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Home My WebLink About216-157MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, October 15, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3R-102 KUPARUK RIV UNIT 3R-102 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/15/2024 3R-102 50-029-23572-00-00 216-157-0 W SPT 3548 2161570 1500 200 200 200 200 200 200 200 200 4YRTST P Adam Earl 8/10/2024 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3R-102 Inspection Date: Tubing OA Packer Depth 1030 1800 1760 1755IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240812135822 BBL Pumped:1.1 BBL Returned:0.9 Tuesday, October 15, 2024 Page 1 of 1 9 9 9 9 99 9999 99 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.15 15:11:00 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Defeated LPP/SSV on well 3R-102 (PTD# 216-157) Date:Tuesday, March 8, 2022 5:45:24 PM Attachments:image001.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Tuesday, March 8, 2022 5:49 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com>; NSK Prod Engr Specialist <n1139@conocophillips.com>; NSK Optimization Engr <n2046@conocophillips.com>; CPF3 Ops Supv <n2070@conocophillips.com>; CPF3 DS Lead Techs <n1105@conocophillips.com>; Braun, Michael (Alaska) <Michael.Braun@conocophillips.com>; Kholeif, Will <Will.Kholeif@conocophillips.com> Subject: Defeated LPP/SSV on well 3R-102 (PTD# 216-157) Mr. Regg, The low pressure pilot (LPP) on injection well 3R-102 (PTD# 216-157) was defeated on Saturday, 03/05/2022 during pigging operations. The well is currently at a wellhead injection pressure of -2 psig at an injection rate of 2018 bwpd. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the “Drill Site Defeated Safety Device Log.” The AOGCC will be notified when the injection pressure has increased to above 25 psig and the LPP/SSV function is returned to normal, in accordance with “Administrative Approval No. CO 406B.001.” Please let me know if you have any questions, Brian Lewis Senior Production Engineer – CPF3 Phone: (907) 263-4535 | Cell: (918) 521-8990 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Defeated LPP/SSV on well 3R-102 (PTD# 216-157) Date:Wednesday, March 2, 2022 10:04:10 PM Attachments:image001.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Wednesday, March 2, 2022 7:24 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com>; NSK Prod Engr Specialist <n1139@conocophillips.com>; NSK Optimization Engr <n2046@conocophillips.com>; CPF3 Ops Supv <n2070@conocophillips.com>; CPF3 DS Lead Techs <n1105@conocophillips.com>; Braun, Michael (Alaska) <Michael.Braun@conocophillips.com>; Kholeif, Will <Will.Kholeif@conocophillips.com> Subject: RE: Defeated LPP/SSV on well 3R-102 (PTD# 216-157) Mr. Regg, The low pressure pilot on injection well 3R-102 (PTD# 216-157) has been returned to service as of 03/02/2022. It was defeated on 01/29/2022. The following notification is in accordance with “Administrative Approval No. CO 406B.001.” Thank you, Brian Lewis Senior Production Engineer – CPF3 Phone: (907) 263-4535 | Cell: (918) 521-8990 From: CPF3 Prod Engrs Sent: Monday, January 31, 2022 6:09 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com>; NSK Prod Engr Specialist <n1139@conocophillips.com>; NSK Optimization Engr <n2046@conocophillips.com>; CPF3 Ops Supv <n2070@conocophillips.com>; CPF3 DS Lead Techs <n1105@conocophillips.com>; Braun, Michael (Alaska) <Michael.Braun@conocophillips.com>; Kholeif, Will <Will.Kholeif@conocophillips.com> Subject: Defeated LPP/SSV on well 3R-102 (PTD# 216-157) Mr. Regg, The low pressure pilot (LPP) on injection well 3R-102 (PTD# 216-157) was defeated on Saturday, 01/29/2022. The injector had been shut in due to pigging operations. It was returned to service on the same day, but the injection pressure was below the pressure required for the LPP to reset. The well is currently at a wellhead injection pressure of -5 psig at an injection rate of 1900 bwpd. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the “Drill Site Defeated Safety Device Log.” The AOGCC will be notified when the injection pressure has increased to above 25 psig and the LPP/SSV function is returned to normal, in accordance with “Administrative Approval No. CO 406B.001.” Please let me know if you have any questions, Brian Lewis Senior Production Engineer – CPF3 Phone: (907) 263-4535 | Cell: (918) 521-8990 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Defeated LPP/SSV on well 3R-102 (PTD# 216-157) Date:Monday, January 31, 2022 6:55:36 PM Attachments:image001.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Monday, January 31, 2022 6:09 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com>; NSK Prod Engr Specialist <n1139@conocophillips.com>; NSK Optimization Engr <n2046@conocophillips.com>; CPF3 Ops Supv <n2070@conocophillips.com>; CPF3 DS Lead Techs <n1105@conocophillips.com>; Braun, Michael (Alaska) <Michael.Braun@conocophillips.com>; Kholeif, Will <Will.Kholeif@conocophillips.com> Subject: Defeated LPP/SSV on well 3R-102 (PTD# 216-157) Mr. Regg, The low pressure pilot (LPP) on injection well 3R-102 (PTD# 216-157) was defeated on Saturday, 01/29/2022. The injector had been shut in due to pigging operations. It was returned to service on the same day, but the injection pressure was below the pressure required for the LPP to reset. The well is currently at a wellhead injection pressure of -5 psig at an injection rate of 1900 bwpd. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the “Drill Site Defeated Safety Device Log.” The AOGCC will be notified when the injection pressure has increased to above 25 psig and the LPP/SSV function is returned to normal, in accordance with “Administrative Approval No. CO 406B.001.” Please let me know if you have any questions, From:Regg, James B (CED) To:AOGCC Records (CED sponsored) Subject:FW: Defeated LPP/SSV on well 3R-102 (PTD# 216-157) Date:Tuesday, October 12, 2021 10:53:39 AM Attachments:image001.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Monday, October 11, 2021 4:20 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com>; NSK Prod Engr Specialist <n1139@conocophillips.com>; NSK Optimization Engr <n2046@conocophillips.com>; CPF3 Ops Supv <n2070@conocophillips.com>; CPF3 DS Lead Techs <n1105@conocophillips.com>; Braun, Michael (Alaska) <Michael.Braun@conocophillips.com> Subject: RE: Defeated LPP/SSV on well 3R-102 (PTD# 216-157) Mr. Regg, The low-pressure pilot on injection well 3R-102 (PTD# 216-157) is back in service as of 10/10/2021. The pilot was defeated on 10/02/2021. The following notification is per “Administrative Approval No. CO 406B.001.” Thank you, Devin Kozak CPF3 PE (Fill-in) From: CPF3 Prod Engrs Sent: Thursday, October 7, 2021 5:07 PM To: jim.regg@alaska.gov Cc: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com>; NSK Prod Engr Specialist <n1139@conocophillips.com>; NSK Optimization Engr <n2046@conocophillips.com>; CPF3 Ops Supv <n2070@conocophillips.com>; CPF3 DS Lead Techs <n1105@conocophillips.com>; Braun, Michael (Alaska) <Michael.Braun@conocophillips.com> Subject: Defeated LPP/SSV on well 3R-102 (PTD# 216-157) Mr. Regg, The low pressure pilot (LPP) on injection well 3R-102 (PTD# 216-157) was defeated on 10/02/2021. The injector had been shut in due to ongoing facility operations on the seawater injection line starting 09/29/2021. After being returned to service, the injection pressure was still below the pressure required for the LPP to reset. The well is currently at a wellhead injection pressure of 122 psig at an injection rate of 1900 bwpd. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the “Drill Site Defeated Safety Device Log.” The AOGCC will be notified when the injection pressure has increased to above 250 psig and the LPP/SSV function is returned to normal, in accordance with “Administrative Approval No. CO 406B.001.” Thank you, Brian Lewis Senior Production Engineer – CPF3 Phone: (907) 263-4535 | Cell: (918) 521-8990 From:Regg, James B (CED) To:AOGCC Records (CED sponsored) Subject:FW: Defeated LPP/SSV on well 3R-102 (PTD# 216-157) Date:Thursday, September 9, 2021 8:20:49 AM Attachments:image001.png reviewed Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Wednesday, September 8, 2021 5:06 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com>; NSK Prod Engr Specialist <n1139@conocophillips.com>; NSK Optimization Engr <n2046@conocophillips.com>; CPF3 Ops Supv <n2070@conocophillips.com>; CPF3 DS Lead Techs <n1105@conocophillips.com>; Braun, Michael (Alaska) <Michael.Braun@conocophillips.com>; Kholeif, Will <Will.Kholeif@conocophillips.com> Subject: Defeated LPP/SSV on well 3R-102 (PTD# 216-157) Mr. Regg, The low pressure pilot (LPP) on injection well 3R-102 (PTD# 216-157) is defeated today, 09/08/2021. The injector had been shut in due to facility operations on the seawater injection line. It was returned to service today, and the injection pressure is still below the pressure required for the LPP to reset. The well is currently at a wellhead injection pressure of -7 psig at an injection rate of 1600 bwpd. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the “Drill Site Defeated Safety Device Log.” The AOGCC will be notified when the injection pressure has increased to above 250 psig and the LPP/SSV function is returned to normal, in accordance with “Administrative Approval No. CO 406B.001.” Please let me know if you have any questions, Brian Lewis Nib -� CZ —1 C�2— P76 Z4� 1 SZc Regg, James B (CED) From: NSK Optimization Engr <n2046@conocophillips.com> -7` Sent: Sunday, June 27, 2021 7:44 PM To: Regg, James B (CED) Cc: Well Integrity Specialist CPF1 & CPF3; NSK Prod Engr Specialist; CPF3 Ops Supv; CPF3 DS Lead Techs; CPF3 Prod Engrs; Braun, Michael (Alaska); Kholeif, Will; Martin, Kenneth Lloyd Subject: Defeated LPP/SSV on CPAI well 3R-102 on 6/27/2021 Jim, I'm filling in as the emergency contact for the Production Engineers this weekend and would like to report that the low pressure pilot (LPP) on well 3111-102 (PTD# 216-157) was defeated today, 6/27/2021. The well is currently injecting at a rate of 1900 BWPD and wellhead pressure is on a vacuum. