick intensity and 10.5 ppg MW. Planned BOP test pressure Rams test to 4,000 psi/250 psi. Annular test to 3,500 psi/250 psi Integrity Test—12-1/4" hole LOT after drilling 20'-50' of new hole 9-5/8" Casing Test 4,000 psi surface pressure Intermediate 2 Interval Maximum anticipated BHP 3,473 psi at the TDF at 8,563' TVDss (7.8 ppg EMW) Maximum surface pressure 2,616 psi (0.10 psi/ft gas gradient to surface) 25 bbls with > 11.29 ppg frac gradient. Kick tolerance Assumes 7.8 ppg pore pressure in the TDF + 0.5 ppg kick intensity and 10.5 ppg MW. Planned BOP test pressure Rams test to 4,000 psi/250 psi. Annular test to 3,500 psi/250 psi 7" Liner Top Packer 4,000 psi surface pressure Integrity Test—8-1/2" hole FIT after drilling 20'-50' of new hole 7" Casing Test 4,000 psi surface pressure Production Interval Maximum anticipated BHP 3,352 psi in the TLSB at 8,712' TVDss (7.4 ppg EMW) Maximum surface pressure 2,481 psi (0.10 psi/ft gas gradient to surface) Infinite with >8.79 ppg frac gradient. Kick tolerance Assumes an 7.4 ppg max pore pressure in the TLSB + 0.5 ppg kick intensity and 8.5 ppg MW. Planned BOP test pressure Rams test to 4,000 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 4,000 psi surface pressure Planned completion fluids 8.5 ppg seawater/2,200 ft diesel to 2,038ft TVDss L1-13 PTD Page 8 6/22/2016 . • Variance Requests 1. To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, it is requested to drill without a flow paddle for the first portion of the surface hole. After drilling past the larger rocks and wood sections, the flow paddle will be put back in the flow line (<1000 ft). This is a variance from 20 AAC 25.033. Procedures/Safeguards with paddle removed: Fluid levels will be monitored in the pits for both gains and losses while drilling. Alarms will be set to indicate if gain or loss of more than 5 bbls has occurred. The well will be monitored for flow when the pumps are off at each connection. The planned 8.6 - 8.8 ppg fluid will provide over balance to formation fluid. 2. The Lisburne formation is highly faulted/naturally fractured with high lost circulation potential. ECD's while drilling out of 7" shoe will be greater than the required FIT for kick tolerance. Assuming zonal isolation objectives are met on the 7" liner job, and if lost circulation occurs prior to drilling 20 ft. of new formation, it is requested to drill to TD without obtaining a FIT. A similar event occurred in 2015 on L1-23(PTD 215-060) and a variation request was granted. L1-13 PTD Page 9 6/22/2016 • • L1-13 — Drill and Complete Operations Summary Current Condition and Well History: 1. Install and survey 20" conductor and cellar box. 2. Weld on landing ring. 3. Level pad and prepare location. 4. Confirm cretaceous injection pressures. 5. Validate injection/production in area per SOR. Rig Operations: 1. MIRU Parker 272: a. Survey conductor with rig over it to ensure rig is centered over the hole. b. RU diverter system and test. Notify AOGCC 24 hours in advance of test. 2. Drill 16" Surface Hole Section: a. Take on 8.7 ppg MAXDRIL-N. b. PU enough 5" drill pipe to drill the surface hole. c. Make-up 16" directional drilling assembly with MWD/GR/UBHO tool string. d. Clean out 20" conductor, spud well and directionally drill surface hole to the base of the permafrost. (Gyro until clean MWD surveys). e. At the base of the permafrost circulate hole clean and condition mud as required. f. Perform wiper trip to the top of the HWDP. g. Drill ahead per directional plan. Ensure minimum mud weight is increased to 9.0 ppg at least 200' before reaching the SV6. h. Drill remainder of surface hole to planned casing point at the base of the SV4. i. Circulate hole clean and condition mud as required. j. Perform wiper trip to base of permafrost. k. Trip back to TD, circulate hole clean and condition mud for running 13-3/8" casing. I. POOH and LD BHA. 3. Run & Cement 13-3/8" Surface Casing: a. Run 13-3/8", 68 ppf, L-80, BTC surface casing with Volant tool. Install Torque rings in each connection. b. Cement with 15.8 ppg Class G tail cement and non-freezing cement to surface. c. Pressure test casing to 3,500 psi for 5 minutes on plug bump. d. RD cementing equipment and flush and RD diverter system. e. NU FMC 13-5/8" 5M New Standard Big Bore wellhead system and test as required. f. NU and pressure test 13-5/8" 5M BOPE. (Configured from top to bottom: 13-5/8" annular preventer, 2-7/8" x 5-1/2" VBRs in the upper cavity, blind/shear rams, mud cross and 2-7/8" x 5- 1/2"VBRs in the lower cavity). ➢ Test rams to 250 psi/4,000 psi with 4" and 5" test joints. v Test annular to 250 psi /3,500 psi with 4" test joint. L1-13 PTD Page 10 6/22/2016 • • 4. Drill 12-1/4" Intermediate#1 Hole Section: a. PU enough 5" drill pipe to drill the 12-1/4" first intermediate hole. b. Test 13-3/8" casing to 250 psi for 5 minutes / 3,500 psi for 30 minutes after cement reaches a minimum of 500 psi compressive strength. c. MU 12-1/4" drilling assembly with MWD/GR/RES tool string. d. RIH and tag float collar or TOC. Drill out all but 10 ft of shoe track and then displace to 9.6 ppg LSND mud. Drill out remainder of shoe track. e. Drill at least 20' but no more than 50' of new formation and CBU. f. Pull inside casing and perform LOT. g. Drill ahead per directional plan. Ensure mud weight is increased to a minimum of 10.5 ppg at least 200' above the CM3. h. Continue drilling to the 9-5/8" intermediate 1 casing point which is at HRZ. CBU as needed for cutting samples to properly identify HRZ. i. At casing point, circulate hole clean and condition mud as needed. j. Perform wiper trip, bringing ghost reamer up to the previous casing shoe. k. Run back to bottom, circulate hole clean and condition mud for running 9-5/8" casing. I. POOH and LD BHA. If backreaming is necessary, trip back to TD and POH on elevators for final trip out. 5. Run and Cement 9-5/8" Intermediate Casing: a. Change rams to 9-5/8" FBRs in upper cavity. Test to 250 psi/4,000 psi. b. Run 9-5/8", 47 ppf, L-80, VT intermediate casing. c. Stage pumps up and condition mud for cement job. Cement with 15.8 ppg Class G Tail and 11.5 ppg lead cement. d. Immediately following the plug bump, initiate injection down the OA by pumping 5 bbls of drilling fluid to ensure annulus remains open for freeze protection. Continue to pump 3 - 5 bbls of drilling fluid down the OA every hour until the lead cement reaches 500 psi compressive strength. e. Install casing pack-off and test per FMC representative's procedures/instructions. f. RD cementing equipment and flush stack. g. Change rams to 2-7/8" x 5-1/2"VBR in upper cavity. Test to 250 psi /4,000 psi. h. Freeze-protect the 13-3/8" x 9-5/8" annulus once the cement has reached 500 psi compressive strength. 6. Drill 8-1/2" Intermediate#2 Hole Section: a. PU additional 5" drill pipe as required to drill the 8-1/2" second intermediate hole. b. MU 8-1/2" drilling assembly with MWD/GR/RES/GAB tool string. c. Once the lead cement has reached 500 psi compressive strength, pressure test 9-5/8 casing to 4,000 psi for 30 minutes. d. RIH and tag float collar or TOC. Drill out all but 10 ft of shoe track, and then displace to 10.3 — 10.5 ppg LSND mud. Drill out remainder of shoe track. e. Drill at least 20' but no more than 50' of new formation and CBU. f. Pull inside casing and perform the FIT. 9 -- - - •- • - ••-- - - -- - • - -_. CBU as needed for cutting samples to properly identify Lisburne boundary. Unable to drill past 12,693' MD due to encountering total losses attributed to an unforeseen fracture. h. Set bridge plug at 12,109' MD and squeezed 43.5 bbls of cement below. i. Placed 500' balanced cement plug on top of bridge plug. Pressure test plug to 3,500 psi. L1-13 PTD Page 11 6/22/2016 • j. Rig up e-line and set EZSV at 10,760'. Set whipstock at 10,750' MD and mill window+20' of new formation. k. Perform FIT. I. Drill 8-1/2" Intermediate 2 hole interval to TD at 13,951' MD. m. At casing point, circulate hole clean and condition the mud as needed. n. Perform wiper trip to the previous casing shoe. o. Run back to bottom, circulate hole clean and condition mud for running the 7" liner. p. POOH and lay down the BHA. If backreaming is necessary, trip back to TD and POH on elevators on the final trip. 7. Run and Cement 7" Intermediate/Production Liner: a. Change rams to 7" FBRs rams in the upper cavity. Test to 250 psi/4,000 psi. b. Run 7", 26 ppf, L-80, VAM Top HC intermediate liner with 150' lap into the 9-5/8" casing shoe. c Stage pumps up and condition mud for cement job. Cement to the TOL with 15.8 ppg Cement 1,500' MD above top of Sag with 15.8 ppg and TOC at 11,645' MD. d. Set the liner hanger and liner top packer. LD Liner running tool. e. Change rams to 2-7/8"x 5-1/2"VBRs in upper cavity. Test to 250 psi/4,000 psi. 8. Drill 6-1/8" Production Hole Section: a. PU enough 4" and 5" drill pipe to drill the 6-1/8" production hole. b. Test 7" liner to 250 psi for 5 minutes /4,000 psi for 30 minutes after cement reaches a minimum of 500 psi compressive strength. c. Make-up 6-1/8" drilling assembly with MWD/GR/RES/NEU/DEN/PEF/Image/Neutron Caliper. d. RIH and tag landing collar or TOC. Displace to 8.5 ppg Flo-Pro SF fluid before drilling the shoe track. e. Perform a 30 min no-flow test with 8.5 ppg fluid. f. Drill at least 20' but no more than 50' of new formation and CBU. g. Pull inside casing and perform the FIT. h. Drill ahead to TD per directional plan and rig site geologist as bit performance allows. POOH to replace bit if required. i. At casing point, circulate hole clean and condition the mud as needed. j. Perform wiper trip to the previous casing shoe. k. Run back to bottom, circulate hole clean and condition mud for running casing. I. POOH, LD excess 4" drill pipe and BHA. 9. Run and Cement 4-1/2" Production Liner: a. Run 4-1/2", 13.5 ppf, 13Cr-85, Hydril 521 production liner with 150 ft lap into the 7" liner shoe. b. Drop toe circulating valve (TCV) ball and set the liner hanger and liner top packer. Displace well to clean seawater above the liner top. c. Pressure test 9-5/8" casing x 7" liner x 4-1/2" liner to 4,000 psi for 30 minutes. d. POOH, LD liner running tool. 10. Run 4-1/2" Completion: a. RU and run a 4-1/2", 12.6 ppf, 13Cr-85, VamTop completion. Space out and land the tubing with the tubing tail inserted into the liner tie back sleeve. Run in lock down screws. b. Displace well to seawater completion fluid through the IA. c. Drop ball and rod with rollers to RHC plug. L1-13 PTD Page 12 6/22/2016 • • d. Test tubing to 250 psi for 5 minutes and then set production packer with 4,000 psi. e. Hold 4,000 psi for 30 minutes for tubing pressure test. f. Bleed tubing pressure down to below 2,000 psi. g. Pressure test IA to 250 psi for 5 minutes /4,000 psi for 30 minutes. Bleed down Tubing to 0 psi and shear DCR-1. Pump both ways to confirm shear. h. Pump enough diesel freeze protect fluid into the IA to protect to 2,200 ft TVD on both tubing and IA. i. RU jumper line between tubing and IA to allow diesel to U-tube into tubing. 11. Nipple Down BOPE/Nipple Up Production Tree and Freeze Protect: a. Install TWC and test. Nipple down BOPE. b. N/U the tubing head adapter flange and dry hole tree. c. Test tubing head adapter flange and tree to 250 psi for 5 minutes/5,000 psi d. Install VR plugs in the annulus valves as needed and secure the well. Ensure that both IA and OA are protected by two barriers. 12. Release Rig: a. Rig down and move off location. Post-Rig Operations: 1. Change out from dry hole tree to 6,500 psi tree for acid treatment. 2. DSM Pull TWC. 3. MIRU slick line. Pull ball and rod / RHC plug from landing nipple below production packer. 4. Negative pressure test 7" Liner Top 5. Perform acid stimulation. 6. Install GLVs. SBHPS. 7. ASRC Flow Back with N2 assist. 8. Possible two additional service coil interventions within 6 months of POP. 9. PPROF. 