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Thank you, Emily Zanto GKA Optimization Engineer ConocoPhillips Alaska, Inc. Office: 907-263-4312 Mobile: 907-632-5889 Nwl 3i2—I oZ �� Gr6iS70 Regg, James B (CED) From: CPF3 Prod Engrs <n1223@conocophillips.co Sent: Tuesday, March 16, 2021 12:13 PMlgq To: Regg, James B (CED) [[ 1 Cc: CPF3 DS Lead Techs; CPF3 Ops Supv; Kozak, Devin; Braun, Michael (Alaska) Subject: Defeated LPP/SSV on CPAI Well 311-102 on 3/16/2021 Jim, The low pressure pilot (LPP) on well 3R-102 (PTD# 216-157) was defeated today, 3/16/2021, when the wellhead pressure dropped to the LPP setpoint. The well is currently injecting at 1995 BWPD with a wellhead pressure of 30 psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Marina Krysinski / Kenneth Lloyd Martin CPF3 Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7871 Marina's Cell: (907) 399-7791 K,ra( ,P16 E44c157C Regg, James B (CED) From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Friday, December 4, 2020 4:30 PM k' �� Z To: Regg, James B (CED) Cc: NSK Prod Engr Specialist; NSK Optimization Engr; CPF3 Ops Supv; CPF3 DS Lead Techs; NSK Fieldwide Operations Supt Subject: 3R-102 (PTD# 216-157-0) LPP/SSV Return to Service Mr. Regg, The low pressure pilot on injection well 3R-102 (PTD# 216-157-0) has been returned to service. It was defeated on 23 - Nov -2019. The following notification is in accordance with "Administrative Approval No. CO 4068.001." Thanks, Kaelin Ellis / Rachel Kautz CPF3 Production Engineer Cell: 907-360-0961 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Oct 13, 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jessie Chmielowski: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, Roger Mouser ConocoPhillips Well Integrity Field Supervisor Roger Mouser Digitally signed by Roger Mouser Date: 2020.10.13 13:10:42 -08'00' By Samantha Carlisle at 1:21 pm, Oct 13, 2020 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 10/13/20 2K 2M 3K 3O 3Q 3R 3S pad Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal 2K-30 50103207580000 2170720 22" 0.3 6" 3/8/2020 2.5 9/29/2020 2K-32 50103207570000 2170420 29" 0.5 6" 3/8/2020 3 9/29/2020 2M-37 50103207450000 2160820 30" 0.4 9" 7/31/2020 2.1 9/29/2020 2M-38 50103207460000 2160830 4" N/A 4" N/A 2.5 9/29/2020 3K-32 50029227630000 1970760 10"Conductor extension 10" 4/27/2019 2.5 9/27/2020 3K-34 50029228790000 1980770 14" Conductor extension 14" 4/27/2019 9 9/27/2020 3O-01A 50029218360000 2151910 62" 0.70 11" 3/8/2020 4.25 9/27/2020 3O-19 50029227530000 1970500 13"Conductor extension 13" 4/27/2019 4.25 9/27/2020 3O-20 50029227500000 1970450 21 5.00 17" 9/27/2020 6 9/27/2020 3Q-22 50029226250000 1951860 20' 3.25 8" 3/8/2020 4.25 9/26/2020 3R-101 50029235740000 2170130 21" 0.40 8" 8/14/2020 1 9/26/2020 3R-102 50029235720000 2161570 54" 1.10 6" 8/14/2020 6 9/26/2020 3R-105 50029236510000 2191340 22" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-106 50029236410000 2190970 36" 0.60 9" 8/14/2020 3.5 9/26/2020 3R-107 50029236600000 2191810 32" 0.60 9.5" 8/14/2020 1 9/26/2020 3R-111 50029236430000 2191050 25" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-112 50029236370000 2190850 36" 0.60 14"8/14/2020 7 9/26/2020 3S-611 50103207740000 2181030 11' 10" 2.50 8"6/30/2019 2.5 9/27/2020 3S-612 50103207770000 2181110 43" 0.75 8" 6/30/2019 3.5 9/27/2020 3S-613 50103207350000 2160200 22" 0.75 8" 6/30/2019 1.7 9/27/2020 MEMORANDUM TO: Jim Regg P.I. Supervisorfll FROM: Brian Bixby Petroleum Inspector Well Name KUPARUK RIV UNIT 3R-102 Insp Num: mitBDB200813152359 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, August 17, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc - 3R -102 KUPARUK RIV UNtT 3R-102 Src: Inspector Reviewed By: P.I. Supry `� Comm API Well Number 50-029-23572-00-00 Inspector Name: Brian Bixby Permit Number: 216-157-0 Inspection Date: 8/13/2020 Well 3R-102--11 Packer �Typ - e Inj w "TVD Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 3548 Tubing 0 -- 0 -- 0 0 - PTD 2161570 Type Test'' SPT 'Test psi 1500 IA 890 1800 1750 - 1750 BBL Pumped: 1.1 11313L Returned: 1.1 OA 210 210 - 210 - 210 - Intervall 4YRTSTp/F P i - i Notes: This is a West Sak injector that has no pressure. The well is injecting at 1440 BPD with no tubing pressure. Monday, August 17, 2020 Page I of 1 W,t4 3P -1D Z. MZIX70 Regg, James B (CED) From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Saturday, November 23, 2019 3:55 PM To: Regg, James B (CED) Cc: Well Integrity Compliance Specialist WINS & CPF3; NSK Prod Engr Specialist; NSK Optimization Engr; CPF3 Ops Supv, CPF3 Ops & DOT Pipelines Supt; CPF3 DS Lead Techs; Valentine, Doug K Subject: Defeated LPP/SSV on well 3R-102 (PTD# 216-157-0) Mr. Regg, ./ The low pressure pilot (LPP) on injection well 3R-102 PTD# 216-157-0) is now defeated as of 23 -Nov -2019. The well was shut in 27 -July -19 for reservoir pressure management during nearby drilling. After returning the well to injection this morning, the wellhead pressure has not risen high enough to place the low pressure pilot in service. The well is currently at a wellhead injection pressure near atmospheric and an iniection rate of 600 bwod. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Drill Site Defeated Safety Device Log." . The AOGCC will be notified when the injection pressure has increased to above 250 psig and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Thanks, Kenneth Lloyd Martin/Kaelin Ellis PERA/CPF3 Production Engineers Ph: (907) 659-7871 Pager: (907) 659-7000 pp# 328 ProActive Diagnostic Services, Inc. WELL LOG TRANSMITTAL To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907)793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection (Caliper / MTT) 21615; 31136 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 : 1) Injection Profile 2) Signed Print Name: ProActive Diagnostic Services, Inc. RECEIVE® Attn: Diane Williams 130 West International Airport Road Suite C AUG 2 9 2019 Anchorage, AK 99518 AOGCC pdsa nch ora a e(&memo ry I on.com 16 -Jul -19 3R-102 CD 50-029-23572-00 Date : V �{ G PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245.8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEOMEMORYLOGCOM WEBSITE: WWW.MEMORYLOG.COM htTsd/readcasedhole-my. sharepolntcoMpetsonal/diene williams_readcesedhole oom/Dowments.D Drive/Achivea/MasteriemplateFills T] mplatee/DistributioNTranamittalSheeta/ConocoPhillips_Transmitdocx MA 3P_- i cz 2-I(a15-70 Regg, James B (CED) From: CPF3 Prod Engrs <nl223@conocophillips.com> Sent: Saturday, July 27, 2019 7:21 PM OW 1I3D'�cj To: Regg, James B (CED) 6l Cc: CPF3 DS Lead Techs; Valentine, Doug K Subject: LPP returned to Service on well 3R-102 on 7/26/2019 Jim, The low-pressure pilot (LPP) on well KRU 3R-102 (PTD# 216-157-0) was returned to services a on 7/27/2019, after the well was shut in when wellwork was completed. The LPP had been defeated on 7/7/2019, after the well was returned to service following completed wellwork. This notification is in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Devin Kozak CPF3 Production Engineer Fill-in ConocoPhillips Alaska, Inc. Office: (907) 659-7871 KaL 3F- —jvz P71) VO JS -70 Regg, James B (CED) From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Sunday, July 7, 2019 8:54 AM 10C',I 1161m To: Regg, James B (CED) Cc: Well Integrity Compliance Specialist WINS & CPF3; NSK Prod Engr Specialist; NSK Optimization Engr; CPF3 Ops Supv; CPF3 Ops & DOT Pipelines Supt; CPF3 DS Lead Techs; Valentine, Doug K; Jolley, Liz C Subject: Defeated LPP/SSV on well 311-102 Mr. Regg, i The low pressure pilot (LPP) on injection well 3R-102 (PTD# 216-157-0) has just been defeat as of 7 -July -2019. The well was shut in for a 6 -July for surveillance. After returning the well to injection at a reduced injection rate, the wellhead pressure has not risen high enough to place the low pressure pilot in service. The well is currently at a wellhead injection pressure of 167 psi and an injection rate of 975 bwpd. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Drill Site Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 250 psig and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Thanks, Kenneth Lloyd Martin/Kaelin Ellis PERA/CPF3 Production Engineers Ph: (907) 659-7871 Pager: (907) 659-7000 pp# 328 atk 3P -40-7-- M 2lrc1570 Regg, James B (CED) From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Monday, May 20, 2019 9:52 AM r 151goll p To: Regg, James B (CED) ��liC�J Subject: 3R-102 Low Pressure Pilot Jim, The drillsite operator placed the low pressure pilot for well 3R-102 since the injection pressure is now high enough to engage the pilot. Thanks, Rodney Murray CPF3 Production Engineer Fill -In ConocoPhillips Alaska 0:(907)659-7871 'I j q, 4-jzzli,7 IT-" Je—1 oZ- P-1-' Regg, James B (DOA) From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Monday, April 22, 2019 5:16 AM �G�li Z 4�nG7i'Ll To: Regg, James B (DOA) ll Cc: NSK Well Integrity Supv CPF3 and WNS; NSK Prod Engr Specialist; NSK Optimization Engr; NSK West Sak Prod Engr; CPF3 Ops Supv; CPF3 Ops & DOT Pipelines Supt; CPF3 DS Lead Techs; CPF3 Maint Supv; Valentine, Doug K; Jolley, Liz C; Martin, Kenneth Lloyd; Plunkett, Ethan T; Aleshire, Lynn Subject: Defeated LPP/SSV on well 3R-102 (4/22/2019) Good morning Mr. Regg, The low pressure pilot (LPP) on injection well 311-102 (PTD# 216-157-0) was defeated April 22nd, 2019. The well had been shut in for 11 days due to scheduled Drillsite maintenance and construction. After the initial monitoring period since returning the well on injection, the wellhead pressure did not rise high enough to place the low pressure pilot in service. The well is currently at a wellhead injection pressure of 121 psi and an injection rate of 1555 barrels of water per day. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 250 psig and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please reach out with questions. Best, Ethan Plunkett / Kenneth Lloyd Martin CPF3 Production Engineer I Office x7871 I Cell (918) 812-2294 1 Pager x328 I Radio 343 Kek 3F-- 10z Plt� z46isic Regg, James B (DOA) From: Martin, Kenneth Lloyd <K.L.Martin@conocophillips.com> Sent: Friday, April 5, 2019 1:13 PM To: Regg, James B (DOA) Cc: NSK Well Integrity Supv CPF3 and WINS; NSK Prod Engr Specialist; CPF3 Ops Supv, CPF3 Ops & DOT Pipelines Supt; CPF3 DS Lead Techs; CPF3 Maint Supv; Valentine, Doug K; CPF3 Prod Engrs; NSK SVS Tech Subject: Returned to Service -PP/SSV on well 311-102, PTD 216-157-0 Mr. Regg, The wellhead pressure on 3R-102 has now risen sufficiently to put the Low Pressure Pilot and SVS back in service and that was accomplished at 11:30 this morning, April 5, 2019. The current pressure is 285 psi and the current rate is 1550 BWPD. Thank you, a�. ' Kenneth Lloyd Martin/Ethan Plunkett PERA/CPF3 Production Engineers Ph: (907) 659-7871 Pager: (907) 659-7000 pp# 328 From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Wednesday, March 20, 2019 5:37 PM To: jim.regg@alaska.gov Cc: NSK Well Integrity Supv CPF3 and WINS <n2549@conocophillips.com>; NSK Prod Engr Sp alist <n1139@conocophillips.com>; NSK Optimization Engr <n2046@conocophillips.com>; West Salk Prod Engr <n1638@conocophillips.com>; CPF3 Ops Supv <n2070@conocophillips.com>; CPF ps DOT Pipelines Supt <n1175@conocophillips.com>; CPF3 Prod Engrs <n1223@conocophillips.com>• PH DS Lead Techs <n1105@conocophillips.com>; CPF3 Maint Supv <n2069@conocophillips.c >; Valentine, Doug K <Doug.K.Valentine@conocophillips.com>; Jolley, Liz C <Liz.C.Jolley@co cophillips.com>; Martin, Kenneth Lloyd <K.L.Martin@conocophillips.com>; Plunkett, Ethan T <Ethan.T.Plun t@co nocophillips.com> Subject: Defeated LPP/SSV on well 311-102 Mr. Regg, The low pressure pilot (LPP) on injection well 3R- (PTD# 216-157-0) was defeated 20 -Mar -2019. The well had been shut in for 7 days due to routine pressure fal'laff testing. After the initial monitoring period since returning the well on injection, the wellhead pressure did not r' high enough to place the low pressure pilot in service. �2L1 PTt zl6 i S70 Regg, James B (DOA) From: CPF3 Prod Engrs <nl223@conocophillips.com> 2IZ(I (� Sent: Wednesday, March 20, 2019 5:37 PM 1Y /� ✓ 11 To: Regg, James B (DOA) Cc: NSK Well Integrity Supv CPF3 and WNS; NSK Prod Engr Specialist; NSK Optimization Engr; NSK West Sak Prod Engr; CPF3 Ops Supv; CPF3 Ops & DOT Pipelines Supt; CPF3 Prod Engrs; CPF3 DS Lead Techs; CPF3 Maint Supv; Valentine, Doug K; Jolley, Liz C; Martin, Kenneth Lloyd; Plunkett, Ethan T Subject: Defeated LPP/SSV on well 3R-102 Mr. Regg, The low pressure pilot (LPP) on injection well 311-102 (PTD# 216-157-0) was defeated 20 -Mar -2019. The well had been shut in for 7 days due to routine pressure fall off—testing. After the initial monitoring period since returning the well on injection, the wellhead pressure did not rise high enough to place the low pressure pilot in service. The well is currently at a wellhead injection pressure of 91 psi and an injection rate of 1542 bwpd. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." ✓ The AOGCC will be notified when the injection pressure has increased to above 250 psig and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Best Regards, Doug Valentine Doug Valentine in behalf of Ethan Plunkett / Kenneth Lloyd Martin CPF3 Production Engineers I Office x7871 I C: 208-932-52801 Pager x328 I Radio 343 ret( 3iZ-ioz zi(j5ZW Regg, James B (DOA) From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Tuesday, November 7, 2017 7:11 AM )`171(7 To: Regg,James B (DOA) - f Cc: NSK Prod Engr Specialist; NSK Optimization Engr; Pessetto, Scott T; NSK West Sak Prod Engr; CPF3 Ops Supv; CPF3 Ops & DOT Pipelines Supt; CPF3 DS Lead Techs Subject: Return to Service of LPP/SSV on Well 3R-102 Mr. Regg, Well 3R-102 (PTD 216-157-0) is now injecting at 420 PSIG, and the low pressure pilot controlled safety system was -placed in service last night(11/6/2017)with a pilot setting of 250 PSIG.The well now has its safety systems in service. Please let me know if you have any questions, Thank you, Toon Changklungdee/Kenneth L. Martin CPF3 Production Engineer Office: (907)659-7871 Pager: (907)659-7000 pp 328 SCANNED 1 ri-1,Z 31�-(c9z • P a«r-7 0 Regg, James B (DOA) From: CPF3 Prod Engrs <n1223@conocophillips.com> / f Sent: Monday, October 23, 2017 3:19 PM q`2 l OI Z3 ! 7 To: Regg, James B (DOA) Subject: Defeated LPP/SSV on CPAI Well 3R-102 on 10/23/2017 Mr. Regg, The low pressure pilot (LPP) on injection well 3R-102 (PTD#216-157) has been defeated as of 15:01 today, October 23, 2017, as we returned the well to injection. The well had been shut in since September 11th, due to lack of reservoir offtake in the area. The well is currently at a wellhead injection pressure of 210 psig and rate at 950 BWPD.The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 PSIG and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Thank you, .7(xtmeffl.[�.�.ayd Kenneth Lloyd Martin/Toon Changklungdee PERA/CPF3 Production Engineers Ph: (907) 659-7871 Pager: (907) 659-7000 pp#328 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,August 10,2017 TO: Jim Regg � P.I.Supervisor 1�e�>Ly i, (5(Z(I 7 SUBJECT: Mechanical Integrity Tests l CONOCOPHILLIPS ALASKA,INC. 3R-102 FROM: Chuck Scheve KUPARUK RIV UNIT 3R-102 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Z NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3R-102 API Well Number 50-029-23572-00-00 Inspector Name: Chuck Scheve Permit Number: 216-157-0 Inspection Date: 8/5/2017 Insp Num: mitCS170806073650 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3R-102 - Type Inj W' TVD 3548 Tubing 322 322 - 322 - 322 • PTD 2161570 - Type Test SPT Test psi 1500 IA 820 1800 • 1750 - 1750 - BBL Pumped: 1.5 BBL Returned: 1.2 OA 225 - 252 - 239 235 • Interval j INITAL P/F P — — Notes: Initial test post conversion to injection. Packer TVD taken from operators report. SCANNED FEB 2 32013, Thursday,August 10,2017 Page 1 of 1 ` • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:PROD to WINJ 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development E Exploratory ❑ 216-157 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service ❑ 6.API Number: 99510 50-029-23572-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 355023,ADL 373301,ADL 355024 KRU 3R-102 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 14,950 feet Plugs measured None feet true vertical 3,386 feet Junk measured None feet Effective Depth measured 0 feet Packer measured 8452 feet true vertical 0 feet true vertical 3548 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 119' 119' Surface 2,250' 10-3/4" 2,292' 2,169' ,p t .4 ,,1 ::rte Intermediate 6,759' 7-5/8" 8,595' 3,563' y`�t f- V Liner 4,137' 4-1/2" 12,582' 3,548' <.UJ : 0 ' ?Q17 Perforation depth Measured depth 8616'-10792' feet True Vertical depth 3550'-3585' feet Tubing(size,grade,measured and true vertical depth) 4-1/2" L-80 8492' 3552' Packers and SSSV(type,measured and true vertical depth) Al -Injection Valve 1971' 1909' BAKER HRD-E ZXP w/HDs 8445' 3547' 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNEDTreatment descriptions including volumes used and final pressure: NOV 1 3 2U 7'J 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 840 450 140 1270 215 Subsequent to operation: 0 0 1000 900 250 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑.. Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run U 16.Well Status after work: Oil U Gas U WDSPL U Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑., WAG ❑ GINJ ❑ SUSP❑ SPLUG 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: 317-236 Authorized Name: Scott T.Pessetto Contact Name: Scott Pessetto Authorized Title: Petroleum Engineer Contact Email:scott.t.pessetto@cop.com Authorized Signature: ,�� /�-- Date: 05/0}/11- Contact Phone: (907)263-4146 V1ti10fiiiJ7-- /A. ro0q � RBDMS t,i-- 411( 1 1 2017 Form 10-404 Revised 4/2017 Submit Original Only • S Scott T.Pessetto Petroleum Engineer ANC 1352 700 G Street ConocoPhillips Anchorage,AK 99501-3448 Phone:(907)263-4146 Scott.T.Pessetto@conocophillips.com August 7, 2017 AOGCC Commissioner ' 0 State of Alaska, Oil & Gas Conservation Commission A U s 0 7_017 333 W. 7th Ave. Ste. 100 Anchorage, AK 99501 Mkt. ` . Dear Commissioner, Enclosed you will find 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. regarding 3R-102 (PTD# 216-157). If you have any questions regarding this matter, please contact myself at 907-263-4146. Sincerely, Scott Pessetto Attachments Report of Sundry Well Operations Daily Report of Well Operations 3R-102 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/09/17 JET ICE PLUG WITH COIL TUBING, REMOVE HYDRATES 06/13/17 REPLACE GLVs with DVs 06/30/17 SET Al-INJECTION VALVE @ 1970' RKB 07/18/17 MILL ICE WITH COIL TUBING 08/05/17 (ISW) INITIAL STATE WITNESSED (Chuck Scheve) MITIA PASSED TO 1800 PSI. • K/wt 3la-tc-Z PTh 21 rol 57 0 Regg, James B (DOA) From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Friday, August 4, 2017 7:05 PM To: Regg,James B (DOA) �9, 616117 Cc: NSK Optimization Engr Subject: LPP/SSV on KRU Well 3R-102 (PTD#216-157) returned to service 08/04/2017 Jim, 3R-102's wellhead injection pressure has risen to 320 psig, which allows us to put the low pressure pilot in service. .� It was returned to service at 03:30 PM on 08/04/2017. ✓ Currently the well is injecting 980 BWPD and the safety systems have been removed from the defeated safety log. If you have any questions please feel free to contact the CPF3 Production Engineers for more information This notification is in accordance with "Administrative Approval No. CO 4066.001." Hilaire Yemeli Gozon, Senior Petroleum Engineer On behalf of: Kenneth Lloyd Martin/Toon Changklungdee CPF3 Production Engineers Ph: (907) 659-7871 SCANNEEI ' Pager: (907) 659-7000 pp#328 From: CPF3 Prod Engrs Sent:Wednesday,July 19, 2017 4:22 PM To: Regg,James B (DOA)<jim.regg@alaska.gov> Subject: Defeated LPP/SSV on KRU Well 3R-102 (PTD#216-157) on 07/19/20 -correction Hello Jim, Just arrived back on the slope. My alternate left a draft f: Lynn, and I think she missed the date change. Apparently they attempted to bring the well onto ' jection on July 4, but the tubing was frozen. Actual injection commenced at 06:44 this ''riling,July 19th, after a cleanout. The safety defeated log was updated this morning and the well was manned until e note was sent to you. Sorry for the confusion. Xennetti,efogel Kenneth Lloyd Male..., Toon Changklungdee 1 or 7,4 -%.?, THE STATE Alaska Oil and Gas of T e cKA Conservation Commission 1�1Z V 'Witt_ 333 West Seventh Avenue *a: GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Scott T. Pessetto Petroleum Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 SCAWS6NOV 0 12017 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool,KRU 3R-102 Permit to Drill Number: 216-157 Sundry Number: 317-236 Dear Mr. Pessetto: 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, Daniel T. Seamount,Jr. Commissioner DATED this2day of June, 2017. RBDMS IA- JUN 2 7 2017 RECEIVED STATE OF ALASKA JUN 0 9 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon LI Plug Perforations 0 Fracture Stimulate LI Repair Well U Operations shutdown LI Suspend 0 Perforate ❑ Other Stimulate❑ Pull Tubing ❑ Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: PROD to WINJ 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development 0. 216-157 ' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P. 0. Box 100360, Anchorage, Alaska 99510 50-029-23572-00-00 7.If perforating: IV 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Nf K R U Alb • Will planned perforations require a spacing exception? Yes ❑ No Q / WvPtf'CTRO5 3R-102 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355023, ADL 373301, ADL 355024 ' Kuparuk River Field/West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 14,950' 3,386' Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 119' 119' Surface 2,250' 10-3/4" 2,292' 2,169' Intermediate 6,759' 7-5/8" 8,595' 3,563' Liner 4,137' 4-1/2" 12,582' 3,548' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): slotted liner 8616'-10792' 3550'-3585' 4-1/2" L-80 8492' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): SSSV=Al -Injection Valve ' MD=1971',TVD=1909' PACKER=BAKER HRD-E ZXP w/HD's 1 MD=8445,TVD=3547' 12.Attachments: Proposal Summary V Wellbore schematic IA 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q' Service D 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 6/15/2017 OIL ❑ WINJ 0 ' WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS 0 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 be deviated from without prior written approval. Authorized Name: Scott T.Pessetto Contact Name: Scott Pessetto Authorized Title: Petroleum Engineer Contact Email: scott.t.pessetto©conocophillips.com / Contact Phone: (907)263-4146 Authorized Signature: _.✓ 4 T Date: vlB/� COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3k-7- 23 Cz Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ( Location Clearance ❑ t4sF (012-(0/1"'1 Other: "[ Post Initial Injection MIT Req'd? Yes "No ❑ I1' 201 Spacing Exception Required? Yes 0 No Id Subsequent Form Required: /© —' 1 (2/J RBDMS L}--JUN 2 APPROVED BY ‘ Approved by: COMMISSIONER THE COMMISSION Date: /26117 //,13 6017- rm. 6/2,1/I , O3/i7 Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ORIGINAL RECEIVED JUN 0 9 2017 Scott T.Pessetto Petroleum Engineer AOGCCAOGCCANCl352 700 G Street ConocoPhillips Anchorage,AK 99501-3448 Phone:(907)263-4146 June 8,2017 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave. Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit Well 3R- 102 from Oil Production to Water Injection service. Enclosed you will find 10-403 Applications for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 3R-102, (PTD#216-157) If you have any questions regarding this matter,please contact myself at 907-263-4146. Sincerely, Scott Pessetto Attachments: Sundry application Proposal Summary AOR Detail Area Map Well schematic Affidavit per 20AAC 25.402(c)(3) 3R-102 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert West Sak Well 3R-102 (PTD# 216-157)from Production Service to Water Injection service. Area of Review: West Sak well 3R-102 was completed as a producer on 3/22/17. To enhance recovery in the reservoir pattern, it is requested to convert well 3R-102 to injection service to support offset production well 3R-101. The top of the Ugnu A sand was found at 6,397' MD/3,256'TVD The top of the WSak D sand was found at 8,544' MD/3,558'TVD Area Map with 1/4 mile radius around target injection zone(see attached): The map attached shows that, in addition to the offset producer 3R-101, there are two ENI wells that are within a 1/4 mile radius of the 3R-102 penetrations of the West Sak interval. These wells are OP21- WW01, and OP22-WW03. ENI has been mailed a copy of the application for injection per 20 AAC 25.402 (c)(3) Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 3R-102 is good and is classified as a normal well. The injection tubing/casing annulus is isolated via a Baker HRD-E ZXP packer located at MD = 8,445', TVD = 3,547' CBL and interpretation of the cement quality: See attached AOR detail for offset well condition. The 20" Conductor was cemented with 5 1/2 sx of Portland Cement The 10-3/4" Surface casing was cemented with 1,274 bbls LiteCrete The 7-5/8" Intermediate casing was cemented with 862 sx Class"G" Conditions for approval (if applicable): Post Initial inj MIT-IA required Include proof of written notification to ENI of injection per 20 AAC 25.402 (c)(3) B �m/t? Tv c� ;;jecoc cod 1if fin` 6., �� P� vGni7s� No /Peg/f welt � f�seN (e,Vtew {�r Cb�,vers;d/►. ��47 2 Lc - }\}{ \ -2 ) 2 §i - 8. \ } -.=4 2 2 0 e w | Z\ ƒ !] ) $\_ _ % c9 -2 7 t S!a 00 77@ _ } Een ) ( \r f [/ _ , zo, '— zz �— » 0 . - -/k \\{\ AL } |®_ } !®_ } | : 2 c we CO \ r ( § k \§ \ k \) G \) f \ ! ! ; e \ \; ; \{ } a { ± ,°3 / &® ! m = 72 5 % § \/ /�) G\ \! § t) 00 j ) ` V § « § � { o - - I : \! \{ - - -.3. 5 $ /} _ E. { ) W | ƒ � ! $` ! ti- ! - Ce `� $ /{ 0 \) �= �J ) \} r# \\ Q i 3 3 , w®] w `O 6 V 2 CC ! < |+ - r % , , , , , O P \ \ Qi F, - - - M 0 , , , , , \{ \ \ \ j ) `S \ \ 1 i, 4 15 g } }• § / 8 Li ) 02. .' )) )) \\ \ \j \ ® 0, m ! / $ \ k \ \ \ \ \ \ • AD L390616 AD L390615 ADL391283 1280 ac. �� 3780 ac. ENI US 1280 ac. ENI US ENI US Nikaitchuq Schrader �-�� _� Unit Bluff PA T1 4N R9E a..csa<s asas�+�•rsasa=s'a-s.rsa=s rsa-srsrs ss rs r�.s:s.r ... rsr..s...s a-srs�s.rs-a srs sasss:s...scsr�.ss rs rs.asrs.ra. Kuparuk i T13NR9E River 3R-101 Unit , 381101 3R-101L1 1 L1PB1 r 3R-102 1, OPP r6 •—..�.a.a.a..� 5 a i I ADL355024 E 931934000 i 11800 ac. i CPAI BP 1 CVX j XOM i N \ I ADL373301 V Kuparuk PA 931953000 7, 677 ac. CPAI BP ADL .5023 93193 000 CVX 3255 a.. XOM CPAI // / PV X Gr::--;-.1 a XOM `U.' 7 9 ,© Well Pad Well Trajectory IADL025513 monignage Open Interval 931796000 2560 ac. EnOpen Interval Quarter-mile Buffer ADL025512 CPAI 931795000 Other Active Wells 2544 ac. ConocoPhillips R...-.j Kuparuk PA CPAI „_� BP Alaska,Inc. L..aJ Schrader Bluff PA CVX •—•—• XOM N3 R-102 1AKUnit MI CPAI Feet Form 10-403 0 1,000 2,000 ail ENI US Date: 5/1/2017 • • 3R-102wp09 3-D View OP19-03,OP16-030,131,OP16-03L1PB • ' ....................... OP19-T1N,0P19-T1N,OP19-T1N Plan:3R-101,Plan:311-101,3R-101wp1 "- ... J Plan:3R-101,Plan:3R-101L1,3R-101L1wp1 .OP19-TIN,OP19 Tf NPBf,OP19-T1 NPBI . az s Plan'3R-102,Plan.3R-102.30-10 •s • • • lt. '' ll!! .......................... ..::. ... .. • OP22W W o3,OP22-W W03,OP22-W W03 .. .. . . .......................,...... 7/ 7'''' • ;` OP21-WW01 O'--wwo1,OP21 EraMIZEIZIE • -'klss�slss yn:ss: \ 30-120 3R-120 32-12a O—o d W E, N =g� d m , • ° s emm n Oo, ecoo-a1a a co r,ri l7 IT M en zn O cO pp`` @") V V (V V qa' N a V 'b b I I O M p, C i11 �r.7 III -',.1 ti A III .0 111 4 v 0 11 v N 00 M II Ln V1 oo 11 13 N N .N I �\ li I V �I b Q z)q II1 M I IIr. N II Z a II Cr 11 C] q meq+ ..a a1 1 N 00 N C` II P. 7b N a N O O O C1J E.4 j a q c o IIo Q a O I—� OM q cH - - • I I ,W a casco > 4 M v 4t qt CO U1 GM C M c, _ III •, JO C Vl O IIU N"I• o os.a Oq `aQ O Hi \ A q Ti .S4 .G CD a c 3 N - x -no io III a m o �/ m O .