10. Install the well house, instrumentation, s-riser. L1-13 PTD Page 13 6/22/2016 • • L1-13 Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control / Reservoir Pressures: A. Intermediate Hole 1: The UG4 is expected to be a 9.3 ppg EMW. The CM1, CM2 and CM3 are expected to be a 10.2 ppg EMW. Formation pressures will be controlled with a 9.6 — 9.8 ppg mud to drill to within 200' MD of the CM3. At this point, there will be a weight up to 10.4 — 11.0 ppg to drill the rest of the interval to TD. B. Intermediate Hole 2: The Ivishak is expected to be at a 8.1 ppg EMW. Reservoir pressures will be controlled with a 10.3— 10.7 ppg mud needed to drill the Kavik. C. Production Hole: The Lisburne is expected to be at a 7.4 ppg EMW. Reservoir pressures will be controlled by using 8.5—9.0 ppg water based mud. II. Lost Circulation/Breathing A. Intermediate Hole 1: There are no expected fault crossings in the first intermediate hole. However, breathing has been known to occur in the Colville on other Drill Sites in Prudhoe Bay as a result of high ECD's. B. Intermediate Hole 2: There are no expected fault crossings in the second intermediate hole. However, the Ivishak will be drilled with a high mud weight/pore pressure differential which increases the likelihood of lost circulation. C. Production Hole: There are 5 expected fault crossings in the production hole. Past wells have experienced severe lost circulation and well bore breathing in the Lisburne. III. Fault Locations Formation Where MD TVDss Throw Direction and Lost Circ Encounter Fault Intersect Intersect Magnitude Uncertainty Potential Fault#1: Lisburne 13,438.0 8,928.0 30-40 SW ±150 Med - High Fault#2: Lisburne 13,895.0 8,919.0 30-40 S ±150 Med - High Fault#3: Lisburne 14,510.0 8,892.0 80-100 N ±150 Med - High Fault#4: Lisburne 15,281.0 8,858.0 35-45 S ±150 Med - High Fault#5: Top of 16,400.0 8,808.0 50-70 S ±150 Med - High Lisburne IV. Integrity Testing Test Point Test Depth Test type EMW(lb/gal) 13-3/8" Shoe 20'-50' from the 13-3/8" shoe LOT 11.52 ppg 9-5/8" Shoe 20'-50' from the 9-5/8" shoe FIT 11.29 ppg 7" shoe 20'-50' from the 7" shoe FIT 8.79 ppg V. Hydrogen Sulfide L1-Pad is not considered an H2S site. Recent H2S data from the pad is as follows: Well Name H2S Date of Level Reading #1 Closest SHL Well H2S Level L1-15 (Lisburne) 20 ppm 12/17/2014 #2 Closest SHL Well H2S Level L1-09(Lisburne) 50 ppm 4/4/2014 #1 Closest BHL Well H2S Level NGI-08 (Ivishak) n/a n/a #2 Closest BHL Well H2S Level 18-11B (Ivishak) 0 ppm 10/1/2014 #3 Closest BHL Well H2S Level WGI-07(Ivishak) n/a n/a #4 Closest BHL Well H2S Level L1-09(Lisburne) 50 ppm 4/4/2014 Max Recorded H2S on Pad/Facility L1-09 (Lisburne) 50 ppm 4/4/2014 VI. Anti-Collision Issues Wp02 has one well that fails major risk criteria. PRUDHOE BAY ST1 / PRUDHOE BAY ST1 PB1 has been fully P/A and is fully cemented. CONSULT THE LI-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. L1-13 PTD Page 14 6/22/2016 • • PARKER 272 BOP STACK RAM TYPE BOP: DUTCH LOCK DOWN FLANGE SHAFFER LXT DOUBLE BOP 13 5/8"-5M 13 5/S"-5M STUDDED TOP 6,,, )i _ . 13 5/8"-5M FLANGED BOTTOM ""°"" W/(2) 14" UL2 OPERATOR, UPPER CAVITY ° o ANNULAR BOP: HFFERAND (2) 14" PSLK W/BSTR OPERATOR, `n'�' �� S3 AS/8" 5MTSTUDDEO TOP LOWER CAVITY 13-5 8 5M FLANGED BOTTOM o / 0 I I DRILLING CROSS: II 13 5/8"-5M FLANGED TOP — I CT— ..., r EI y 13 5/8"-5M FLANGED BOTTOM l , r- 3 W (2) 3 1/8"-5M SIDE OUTLETS II II II l • \J— •• f II r I KILL LINE: —WWI .r� r��� rl���/�� 2-1/16" 5M FLEX HOSE —lSl1 WI •' 1"•-� (/.1 •} INI,1-.�- J ► 2-1/16" 5M X 3-1/8" 5M D.S.A. / �I 3-1/8" 5M FLANGED MANUAL GATE VALVE m 3-1/8" 5M FLANGED HYDRAULIC GATE VALVE E ,�►'yr -- o 2.3 3 E ■�I. oo ° U 3 I 1 CHOKE LINE: RAM TYPE BOP: 3-1/8" 5M FLANGED MANUAL GATE VALVE _ SHAFFER LXT SINGLE 13 5/8" 5M 3-1/8" 5M FLANGED HYDRAULIC GATE VALVE 13 5/8"-5M STUDDED TOP 13 5/8"- 5M FLANGED BOTTOM 3-1/8" 5M FLEX HOSE W/(2) 14" UL2 OPERATOR L1-13 PTD Page 15 6/22/2016 r -31 I I I-Pil,:16/1 SI 12 I T 531 11:::.1:kj I 1 - *V,- ',1.:', 11 _ D,S. 1 ,) 11111(11 .pRo j 30 I) t GT � - ■ 28 " Atir 1 27 i a l,. CPF Y CCP , ,._ a- 11'1 .;` -. ,1 — 23 ii 1 i 1 21 ill -, 11 2D VICINITY MAP / N.T.S. / \1 I — I _ I 15 in 1 .its0 WA No 1 $14gy N„ »s .t 671 , \ 11 , tr :49m .*' 4. s■ 1 're*es «^.�'�i $� $8 ,. I • »/x10200 F. :arrtivri » . tier 1 II MANN a 1 1 • I SURVEYOR'S CERTIFICATE I I HEREBY CERTIFY THAT I AM I PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT I THIS AS-BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT I SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE _ _ '®- "" (". I '' CORRECT AS OF JANUARY 29, 2016, II NOTES: LEGEND 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD27. AS-BUILT CONDUCTOR 2. BASS OF LOCATION IS D.S. L-1 MONUMENTS L-1 NORTH AND GRAPHIC SCALE L-1 SOUTH. I EXISTING WELL 3. BASIS OF ELEVATOR IS BP MEAN SEA LEVEL(MSL) DATUM. 0 100 200 400 4. GEODET C POSITIONS ARE NAD27. I = t 5. PAD MEAN SCALE FACTOR IS: 0.9999405. ( IN FEET ) 1 inch = 200 ft. 6. DATE OF SURVEY: JANUARY 29, 2016. 7. REFERENCE FIELD BOOK: NS16-06 PGS. 01-04. LOCATED WITHIN PROTRACTED SECTION 1, T. 11 N., R. 14 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS L1-13 Y=5,974,893.73 N=4,948.83 70'20'10.172" 70.3361589° 12.9' 2,541' FSL / X= 688,600.88 _E=4,789.33 148'28'10.9627_ 148.4697116° ' 2,801' FEL Dhkm: __... JACOBS 0 b CHE ow ,A Øbp 1KLEIN 13O/1 I pNAttlNt; FR815 DELI 32 ` ` 54�l LISBURNE O.S. L-1 AS—BUILT CONDUCTOR LOCATION Oa I/3011.ISSUED FOR INFORMATION JJ 4K 1" = 200' WELL L1-13 1 oF 1 Nn. 04,, '31 v,,,o, ,I Y C 4 0 0 III " 11 11�_ W 40 .. `m2 gz O. CO 4.0 0 a a)Q CZ —J a) Q I Z CO Cn .V C I. U ino a. o Q. e. N L L N J 7 M M tli O N a T r E ML g Z J J J a W N 1k 0 4lex. • • iA m W CO 705 N O O �� N C O O N O O N f- O au • I o O N LnN iii N N M N. 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CO CO a) o O a -0 n 0 0 0 CO o v v v c v (n CO CO v CO v (n (n < E U) 13 i e± L n O O 6 N M 6 6 N 6 6 N- O V r 6 r N- O tOQMMM y O.fM O r M O nO M 0)O 0) M M r MO O r (O O `,;4 :7C 4co ' ' y Q a O O O O N N M M VV R ..6 (O N co- O OOZ J J J J J <- A- . ,- . . . rr r r A- rrrrr NCO 0 O .2O to 7 1 O N 0 I c c c (0 'I* Z 0. u O c Q r d _ a so o 0aio33a a N • • Qbp North America - ALASKA - BP Lisburne Lis DS 01 L1-13 L1-13_Option C L1-13 wp05C Anticollision Summary Report 21 June, 2016 rI BAKER HUGHES • • BP VI1 0 bp Anticollision Report BAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well L1-13 Project: Lisburne TVD Reference: L1-13 Plan @ 60.05usft(PARKER 272) Reference Site: Lis DS 01 MD Reference: L1-13 Plan @ 60.05usft(PARKER 272) Site Error: 0.00usft North Reference: True Reference Well: L1-13 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore L1-13_Option C Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: L1-13 wp05 Offset TVD Reference: Offset Datum Reference L1-13 wp05 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 10,600.00 to 17,430.59usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,938.34usft Error Surface: Elliptical Conic , Survey Tool Program Date 6/21/2016 i From To (usft) (usft) Survey(Wellbore) Tool Name Description 1 96.00 803.00 Gyrodata Gyro SS 16"(L1-13) GYD-GC-SS Gyrodata gyro single shots 898.56 5,159.13 BH OTK MWD+IFR+MS 16"(L1-13) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 5,237.09 10,635.74 BH OTK MWD+IFR+MS 12-1/4"(L1-13) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 10,635.74 10,700.00 L1-13 wp05(L1-13_Option C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 10,700.00 11,200.00 L1-13 wp05(L1-13_Option C) INC+TREND Inclinometer+known azi trend 11,200.00 12,400.00 L1-13 wp05(L1-13_Option C) MWD MWD-Standard 11,200.00 13,956.00 L1-13 wp05(L1-13_Option C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 13,956.00 15,500.00 L1-13 wp05(L1-13_Option C) MWD MWD-Standard 13,956.00 17,430.59 L1-13 wp05(L1-13_Option C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 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) Lis DS 01 L1-01-L1-01-L1-01 Out of range L1-01-Plan#119 L1-01A-Plan#119 Out of range L1-09-L1-09-L1-09 Out of range L1-13-L1-13-L1-13 10,987.29 11,000.00 58.35 147.79 -44.68 FAIL-Major Risk L1-13-L1-13-L1-13 wp04D 10,836.92 10,725.00 19.37 283.77 -260.24 FAIL-Major Risk L1-15-L1-15-L1-15 Out of range L1-15-L1-15A-L1-15A Out of range L1-15-L1-15A-Plan#20e Out of range L1-15-L1-15APB1-L1-15APB1 Out of range PB DS 15 15-16-15-16B-15-16B 16,532.52 14,825.00 256.58 47.13 213.82 Pass-Minor 1/200 15-16-15-16BPB1-15-16BPB1 17,273.54 13,240.00 1,481.83 590.85 910.50 Pass-Major Risk PRUDHOE BAY ST 1 PRUDHOE BAY ST 1-PRUDHOE BAY ST 1-PB 14,699.62 9,000.00 200.12 15.38 190.69 Pass-Minor 1/200 PRUDHOE BAY ST 1-PRUDHOE BAY ST 1 PB1 14,775.50 8,593.00 429.65 15.56 428.95 Pass-Minor 1/200 WGI WGI-02-WGI-02-WGI-02 10,613.56 8,200.00 1,483.89 390.93 1,152.53 Pass-Major Risk WGI-09-WGI-09-Plan WGI-09 Wp 6 Out of range WGI-09-WGI-09-WGI-09 Out of range 6/21/2016 11:19:43AM Page 2 of 3 COMPASS 5000.1 Build 81B III • BP tred'- AS 0 bp Anticollision Report BAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well L1-13 Project: Lisburne ND Reference: L1-13 Plan @ 60.05usft(PARKER 272) Reference Site: Lis DS 01 MD Reference: L1-13 Plan @ 60.05usft(PARKER 272) Site Error: 0.00usft North Reference: True Reference Well: L1-13 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore L1-13_Option C Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: L1-13 wp05 Offset TVD Reference: Offset Datum Reference Depths are relative to L1-13 Plan @ 60.05usft(PARKER Coordinates are relative to:L1-13 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:1.44° Ladder Plot 2000— L .i II II _1 i _1 _J H II i 1500— � .- 11 1 oI II 11 /I c o i ill 11 I'2 11 li /II rn 1000- 6) i 11 PI' I it 0 o n 1M1 �, In a� :oi 11 O• 500— I II HU. v 1 F' I'ail• III pi fi'J ' /9 I I I9 I 0 I I I I 0 3000 6000 9000 12000 15000 18000 Measured Depth(3000 ustt<n) LEGEND 1 -A- L1-21,L1-21,L1-21 V1 -e- 15-37,15-37,15-37 V1 3 - 15-16,15-16,15-16 V5 $ 15-37,15-37A,15-37A V2 A Plan#119 V2 -4-. 15-16,15-16A,15-16A V3 $ 15-37,15-37APB1,15-37APB1 V1 1 $ 15-16,15-166,15-16B VO 1-- 15-37,15-37C,15-37C V0 1 -e- 15-16,15-16BPB1,15-16BPB1 VO .. PRUDHOEBAY ST1,PRUDHOEBA) )040V0 -e- 15-36,15-36,15-36 V1 i PRUDHOEBAY ST1,PRUDHOEBA) 1 -->t- 15-36,15-36A,15-36A V2 WG 1-02,W31-02,W 3l-02 V1 1 $ 15-36,15-36APB1,15-36APB1 V3 -)- WG1-09,WG1-09,Plan WGI-09Wp6V1. V3 -e- 15-36,15-36B,15-36B V7 -4- WGl-09,WGI-09,WGI-09 V7 :0e v2 -I- 1 b-ib,15-ibtSrtS1,15-3bH}-n31 Vt3 $ L1-13WpU5 6/21/2016 11:19:43AM Page 3 of 3 COMPASS 5000.1 Build 81B TREE= L 1 �13 V4El_LHEAD= PROP ED SAFETY NOTES: WELL ANGLE>70°@ ACTUATOR= CHROME TBG&LNR"°'MAX DLS: °@ ' NTIAL KB.ELEV= REV 1 I NTIAL.BE ELEV= 2 --14-112"OTIS X Nl'. U 3.813" KOP= _"C:OND — —80' Max Angle= ° GAS LFT MANDRELS I Datum MJ= p__ ST MJ TVD DEV TYPE VLV LATCH FORT DATE Datum TVD= � � 5 ii, 4 13-3/8"CSG,68#,L-80 BTC,D --I=12.415" � 5212' 3 2 TOP OF CMT(_/_t_) H —7503' ., 1 9. H4-1/2"OTISX NP,D=3.813" 1i l Pi 4 ti TOP OF 7"LNR 10600' s L Ai i 10600' hl 9-5/8"X 7"WFT TSP5H3 LIP,D= _ 41! A H 9-5/8"X 7"INET W FiR HGR,D= ' 1,1 Minimum ID =_ N --14-112"WLEG,D=3.958" Ili t 13801' 7'X 5"BKR HRD-E ZXFN l ZXPN LIP,D=4.32" R BKR WHIPSTOCK(_/_/_) 10760' It; t HES EZSV (!t—/_J 10760' TOP OF CMT(,,j /_) —11609' •I !i I �t% *Y 1f 9518"SQZPKRH 12109' *sus � ''P 5 T LNR 26#,L-80 VAM TOP, 13951' _ r .0383 bpf D=6.276" ' 9-5/8"CSG,47#,L-80 YAM TOP,D=8.681" H 12199' r!' .t. HES SWELL PACKERS NO SIZE TOP DEPTH MND MSS 10 4-1/2" 3.958" ,.=•—'=, 9 4-1/2" 3.958" NMI 8 4-1/2" 3.958" _SLIDING SLV,ID=3.813" r:.. 7 4-1/2" 3.958" NO DEPTH 0/C DATE MN ID inn 6 4-1/2" 3.958" "• 5 4-1/2" 3.958" 6 C . 4 4-1/2" 3.958" EI rz. 3 4-1/2" 3.958" 4 C ,� a 2 4-1/2" 3.958" � 3 C «- 1 4-1/2" 3.958" 2 O ../ 1 C 8 VT OPEN HOLE H 12693' O=OF'9N C=CLOSED 11111111 . 4 y4 4-1/2"LNR,13.5#,13CR-86 HYD 521, 17430' firms .0150 bpf,D=3.920" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY INT 1_I_ INITIAL COMPLETION WELL: L1-13 02/18/16 JM) BUt_T PROPOSAL PERMT No: '2160030 06/20/16 JNUJM3 PROPOSED PB1 P&A MI No: 50-029-23563-00 06/22/16 BG/JM) PROPOSED REV 1 — SEC.1,TUN,14E,2542 FSI 8 2478'Fa BP Exploration(Alaska) • • TRANSMITTAL LETTER CHECKLIST WELL NAME: 1 U/ / 73 (a. PTD: Development Service _Exploratory Stratigraphic Test Non-Conventional / jI FIELD: r' L pi1..., POOL: /.` 4c-f v-I'LL 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 0 • F 1 Ta o N : N N d N a)• ❑ CO O `m ° - in 0a) a � c z 3 a) m Q o03 3 0 c m CO. a' f6 u_ N �, �, g co N ii a). N: N: ii N a c W: °:o. o. oO - a Tao, N M °>' Caa)7: •>3' yC N . , a) .c • aoNd C C0 O, 0 a 8 ' ED.. @ z O 0- 0 r, •c' a): a) a °: Y:co c 0 C ' 0, CO ,NF: ': EO 0 2: 03 c • o .0 co O J C: �: ca O: -Op: � . : y: N� a o: N: p. C la co co c D' O' a .@ya (07 .o p , > `, ay a0 • U) N. o. N y , O: J' C) C' 2 a) CO >- aO' 'cO a o an' OmQm 0 : ° a) 'yf• ap No (0_ L �: v. 3 V • Z a ctp ca ' ) _ t o Q m': A 0 14. (T)' 2 c, ' �Fil': C' o o m': E; �': a c E 0 C; W' W. a V:as 0 U' U' C 'ca - y' 3 m N: N: a)' E, O t - - , 0 ,,..7 E -c , o' - o': n �, m. 0) o, d E. �': 0 o`-°a, a) J �' 0� N. p .. p. , ' U: V: L: c' x. CO c0 d� C' •0 O CO d' OU E. ; c' N '-. O a: .ce Q: j. 2, g I _ n ca 1.4 . _ia . I j co di ❑ FZ Q; U)) UU: U 'al UUUUN Uy: QQQQUVN: oo2 U QU UUUUtl: U, UQoU) QQQa z r; >- >- >- >- >- >- >- >- >- >-, >- z z z z >- >- >- z z >- >- z >- >- >- >- >- >- >- >-. z z >- z z z co -cis U To i.7- — , . 8, v. o .0 U o c �. , o Z o �, w D. aoi . o Lu Z �. -a .C . O. N: • O a a): O: LL re0 tt.'....1 uhI Nm . . .ca -0 : Q. co Ca) co . a . cfyc •Q N , -OaV: N' C0 :C• O C . a > .o. � o O ° c: c � ,, 3 •c 3 � Mp. a v2u ' 0 m coS Z C W - ' m, go , a3d tN • --2_4) baaaoa) c ❑ comp o) aa , cc0c = Q E E _ •p C c E a) O ,,,,c') C' C; y • I- C OO 0.5 C La) Q N t C1 p' � : in aaCcaaQc - 1i° IHdIi1flH • � Ooc0 m �'a), N: ' 6 cu. N' Ma) Uf) 2, ` 0U4_ 3' N' a' Np' W O o z 's. v c2y7,-, 0 •o 3 3 ' 2 ao :355 : o . v8av, a- a � a). o ..6 .c U OaN ' a ' O8' 8' > EoaNN " QOv E wOE ' CO ' Ca , j' . o ,N - N iN . U : : aC Vp. -p ' NU E0)8 co Oa5 =: O06 Q La a), a a E �: a yyaL' � 'a , a ca 8) ' NOS CU N 5 p: OC p-p aUOE: faO: O: c' 4 2 !1ca +- � C2. O (ac - mpa °' >> m ., 3I' 0a 'No, a) O 0yc ca a p >, caaa) a) 3Ev 0) c a, CT a)` m 3w a o , a >, , a) i ma Vp •oo • -d: m aa a •oC a) , y •Na) a) > . .c aa) v .- 0 .0 C 0 cE ) X O .cc, N °) .3N' aaNN' 0 N' R 72. .2 Vs, C a) Cpca ca 7 OU rnO _ N E 31w c o0a ° ° 0' O y cc> � a) o o - m •o` m rvia •a- 0 •0 oit) .. -: o .. . a), o0 , : 0: : d) ?. cr) iii a) ya: O .j m Emv 05; a, aEE c 3 9c c ,ESII, y c c a. a o ` aV € to a c c CD v a a a) m 03 � oo722 ca aa) •o c OO toa) a) co aa) o,Y ° CL° -J U) * O; Oa, ao, ; ¢ az o0) 0000 ¢ °- Q - ammom' 20- 00) 0, 0,, ❑ I"I E. O — N M v in (O N. CO O) O M -<::, cn CO � CO O) O C N M e} to (0 W O) • E —. N M ' 1p co h CO O) N N f.'1' N N N N N N M M M M M M M (-1-, M M O O U m co m a) E o C a, o ca (N N a) (N U O c fn � N 01 o N O y I- O :iN CW i 0 C °'E0 CL i r CV co co C 1: N 0 O) 1 ik .la C a O ` o U W ❑ E 0) o a d Q Q Q a 1 0 • • PTD 2t6 - oo3 Loepp, Victoria T (DOA) From: Jakabosky,Troy <Troy.Jakabosky@bp.com> Sent: Tuesday,April 05, 201610:09 AM To: Loepp,Victoria T(DOA) Subject RE: PTD#:216-003 PBU L1-13 Change in BOP Stack Follow Up Flag: Follow up Flag Status: Flagged Thank you. From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, April 05, 2016 10:05 AM To: Jakabosky,Troy Subject: PTD #: 216-003 PBU L1-13 Change in BOP Stack Troy, This change to the BOP stack is approved. Please include this approval with the PTD. 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.Loeop aC2alaska.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.loeop@alaska.gov From: Jakabosky,Troy [mailto:Troy.Jakabosky@bp.com] Sent:Tuesday, April 05, 2016 9:55 AM To: Loepp,Victoria T(DOA) Subject: RE: PTD #: 216-003 L1-13 Victoria—I sent this change to the PTD to you a couple of weeks ago. I just wanted to make sure you didn't need anything additional? Thanks,Troy 1 • From: Jakabosky,Troy Sent: Monday, March 21, 2016 1:38 PM To: victoria.loepp@alaska.gov Subject: PTD #: 216-003 L1-13 Victoria, There has been a change in the BOP stack and ram configuration for well L1-13. I have attached the schematic of the BOP stack that will be used for this well,and included the modified operational summaries below(changes in RED). PTD#:216-003 Thanks,Troy PTD Drilling Rig Operations: 1. MIRU Parker 272: a. Survey conductor with rig over it to ensure rig is centered over the hole. b. RU diverter system and test. Notify AOGCC 24 hours in advance of test. 2. Drill 16" Surface Hole Section: a. Take on 8.7 ppg MAXDRIL-N. b. PU enough 5"drill pipe to drill the surface hole. c. Make-up 16"directional drilling assembly with MWD/GR/UBHO tool string. d. Clean out 20"conductor, spud well and directionally drill surface hole to the base of the permafrost. (Gyro until clean MWD surveys). e. At the base of the permafrost circulate hole clean and condition mud as required. f. Perform wiper trip to the top of the HWDP. g. Drill ahead per directional plan. Ensure minimum mud weight is increased to 9.0 ppg at least 200' before reaching the SV6. h. Drill remainder of surface hole to planned casing point at the base of the SV4. i. Circulate hole clean and condition mud as required. j. Perform wiper trip to base of permafrost. k. Trip back to TD, circulate hole clean and condition mud for running 13-3/8"casing. 2 0 0 I. POOH and LD BHA. 3. Run&Cement 13-3/8" Surface Casing: a. Run 13-3/8", 68 ppf, L-80, BTC surface casing with Volant tool. Install Torque rings in each connection. b. Cement with 15.8 ppg Class G tail cement and non-freezing cement to surface. c. Pressure test casing to 3,500 psi for 5 minutes on plug bump. d. RD cementing equipment and flush and RD diverter system. e. NU FMC 13-5/8"5M New Standard Big Bore wellhead system and test as required. f. NU and pressure test 13-5/8" 5M BOPE. (Configured from top to bottom: 13-5/8" annular preventer, 2-7/8" x 5" VBRs in the upper cavity, blind/shear rams, mud cross and 2-7/8" x 5"VBRs in the lower cavity). • Test rams to 250 psi/4,000 psi with 4"and 5"test joints. • Test annular to 250 psi/3,500 psi with 4"test joint. 4. Drill 12-1/4" Intermediate#1 Hole Section: a. PU enough 5"drill pipe to drill the 12-1/4"first intermediate hole. b. Test 13-3/8" casing to 250 psi for 5 minutes / 3,500 psi for 30 minutes after cement reaches a minimum of 500 psi compressive strength. c. MU 12-1/4"drilling assembly with MWD/GR/RES tool string. d. RIH and tag float collar or TOC. Drill out all but 10 ft of shoe track and then displace to 9.6 ppg LSND mud. Drill out remainder of shoe track. e. Drill at least 20' but no more than 50'of new formation and CBU. f. Pull inside casing and perform LOT. g. Drill ahead per directional plan. Ensure mud weight is increased to a minimum of 10.5 ppg at least 200'above the CM3. h. Continue drilling to the 9-5/8" intermediate 1 casing point which is at HRZ. CBU as needed for cutting samples to properly identify HRZ. i. At casing point, circulate hole clean and condition mud as needed. j. Perform wiper trip, bringing ghost reamer up to the previous casing shoe. k. Run back to bottom, circulate hole clean and condition mud for running 9-5/8" casing. I. POOH and LD BHA. If backreaming is necessary, trip back to TD and POH on elevators for final trip out. 5. Run and Cement 9-5/8" Intermediate Casing: a. Change rams to 9-5/8" FBRs in upper cavity. Test to 250 psi/4,000 psi. b. Run 9-5/8", 47 ppf, L-80,VT intermediate casing. 3 • • c. Stage pumps up and condition mud for cement job. Cement with 15.8 ppg Class G Tail and 11.5 ppg lead cement. d. Immediately following the plug bump, initiate injection down the OA by pumping 5 bbls of drilling fluid to ensure annulus remains open for freeze protection. Continue to pump 3 - 5 bbls of drilling fluid down the OA every hour until the lead cement reaches 500 psi compressive strength. e. Install casing pack-off and test per FMC representative's procedures/instructions. f. RD cementing equipment and flush stack. g. Change rams to 2-7/8" x 5"VBR in upper cavity. Test to 250 psi/4,000 psi. h. Freeze-protect the 13-3/8"x 9-5/8"annulus once the cement has reached 500 psi compressive strength. 6. Drill 8-1/2" Intermediate#2 Hole Section: a. PU additional 5"drill pipe as required to drill the 8-1/2"second intermediate hole. b. MU 8-1/2"drilling assembly with MWD/GR/RES/GAB tool string. c. Once the lead cement has reached 500 psi compressive strength, pressure test 9-5/8 casing to 4,000 psi for 30 minutes. d. RIH and tag float collar or TOC. Drill out all but 10 ft of shoe track, and then displace to 10.3— 10.5 ppg LSND mud. Drill out remainder of shoe track. e. Drill at least 20' but no more than 50'of new formation and CBU. f. Pull inside casing and perform the FIT. g. Continue drilling to the intermediate 2 casing point at TLSB. CBU as needed for cutting samples to properly identify Lisburne boundary. h. At casing point, circulate hole clean and condition the mud as needed. i. Perform wiper trip to the previous casing shoe. j. Run back to bottom, circulate hole clean and condition mud for running the 7" liner. k. POOH and lay down the BHA. If backreaming is necessary, trip back to TD and POH on elevators on the final trip. 7. Run and Cement 7" Intermediate/Production Liner: a. Change rams to 7" FBRs rams in the upper cavity. Test to 250 psi/4,000 psi. b. Run 7", 26 ppf, L-80, VAM Top HC intermediate liner with 150' lap into the 9-5/8"casing shoe. c. Stage pumps up and condition mud for cement job. Cement to the TOL with 15.8 ppg Class G cement. d. Set the liner hanger and liner top packer. LD Liner running tool. e. Change rams to 2-7/8"x 5"VBRs in upper cavity. Test to 250 psi/4,000 psi. 8. Drill 6-1/8"Production Hole Section: a. PU enough 4"and 5"drill pipe to drill the 6-1/8" production hole. 4 • • b. Test 7" liner to 250 psi for 5 minutes/4,000 psi for 30 minutes after cement reaches a minimum of 500 psi compressive strength. c. Make-up 6-1/8"drilling assembly with MWD/GR/RES/NEU/DEN/PEF/Image/Neutron Caliper. d. RIH and tag landing collar or TOC. Displace to 8.5 ppg Flo-Pro SF fluid before drilling the shoe track. e. Perform a 30 min no-flow test with 8.5 ppg fluid. f. Drill at least 20' but no more than 50'of new formation and CBU. g. Pull inside casing and perform the FIT. h. Drill ahead to TD per directional plan and rig site geologist as bit performance allows. POOH to replace bit if required. i. At casing point, circulate hole clean and condition the mud as needed. j. Perform wiper trip to the previous casing shoe. k. Run back to bottom, circulate hole clean and condition mud for running casing. I. POOH, LD excess 4"drill pipe and BHA. 9. Run and Cement 4-112" Production Liner: a. Run 4-1/2", 13.5 ppf, 13Cr-85, Hydril 521 production liner with 150 ft lap into the 7" liner shoe. b. Drop toe circulating valve (TCV) ball and set the liner hanger and liner top packer. Displace well to clean seawater above the liner top. c. Pressure test 9-5/8"casing x 7" liner x 4-1/2"liner to 4,000 psi for 30 minutes. d. POOH, LD liner running tool. 10. Run 4-1/2"Completion: a. RU and run a 4-1/2", 12.6 ppf, 13Cr-85, VamTop completion. Space out and land the tubing with the tubing tail inserted into the liner tie back sleeve. Run in lock down screws. b. Displace well to seawater completion fluid through the IA. c. Drop ball and rod with rollers to RHC plug. d. Test tubing to 250 psi for 5 minutes and then set production packer with 4,000 psi. e. Hold 4,000 psi for 30 minutes for tubing pressure test. f. Bleed tubing pressure down to below 2,000 psi. g. Pressure test IA to 250 psi for 5 minutes/4,000 psi for 30 minutes. Bleed down Tubing to 0 psi and shear DCR-1. Pump both ways to confirm shear. h. Pump enough diesel freeze protect fluid into the IA to protect to 2,200 ft TVD on both tubing and IA. i. RU jumper line between tubing and IA to allow diesel to U-tube into tubing. 5 • • 11. Nipple Down BOPE/Nipple Up Production Tree and Freeze Protect: a. Install TWC and test. Nipple down BOPE. b. N/U the tubing head adapter flange and dry hole tree. c. Test tubing head adapter flange and tree to 250 psi for 5 minutes/5,000 psi d. Install VR plugs in the annulus valves as needed and secure the well. Ensure that both IA and OA are protected by two barriers. 