�.. Novo � q mm vU3 I1� I I Imo{ 'o U E (� ,-. _ k00 � Uq M dQH mi � Y � ' D ••g ' � 1 �j X CO A � 0N H c7v � r • R\ COQ "Z" .Y• "4.7 Ey q :-a X O Fr .v5. > }0 O a R V1 N CO en L' z^- U o0 at a oo C7 v @� , ,''C N 12,' 0 Mr ..., • O O T co Q x va F 0n> 2 0 000 rn F' co vi X XFv" o0 "foaol R - N �A m try L` V v •C M OCr).0 r MOEM .1 al O N o Co aoo o .4_______--------1HUa m q ti N O y L C 0. p N V 7 � " oo N 7 q C 1• O O O 0 CA v In 1.3 bAm '' 7 N ti▪ C-) m a O ConocoPhillips Well Schematic 3R-102(Injector) 3R-102 Completion Schematic As Run 4/17/2017 Alaska K Hanford TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Scott T. Pessetto Request of ConocoPhillips Alaska, Inc.for ) Converting to Injection for the 3R-102 Well ) under the Provisions of 20AAC 25.402(c)(3) ) STATE OF ALASKA ) §§ THIRD JUDICIAL DISTRICT ) Scott T. Pessetto, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Scott T. Pessetto, and I have personal knowledge of the matters set forth herein. 2. I am a Petroleum Engineer for the well operator,ConocoPhillips Alaska, Inc. ("CPAP') 3. Pursuant to 20 AAC 25.402(c)(3)CPAI prepared the attached application for injection. 4. On or about June 1, 2017, CPAI sent a copy of the application for injection by certified mail to the last known address of all other owners, landowners, surface owners, and operators of record within a one-quarter mile radius of the current proposed well trajectory. Subscribed and sworn to this 7th day of June,2017. `--4 (7<)------4— Scott ' t — Scott T. Pessetto STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 7th day of June,2017, by Scott T. Pessetto. 4--eL22.4_4, c( 2 t(7<Zr--) Notary Public, State of Alaska My Commission Expires: STATE OF ALASKA NOTARY PUBLIC ' REBECCA SWENSEN •" � 6A�CotWsNasian Ezp(�pip.77.2020. Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday, December 21, 2016 8:11 AM To: Hallford, Kelsey Subject: RE: 3R-102 injector new drill (PTD 216-157)AOR This should be processed in the next couple of days- From: Hallford, Kelsey [mailto:Kelsey.Hallford@conocophillips.com] Sent:Tuesday, December 20, 2016 3:27 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: RE: 3R-102 injector new drill(PTD 216-157)AOR Hello Victoria, As we're getting close to the Holidays and closed offices, I wanted to check in with you to see if you needed anything from me with regards to the 3R-102 PTD? Kelsey From: Hallford, Kelsey Sent:Thursday, December 08, 2016 1:05 PM To:'Loepp,Victoria T(DOA)'<victoria.loepp@alaska.gov> Subject: RE: 3R-102 injector new drill(PTD 216-157)AOR TheY4 mile plat is in the submitted PTD,directional plan attached here for easier access.The planned spud at the date of 10-401 submittal was December 15`h,there have been some rig schedule changes and we are now planning for spud between Last week of December and the first week of January. Kelsey From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday, December 08,2016 12:59 PM To: Hallford, Kelsey<Kelsey.Hallford@conocophillips.com> Subject: [EXTERNAL]RE:3R-102 injector new drill (PTD 216-157)AOR Kelsey, We can't permit a well as an injector without a review. Approving a PTD for a well as an injector implies injection is approved.The AOR is always required for a injector PTD(10-401).The other option is to permit the well as a producer and submit a 10-403 for conversion to a WI at such time an AOR would be required. The table below looks complete. I will review. Do you have a map that indicates all wells in the X mile radius?That should be included. What is the planned spud date? Thanx, 1 Victoria From: Hallford, Kelsey[mailto:Kelsey.Hallford@conocophillips.com] Sent:Thursday, December 08,2016 11:47 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: RE: 3R-102 injector new drill(PTD 216-157)AOR Victoria, Is the below spreadsheet sufficient for the AOR?Guy mentioned this wasn't required until we applied for a permit to inject via the 10-403 form as we will need a sundry to switch from pre-production to injection, and I didn't find any guidance under the drilling regulations on the AOGCC site. Let me know if there is further information you're requesting. Top of West Sak TOC Determined Well Name Status D Sand(MD/ TOC(MD/TVD) By Reservoir Status Zonal Isolal TVD) Proposed Column of cern( 3R-102 8,427'/3,528' 5,044'/3,020' Sonic LWD Not Yet Drilled 500'above Ug Injector 5,044'MD/3,C Calculated with Perfs open for Column of cern 3,826' MD to OP21ww01 Water Producer 3,883'/3,516' 2,960'/2,865' 40%washout, no production in 2,860' MD, is( losses during job Ivishak West Sa Perfs open for Surface csg set t Returns to D Sand @ 4,02 OP22ww03 Water Producer 3,815'/3,523' Surface surface production in 3,728'TVD, Ivishak cemented to s Thanks, Kelsey From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday, December 08,2016 7:25 AM To: Hallford, Kelsey<Kelsey.Hallford@conocophillips.com> Subject: [EXTERNAL]RE: 3R-102 injector new drill (PTD 216-157)AOR Kelsey, To be approved and permitted as an injector,an AOR is necessary as a part of the 10-401 permit. Please provide this data for review. I understand Guy forwarded his AOR information paper for your reference. 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 2 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.Loem@alaska.gov From:Hallford, Kelsey [mailto:Kelsey.Hallford@conocophillips.comj Sent:Wednesday, December 07,2016 4:12 PM To:Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov>;Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov>; Bearden,J Daniel<J.Daniel.Bearden@conocophillips.com> Subject: RE:3R-102 injector new drill (PTD 216-157) Victoria, I have had a couple discussions with Guy regarding his request for AOR and notification for the two ENI Oliktok Point wells that are within the 1/4 mile radius of our wellbore. However,after discussing these items with our compliance team, I believe both of those requests will be addressed when we submit the Permit to Inject(10-403)as this is a pre-produced injector. While the AOR and notification will accompany the 10-403, I have done the due diligence at this stage to ensure zonal isolation for both OP21ww01(PTD 210-187)and OP22ww03 (PTD 213-054). Both of these water source wells have cement across the West Sak interval in either their surface or intermediate casing strings. Is this data something you require for your review of the 10-401 for 3R-102 injector(PTD 216-157)? Please let me know if you require further information. Regards, Kelsey Hallford GKA Drilling Engineer ConocoPhillips,Alaska 907-265-1577 work 907-440-0004 cell From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Tuesday, November 22,2016 3:25 PM To: Hallford, Kelsey<Kelsey.Hallford@conocophillips.com> Cc: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject: [EXTERNAL]RE: 3R-102 injector new drill (PTD 216-157) Kelsey, Had the wrong email for you .. here you go. Re attached the AOR tips letter. Guy Schwartz Sr. Petroleum Engineer 3 • AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226)or(Guv.schwartz@alaska.gov). From:Schwartz,Guy L(DOA) Sent:Tuesday, November 22,2016 3:21 PM To:'Kelsey.hallfod@cop.com'<Kelsey.hallfod@cop.com> Cc: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject: RE: 3R-102 injector new drill (PTD 216-157) Kelsey, Also per 20 AAC 25.402(C)(3)you must notify any operators or surface owners within%mile of the injector are notified and provided a copy of the application for injection (ie PTD). This would obviously be ENI. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Schwartz,Guy L(DOA) Sent:Tuesday, November 22,2016 3:08 PM To: Keisey.hallfod@cop.com Cc: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject:3R-102 injector new drill (PTD 216-157) Kelsey, In looking over the Permit to Drill application I didn't see much information regarding a%mile AOR . The ENI Oliktok Point wells should be included if they are within the 1/4 mile area. The 3D plots make It appear that they have wellbores that pass thru the West Sak sands within the area limits. Attached is a tips note I put out last year. 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U V • - U E 0 . 0 0. c, p 0 Q Q Q 0 0 0 0 Q Q o o a) o 2 aa)) O o ate) a d a M w Lu W w w w w Lu w J J 3 ? 0 a 0 0 0 C ! t o r o N N N. bZ cg M N ch U_ N e N z i II 11 11% J z O \, z ill' g ° Ct a c 0 a a J J W _ f d 0 oI W z J C.) c°, o z Q y3 J o 0. is c 2 — o O I O N p N E w co o v Q . 0s th H I- W > N 1W ) 11, V/ cc 4 N 0 AI"a Iry Qo Y g a' Q a Z £ 0 m U z / d coc co 1 in m i ,_ .a m CO 3 N u' a) a. o Q�j N V p C G C) •+ a) l0 0 E E E a. � Q 2 C.) c) • • �z Pri) 510 Regg, James B (DOA) From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Wednesday, July 19, 2017 4:22 PM `e�G ( i'l(17 To: Regg,James B (DOA) Subject: Defeated LPP/SSV on KRU Well 3R-102 (PTD# 216-157) on 07/19/2017--correction Hello Jim, Just arrived back on the slope. My alternate left a draft for Lynn, and I think she missed the date change. Apparently they attempted to bring the well onto injection on July 4, but the tubing was frozen. Actual injection commenced at 06:44 this morning,July 19th, after a cleanout. The safety defeated log was updated this morning and the well was manned until the note was sent to you. Sorry for the confusion. 91xanen.C'oyd Kenneth Lloyd Martin/Toon Changklungdee PERA/CPF3 Production Engineers Ph: (907)659-7871 Pager: (907) 659-7000 pp#328 Subject: [EXTERNAL] RE: Defeated LPP/SSV on CPAI Well 3R-102 on 07/03/2017 I need a better timeline here. You defeated the pilot on 7/3 andare just now notifying us? Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: CPF3 Prod Engrs [mailto:n1223@conocophillips.com] Sent:Wednesday,July 19, 2017 7:47 AM To: Regg,James B (DOA) <jim.regg@alaska.gov> 1 • rt • Cc: NSK Optimization Engr<n2046@conocophillips.com>; CPF3 DS Lead Techs<n1105@conocophillips.com> Subject: Defeated LPP/SSV on CPAI Well 3R-102 on 07/03/2017 Mr. Regg, The low pressure pilot(LPP) on injection well 3R-102 (PTD#216-157)was defeated 7/3/16.The well was recently drilled and flowed back for approximately 25 days.The well has been converted and returned to injection on 7/3/2017, however the wellhead pressure did not rise high enough to place the low pressure pilot in service. The well is currently at a wellhead injection pressure of 78 psig and rate at 485 BWPD.The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 PSIG and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Thank you, Lynn Aleshire Lynn Aleshire/Kenneth L. Martin CPF3 Production Engineer Office:(907)659-7871 Pager: (907)659-7000 pp 328 2 214 1 S-3- Z6 t2 2 S ClilUlilbelag er Transmittal#: 28JUN17-SPO1 Drilling & Measurements RECEIVED Product Delivery jLiN 2 8 2017 Customer ConocoPhillips Dispatched To: AOGCC: Meredith Guhl AOGCC Well No 3R-102- REVISED Date Dispatched: 28-Jun-17 Service Order# 17AKA0004 Dispatched By: Stephanie Pacillo Product Description Hardcopy Digital Copy Date Color Log Prints: N/A Contents on CD 19-Mar-17 VISION*Service 2" MD x 2"TVD x 5" MD x 5"TVD x Digital Data ► EVi, N/A Contents on CD 19-Mar-17 LAS/DLIS Data x composite DLIS includes GR data CD 1 Contents on CD 19-Mar-17 Data: DLIS/LAS x Graphics: PDF x Surveys: PDF/XLS x Please sign and email a copy to: Please sign and email a copy to: Tom.Osterkampconocophillips.com AlaskaPTSPrintCenter(c�slb.com Attn:Tom Osterkamp Attn:Stephanie Pac illo Received By: � P � �, w/(9--61 f l �' • PTV � 157-- Loepp, Victoria T (DOA) From: Sullivan, Michael <Michael.Sullivan@conocophillips.com> Sent: Thursday, May 18, 2017 10:44 AM To: Loepp,Victoria T(DOA); Regg,James B (DOA) Cc: CPF3 Prod Engrs; Driscoll, Michael D; Pessetto, Scott T Subject: RE: KRU 3R-102i(PTD 216-157) Request for Permission to resume manned production Follow Up Flag: Follow up Flag Status: Flagged Victoria, After internally discussing our options.We have decided to remove the faulty K-valve,and continue with 24-hour manned production until June 1st.After which,well 3R-102 will be SI and converted to injection. Before bringing the well online injection,all necessary paperwork will be filed and approval given. Thanks again, Michael Sullivan Viscous Petroleum Engineer ConocoPhillips Alaska Office: 907-263-4123 Cell: 907-231-9953 From:Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday, May 17,2017 1:47 PM To:Sullivan, Michael<Michael.Sullivan@conocophillips.com>; Regg,James B(DOA)<jim.regg@alaska.gov> Cc: Regg,James B(DOA)<jim.regg@alaska.gov> Subject: [EXTERNAL]RE: KRU 3R-102i(PTD 216-157) Request for Permission to resume manned production Michael, Continuing 24-hour manned production is acceptable. A SSSV must be installed and have a passing test,or the well must be shut in no later than June 1—30 days from the start of the well test. Use of a K valve does require a sundry application and approval. Please submit as soon as possible if you plan to install another type of k valve. 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.Loep,i 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.Loem@alaska.gov 1 • • From:Sullivan, Michael [mailto:Michael.Sullivan@conocophillips.com] Sent:Wednesday, May 17, 2017 10:53 AM To: Regg,James B(DOA)<iim.regg@alaska.gov>; Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:CPF3 Prod Engrs<n1223@conocophillips.com>; Pessetto,Scott T<Scott.T.Pessetto@conocophillips.com>; Driscoll, Michael D<Michael.D.Driscoll@conocophillips.com> Subject: RE: KRU 3R-102i(PTD 216-157) Request for Permission to resume manned production Jim, I am told the surface safety systems were tested and passed all tests Michael Sullivan Viscous Petroleum Engineer ConocoPhillips Alaska Office: 907-263-4123 Cell: 907-231-9953 From: Regg,James B(DOA) [mailto:jim.regg@alaska.gov] Sent:Wednesday, May 17,2017 10:51 AM To:Sullivan, Michael<Michael.Sullivan@conocophillips.com>; Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:CPF3 Prod Engrs<n1223@conocophillips.com>; Pessetto,Scott T<Scott.T.Pessetto@conocophillips.com>; Driscoll, Michael D<Michael.D.Driscoll(Wconocophillips.com> Subject: [EXTERNAL]RE: KRU 3R-102i(PTD 216-157) Request for Permission to resume manned production Was the entire SVS tested or just the Kvalve? Jim Regg Supervisor, Inspections AOGCC 333 W.7ch Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or lim.regg@alaska.gov. From:Sullivan, Michael [mailto:Michael.Sullivan@conocophillips.com] Sent:Wednesday, May 17,2017 10:45 AM To: Regg,James B(DOA)<jim.regg@alaska.gov>; Loepp,Victoria T(DOA)<victoria.Ioepp@alaska.gov> Cc:CPF3 Prod Engrs<n1223@conocophillips.com>; Pessetto,Scott T<Scott.T.Pessetto@conocophillips.com>; Driscoll, Michael D<Michael.D.Driscoll@conocophillips.com> Subject: KRU 3R-102i(PTD 216-157) Request for Permission to resume manned production Importance:High Victoria/Jim, 3R-102 failed a state witnessed test of the type K SSSV this morning. I am told the surface safety system passed its test. 2 • • We had chosen to install and test a type K valve because it appeared the well would fail a no-flow test. We would like to return the well to"24 hour manned" production until the end of our scheduled 30 day test period. We will be pursuing the installation of another type K valve,and if we are successful in installing another K valve before the end of the test period we will request another state witnessed test. Because the well now has a failed SSSV,we want to specifically confirm that it is acceptable to the AOGCC to return the well to production under manned operation. The well is currently shut in and will not be returned to manned production until we receive a response from you. Thanks in advance, Michael Sullivan Viscous Petroleum Engineer ConocoPhillips Alaska Office: 907-263-4123 Cell: 907-231-9953 From: Regg,James B(DOA) [mailto:iim.regg@alaska.gov] Sent:Wednesday, May 03, 2017 9:09 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; NSK Prod Engr Specialist<n1139@conocophillips.com> Subject: [EXTERNAL]RE: KRU 3R-102i(PTD 216-157)SSSV Requirement during pre-production This is predicated on a passing performance test of the LPS and SSV per regulation for a new well—refer to 20 AAC 25.265(h)(4). From:Loepp,Victoria T(DOA) Sent:Wednesday, May 3, 2017 8:36 AM To: NSK Prod Engr Specialist<n1139@conocophillips.com> Cc: Regg,James B(DOA)<jim.regg@alaska.gov> Subject: RE: KRU 3R-102i(PTD 216-157)SSSV Requirement during pre-production Darrell, The No Flow Test procedure outlined in your attached document is consistent with Guidance Bulletin 10-004 and is approved. The well may be unmanned for the 14 days after the well is put into service while conducting a NFT and/or installing a K valve. After 14 days,the well must be manned if the well is capable of unassisted flow and the SSSV is not operable. 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 aC�.alaska.eov 3 • CONFIDENTIALITY NOTICE:This e-mail messse,including any attachments,contains informati from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: NSK Prod Engr Specialist [mailto:n1139@ conocophillips.comj Sent:Tuesday, May 02,2017 6:08 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; Regg,James B(DOA)<jim.regg@alaska.gov> Cc:Coberly,Jonathan<Jonathan.Coberly@conocophillips.com>; Driscoll, Michael D <Michael.D.Driscoll@conocophillips.com>; NSK POP Lead<n2490@conocophillips.com>;Sullivan, Michael <Michael.Sullivan@conocophillips.com>; CPF3 Prod Engrs<n1223@conocophillips.com>;CPF3 Ops Supv <n2070@conocophillips.com> Subject: RE: KRU 3R-102i(PTD 216-157)SSSV Requirement during pre-production Victoria, Please review and provide written approval for the No Flow Test procedure enclosed.We would like to conduct this test on Saturday 5/6/17 and we will provide the State Inspector 24hr notice of the planned test. In regards to your note below;AOGCC regulations state that a subsurface safety valve can be temporarily blocked or removed from a well and but has to be made operable and tested within 14 days from the date the well is returned to service. I was wondering if this would apply to 3R-102 and we would not have to man the well for 14 days while we conduct the No Flow Test and the SVS test. If the well does not obtain an acceptable No Flow Test then it would be manned for the continuation of the 30 day pre-production period or a K valve installed. Please let us know if this is acceptable. Thanks, Darrell Humphrey/Matthew Raiche Production Engineering Specialist IPV ConocoPhillips Alaska Ph:907.659.7535 I Pg:924 I Mail: NSK 69 From:Sullivan, Michael Sent:Tuesday, May 02,2017 2:54 PM To:CPF3 Prod Engrs<n1223@conocophillips.com> Cc: NSK Prod Engr Specialist<n1139@conocophillips.com>;Coberly,Jonathan<Jonathan.Coberly@conocophillips.com>; Driscoll, Michael D<Michael.D.Driscoll@conocophillips.com>; NSK POP Lead<n2490@conocophillips.com> Subject: FW: KRU 3R-102i(PTD 216-157)SSSV Requirement during pre-production All, See below the AOGCC response regarding our concerns with the 3R-102 pre-production period. Toon, Please relay this to Operations and move forward with your preferred option. Thanks in advance, Michael Sullivan Viscous Petroleum Engineer 4 ConocoPhillips Alaska • • Office: 907-263-4123 Cell: 907-231-9953 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, May 02,2017 2:49 PM To:Sullivan, Michael<Michael.Sullivan@conocophillips.com> Cc: Regg,James B(DOA)<iim.regg@alaska.gov> Subject: [EXTERNAL]KRU 3R-102i(PTD 216-157)SSSV Requirement during pre-production Michael, We discussed several options concerning pre-producing KRU 3R-102i without a SSSV for 30 days. 1. Produce the well several days and perform a NFT. If the well passes a NFT,then it is acceptable to produce the well without a SSSV. If the well flows on its own, install a K valve OR produce the well with manned surveillance during the 30 day pre production period. 