12. Release Rig: a. Rig down and move off location. « File:Cameron Stack(2).pdf» Troy Jakabosky Drilling Engineer bp 900E. Benson Blvd.Cube 748C Anchorage,AK 99508 Office 907.564.4868 Cell 907.632.2609 6 • • pro Z`6 —OC3 Loepp, Victoria T (DOA) From: Jakabosky,Troy <TroyJakabosky@bp.com> Sent: Monday, March 21,2016 1:38 PM To: Loepp,Victoria T(DOA) Subject: PTD#:216-003 L1-13 Attachments: Cameron Stack(2).pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, There has been a change in the BOP stack and ram configuration for well L1-13. I have attached the schematic of the BOP stack that will be used for this well,and included the modified operational summaries below(changes in RED). PTD#:216-003 Thanks,Troy PTD Drilling Rig Operations: 1. MIRU Parker 272: a. Survey conductor with rig over it to ensure rig is centered over the hole. b. RU diverter system and test. Notify AOGCC 24 hours in advance of test. 2. Drill 16"Surface Hole Section: a. Take on 8.7 ppg MAXDRIL-N. b. PU enough 5"drill pipe to drill the surface hole. c. Make-up 16"directional drilling assembly with MWD/GR/UBHO tool string. d. Clean out 20" conductor, spud well and directionally drill surface hole to the base of the permafrost. (Gyro until clean MWD surveys). e. At the base of the permafrost circulate hole clean and condition mud as required. f. Perform wiper trip to the top of the HWDP. g. Drill ahead per directional plan. Ensure minimum mud weight is increased to 9.0 ppg at least 200' before reaching the SV6. h. Drill remainder of surface hole to planned casing point at the base of the SV4. i. Circulate hole clean and condition mud as required. j. Perform wiper trip to base of permafrost. k. Trip back to TD, circulate hole clean and condition mud for running 13-3/8°casing. I. POOH and LD BHA. 1 • 3. Run&Cement 13-3/8"Surface Casing: a. Run 13-3/8", 68 ppf, L-80, BTC surface casing with Volant tool. Install Torque rings in each connection. b. Cement with 15.8 ppg Class G tail cement and non-freezing cement to surface. c. Pressure test casing to 3,500 psi for 5 minutes on plug bump. d. RD cementing equipment and flush and RD diverter system. e. NU FMC 13-5/8"5M New Standard Big Bore wellhead system and test as required. f. NU and pressure test 13-5/8" 5M BOPE. (Configured from top to bottom: 13-5/8" annular preventer, 2-7/8" x 5" VBRs in the upper cavity, blind/shear rams, mud cross and 2-7/8"x 5"VBRs in the lower cavity). • Test rams to 250 psi/4,000 psi with 4"and 5"test joints. • Test annular to 250 psi/3,500 psi with 4"test joint. 4. Drill 12-1/4" Intermediate#1 Hole Section: a. PU enough 5"drill pipe to drill the 12-1/4"first intermediate hole. b. Test 13-3/8" casing to 250 psi for 5 minutes / 3,500 psi for 30 minutes after cement reaches a minimum of 500 psi compressive strength. c. MU 12-1/4"drilling assembly with MWD/GR/RES tool string. d. RIH and tag float collar or TOC. Drill out all but 10 ft of shoe track and then displace to 9.6 ppg LSND mud. Drill out remainder of shoe track. e. Drill at least 20' but no more than 50'of new formation and CBU. f. Pull inside casing and perform LOT. g. Drill ahead per directional plan. Ensure mud weight is increased to a minimum of 10.5 ppg at least 200'above the CM3. h. Continue drilling to the 9-5/8" intermediate 1 casing point which is at HRZ. CBU as needed for cutting samples to properly identify HRZ. i. At casing point, circulate hole clean and condition mud as needed. j. Perform wiper trip, bringing ghost reamer up to the previous casing shoe. k. Run back to bottom, circulate hole clean and condition mud for running 9-5/8"casing. I. POOH and LD BHA. If backreaming is necessary, trip back to TD and POH on elevators for final trip out. 5. Run and Cement 9-5/8" Intermediate Casing: a. Change rams to 9-5/8"FBRs in upper cavity. Test to 250 psi/4,000 psi. b. Run 9-5/8", 47 ppf, L-80, VT intermediate casing. c. Stage pumps up and condition mud for cement job. Cement with 15.8 ppg Class G Tail and 11.5 ppg lead cement. d. Immediately following the plug bump, initiate injection down the OA by pumping 5 bbls of drilling fluid to ensure annulus remains open for freeze protection. Continue to pump 3 - 5 bbls of drilling fluid down the OA every hour until the lead cement reaches 500 psi compressive strength. e. Install casing pack-off and test per FMC representative's procedures/instructions. f. RD cementing equipment and flush stack. g. Change rams to 2-7/8" x 5"VBR in upper cavity. Test to 250 psi/4,000 psi. h. Freeze-protect the 13-3/8"x 9-5/8"annulus once the cement has reached 500 psi compressive strength. 6. Drill 8-112" Intermediate#2 Hole Section: a. PU additional 5"drill pipe as required to drill the 8-1/2" second intermediate hole. b. MU 8-1/2"drilling assembly with MWD/GR/RES/GAB tool string. 2 • • c. Once the lead cement has reached 500 psi compressive strength, pressure test 9-5/8 casing to 4,000 psi for 30 minutes. d. RIH and tag float collar or TOC. Drill out all but 10 ft of shoe track, and then displace to 10.3— 10.5 ppg LSND mud. Drill out remainder of shoe track. e. Drill at least 20' but no more than 50'of new formation and CBU. f. Pull inside casing and perform the FIT. g. Continue drilling to the intermediate 2 casing point at TLSB. CBU as needed for cutting samples to properly identify Lisburne boundary. h. At casing point, circulate hole clean and condition the mud as needed. i. Perform wiper trip to the previous casing shoe. j. Run back to bottom, circulate hole clean and condition mud for running the 7" liner. k. POOH and lay down the BHA. If backreaming is necessary, trip back to TD and POH on elevators on the final trip. 7. Run and Cement 7" Intermediate/Production Liner: a. Change rams to 7" FBRs rams in the upper cavity. Test to 250 psi/4,000 psi. b. Run 7", 26 ppf, L-80,,VAM Top HC intermediate liner with 150' lap into the 9-5/8"casing shoe. c. Stage pumps up and condition mud for cement job. Cement to the TOL with 15.8 ppg Class G cement. d. Set the liner hanger and liner top packer. LD Liner running tool. e. Change rams to 2-718" x 5"VBRs in upper cavity. Test to 250 psi/4,000 psi. 8. Drill 6-1/8" Production Hole Section: a. PU enough 4"and 5"drill pipe to drill the 6-1/8" production hole. b. Test 7" liner to 250 psi for 5 minutes/4,000 psi for 30 minutes after cement reaches a minimum of 500 psi compressive strength. c. Make-up 6-1/8"drilling assembly with MWD/GR/RES/NEU/DEN/PEF/Image/Neutron Caliper. d. RIH and tag landing collar or TOC. Displace to 8.5 ppg Flo-Pro SF fluid before drilling the shoe track. e. Perform a 30 min no-flow test with 8.5 ppg fluid. f. Drill at least 20' but no more than 50' of new formation and CBU. g. Pull inside casing and perform the FIT. h. Drill ahead to TD per directional plan and rig site geologist as bit performance allows. POOH to replace bit if required. i. At casing point, circulate hole clean and condition the mud as needed. j. Perform wiper trip to the previous casing shoe. k. Run back to bottom, circulate hole clean and condition mud for running casing. I. POOH, LD excess 4"drill pipe and BHA. 9. Run and Cement 4-1/2" Production Liner: a. Run 4-1/2", 13.5 ppf, 13Cr-85, Hydril 521 production liner with 150 ft lap into the 7" liner shoe. b. Drop toe circulating valve (TCV) ball and set the liner hanger and liner top packer. Displace well to clean seawater above the liner top. c. Pressure test 9-5/8"casing x 7" liner x 4-1/2" liner to 4,000 psi for 30 minutes. d. POOH, LD liner running tool. 10. Run 4-1/2"Completion: a. RU and run a 4-1/2", 12.6 ppf, 13Cr-85, VamTop completion. Space out and land the tubing with the tubing tail inserted into the liner tie back sleeve. Run in lock down screws. 3 • • b. Displace well to seawater completion fluid through the IA. c. Drop ball and rod with rollers to RHC plug. d. Test tubing to 250 psi for 5 minutes and then set production packer with 4,000 psi. e. Hold 4,000 psi for 30 minutes for tubing pressure test. f. Bleed tubing pressure down to below 2,000 psi. g. Pressure test IA to 250 psi for 5 minutes/4,000 psi for 30 minutes. Bleed down Tubing to 0 psi and shear DCR-1. Pump both ways to confirm shear. h. Pump enough diesel freeze protect fluid into the IA to protect to 2,200 ft TVD on both tubing and IA. i. RU jumper line between tubing and IA to allow diesel to U-tube into tubing. 11. Nipple Down BOPE/Nipple Up Production Tree and Freeze Protect: a. Install WC and test. Nipple down BOPE. b. N/U the tubing head adapter flange and dry hole tree. c. Test tubing head adapter flange and tree to 250 psi for 5 minutes/5,000 psi d. Install VR plugs in the annulus valves as needed and secure the well. Ensure that both IA and OA are protected by two barriers. 12. Release Rig: a. Rig down and move off location. Troy Jakabosky Drilling Engineer bp 900E. Benson Blvd.Cube 748C Anchorage,AK 99508 Office 907.564.4868 Cell 907.632.2609 4 • • i �I 1 ,a g _ gA' '3 '‘.1 x;a I. a - :16 a aq! a af Ose, k $$gb eu WaoI� -jag 51 A 11,41 ..RI! '' i 11111 _ 4 K "a," g ..333 %3332.2 a= 31ax 13�I�I p( nn F h aj •":2"0.1 !-f^13 7777 .'f'fM w LL����':,.. ...�. � �_ _ tin � `�—_ p G tsi 2 2 4$ $ PA PA 1A1 gli 1 i WAS W:SM 3! II ilr 111 ; till l�'" t J \per I 'It►',4'I�Illiai'd —_---- — 1 U I C SLIC.4illb PX a! - z . 1'aiitii B. 1111i1N111 gwwai Iii I iii I g $g29 .g. i liii � ta2 tbaa o it W (1310 INTIM'9330 3't °N yM ,i,:- e, u -.ie 1, 40 --AA C-,9 NV t-ti ,t/1 of-,a C $ .t/1 o-.a 0 1 $ fun Nowna) tPD LOF 7, r \\ 11/j,"s THE STATE S Alaska Oil and Gas �. /\ Conservation Commission LSKA -£ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 . M O Main: 907.279.1433 ALAS1' Fax: 907.276.7542 www.aogcc.alaska.gov Frank Roach Drilling Engineer BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU L1-13 BP Exploration(Alaska), Inc. Permit to Drill Number: 216-003 Surface Location: 2541' FSL, 2801' FEL, SEC. 01, T11N, R14E, UM Bottomhole Location: 4367' FNL, 1245' FEL, SEC. 10, T11N, R14E, UM Dear Mr. Roach: 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, et Cathy P Foerster Chair DATED this z_z)day of January, 2016. RECEIVED STATE OF ALASKA Eir SKA OIL AND GAS CONSERVATION COMMIS JAN 05 2016 PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: lb. Proposed Well Class: Exploratory-Gas 0 Service-WAG 0 Service-Disp 0 1 c.S c likpeoQed for: Drill IZI• Lateral 0 Stratigraphic Test 0 Development-Oil 0 ' Service-Winj 0 Single Zone 121* Colabed Gas 0 Gas Hydrates 0 Redrill 0 Reentry ❑ Exploratory-Oil 0 Development-Gas 0 Service-Supply 0 Multiple Zone 0 Geothermal 0 Shale Gas 0 2. Operator Name: 5. Bond Blanket 0 Single Well ❑ 11. Well Name and Number: BP Exploration(Alaska),Inc Bond No. 6194193 • PBU L1-13• Address: 12. Field/Pool(s): 3. 6. Proposed Depth: P.O.Box 196612 Anchorage,AK 99519-6612 MD: 16605'• TVD: 8861' • PRUDHOE BAY,LISBURNE OIL • 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): ADL 028302&028303 s Surface: 2541'FSL,2801'FEL,Sec.01,T11N,R14E,UM 8. Land Use Permit: 13. Approximate spud date: 1112'FNL,5143'FEL,Sec.11,T11N,R14E,UM 84-62 March 25,2016 Top of Productive Horizon: Total Depth: 4367'FNL,1245'FEL,Sec.10,T11N,R14E,UM 9. Acres in Property: 2560 14.Distance to Nearest Property: 16500 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above MSL: 61.1•feet 15. Distance to Nearest Well Open Surface:x- 688601 ' y- 5974894 ' Zone - ASP 4 GL Elevation above MSL: 12.7.feet to Same Pool: 3400 16. Deviated wells: Kickoff Depth: 500 feet 17. Maximum Anticipated Pressures in psig(see 20 MC 25.035) Maximum Hole Angle: 93 degrees Downhole: 3473 • Surface: 2616 • 18. Casing Program: Specifications Top-Setting Depth-Bottom Cement Quantity,c.f,or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42 20" 129# A-53 80' Surface Surface 80' 80' 260 sx Arctic Set(Aoorox.) 16" 13-3/8" 68# L-80 BTC , 5231' Surface Surface 5231' 3717' 2675 sx DeepCrete,312 sx Class'G' 12-1/4" 9-5/8" 47# L-80 VamToo 12049' Surface Surface 12049' 7981' 1424 sx LiteCrete,218 sx Class'G' 8-1/2" 7" 26# L-80 VamTogHC 932' 12073' 8001' 13005' 8778' 225 sx Class'G' 6-1/8" 4-1/2" 12.6# 13Cr85 Hydril521 3760' 12845' 8655' 16605' 8861' Uncemented Sliding 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): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Porfnrafinn north MD(r)• I Porfnratir n north'run(ft). 20.Attachments Property Plat 0 BOP Sketch El Drilling Program El Time v.Depth Plot 0 Shallow Hazard Analysis 0 Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program 0 20 MC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Date 22.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated Contact Jakaboskv,Troy from without prior written approval. Email Troy.Jakabosky@bp.com Printed Name Frame.. oath Title Drilling Engineer Signature / Q Phone +1 907 564 4373 Date 0//0.6/Z0/6 < Commission Use Only Permit to Drill �,�E rmit Approval I� See cover letter for other Number: �1�j "� API Number: 50 -2353"'fit'`bate: Il�� requirements: / Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: lId Other: i3 OP -"C 5.-f" to 4VC2 (7 S/ / Samples req'd: Yes 0/ No Q Mud log req'd: Yes ❑J/ No r$nil til a rp r V«h -t✓ 71-e-5-i- H2S measures Yes Y No 0 Directional svy req'd: Yes IBJ No 0 to Z50u pr-t) / Spacing exception req'd: Yes 0 No Fid Inclination-only svy req'd: Yes 0 No C� Fl e",.. p e-(lt we.- r•ved 1171,6 i Civ 'litJ Pyr 2Ubri3C W a b'Vtr fr' F77- o t/r d f 7 st!/�t✓w/'11 '2,� t -0i 01,Post lnitr a�inleu on NIT req'd: Yes 0 No le :'va!yet r riS a-Fd-z � G t'n c r C c wr re,f J o b, V APPROVED BY Approved b . v COMMISSIONER THE COMMISSION Date:/_ �� ORI INAL Form 10-401 Revised 11/2015 This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit Form and 4 // 1/7-1- '! G ( . Attachments inDuplicate kap • To: Alaska Oil&Gas Conservation Commission From: Troy Jakabosky, ODE Date: January 5, 2016 Re: L1-13 Permit to Drill The L1-13 well is scheduled to be drilled by Parker 272 in March 2016. This grassroots well is a producer targeting the Lisburne formation. The planned well is a four string design using a 13-3/8"surface casing, 9-5/8"first intermediate casing, 7" second intermediate liner, and 4-1/2" production liner. The surface casing will be set in the SV4 shale. The first intermediate casing will be set at the top of the HRZ. The second intermediate liner will be set at the top Lisburne, and the production liner will be set will be set at the top Lisburne with the toe of the well extending into the Kavik. The production interval will be completed with a cementless liner, and the well will be acid stimulated and possible fracture stimulated post rig. .7iiO Y P P` P P P1 � T.= m antici a ed rface press a from the Lisburne with a full column of gas from TD to surface is :1 psi assumes 7 ppg EMW most likely pore pressure and a 0.1 psi/ft gas gradient). The well will b- drilled Parker 272 using their 5,000 psi four preventer BOP stack(3 rams and an annular). The BOP r- ill be tested to 4,000 psi and the annular will be tested to 3,500 psi. A detailed operations summary is included with the permit application. In addition to a planned well summary, a directional plan and proposed completion diagram is attached to the permit application. If there are any questions concerning information on L1-13, please do not hesitate to use the contact information below. Troy Jakabosky Office: (907) 564-4868 Cell: (907)632-2609 Email: trov.iakaboskv(c�bp,com Attachments: L1-13 Wellbore Schematic Directional Plan As-Staked Survey BOPE Equipment/Diverter Schematics Well Head Schematic Tree Schematic L1-13 PTD Page 1 1/5/2016 • Planned Well Summary Well L1-13 Well Producer Target Lisburne Type Objective Current Status Grass Roots Well Estimated Start Date: 3/25/2016 Time to Complete: 50.2 Days Surface Northing Easting Offsets TRS Location 5,974,893.89 688,601.06 2541' FSL/2801.1' FEL 11N 14E Sec 1 Northing Easting TVDss Offsets TRS T1 5,971,053.2 681,074.6 8,712 1112' FNL/5143' FEL 11N 14E Sec 11 TLSB TD 5,967,766.9 679,776.9 8,800 4366.6' FNL/ 1244.9' FEL 11N 14E Sec 10 BHL Planned KOP: 500' MD Planned TD: 16,604' MD / 8,800' TVDss Rig: Parker 272 GL-RT: 47.1 RTE (ref MSL): 61.1 Directional — Baker wp02 KOP: 500' MD -60° in the first intermediate section Maximum Hole Angle: -40.0° in the second intermediate section -92° in the production section Close Approach Wells: None Survey Program: Surface to 970' MD= GYRO 970' MD to TD = MWD+IFR+MS Nearest Property Line: -16,500' Nearest Well within Pool: -3,400' L1-13 PTD Page 2 1/5/2016 • • Formation Tops & Pore Pressure Estimate (SOR) Estimated Minimum Most Likely Fluid i(‘ed 6C)-e; Formation Formation Top Pore Pressure Pore Pressure Type (TVDss) (EMW pp.) (EMW pp.) (for sands) CPt'' 61 505 8.4 8.4 N/A , 7 - c� ,�/ BPF 1,812 8.4 8.4 N/A �' SV6 2,425 8.4 8.6 water SV5 3,107 8.4 8.6 water SV4 3,358 8.4 8.6 water SV3 3,796 8.4 8.4 water q/ r /6 SV2 3,953 8.4 8.4 water ! (o SV1 4,325 8.4 8.4 water UG4 4,772 8.4 9.3 water UG4A 4,802 8.4 9.3 water UG3 5,005 8.4 9.3 water UG1 5,435 8.4 9.3 water UG_MA 5,925 8.4 9.3 water UG_MB1 5,980 8.4 9.3 water UG_MB2 6,031 8.4 9.3 water UG_MC 6,096 8.4 9.3 water WS2 6,066 8.5 9.3 N/A WS1 6,252 8.5 9.3 N/A ' CM3 6,488 9.8 10.2 possible /Vse V`./(e hydrocarbons 7 CM2 6,904 9.8 10.2 possible hydrocarbons CM1 7,458 9.8 10.2 possible hydrocarbons THRZ 7,789 9.6 10.3 N/A / ..4(• - /4 Possible PUT 7,970 7.8 8.3 N/A /DMZ -/t" LCU 7,980 9.6 9.9 N/A TKNG 7,980 9.6 9.9 N/A TSGR 8,065 7.8 8.2 gas TSHU 8,115 7.8 8.1 gas TSAD 8,165 7.1 8.1 gas TCGL 8,265 7.1 8.0 gas BCGL 8,325 7.1 8.0 gas TZ2B 8,359 7.1 8.0 gas TZ2A 8,461 7.1 7.9 gas TZ1B 8,526 7.1 7.8 gas TDF 8,563 7.1 7.8 gas BSAD/TKVK 8,596 9.8 9.9 N/A KAVIK 8,596 9.8 9.9 N/A TLSB 8712 5.5 7.4 oil 63. 9 A) L1-13 PTD Page 3 1/5/2016 • • Casing/Tubing Program Hole Liner/ Wt/Ft Grade Conn Length Top Bottom Size Tbg O.D. MD/TVDss MD/TVDss 42" 20"x 34" 129# A-53 - 80' Surface 94'/80' 16" 13-3/8" 68# L-80 BTC 5,231' Surface 5,231'/3,656' 12-1/4" 9-5/8" 47# L-80 VamTop 12,049' Surface 12,049'/7,920' 8-1/2" 7" 26# L-80 VamTop HC 1106' 11 899/7'789 13,005'/8,717' (150' lap) 6-1/8" 4'/" 12.6# 13Cr-85 Hydril 521 3,760' 12,845',/8,594' 16,605/8,800' (150' lap) Tubing 4 '/z" 12.6# 13Cr-85 VamTop 12,850' Surface 12,850'/8,597' (-5' into liner TBS) Mud Program Surface Mud Properties: MMO 16" hole section Depth Interval Density PV YP API FL LSR-YP pH (ppg) (cp) (Ib/100ft2) (2x3-6)rpm Surface -5,231' MD 8.7-9.4 6-20 35-80 <15 25-60 10- 11 Intermediate 1 Mud Properties: LSND 12-1/4" hole section Depth Interval Density P ( YP API FL HTHP FL MBT pH (cp) YP 5,231' MD- 10,187' MD 9.6- 10.0 10-15 20-30 <8 NA <20 8.5 -9.5 10,187' MD- 11,698' MD 10.4- 11.0 10-15 20-30 <8 NA <20 8.5-9.5 11,698' MD- 12,049' MD 10.4- 11.0 10-15 20-30 <5 <10 <20 8.5-9.5 Intermediate 2 Mud Properties: LSND 8-1/2" hole section Depth Interval D(ppgjy P ( YP API FL HTHP FL MBT pH (cp) YP 12,049' MD- 13,005' 10.2- 10.7 10-15 18-25 <5 <10 <20 8.5-9.5 MD Production Mud Properties: Water Based Polymer Fluid (FloPro) 6-1/8" hole section PV YP Depth Interval p(pP9)y (cp) (Ib/OOft2) API FL HTHP FL MBT pH 13,005' MD-TD 8.5-9.0 <8 12-20 <12 NA <4 8.5-9.5 Logging Program 16" Surface: Drilling: Dir/GR Open Hole: None Cased Hole: None 12-1/4" Intermediate 1: Sample Catchers-as required by Geology Drilling: Dir/GR/Res Open Hole: None Cased Hole: None L1-13 PTD Page 4 1/19/2016 • 8-1/2" Intermediate 2: Sample Catchers-as required by Geology Drilling: DIR/GR/GR at bit/Res Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers-as required by Geology Drilling: GR/Res/Neu/Den/Pef/Image/Neutron Caliper Open Hole: None Cased Hole: None Cement Program Casing Size 13-3/8" 68#, L-80 BTC, Surface Casing Lead: Open hole volume+ 350% excess in permafrost and 40% excess below permafrost Basis: Lead TOC: Target surface Tail: Open hole volume+40% excess+80 ft shoe track Tail TOC: 500 ft MD above casing shoe Total Cement Spacer -100 bbls of Viscosified Spacer weighted to-10.5 ppg (Mud Push II) Volume: Lead 910 bbls, 5109 cuft, 2675 sks of 11.0 ppg DeepCRETE, Yield: 1.91 cuft/sk Tail 64.4 bbls, 362 cult, 312 sks 15.8 lb/gal Class G- 1.16 cuft/sk Temp BHST 74° F Casing Size 9-5/8"47#, L-80 VamTop, Intermediate Casing Lead: Open hole volume +40%excess Basis: Lead TOC: Target 656 ft MD above SV1 Tail: Open hole volume+40%excess+ 80 ft shoe track Tail TOC: 500 ft MD above casing shoe Total Cement Spacer -50 bbls of Viscosified Spacer weighted to-11.0 ppg (Mud Push II) Volume: Lead 441.2 bbls, 2477 cuft, 1424 sks of 11.5 ppg LiteCRETE, Yield: 1.74 cuft/sk Tail 44.9 bbls, 252 cult, 218 sks 15.8 lb/gal Class G- 1.16 cuft/sk Temp BHST 135° F Casing Size 7" 26#, L-80 VAM TOP HC, Intermediate Liner Basis: Tail: Open hole volume+40% excess+ 80 ft shoe track+150 ft liner lap+200 ft DP x Csg Total Cement Spacer -35 bbls of Viscosified Spacer weighted to-12.0 ppg (Mud Push II) Volume: Lead N/A Tail 46.9 bbls, 263 cult, 225 sks 15.8 lb/gal Class G- 1.17 cuft/sk Temp BHST 150° F Casing Size 4-1/2" 13.5#, 13Cr-85 HYD 521 Production liner Basis: Sliding Sleeve/Swell Packer Cementless Completion Total Cement N/A N/A Volume: Lead N/A Tail N/A Temp N/A L1-13 PTD Page 5 1/19/2016 • • Surface and Anti-Collision Issues Surface Close Proximity: No wells will be affected by the Parker 272 rig shadow. Sub-Surface Pressure Management: Cretaceous: Evaluate that there has been no significant change in injection in LPC-01 and LPC-02 that would impact our pore pressure prediction for this interval. If injection rates have significantly changed in disposal wells, re-assess impact on PPFG. Ivishak: SBHP in one of the following wells, in order of preference, NGI-08, WGI-02, WGI-06. Compare predicted pressure with FFM pressure. If SBHP gives pressure out of range of that which was predicted or FFM range is out of expected pore pressure range, expected pore pressure will need to be modified, - and PPFG re-calculated. Lisburne: SBHP in L1-15A. If SBHP gives pressure out of range of that which was predicted, expected pore pressure will need to be modified, and PPFG re-calculated. Anti-Collision: Wp02 has one well that fails major risk criteria. PRUDHOE BAY ST1 /PRUDHOE BAY ST1 PB1 has been fully P/A and is fully cemented. - Hydrogen Sulfide - L1-Pad is not considered an H2S site. Recent H2S data from the pad is as follows: Well Name H2S Level Date of Reading #1 Closest SHL Well H2S Level L1-15(Lisburne) 20 ppm I 12/17/2014 #2 Closest SHL Well H2S Level L1-09(Lisburne) 50 ppm 4/4/2014 #1 Closest BHL Well H2S Level NGI-08(Ivishak) n/a n/a #2 Closest BHL Well H2S Level 18-11B(Ivishak) 0 ppm 10/1/2014 #3 Closest BHL Well H2S Level WGI-07 n/a n/a (Ivishak) #4 Closest BHL Well H2S Level L1-09(Lisburne) 50 ppm 4/4/2014 Max Recorded H2S on Pad/Facility L1-09(Lisburne) 50 ppm 4/4/2014 Faults Formation Where MD TVDss Throw Direction and Lost Circ Encounter Fault Intersect Intersect Magnitude Uncertainty Potential Fault#1: Lisburne 13,438.0 8,928.0 30-40 SW ±150 Med - High Fault#2: Lisburne 13,895.0 8,919.0 30-40 S ±150 Med - High Fault#3: Lisburne 14,510.0 8,892.0 80-100 N ±150 Med - High Fault#4: Lisburne 15,281.0 8,858.0 35-45 S ±150 Med - High Fault#5: Top of 16,400.0 8,808.0 50-70 S ±150 Med - High Lisburne 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) f/guidance. L1-13 PTD Page 6 1/5/2016 • • Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 4 000psi, except annular at 3500 � p psi. BOP test frequency for L1-13 will be 14 days with a function test occurring every 7 days. Except in the event of a significant operational issues that may affect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. Intermediate 1 Interval Maximum anticipated BHP 3,023 psi at the WS1 at 6,252' TVDss (9.3 ppg EMW) Maximum surface pressure 2,398 psi at the WS1 (0.10 psi/ft gas gradient to surface) 25 bbls with 11.52 ppg frac gradient. Kick tolerance Assumes 9.3 ppg pore pressure in the WS1 + 0.5 ppg kick intensity and 10.5 ppg MW. Planned BOP test pressure Rams test to 4,000 psi/250 psi. Annular test to 3,500 psi/250 psi Integrity Test—12-1/4" hole LOT after drilling 20'-50' of new hole 9-5/8" Casing Test 4,000 psi surface pressure Intermediate 2 Interval Maximum anticipated BHP 3,473 psi at the TDF at 8,563'TVDss (7.8 ppg EMW) Maximum surface pressure 2,616 psi (0.10 psi/ft gas gradient to surface) • 25 bbls with > 11.29 ppg frac gradient. Kick tolerance Assumes 7.8 ppg pore pressure in the TDF + 0.5 ppg kick intensity and 10.5 ppg MW. Planned BOP test pressure Rams test to 4,000 psi/250 psi. Annular test to 3,500 psi/250 psi 7" Liner Top Packer 4,000 psi surface pressure Integrity Test—8-1/2" hole FIT after drilling 20'-50' of new hole 7" Casing Test 4,000 psi surface pressure Production Interval Maximum anticipated BHP 3,352 psi in the TLSB at 8,712' TVDss (7.4 ppg EMW) • Maximum surface pressure 2,481 psi (0.10 psi/ft gas gradient to surface) Infinite with >8.79 ppg frac gradient. Kick tolerance Assumes an 7.4 ppg max pore pressure in the TLSB + 0.5 ppg kick intensity and 8.5 ppg MW. Planned BOP test pressure Rams test to 4,000 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 4,000 psi surface pressure Planned completion fluids 8.5 ppg seawater/2,200 ft diesel to 2,038ft TVDss L1-13 PTD Page 7 1/5/2016 • Variance Requests 1. To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, it is requested to drill without a flow paddle for the first portion of the surface hole. After drilling past the larger rocks and wood sections, the flow paddle will be put back in the flow line (<1000 ft). This is a variance from 20 AAC 25.033. Procedures/Safeguards with paddle removed: Fluid levels will be monitored in the pits for both gains and losses while drilling. Alarms will be set to indicate if gain or loss of more than 5 bbls has occurred. The well will be monitored for flow when the pumps are off at each connection. The planned 8.6 -8.8 ppg fluid will provide over balance to formation fluid. 