2. Produce the well for 30 days with manned surveillance. Please refer to AOGCC Guidance Bulletin No 10-004 concerning No Flow Testing(NFT). 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.Loeppalaska.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.Loepo@alaska.gov From:Sullivan, Michael [mailto:Michael.Sullivan@conocophillips.com] Sent:Sunday,April 30,2017 3:10 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Driscoll, Michael D<Michael.D.Driscoll@conocophillips.com>; CPF3 Prod Engrs<n1223@conocophillips.com> Subject:3R-102 Pre-Production Clarification Importance: High Victoria, We are prepared to bring online injection well 3R-102 on Tuesday May 2"4, but would like some clarification before we do so. Our plan is to pre-produce well 3R-102 without a SSSV for a total of 30 days.The SSV and LPP will be in service and tested per AOGCC requirements.The pre-production will be manned during the initial startup of the well,which is expected to last approximately 12 hours.After the initial startup,the manned operation will be terminated but extra surveillance will be provided for the remainder of the pre-production period. 5 • • After the pre-production period has completed,well 3R-102 will be converted to injection service and a SSSV will be installed. 1. Is pre-producing the well with the LPP and SSV in service and without a SSSV for 30 days acceptable? 2. Is having the pre-production period un-manned (without a SSSV)after the initial startup acceptable? Thanks in advance, Michael Sullivan Viscous Petroleum Engineer ConocoPhillips Alaska Office: 907-263-4123 Cell: 907-231-9953 6 Loepp, Victoria T (DOA) From: Regg,James B (DOA) Sent: Wednesday, May 03,2017 9:09 AM To: Loepp,Victoria T(DOA); NSK Prod Engr Specialist Subject RE: KRU 3R-102i(PTD 216-157) SSSV Requirement during pre-production Follow Up Flag: Follow up Flag Status: Flagged This is predicated on a passing performance test of the LPS and SSV per regulation for a new well—refer to 20 AAC 25.265(h)(4). From: Loepp,Victoria T(DOA) Sent:Wednesday, May 3, 2017 8:36 AM To: NSK Prod Engr Specialist<n1139@conocophillips.com> Cc: Regg,James B(DOA)<jim.regg@alaska.gov> Subject: RE: KRU 3R-102i(PTD 216-157)SSSV Requirement during pre-production Darrell, The No Flow Test procedure outlined in your attached document is consistent with Guidance Bulletin 10-004 and is approved. The well may be unmanned for the 14 days after the well is put into service while conducting a NFT and/or installing a K valve. After 14 days,the well must be manned if the well is capable of unassisted flow and the SSSV is not operable. 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.00v CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: NSK Prod Engr Specialist[mailto:n1139@conocophillips.com] Sent:Tuesday, May 02,2017 6:08 PM To:Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; Regg,James B(DOA)<jim.regg@alaska.gov> Cc:Coberly,Jonathan<Jonathan,Coberly@conocophillips.com>; Driscoll, Michael D <Michael.D.Driscoll@conocophillips.com>; NSK POP Lead<n2490@conocophillips.com>;Sullivan, Michael <Michael.Sullivan@conocophillips.com>;CPF3 Prod Engrs<n1223@conocophillips.com>;CPF3 Ops Supv 1 • I <n2070@conocophillips.com> Subject: RE: KRU 3R-102i(PTD 216-157)SSSV Requirement during pre-production Victoria, Please review and provide written approval for the No Flow Test procedure enclosed.We would like to conduct this test on Saturday 5/6/17 and we will provide the State Inspector 24hr notice of the planned test. In regards to your note below;AOGCC regulations state that a subsurface safety valve can be temporarily blocked or removed from a well and but has to be made operable and tested within 14 days from the date the well is returned to service. I was wondering if this would apply to 3R-102 and we would not have to man the well for 14 days while we conduct the No Flow Test and the SVS test. If the well does not obtain an acceptable No Flow Test then it would be manned for the continuation of the 30 day pre-production period or a K valve installed. Please let us know if this is acceptable. Thanks, Darrell Humphrey/Matthew Raiche Production Engineering Specialist ConocoPhillips Alaska Ph:907.659.7535 I Pg:924 I Mail: NSK 69 From:Sullivan, Michael Sent:Tuesday, May 02,2017 2:54 PM To:CPF3 Prod Engrs<n1223@conocophillips.com> Cc: NSK Prod Engr Specialist<n1139@conocophillips.com>;Coberly,Jonathan<Jonathan.Coberly@conocophillips.com>; Driscoll, Michael D<Michael.D.Driscoll@conocophillips.com>; NSK POP Lead<n2490@conocophillips.com> Subject: FW: KRU 3R-102i(PTD 216-157)SSSV Requirement during pre-production All, See below the AOGCC response regarding our concerns with the 3R-102 pre-production period. Toon, Please relay this to Operations and move forward with your preferred option. Thanks in advance, Michael Sullivan Viscous Petroleum Engineer ConocoPhillips Alaska Office: 907-263-4123 Cell: 907-231-9953 From: Loepp,Victoria T(DOA) [mailto:victoria.Ioepp@alaska.gov] Sent:Tuesday, May 02,2017 2:49 PM To:Sullivan, Michael<Michael.Sullivan@conocophillips.com> Cc: Regg,James B(DOA)<jim.regg@alaska.gov> Subject: [EXTERNAL]KRU 3R-102i(PTD 216-157)SSSV Requirement during pre-production Michael, 2 • • We discussed several options concerning pre-producing KRU 3R-102i without a SSSV for 30 days. 1. Produce the well several days and perform a NFT. If the well passes a NFT,then it is acceptable to produce the well without a SSSV. If the well flows on its own, install a K valve OR produce the well with manned surveillance during the 30 day pre production period. 2. Produce the well for 30 days with manned surveillance. Please refer to AOGCC Guidance Bulletin No 10-004 concerning No Flow Testing(NFT). 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(tilalaska.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.Loeou@alaska.gov From:Sullivan, Michael [mailto:Michael.Sullivan@conocophillips.com] Sent:Sunday,April 30,2017 3:10 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc: Driscoll, Michael D<Michael.D.Driscoll@conocophillips.com>;CPF3 Prod Engrs<n1223@conocophillips.com> Subject:3R-102 Pre-Production Clarification Importance: High Victoria, We are prepared to bring online injection well 3R-102 on Tuesday May 2"d, but would like some clarification before we do so. Our plan is to pre-produce well 3R-102 without a SSSV for a total of 30 days.The SSV and LPP will be in service and tested per AOGCC requirements.The pre-production will be manned during the initial startup of the well,which is expected to last approximately 12 hours.After the initial startup,the manned operation will be terminated but extra surveillance will be provided for the remainder of the pre-production period. After the pre-production period has completed,well 3R-102 will be converted to injection service and a SSSV will be installed. 1. Is pre-producing the well with the LPP and SSV in service and without a SSSV for 30 days acceptable? 2. Is having the pre-production period un-manned(without a SSSV)after the initial startup acceptable? Thanks in advance, Michael Sullivan Viscous Petroleum Engineer ConocoPhillips Alaska Office: 907-263-4123 3 . v ' • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION - _ WELL COMPLETION OR RECOMPLETION REPORT A la.Well Status: Oil 2 • Gas❑ SPLUG❑ Other ❑ Abandoned ❑ Suspended❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development 0 - Exploratory❑ GINJ ❑ WINJ❑ WAGE WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6.Date Comp.,Susp.,or 14.Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 3/22/2017 216-157/ 3.Address: 7. Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 2/28/2017 . 50-029-23572-00-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 1659'FNL,2949'FEL,Sec 9,T13N,R9E,UM 3/172017 • KRU 3R-102 • �, Top of Productive Interval: 9. Ref Elevations: KB:48.9 17. Field/Pool(s): Wes ,S.K ib 2142'FNL, 1471'FEL,Sec 5,T13N, R9E,UM GL: 9.9 BF: Kupurak River Field/Kupw k Oil Pool Total Depth: 10.Plug Back Depth MD/TVD: 18. Property Designation: 2867'FNL,2415'FEL,Sec 6,T13N,R9E, UM N/A ADL 355023,ADL 373301,ADL 35502 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 520636 y- 6031704 Zone- 4 14,950 b,38(2 931695 TPI: x- 516809 y- 6036490 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 510590 y- 6035754 Zone- 4 N/A 1734/1695 5.Directional or Inclination Survey: Yes - 2 (attached) No ❑ 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) I N/A 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to:mud log,spontaneous potential, gamma ray,caliper,resistivity,porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res/GWD/Periscope/NMR/DEN/Porosity/SonicScope/ t A.JJC, S,u.t:'./2.4/,1- 23. CASING, LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 20 94 H-40 39 119 39 119 42 5 1/2 sx of Portland Cement 10.75 45.5 L-80 42 2291 42 2170 13.5 1274 sx, 11.0ppg LiteCrete W5 5$ 7.625 29.7 L-80 1836 8595 1790 3563 9.875 862 sx 15.8ppg,Class G 4.5 11.6 L-80 8445 12582 3549 3549 6.75 Slotted Liner 24.Open to production or injection? Yes 2 No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/ND of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/ND) Size and Number): 4 1/2 8,492 N/A SLOTTED LINER @ 8616-9289 MD and 3566-3585 ND 26.ACID,FRACTURE,CEMENT SQUEEZE, ETC. 9409 10083 MD and 3583 3553 ND }, Was hydraulic fracturing used during completion? Yes❑ No 2 10371 -10792 MD and 3556-3561 TVD 11078-11795 MD and 3563-3563 ND '517/1(t.1_ Per 20 AAC 25.283(i)(2)attach electronic and printed information 11878-12510 MD and 3560-3550 ND ' '"°' DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 10371 -10792 MD and 3566-3585 ND k,v 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): WAITING FOR HOOKUP 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 1/77- 47/(4137-47/� i RDMS �� P°`.'" - 2 2017 Forrrl yis��11/2015 �� CONTINUED ON PAGE 2 Submit ORIGINIAL on' • • 28.CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No DI If Yes,list formations and intervals cored(MD/TVD,From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No E Permafrost-Top Surface Surface If yes,list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1734 1695 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 8595 3562 information, including reports,per 20 AAC 25.071. West Sak D Sand UGNU C 3663 2809 UGNU B 5915 3173 UGNU A 6397 3256 WEST SAK D 8544 3558 TD 14950 3386 Formation at total depth: WEST SAK D 31. List of Attachments: Daily Operations Summary,Definitive Survey,Cement Report,Schematics Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report.