2. The Lisburne formation is highly faulted/naturally fractured with high lost circulation potential. ECD's while drilling out of 7" shoe will be greater than the required FIT for kick tolerance. Assuming zonal isolation objectives are met on the 7" liner job, and if lost circulation occurs prior to drilling 20 ft. of new formation, it is requested to drill to TD without obtaining a FIT. A similar event occurred in 2015 on L1-23(PTD 215-060) and a variation request was granted. L1-13 PTD Page 8 1/5/2016 ! • L1-13 — Drill and Complete Operations Summary Current Condition and Well History: 1. Install and survey 20" conductor and cellar box. 2. Weld on landing ring. 3. Level pad and prepare location. 4. Confirm cretaceous injection pressures. 5. Validate injection/production in area per SOR. Rig Operations: 1. MIRU Parker 272: a. Survey conductor with rig over it to ensure rig is centered over the hole. b. RU diverter system and test. Notify AOGCC 24 hours in advance of test. 2. Drill 16" Surface Hole Section: a. Take on 8.7 ppg MAXDRIL-N. b. PU enough 5" drill pipe to drill the surface hole. c. Make-up 16" directional drilling assembly with MWD/GR/UBHO tool string. d. Clean out 20" conductor, spud well and directionally drill surface hole to the base of the permafrost. (Gyro until clean MWD surveys). e. At the base of the permafrost circulate hole clean and condition mud as required. f. Perform wiper trip to the top of the HWDP. g. Drill ahead per directional plan. Ensure minimum mud weight is increased to 9.0 ppg at least 200' before reaching the SV6. h. Drill remainder of surface hole to planned casing point at the base of the SV4. i. Circulate hole clean and condition mud as required. j. Perform wiper trip to base of permafrost. k. Trip back to TD, circulate hole clean and condition mud for running 13-3/8" casing. I. POOH and LD BHA. 3. Run &Cement 13-3/8" Surface Casing: a. Run 13-3/8", 68 ppf, L-80, BTC surface casing with Volant tool. Install Torque rings in each connection. b. Cement with 15.8 ppg Class G tail cement and non-freezing cement to surface. - c. Pressure test casing to 3,500 psi for 5 minutes on plug bump. d. RD cementing equipment and flush and RD diverter system. e. NU FMC 13-5/8" 5M New Standard Big Bore wellhead system and test as required. f. NU and pressure test 13-5/8" 5M BOPE. (Configured from top to bottom: 13-5/8" annular preventer, 2-7/8" x 5-1/2" VBRs in the upper cavity, blind/shear rams, mud cross and 2-7/8" x 5- 1/2"VBRs in the lower cavity). ➢ Test rams to 250 psi/4,000 psi with 4" and 5" test joints. ➢ Test annular to 250 psi/3,500 psi with 4" test joint. L1-13 PTD Page 9 1/5/2016 i • 4. Drill 12-1/4" Intermediate#1 Hole Section: a. PU enough 5" drill pipe to drill the 12-1/4"first intermediate hole. b. Test 13-3/8" casing to 250 psi for 5 minutes / 3,500 psi for 30 minutes after cement reaches a minimum of 500 psi compressive strength. c. MU 12-1/4" drilling assembly with MWD/GR/RES tool string. d. RIH and tag float collar or TOC. Drill out all but 10 ft of shoe track and then displace to 9.6 ppg LSND mud. Drill out remainder of shoe track. e. Drill at least 20' but no more than 50' of new formation and CBU. f. Pull inside casing and perform LOT. g. Drill ahead per directional plan. Ensure mud weight is increased to a minimum of 10.5 ppg at least 200' above the CM3. h. Continue drilling to the 9-5/8" intermediate 1 casing point which is at HRZ. CBU as needed for cutting samples to properly identify HRZ. - i. At casing point, circulate hole clean and condition mud as needed. j. Perform wiper trip, bringing ghost reamer up to the previous casing shoe. k. Run back to bottom, circulate hole clean and condition mud for running 9-5/8" casing. I. POOH and LD BHA. If backreaming is necessary, trip back to TD and POH on elevators for final trip out. 5. Run and Cement 9-5/8" Intermediate Casing: a. Change rams to 9-5/8" FBRs in upper cavity. Test to 250 psi/4,000 psi. b. Run 9-5/8", 47 ppf, L-80, VT intermediate casing. c. Stage pumps up and condition mud for cement job. Cement with 15.8 ppg Class G Tail and 11.5 ppg lead cement. d. Immediately following the plug bump, initiate injection down the OA by pumping 5 bbls of drilling fluid to ensure annulus remains open for freeze protection. Continue to pump 3 - 5 bbls of drilling fluid down the OA every hour until the lead cement reaches 500 psi compressive strength. e. Install casing pack-off and test per FMC representative's procedures/instructions. f. RD cementing equipment and flush stack. g. Change rams to 2-7/8" x 5-1/2"VBR in upper cavity. Test to 250 psi/4,000 psi. h. Freeze-protect the 13-3/8" x 9-5/8" annulus once the cement has reached 500 psi compressive strength. 6. Drill 8-1/2" Intermediate#2 Hole Section: a. PU additional 5" drill pipe as required to drill the 8-1/2" second intermediate hole. b. MU 8-1/2" drilling assembly with MWD/GR/RES/GAB tool string. c. Once the lead cement has reached 500 psi compressive strength, pressure test 9-5/8 casing to 4,000 psi for 30 minutes. d. RIH and tag float collar or TOC. Drill out all but 10 ft of shoe track, and then displace to 10.3 — 10.5 ppg LSND mud. Drill out remainder of shoe track. e. Drill at least 20' but no more than 50' of new formation and CBU. f. Pull inside casing and perform the FIT. g. Continue drilling to the intermediate 2 casing point at TLSB. CBU as needed for cutting samples to properly identify Lisburne boundary. h. At casing point, circulate hole clean and condition the mud as needed. i. Perform wiper trip to the previous casing shoe. L1-13 PTD Page 10 1/5/2016 • • j. Run back to bottom, circulate hole clean and condition mud for running the 7" liner. k. POOH and lay down the BHA. If backreaming is necessary, trip back to TD and POH on elevators on the final trip. 7. Run and Cement 7" Intermediate/Production Liner: a. Change rams to 7" FBRs rams in the upper cavity. Test to 250 psi/4,000 psi. b. Run 7", 26 ppf, L-80, VAM Top HC intermediate liner with 150' lap into the 9-5/8" casing shoe. c. Stage pumps up and condition mud for cement job. Cement to the TOL with 15.8 ppg Class G cement. d. Set the liner hanger and liner top packer. LD Liner running tool. e. Change rams to 2-7/8"x 5-1/2"VBRs in upper cavity. Test to 250 psi/4,000 psi. 8. Drill 6-1/8" Production Hole Section: a. PU enough 4" and 5" drill pipe to drill the 6-1/8" production hole. b. Test 7" liner to 250 psi for 5 minutes /4,000 psi for 30 minutes after cement reaches a minimum of 500 psi compressive strength. c. Make-up 6-1/8" drilling assembly with MWD/GR/RES/NEU/DEN/PEF/Image/Neutron Caliper. d. RIH and tag landing collar or TOC. Displace to 8.5 ppg Flo-Pro SF fluid before drilling the shoe track. e. Perform a 30 min no-flow test with 8.5 ppg fluid. f. Drill at least 20' but no more than 50' of new formation and CBU. g. Pull inside casing and perform the FIT. h. Drill ahead to TD per directional plan and rig site geologist as bit performance allows. POOH to replace bit if required. i. At casing point, circulate hole clean and condition the mud as needed. j. Perform wiper trip to the previous casing shoe. k. Run back to bottom, circulate hole clean and condition mud for running casing. I. POOH, LD excess 4"drill pipe and BHA. 9. Run and Cement 4-1/2" Production Liner: a. Run 4-1/2", 13.5 ppf, 13Cr-85, Hydril 521 production liner with 150 ft lap into the 7" liner shoe. b. Drop toe circulating valve (TCV) ball and set the liner hanger and liner top packer. Displace well to clean seawater above the liner top. c. Pressure test 9-5/8" casing x 7" liner x 4-1/2" liner to 4,000 psi for 30 minutes. d. POOH, LD liner running tool. 10. Run 4-1/2" Completion: a. RU and run a 4-1/2", 12.6 ppf, 13Cr-85, VamTop completion. Space out and land the tubing with the tubing tail inserted into the liner tie back sleeve. Run in lock down screws. b. Displace well to seawater completion fluid through the IA. c. Drop ball and rod with rollers to RHC plug. d. Test tubing to 250 psi for 5 minutes and then set production packer with 4,000 psi. e. Hold 4,000 psi for 30 minutes for tubing pressure test. f. Bleed tubing pressure down to below 2,000 psi. g. Pressure test IA to 250 psi for 5 minutes / 4,000 psi for 30 minutes. Bleed down Tubing to 0 psi and shear DCR-1. Pump both ways to confirm shear. L1-13 PTD Page 11 1/5/2016 h. Pump enough diesel freeze protect fluid into the IA to protect to 2,200 ft TVD on both tubing and IA. i. RU jumper line between tubing and IA to allow diesel to U-tube into tubing. 11. Nipple Down BOPE/Nipple Up Production Tree and Freeze Protect: a. Install TWC and test. Nipple down BOPE. b. N/U the tubing head adapter flange and dry hole tree. c. Test tubing head adapter flange and tree to 250 psi for 5 minutes/5,000 psi d. Install VR plugs in the annulus valves as needed and secure the well. Ensure that both IA and OA are protected by two barriers. 12. Release Rig: a. Rig down and move off location. Post-Rig Operations: 1. Change out from dry hole tree to 6,500 psi tree for acid treatment. 2. DSM Pull TWC. 3. MIRU slick line. Pull ball and rod/RHC plug from landing nipple below production packer. 4. Negative pressure test 7" Liner Top 5. Perform acid stimulation. 6. Install GLVs. SBHPS. 7. ASRC Flow Back with N2 assist. 8. Possible two additional service coil interventions within 6 months of POP. 9. PPROF. 10. Install the well house, instrumentation, s-riser. L1-13 PTD Page 12 1/5/2016 L1-13 Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control / Reservoir Pressures: A. Intermediate Hole 1: The UG4 is expected to be a 9.3 ppg EMW. The CM1, CM2 and CM3 are expected to be a 10.2 ppg EMW. Formation pressures will be controlled with a 9.6 — 9.8 ppg mud to drill to within 200' MD of the CM3. At this point, there will be a weight up to 10.4— 11.0 ppg to drill the rest of the interval to TD. B. Intermediate Hole 2: The Ivishak is expected to be at a 8.1 ppg EMW. Reservoir pressures will be controlled with a 10.3— 10.7 ppg mud needed to drill the Kavik. C. Production Hole: The Lisburne is expected to be at a 7.4 ppg EMW. Reservoir pressures will be controlled by using 8.5—9.0 ppg water based mud. II. Lost Circulation/Breathing A. Intermediate Hole 1: There are no expected fault crossings in the first intermediate hole. However, breathing has been known to occur in the Colville on other Drill Sites in Prudhoe Bay as a result of high ECD's. B. Intermediate Hole 2: There are no expected fault crossings in the second intermediate hole. However, the Ivishak will be drilled with a high mud weight/pore pressure differential which increases the likelihood of lost circulation. C. Production Hole: There are 5 expected fault crossings in the production hole. Past wells have experienced severe lost circulation and well bore breathing in the Lisburne. III. Fault Locations Formation Where MD TVDss Throw Direction and Lost Circ Encounter Fault Intersect Intersect Magnitude Uncertainty Potential Fault#1: Lisburne 13,438.0 8,928.0 30-40 SW ±150 Med - High Fault#2: Lisburne 13,895.0 8,919.0 30-40 S ±150 Med - High Fault#3: Lisburne 14,510.0 8,892.0 80-100 N ±150 Med - High Fault#4: Lisburne 15,281.0 8,858.0 35-45 S ±150 Med - High L Fault #5 Top of 16,400.0 8,808.0 50-70 S ±150 Med - High IV. Integrity Testing Test Point Test Depth Test type EMW(lb/gal) 13-3/8" Shoe 20'-50' from the 13-3/8" shoe LOT 11.52 ppg 9-5/8" Shoe 20'-50' from the 9-5/8" shoe FIT 11.29 ppg 7" shoe 20'-50' from the 7" shoe FIT 8.79 ppg V. Hydrogen Sulfide L1-Pad is not considered an H2S site. Recent H2S data from the pad is as follows: Well Name H2S Date of Level Reading #1 Closest SHL Well H2S Level L1-15 (Lisburne) 20 ppm / 12/17/2014 #2 Closest SHL Well H2S Level L1-09(Lisburne) 50 ppm e 4/4/2014 #1 Closest BHL Well H2S Level NGI-08 (Ivishak) n/a n/a #2 Closest BHL Well H2S Level 18-11B (Ivishak) 0 ppm 10/1/2014 #3 Closest BHL Well H2S Level WGI-07 (Ivishak) n/a n/a #4 Closest BHL Well H2S Level L1-09 (Lisburne) 50 ppm 4/4/2014 Max Recorded H2S on Pad/Facility L1-09(Lisburne) 50 ppm 4/4/2014 VI. Anti-Collision Issues Wp02 has one well that fails major risk criteria. PRUDHOE BAY ST1 / PRUDHOE BAY ST1 PB1 has - been fully P/A and is fully cemented. CONSULT THE L1-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. 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CIE c E •o :! — mw c ad ! co ovo . 0 o a • • b p North America - ALASKA - BP Lisburne Lis DS 01 Plan L1-13 Plan L1-13 L1-13 wp02 Anticollision Summary Report 12 February, 2015 grArl atoll" BAKER SLIM' r 0 • BP -MI FAV_ by Anticollision Report BAKER ■-■ J I-■Es Company: North America-ALASKA-BP Local Co-ordinate Reference: Well Plan L1-13 Project: Lisburne TVD Reference: WELL @ 61.10usft(Original Well Elev) Reference Site: Lis DS 01 MD Reference: WELL @ 61.10usft(Original Well Elev) Site Error: 0.00usft North Reference: True Reference Well: Plan L1-13 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore Plan L1-13 Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: L1-13 wp02 Offset TVD Reference: Offset Datum Reference L1-13 wp02 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference 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 1,855.78usft Error Surface: Elliptical Conic ,Survey Tool Program Date 2/12/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 47.10 970.00 L1-13 wp02(Plan L1-13) GYD-GC-SS Gyrodata gyro single shots 970.00 2,300.00 L1-13 wp02(Plan L1-13) MWD MWD-Standard 970.00 5,500.00 L1-13 wp02(Plan L1-13) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 5,500.00 6,700.00 L1-13 wp02(Plan L1-13) MWD MWD-Standard 5,500.00 12,258.00 L1-13 wp02(Plan L1-13) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 12,258.00 13,003.00 L1-13 wp02(Plan L1-13) MWD MWD-Standard 12,258.00 13,003.00 L1-13 wp02(Plan L1-13) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 13,003.00 14,800.00 L1-13 wp02(Plan L1-13) MWD MWD-Standard 13,003.00 16,604.92 L1-13 wp02(Plan L1-13) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 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 9 (usft) (usft) (usft) (usft) Lis DS 01 L1-01-L1-01-L1-01 1,671.50 1,650.00 328.92 30.20 298.72 Pass-Major Risk L1-01-Plan#119 L1-01A-Plan#119 1,671.50 1,650.00 328.92 30.20 298.72 Pass-Major Risk L1-01-Plan#119 L1-01A-Plan#119 L1-01A 47.10 47.10 359.86 1.22 358.64 Pass-Major Risk L1-09-L1-09-L1-09 1,269.07 1,250.00 111.26 19.78 91.49 Pass-Major Risk L1-10-L1-10-L1-10 508.91 500.00 196.74 9.64 187.09 Pass-Major Risk L1-14-L1-14-L1-14 579.75 575.00 177.06 10.08 166.98 Pass-Major Risk L1-15-L1-15-L1-15 783.62 775.00 61.64 14.69 46.95 Pass-Major Risk L1-15-L1-15A-L1-15A 783.62 775.00 61.64 14.69 46.95 Pass-Major Risk L1-15-L1-15A-Plan#20e 783.62 775.00 61.64 14.69 46.95 Pass-Major Risk L1-15-L1-15APB1-L1-15APB1 783.62 775.00 61.64 14.69 46.95 Pass-Major Risk L1-21-L1-21-L1-21 678.70 675.00 237.38 14.17 223.21 Pass-Major Risk NGI NGI-08-NGI-08-NGI-08 12,590.00 10,925.00 839.53 262.87 690.24 Pass-Major Risk PB DS 15 15-16-15-168-15-16B 16,400.01 14,625.00 237.51 332.14 6.84 Pass-Major Risk PRUDHOE BAY ST 1 PRUDHOE BAY ST 1-PRUDHOE BAY ST 1-PB 14,564.44 9,000.00 793.45 17,261.69 -16,400.99 FAIL-Major Risk PRUDHOE BAY ST 1-PRUDHOE BAY ST 1 PB1 14,582.34 8,593.00 858.89 11,856.55 -10,054.32 FAIL-Major Risk WGI WGI-01-WGI-01-WGI-01 7,097.04 5,025.00 779.84 120.68 665.07 Pass-Major Risk WGI-02-WGI-02-WGI-02 7,977.69 5,600.00 544.89 225.81 361.15 Pass-Major Risk WGI-03-WGI-03-WGI-03 6,743.73 5,075.00 954.23 167.27 790.02 Pass-Major Risk WGI-09-WGI-09-Plan WGI-09 Wp 6 7,087.33 4,900.00 400.35 130.06 275.26 Pass-Major Risk WGI-09-WGI-09-WGI-09 7,101.64 4,925.00 401.84 122.11 286.78 Pass-Major Risk 2/12/2015 11:26:45AM Page 2 of 3 COMPASS 5000.1 Build 61 • • BP -alili_ by Anticollision Report BAKER u-■u6NE5 Company: North America-ALASKA-BP Local Co-ordinate Reference: Well Plan L1-13 Project: Lisburne TVD Reference: WELL @ 61.10usft(Original Well Elev) Reference Site: Lis DS 01 MD Reference: WELL©61.10usft(Original Well Elev) Site Error: 0.00usft North Reference: True Reference Well: Plan L1-13 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore Plan L1-13 Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: L1-13 wp02 Offset TVD Reference: Offset Datum Reference Depths are relative to WELL @ 61.10usft(Original Well Coordinates are relative to:Plan L1-13 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04 Central Meridian is 150°0'0.00 W° Grid Convergence at Surface is 1.44° Ladder Plot I 1800— - �I , 1 i 1 / �'% �. r_ , r' -_J_-I_ ! III! __1____ 19i' _J e /1J _I I �i_ _ Ifi1- 1 1 1350— f8,,- dill L rn Tr up UP C -- _. _ J_—_ - J__—_ — ;TL' _—__ . J L J J O i 1 La lig Q ''71 (n 900— _ �' 4 ' A o rr J N (p� O NI I �. 2 ii► , 450— _1 s.i d P I C) .y I- I J J J J 1 I .`!''.! I I 0 I I I I I 0 3000 6000 9000 12000 15000 18000 Measured Depth(3000 usft/in) LEGEND VD L1-15,L1-15A,Plan#20e V2 - - 15-37,15-37C,15-37C V0 1E BPB1 VO L1-15,L1-15APB1,L1-15APB1 V1 —0-- PRUDHOEBAY ST1,PRUDHOEBWI 1 -e- L1-21,L1-21,L1-21 V1 PRUDHOE BAY ST 1,PRUDHOE BM A Plan#119 V2 NGI-08,NG1-08,NG1-08 V2 — VVG1-0I,VVG1-0I,VVG1-01V5 A,PIan#119L1-01 AVO $ 15-36,15-36,15-36 V1 VvG1-132,WG1-02,VVG1-02V1 1 - 15-36,15-36A,15-36A V2 \VG 1-03,VVG l-03,WG 1-03 V1 1 —I— 15-36,15-36APB1,15-36APB1 V3 VVG 1-09,VVG 1-09,Plan VVG l-09 VVp 6 V 1 1 -3f- 15-36,15-36B,15-36B V7 VVGI-09,VVGl-09,VVG1-09V7 1 $ 15-36,15-36BPB1,15-36BPB1 V8 -e- L1-13wo02 2/12/2015 11:26:45AM Page 3 of 3 COMPASS 5000.1 Build 61 • • by North America - ALASKA - BP Lisburne Lis DS 01 Plan L1-13 Plan L1-13 L1-13 wp02 plus 500' MD Anticollision Summary Report 16 December, 2015 rrr�u BAKER HUGHES • • _ ,e4#,. BP F/11111 0.04l', bp Anticollision Report BAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well Plan L1-13 Project: Lisburne TVD Reference: WELL©61.10usft(Original Well Elev) Reference Site: Lis DS 01 MD Reference: WELL @ 61.10usft(Original Well Elev) Site Error: 0.00usft North Reference: True Reference Well: Plan L1-13 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore Plan L1-13 Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: L1-13 wp02 plus 500'MD Offset TVD Reference: Offset Datum Reference L1-13 wp02 plus 500'MD Filter type: NO GLOBAL FILTER:Using user defined selection&filtering criteria 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 200.00usft Error Surface: Elliptical Conic Survey Tool Program Date 12/16/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 47.10 970.00 L1-13 wp02 plus 500'MD(Plan L1-13) GYD-GC-SS Gyrodata gyro single shots 970.00 2,300.00 L1-13 wp02 plus 500'MD(Plan L1-13) MWD MWD-Standard 970.00 5,232.00 L1-13 wp02 plus 500'MD(Plan L1-13) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 5,232.00 6,700.00 L1-13 wp02 plus 500'MD(Plan L1-13) MWD MWD-Standard i 5,232.00 12,223.00 L1-13 wp02 plus 500'MD(Plan L1-13) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 12,223.00 13,005.00 L1-13 wp02 plus 500'MD(Plan L1-13) MWD MWD-Standard 12,223.00 13,005.00 L1-13 wp02 plus 500'MD(Plan L1-13) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 13,005.00 14,800.00 L1-13 wp02 plus 500'MD(Plan L1-13) MWD MWD-Standard 13,005.00 17,104.92 L1-13 wp02 plus 500'MD(Plan L1-13) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 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) Lis DS 01 L1-09-L1-09-L1-09 1,269.07 1,250.00 111.26 19.78 91.49 Pass-Major Risk L1-10-L1-10-L1-10 508.91 500.00 196.74 9.64 187.09 Pass-Major Risk L1-14-L1-14-L1-14 579.75 575.00 177.06 10.08 166.98 Pass-Major Risk L1-15-L1-15-L1-15 783.62 775.00 61.64 14.69 46.95 Pass-Major Risk L1-15-L1-15A-L1-15A 783.62 775.00 61.64 14.69 46.95 Pass-Major Risk L1-15-L1-15A-Plan#20e 783.62 775.00 61.64 14.69 46.95 Pass-Major Risk L1-15-L1-15APB1-L1-15APB1 783.62 775.00 61.64 14.69 46.95 Pass-Major Risk Plan L1-13-Plan L1-13-L1-13 wp02 12,800.00 12,800.00 0.00 266.91 -171.25 FAIL-Major Risk PB DS 15 15-16-15-16B-15-16B 16,410.53 14,550.00 195.11 332.45 29.52 Pass-Major Risk IP L 'i. ' ' L'AILFD--;K.Q1) 'LT Liii'...-\\(.0,c9,11( g -- - ' ---11- MI I 12/16/2015 1:50:18PM Page 2 of 3 COMPASS 5000.1 Build 61 • r • • 4�... BP FARE I hu Anticollision Report BAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well Plan L1-13 Project: Lisburne TVD Reference: WELL @ 61.10usft(Original Well Elev) Reference Site: Lis DS 01 MD Reference: WELL @ 61.10usft(Original Well Elev) Site Error: 0.00usft North Reference: True Reference Well: Plan L1-13 Survey Calculation Method: Minimum Curvature Well Error: 0.O0usft Output errors are at 1.00 sigma Reference Wellbore Plan L1-13 Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: L1-13 wp02 plus 500'MD Offset TVD Reference: Offset Datum Reference Depths are relative to WELL @ 61.10usft(Original Well Coordinates are relative to:Plan L1-13 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:1.44° Ladder Plot i I I 200— — ----'— — 1. I 1 I { i I 1 1 1 1 J _IJ _II J I 1 - 1 I 1 1 w 150— I 1 m 0 J J J J J 1 .16 • I eL cn 100 112C a> U -- ti J J J J J _1 O C 0 50 . o 1 I 1 I I I I I I 1 I 1 I I J J J __ _ _J J J I I 1 1 I I I I 1 I I I ; 0 3000 6000 9000 12000 15000 18000 Measured Depth(3000 usft/in) LEGEND L1-09,L1-09,L1-09V1 L1-15,L1-15A,L1-15AV6 -9- 15-16,15-166,15-16BVO -A-- L1-10,L1-10,L1-10 V1 L1-15,L1-15A,Plan#20eV2 -9- L1-13 wp02 plus 500'MD —4:— L1-14,L1-14,L1-14V1 -9- L1-15,L1-15APB1,L1-15APB1 V1 L1-15,L1-15,L1-15V1 Plan L1-13,Plan L1-13,L1-13 wp02 VO 12/16/2015 1:50:18PM Page 3 of 3 COMPASS 5000.1 Build 61 • t IIII W 11110 . M DM `W0 Northing(750 usft/in) w= p88 8 8,)') 8 88 8 8 8 88 8 8 8 8 8 8 8 8 8 8 8 8 S N V M C] N LL2 O 8 CD CO r O� CD Yom] V , CO N C` O 8 8 8 8 8 8 8 8 8 8 8 9 f] N Ute) U) ILC) Ute) Ute) Urn) LU U) U) U) U) Y) U) U) U) U) U) U) U) 696150 � - � 696150- v MEM 695500 _ ii= 695500 694850 '000mi 1.11111111.1111694850 694200 3 3 11111.1111. 694200 fin_ 693550— x693550 o Moi. z 692900 - o ppb 692900 i - BU E J"J o ' 692250 b • 692250 8 m m m m 4 691600 .0�00 pi �9 691600 z Z?.a 7 690950 - 690950 • 8> 1 690300— 000 690300 S- m 689650- `060 1 ot ■ i 689650 m _ m ,), O ,� 689000 J� A J \ 689000 al CL J C/) 0 688350 1 111:�O 688350 J 1.11 o a a 687700 -687700 zo p o 687050 ,,;0 ^ -687050 ,-� 3 3 686400— ■■,�,`�■Q ; ■■■•■■ 686400 w 2 a laill , ,a 685750 O / 685750 €p a�g� bD685100 , ' limn 8510 i 6 0 bL 85 �g�' w in • it aoo ;1684450 Q 1� 684450 „ W Q' o \, N `` W B 683800 3) '-\' `�I O 1 1,�, 683800 683150 ;r , t ill Q 683150 682500 , 682500 \ 681850- J / 681850 ' 681200 T ; , _ 681200 J J in a 680550 (TA 680550 I ihi�r J J 4 c c a O J 679900 `I� 679900 30.P.a. 679250: r i \ 679250 .11i c g 678600 1E111\ 676600 a N 3 3 n 677950 ■ ■■ ■■■■". 677950 `.Ni ■■ ■11■■'r;�� 677300 3 677300 ■■ ■iiU.0 N■,\ i. 1 676650 IN ■■ 676650 d 676000 I. OEM 676000 675350 � 675350 �■� M�� 674700 mm 674700 ID a - IP. : - = - 1P, § P § PPc § P - 0 (u!/tosn o L)Ju!y;.aoN A • • J (R0 tjEcrl_ I AGI I W J I \�. I o ti 12 C z f \1 I N- d I - n I �I I D.S. L-1 31■ • � '. .,/ I p�cn N — ■ 30 I��r 1A r I ■ 28 CPF ' g �/ 27■ . CCP :i ill 1• I � 23■ VICINITY MAP N.T.S. 21■ / • 20 �\ 1 I LEGEND: 111 ri I + AS-STAKED CONDUCTOR I IN EXISTING CONDUCTOR 15■ E 1 I L1-134 1 \ / ■ ,o / 1 9■ ■ 8 NOTES: 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD27. 2. BASIS OF LOCATION IS D.S. L-1 MONUMENTS L-1 NORTH AND L-1 SOUTH. 3. BASIS OF ELEVATION IS BP MEAN SEA LEVEL DATUM. 4. GEODETIC POSITIONS ARE NAD27. • 2 5. PAD MEAN SCALE FACTOR IS: 0.9999405. 1 • 6. DATE OF SURVEY: DECEMBER 26, 2015. 7. REFERENCE FIELD BOOK: NS15-34 PGS. 68-71. J r - - -1I II- - / I DS—L1GRAPHIC SCALE 0 100 200 400 1 I ( IN FEET ) 1 inch = 200 ft. LOCATED WITHIN PROTRACTED SECTION 1, T. 11 N., R. 14 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC GRAVEL SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) PAD ELEV. OFFSETS Y=5,974,893.89 N=4,949.00 70'20'10.174" 70.3361594' 2,541' FSL L1-13 X= 688,601.06 E=4,789.50 148'28'10.957" 148.4697101' 12'7 2,801' FEL DRACN::LE; KNbill CHECKEbyKLEMANNDATE: 2/27/15DRAMN FRB15 DSL1 01 SHEET. 0 ��Na, LISBURNE D.S. L-1 SCALE: AS—STAKED CONDUCTOR LOCATION 00 12/27/15 ISSUED FOR INFORM/MON DK KM 1"=200' WELL L1-13 1 OF 1 NO. DATE REVISION BY CHK 0 • PARKER 272 BOP STACK RAM TYPE BOP: DUTCH LOCK DOWN FLANGE SHAFFER LXT DOUBLE BOP 13 5/8"-5U 1 13 5/8"-5M STUDDED TOP oma, 13 5/8"-5M FLANGED BOTTOM BOP: W/(2) 14" UL2 OPERATOR, UPPER CAVITY AND (2) 14" PSLK W/BSTR OPERATOR, �� R 113 5/8" SMSAFFERT STUDDED TOP LOWER CAVITY 13-5/8" 5M FLANGED BOTTOM 0 0 I (--- -'' DRILLING CROSS: I 13 5/8"-5M FLANGED TOP _..4- I13 5/8"-5M) 3FLANGED BOTTOM °�,� W(2) 3 1/8"-5M SIDE OUTLETS 1Z.5.2.25'II (j° ° 11 E II �0 i II • KILL LINE: ���� IO 2-1/16" 5M FLEX HOSE .k 76 I) u 2-1/16" 5M X 3-1/8" 5M D.S.A. 3-1/8" 5M FLANGED MANUAL GATE VALVE 3-1/8" 5M FLANGED HYDRAULIC GATE VALVE E ........ 0. 2, ' 3 E 3 — ■ 00• ° ■ I 1 I CHOKE LINE: RAM TYPE BOP: 3-1/8" 5M FLANGED MANUAL GATE VALVE _ SHAFFER LXT SINGLE 13 5/8" 5M 3-1/8" 5M FLANGED HYDRAULIC GATE VALVE 13 5/8"-5M STUDDED TOP 13 5/8"- 5M FLANGED BOTTOM 3-1/8" 5M FLEX HOSE W/(2) 14" UL2 OPERATOR L1-13 PTD Page 14 1/4/2016 • 0 Enter/Exit ` ; i Enter/Exit i -.4-r--— __ � -- I // �-,,490 —\► � ,7) 1 `\ I 1 CI. \ I I ) 0 I \, I 1 1 1 1 1 01 I (' I ■ 31 t 1 I f : _J)I i0 ■ _ 1111 I I 1 ■ 27 1 J Q � o , I 1 1 '� / j JI 1 1 1 I , I 1 U 1 I I i I 21 ■ t 1 I CisL;1-13 ' 1 Diverter Exclusion Zine Q _-i // \ (75'Radius from End I` \ M I of Diverter) 1 I ( M It i L I 4E11 1 [-1II I i I �- I / 1 Dai�of / t N 14 Flowirectifot Diverter t 1 in Use t / Loader DuP2{king Prohibited I 93' ring su{faceHole 1 Dulling 1 309' I I I I t2 I t ■ 1 �' , 1 i e I N / Traffic Access °I I 1 1 11( // to Each Pad 1-1 1 \ i / Entrance < 1 N Ener/Exit'-=---/ N l /'Z' '1 J E I f� // \-, \ 111 7 It , I I 1 I*I / \ '\'. I 1 / 1 1 / 1 [Imo]Z ] I II I ;U� i — / I I ,'i 11 - f 1'��� 1 1 , / 1 L 4�4 I / 1 , ), I\/ ■ WELL A WELL INJECTOR DATE : 03/18/2015 SCALE : 1"= 200 MAP DATE : 2014 PBU - DSL1 For current Well and Service information please see Atlas: http://alaska-gis.bpweb.bp.com bs14495.mxd • 1 • I 1 a aI I 21 • 1 17 1 — X13 ' Diverter Exclusion Zane \ (75' Radius from End' I of Diverter) I 1 I ` 1i I I • 14 Directioln of Flow for Diverter 1:1I I in Use I I __� I N s ' ■ 10 I 9 ' ■ 1 1 Loader Parking Prohibited 93' During Sul-face Hole �. -- Drilling 1 i 309' 1 1 Parker Pig 272/273 • New Diverter Layout Showing Distance to Ignition Sources in Red . JGS 1-2-2016 20' Exclusion it Zone Loader Parking Prohibited 7/7/,x/ w Air I n: II : ,,,,,„,, .... III/M aft. 1110. � 0% Heaters \ , Utility Modul +;• Drill Mo• ule \ 1 ../..- ..,7/77,,—:„(„,/ / _dam.... Rig Cellar 1-F 75, (Dumrr r Well Hous- # Y ' f/ R ig FloCtilever Nlers Fit/7/V///17/ 11Diverter Vent Line / Cellar, BOP Deck 8\ <-50'-- / Rig Floor Are All / Classified Areas w / (No Ignition Sources) / / / 4 / / el 0 A/ 4411M ud Module '' ...Oa.. w Air Heater V Vac Trucks Note 1 -All ignition sources are outside the 75' radius from the end of the diverter vent line. Boilers are located on a deck 2 levels below the air heaters on the rig. Note 2 -An exclusion zone will be used to keep the loader from parking in the 75' radius around the diverter vent. •CiIa. mom) 0 ›N < a mommi (r) a swin L() + •••••• 0 II mEC (9C3 CO .., I Li. -)....„ ... Nimmim 0 , . c.,,,,,,„„... „,.,..—... .. .... .............. ..,„,—.......,- 1.: i... 1 0 b , la) , 4 „. ......., a1 •811•••• QM. 0 ‘+'•••• 0 CaW• • 0 CD • • 28.31 2 4 1/16-5000 dal 0 0 4 1/16-5000 MOD 120 GV { I I 4 0 0 mum ( 11 ) ia O 0, • O 92.25 LLW1-U�Lili 4 1/16-5000 MOD 120 GV -TO O �\ 4 1/16-5000 MOD 120 GV ACID 50.12 O O Oy gni PP- I ebb4 1/16-5000 MOD 120 GV +- - \-‹0 0 o 44,44(V PRIVATE AND CONFIDENTIAL REVISIONS DESCRIPTION sIs commit at NE lwaiWTO1 COO..IRA.ME 71(LOBIEEPITILL ARS EXCLUSIVE PROPERTY Or TIOKKOLIFS yr,SOT O EXPRESS.1191•111.91,0104 °pMeAo EZ oR fMCr E.F01.1.0. 4 1/16-5000 TREE 'H�nM° °�"'"� SIBIG DRAFTINGREVIEW 08-01-06 4101.0.P ORTICLES MAC...ION TAS W/ 4 1/16-5000 WING G ODO.111.0 COM..RAC TEDROLOVERDERVI.TAO 1.11DAL ORTNIES OR PARIS THEREOF SI.NOT n MIL10Nw 08-01-06 p 0 .»� .aEmR.smIT.AL11 101.01.TEnEOLO410 APPROX. AMILTON 08-0I-06 RDM100023007 • ! 1 T • ! 1' 7.,....__ i _ .• 1 • ! 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',,, ..,,,o ; 4v,, ,,,IJ ---- TREE= WELLT°= L�-13 Proposed KB.ELEV_ BF.ELEV= MOP I 1111 Max angle= Datum MD= 20"Conductor--80 Datum 1VD= 2,200'-4-1/2"HES X NIP, ID=3.813" ' r / GAS UFT MANDRELS ST MD WD DEV TYPE VW LATCH PORT DATE 5 5800 4,p31 4 9800 6105 11200 7244 3 11900 7851 Minimum ID = 2 12600 8457 C11 3,656'TVDss(SV4) 13-3/8"CSG,68#, L-80 BTC, ID= 12.415"-5,231' —TOC-5,900' MD(656' MD above SV1 per BP 100221 5.4.4.3) TOL-11,899' 9-5/8"CSG,47#, L-80 VT, ID=8.681"-12,049' g \ , THRZ 12,651'-7"X4-1/2"4-1/2"HES X NIP, ID=3.813" 12,731'-7"X 4-1/2"TNT PKR 4-1/2"HES X NIP, ID=3.813"-12,762' 12,834'-4-1/2"HES X NIP, ID=3.813" 4-1/2"TBG, 12.6#,13Cr-85 VAM Top, ID=3.958"-12,850 1 12,845' 4-1/2"WLEG, ID=4" 12,855'-7"X 5" BKR ZXP PKR&Flexiock HNGR 7"Liner, 26#, L-80 Vam Top HC, ID=6.276"-13,005' 4 40° Inc-7"@ Top Wahoo IX z 4-1/2"LNR, 13.5#,13Cr-85,HYD 521, ID=3.920"-16,605' 116,93° DATE REV BY COM ENTS DATE REV BY COM ENTS FRUDHOE BAY MIT 02/22(15 DJVM Update WBS WELL: L1-13 02/26115 DVM New casing points per SOR FERMIT No: 03/16/15 DJVM Input GLM depths per SOR AR No: SEC N E'FNLFVVL BP Exploration(Alaska) WEL LT = ACTUATOR A-13 Proposed KB. LA/= BF.E LEV= MaxKO = /� Max Angle= Datum MD= 20"Conductor--80' Datum TVD= 2,200'-4-1/2" HES X NIP, ID=3.813" GAS UFT MANDRELS ST ND TVD BEV TYPE VLV LATCH FORT DATE 5 5800 4001 4 9800 6105 11200 7244 3 11900 7851 Minimum ID = 1.252"ball seat on 2 12600 8457 bottom frac sleeve -16,400' 3,656'TVDss(SV4) 13-3/8"CSG, 68#, L-80 BTC, ID= 12.415"-5,231'�" -TOC-5,900'MD(656'MD above SV1 per BP 100221 5.4.4.3) TOL-12,073' 9-5/8"CSG,47#, L-80 VT, ID=8.681"- 12,223' ; \ TSGR 12,651'-7"X4-1/2"4-1/2"HESX NIP, ID=3.813" 12,731'-7"X 4-1/2"TNT PKR 4-1/2" HES X NIP, ID=3.813"-12,762' -- 12,834'-4-1/2" HESX NIP, ID=3.813" 4-1/2"TBG, 12.6#,13Cr-85 VAM Top, ID=3.958"- 12,850 12,845'-4-1/2"WLEG, ID=4" Co 12,855'-7"X 5" BKR ZXP PKR& Flexlock HNGR 7" Liner, 26#, L-80 Vam Top HC, ID=6.276"-13,005' Al 40° Inc-7"@ Top Wahoo ® I �I ►moi ►1 ►1 /1 ►1 ►1 4-1/2" LNR, 13.5#,13Cr-85,HYD 521, ID=3.920"- 16,605' 93° DATE REI/BY COMMENTS DATE FEV BY COMYBRS FRUDHOE BAY MT 02/22/15 DJVM Update WBS WELL: L1-13 02/26/15 DJVM New casing points per SOR PERM-No: 03/16/15 DJVM Input GLM depths per SOR AR No: SEC N E'FTL'RM_ BP Exploration(Alaska) • • Casing/Tubing Program Hole Liner/ Wt/Ft Grade Conn Length Top Bottom Size Tbg O.D. MD/TVDss MD/TVDss 42" 20"x 34" 129# A-53 - 80' Surface 94' /80' 16" 13-3/8" 68# L-80 BTC 5,231' Surface 5,231'/3,656' 12-1/4" 9-5/8" 47# L-80 VamTop 12,049' Surface 12,049' /7,920' 8-1/2" 7" 26# L-80 VamTop HC 932' 12,073'/7,940' 13,005'/8,717' (150' lap) 6-1/8" 4 'A" 12.6# 13Cr-85 Hydril 521 3,760' 12,845',/8,594' 16,605/8,800' (150' lap) Tubing 4 '/2" 12.6# 13Cr-85 VamTop 12,850' Surface 12,8 /e ' (-5' int12,85o oo l linerr TTBBS) Mud Program Surface Mud Properties: MMO 16" hole section Depth Interval Density PV YP API FL LSR-YP pH (ppg) (cp) (Ib/100ft2) (2x3-6)rpm Surface - 5,231' MD 8.7-9.4 6-20 35-80 <15 25-60 10- 11 Intermediate 1 Mud Properties: LSND 12-1/4" hole section PV YP Depth Interval Density (cp) (Ib/OOft2) API FL HTHP FL MBT pH 5,231' MD- 10,187' MD 9.6- 10.0 10-15 20-30 <8 NA <20 8.5 -9.5 10,187' MD- 11,698' MD 10.4- 11.0 10-15 20-30 <8 NA <20 8.5 -9.5 11,698' MD- 12,049' MD 10.4- 11.0 10-15 20-30 <5 <10 <20 8.5 -9.5 Intermediate 2 Mud Properties: LSND 8-1/2" hole section Depth Interval D(pP9)y PV YP (cp) (Ib/100ft2) API FL HTHP FL MBT pH 12,049' MD- 13,005' MD 10.2- 10.7 10-15 18-25 <5 <10 <20 8.5-9.5 Production Mud Properties: Water Based Polymer Fluid (FloPro) 6-1/8" hole section PV YP Depth Interval D�pP9)y (cp) (Ib/OOft2) API FL HTHP FL MBT pH 13,005' MD-TD 8.5-9.0 <8 12-20 <12 NA <4 8.5-9.5 Logging Program 16" Surface: Drilling: Dir/GR - Open Hole: None Cased Hole: None 12-1/4" Intermediate 1: Sample Catchers-as required by Geology Drilling: Dir/GR/Res - Open Hole: None Cased Hole: None L1-13 PTD Page 4 1/5/2016 • • 8-1/2" Intermediate 2: Sample Catchers-as required by Geology Drilling: DIR/GR/GR at bit/Res - Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers-as required by Geology Drilling: GR/Res/Neu/Den/Pef/Image/Neutron Caliper • Open Hole: None Cased Hole: None Cement Program Casing Size 13-3/8"68#, L-80 BTC, Surface Casing Lead: Open hole volume + 350% excess in permafrost and 40% excess below permafrost . Basis: Lead TOC: Target surface Tail: Open hole volume +40% excess + 80 ft shoe track Tail TOC: 500 ft MD above casing shoe Total Cement Spacer -100 bbls of Viscosified Spacer weighted to -10.5 ppg (Mud Push II) Volume: Lead 910 bbls, 5109 cuft, 2675 sks of 11.0 ppg DeepCRETE, Yield: 1.91 cuft/sk Tail 64.4 bbls, 362 cuft, 312 sks 15.8 lb/gal Class G- 1.16 cuft/sk Temp BHST 74° F Casing Size 9-5/8"47#, L-80 VamTop, Intermediate Casing Lead: Open hole volume+40% excess Basis: Lead TOC: Target 656 ft MD above SV1 Tail: Open hole volume +40% excess + 80 ft shoe track Tail TOC: 500 ft MD above casing shoe Total Cement Spacer -50 bbls of Viscosified Spacer weighted to -11.0 ppg (Mud Push II) Volume: Lead 441.2 bbls, 2477 cuft, 1424 sks of 11.5 ppg LiteCRETE, Yield: 1.74 cuft/sk Tail 44.9 bbls, 252 cuft, 218 sks 15.8 lb/gal Class G- 1.16 cuft/sk Temp BHST 135° F Casing Size 7"26#, L-80 VAM TOP HC, Intermediate Liner Basis: Tail: Open hole volume +40% excess + 80 ft shoe track+150 ft liner lap +200 ft DP x Csg Total Cement Spacer -35 bbls of Viscosified Spacer weighted to -12.0 ppg (Mud Push II) Volume: Lead N/A Tail 46.9 bbls, 263 cuft, 225 sks 15.8 lb/gal Class G- 1.17 cuft/sk Temp BHST 150° F Casing Size 4-1/2" 13.5#, 13Cr-85 HYD 521 Production liner Basis: Sliding Sleeve/Swell Packer Cementless Completion Total Cement N/A N/A Volume: Lead N/A Tail N/A Temp N/A L1-13 PTD Page 5 1/5/2016 • • Loepp, Victoria T (DOA) From: Jakabosky,Troy <Troy.Jakabosky@bp.com> Sent: Tuesday,January 19,2016 1:54 PM To: Loepp,Victoria T(DOA) Subject: RE: PBU L1-13 PTD Thank you. Troy Jakabosky Drilling Engineer bp 900E. Benson Blvd. Cube 748C Anchorage,AK 99508 Office 907.564.4868 Cell 907.632.2609 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday,January 19, 2016 1:53 PM To: Jakabosky,Troy Subject: RE: PBU L1-13 PTD This is good. I will incorporate your changes. Thanx, Victoria From: Jakabosky,Troy [mailto:Troy.Jakabosky@bp.com] Sent:Tuesday,January 19, 2016 12:33 PM To: Loepp,Victoria T(DOA) Subject: RE: PBU L1-13 PTD Victoria—yes. End of march. Just looking for an update....to answer every ones questions.Thank you. Can I submit an correction? We shortened the 9-5/8 intermediate to 12,049(it was 12,223) and now puts the shoe in the HRZ. This is consistent with the last three Lisburne wells. I have attached two pages of the PTD,and the schematic. If there is anything else you need, please let me know? Thanks,Troy Troy Jakabosky Drilling Engineer bp 900E. Benson Blvd.Cube 748C Anchorage,AK 99508 1 • Loepp, Victoria T (DOA) From: Jakabosky,Troy <Troy.Jakabosky@bp.com> Sent: Tuesday,January 19, 2016 1:54 PM To: Loepp,Victoria T(DOA) Subject: RE: PBU L1-13 PTD Thank you. Troy Jakabosky Drilling Engineer bp 900E. Benson Blvd.Cube 748C Anchorage,AK 99508 Office 907.564.4868 Cell 907.632.2609 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp©alaska.gov] Sent:Tuesday, January 19, 2016 1:53 PM To: Jakabosky,Troy Subject: RE: PBU L1-13 PTD This is good. I will incorporate your changes. Thanx, Victoria From: Jakabosky,Troy [mailto:Troy.Jakaboskv@abp.com] Sent: Tuesday,January 19, 2016 12:33 PM To: Loepp, Victoria T(DOA) Subject: RE: PBU L1-13 PTD Victoria—yes. End of march. Just looking for an update....to answer every ones questions.Thank you. Can I submit an correction? We shortened the 9-5/8 intermediate to 12,049(it was 12,223) and now puts the shoe in the HRZ. This is consistent with the last three Lisburne wells. I have attached two pages of the PTD, and the schematic. If there is anything else you need, please let me know? Thanks,Troy Troy Jakabosky Drilling Engineer bp 900E. Benson Blvd.Cube 748C Anchorage,AK 99508 1 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: L /1- PTD: 2_/6 -Development Service Exploratory Stratigraphic Test Non-Conventional FIELD: i 7 e.– POOL: (5 i �l _� CI 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 • • m , , , , , u) , 0) a , N 0 O G c0, O. fn Ei -6 ai a), N. a). co 2 c : N: J Wc. 0 3 Q' C: W: �: c E O °' '— m 3 0; o, a) 3 2 u) w O m c0) .0 V' a) 3 _ .. 0 ami. 4 0 3. 2; v; 3; 2 0 E. a). a o a) �: V 16' c c °: a): o �: w'. E o g o �: (ucs) o Co O: C co w' CM V1 O. 7 O O J , N ' �- co O: =p, a p: 0 o. C' t p, 0` CO p. ca .O ` D O. N y. 0 y. a `y. N. N. O. y cwa p ca, O a, < Q O .� � o c 2 m o �. a, v m , ,�° ay • a. D• o ,, m 3. Ce 0° . ai. m. ; i, 3. a) ?r f0. ca m Q 2' 0) � a rz .5 E (a) ; ad4; 0 ' , w0X a �; � c� c c y. 3 co N, 0, 3 E; ; ; r , �. E ; 0 11-1 o, t �; f °. aE a. Cm O . 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