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: Kelsey Hallford ft 265-1577 Email: kelsey.hallfordncop.com Printed Name: C.L.Af rU �e�ef ‘Aakkc001,. Drilling.M negef A aA! Signature: / Phone: 265-6120 Date: 2_0) i INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: 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 lb: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results,including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report, production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • Wellhead/Tubing Head/Tree, 10-3/4"x 4-1/2",5,000 psi 3R-102 Injector (As Run) Slotted Liner I L 4.5 x 3.812"DB nipple @ 1971'MD/1909'TVD(29.69 deg) Gas Lift Mandrel, CAMCO 4.5"x 1"KMBG w/Dummy,BK-5 Latch @ 2601'MD/2397'TVD(44.59 deg) Tubing String: 4-1/2",12.6#,L-80 TXP Mule Shoe depth of 8492'MD Gas Lift Mandrel, CAMCO 4.5"x 1"KMBG w/2500 psi SOOV,BEK Latch @8266'MD/3524'TVD(82.03 deg) 4.5"x 3.75"DB-6 nipple @ 8334.83'MD/3533'TVD(82.21 deg) it 4.5"Halliburton Mirage Plug @ 8398'MD/3541'TVD(82.8 deg) 4-1/2"Slotted Liner TD @ 12582'MD/3549'TVD 6-3.4"OH TD @ 92 degrees @ 14950'MD/ packer&Liner Hanger Slotted Liner, 4-1/2", 3987'Lined Lateral 3386'ND 8445'MD/3547'TVD11.6#L80 IBTM @93 degrees @83.3 degress f):. � 6355'Lateral 50 ft above 7-5/8"shoe) ir-ii ® 111 _n 7-5/8",29.7#,L-80,Hyd563,Casing NI = S _*E_ ;' ' @ 8595'MD/3563'TVD @ 85.34 degrees 6"Swell Packer 6"Swell Packer i 6-3/8"Swell Packer_74-1/2"Solid Shoe TD 9-7/8"hole #5—CC—10361'MD #3—AA—11068'MD #1—A—12544'MD #6—DD—10097'MD #4—BB—10805'MD #2—B—12522'MD KUP C 3R-102 onoc #I M(ll1 15 Well Attribt Max AngIeD TD Alaska,Inc,. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Canoco`Pfliihps 500292357200 TRACT OPERATION WSAKTRO5 SVC 96.27 13,808.53 14,950.0 .-. Comment H2S(ppm) Date Annotation End Date KB-Grd(R) -Rig Release Date 3R-102,4/20/20176:45:04 AM SSSV:NIPPLE Last WO'. 39.10 3/22/2017 • Vertical schematic.(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:New Well jennalt 4/18/2017 HANGER;9A i. •Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(L..Grade Top Thread CONDUCTOR 20 19.124 39.0 119.0 119.0 62.58 B Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(L..Grade Top Thread SURFACE 103/4 9.950 41.7 2,291.5 2,169.9 45.50 L-80 Hydril 563 Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread INTERMEDIATE 75/8 6.875 1,835.8 8,595.1 3,563.4 29.70 L-80 Hyd563 III Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread I LINER 41/2 4.000 8,445.5 12,582.0 3,548.7 11.60 L-80 IBT-m Liner Details CONDUCTOR;39.0-119.0 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Inc!(°) Item Des Com (in) 8,465.4 3,549.2 83.53 NIPPLE Baker 5""RS"Packoff Seal Nipple 15.5 ppf L-80 Hyd 4.860- 563 box x box 8,468.2 3,549.6 83.56 HANGER Baker 5.5"x 7.625"Flex-Lock Liner Hanger L-80 Hyd 4.810 /2 NIPPLE;1,970.5 563 pin x pin 8,478.0 3,550.7 83.67 SBE Baker 190-47 Sealbore Extension,5-1/2"L-80 Hyd 4.750 563 box x 5.5"Hyd 563 pin 10,097.4 3,552.7 92.24 Swell Packer Baker-"Swell Packer#6-"DD"6.00"OD SN: 3.930 052826-001-36-MOD 10,360.9 3,556.1 87.38 Swell Packer Baker-"Swell Packer#5-"CC"6.00"OD SN: 3.970 052826-001-39-MOD SURFACE;41.7-2,291.5 10,804.6 3,561.6 89.47 Swell Packer Baker-"Swell Packer#4-"BB"6.00"OD SN: 3.920 I 052826-001-30-MOD GAS LIFT;2,801.2 11,068.1 3,563.7 91.43 Swell Packer Baker-"Swell Packer#3-"AA"6.00"OD SN: 3.940 I 052826-001-22-MOD I 12,522.3 3,550.0 91.65 Swell Packer Baker-"Swell Packer#2-"B"6.37"OD SN: 3.970 049169-001-16 GAS LIFT;8,268.1 12,543.9 3,549.5 91.41 Swell Packer Baker-"Swell Packer#1-"A"6.37"OD SN: 3.970 049168-001-34 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.. Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection NIPPLE;9,334.8 - ///SING 41/2 3.958 9.4 8,492.4 3,552.2 12.60 L-80 TXP-m Completion Details Nominal ID ■ Top(ftKB) Top(TVD)(ftKB) Top Incl TI Item Des Com (in) w u�,e.397 9.4 9.4 0.02 HANGER Vetco Gray 13-1/2"x 4-1/2"MB228 Tubing hanger to LDS 3.900 1,970.5' 1,910.0 29.69 NIPPLE Camco 4-1/2"x 3.812"DB-6 nipple 29.69 3.812 Deg/1909'TVD LOCATOR;8,451.5 ,III® 8,334.8 3,533.0' 82.20 NIPPLE Camco 4-1/2"x 3.75"DB-6 nipple 3.750 A, 82.21 Deg/3533'TVD 8,397.6' 3,541.2' 82.80'PLUG Halliburton 4-1/2"Mirage Plug,Hyd 563 3.880 SEAL ASSY;8,452.3 82.80 deg/3541'TVD (l€ 8,451.5 3,547.7 83.38 LOCATOR Baker Locator(OD 5.49")8 Crossover collar on top of - 3.930 lik4.5"STL joint 8,452.4 3,547.8 83.39 SEAL ASSY Baker Seal Assembly---below located 3.870 Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn INTERMEDIATE;1,835.8- 1 8,616.8 9,288.7 3,565.8 3,584.6 3/20/2017 32.0 SLOTS 8 x slots in a row at 3" 8,595.1 long per slot,giving 32 x slots per foot SLOTS;8,616.8-9,288.7 4 ' 9,409.0 10,083.5 3,583.3 3,553.2 3/20/2017 32.0 SLOTS 8 x slots in a row at 3" Clong per slot,giving 32 x SLOTS;9,409.0-10,083.5 i- slots per foot -"If 10,370.9 10,792.4 3,556.5- 3,561.5 3/20/2017 32.0 SLOTS 8 x slots in a row at 3" long per slot,giving 32 x slots per foot 11,078.1 11,794.8 3,563.4 3,563.2 3/20/2017 32.0 SLOTS 8 x slots in a row at 3" long per slot,giving 32 x slots per foot 11,818.3 12,510.3 3,559.7 3,550.4 3/20/2017 32.0 SLOTS 8 x slots in a row at 3" Sr long per slot,giving 32 x slots per foot SLOTS;10,370.9-10,792.4 J Mandrel Inserts11611 _ St • ati N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD lin) Sera Type Type (in) (psi) Run Date Corn 1 2,601.2' 2,397.3 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 3/21/2017 2 8,266.1 3,523.4 Camco KBMG 1 GAS LIFT SOV BEK 0.000 0.0 3/21/2017 Notes:General&Safety End Date Annotation NOTE' SLOTS;11,078.0-11,794.7 SLOTS;11,876.312510.3 L I lit lir LINER;8,445.5-12,582.0 • Operations Summary (with Timelogtpths) 0 0 3R-102 ifs Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/25/2017 2/25/2017 2.00 MIRU MOVE RURD P Release from 1D-103 @ 16:00 hrs. 0.0 0.0 16:00 18:00 Unplug electrical interconnect from modules,pull motor,pump,and pit modules apart and stage on pad. 2/25/2017 2/25/2017 0.50 MIRU MOVE RURD P Remove rig mats from under motor, 0.0 0.0 18:00 18:30 pump,and pit modules. 2/25/2017 2/25/2017 1.00 MIRU MOVE RURD P Skid floor and raise stompers. 0.0 0.0 18:30 19:30 SIMOPS-Install sub tow tongue and raise cellar door. 2/25/2017 2/25/2017 1.00 MIRU MOVE MOB P Hook up sow truck and bulldozers to 0.0 0.0 19:30 20:30 sub and pull sub off 1D-103. Note:Weather condition increased to phase 1 fieldwide main roads and phase 2 fieldwide for drillsites and access roads at 20:30 hrs. 2/25/2017 2/25/2017 2.00 MIRU MOVE MOB P Stage all modules on spine road for 0.0 0.0 20:30 22:30 transporting to 3R. Note:Weather condition continuing to deterioate to phase 2 fieldwide on all roads at 21:45 hrs. 2/25/2017 2/26/2017 1.50 MIRU MOVE MOB P Move rig in 1 x convoy from 1D to 0.0 0.0 22:30 00:00 KOC. 2/26/2017 2/26/2017 10.50 MIRU MOVE MOB T Stage rig at KOC and wait on weather. 0.0 0.0 00:00 10:30 Weather continuing to deterioate to phase 2 on main roads/phase 3 on drill sites and access roads at 01:00 hrs.Clean and maintain rig equipment. 2/26/2017 2/26/2017 1.50 MIRU MOVE MOB P Move rig from KOC to 1Q-pad and 0.0 0.0 10:30 12:00 change out crews. 2/26/2017 2/26/2017 1.50 MIRU MOVE MOB P Move rig from 1Q-pad and stage at 12 0.0 0.0 12:00 13:30 acre pad. 2/26/2017 2/26/2017 1.50 MIRU MOVE MOB P Clear snow from 3R-pad.Set pump 0.0 0.0 13:30 15:00 and power complex on stompers and release 3 x sow trucks.Transport truck shop and parts trailer to 12 acre pad. 2/26/2017 2/26/2017 1.75 MIRU MOVE MOB P Transport pit module and sub complex 0.0 0.0 15:00 16:45 from 12 acre pad to 3R-pad.Stage pit complex on pad and line up sub for spotting over well. 2/26/2017 2/26/2017 0.25 MIRU MOVE MOB P Set remaining rig mats for sub 0.0 0.0 16:45 17:00 complex. 2/26/2017 2/26/2017 1.00 MIRU MOVE MOB P Spot sub over 3R-102. 0.0 0.0 17:00 18:00 2/26/2017 2/26/2017 1.00 MIRU MOVE MOB P Set sub stompers.SIMOPS-remove 0.0 0.0 18:00 19:00 sub tow tongue. Note:Had to remove excess dirt/ice from below sub stomper mats due to the mat being slighty too high. 2/26/2017 2/26/2017 0.50 MIRU MOVE MOB P Skid rig floor in place.SIMOPS bring 0.0 0.0 19:00 19:30 over remaining modules and stage on pad. Page 1/29 Report Printed: 4/17/2017 DriWorm tperations Summary (with Timeloggepths) o� &Wens 3R-102 ConocoPhillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/26/2017 2/26/2017 2.00 MIRU MOVE MOB P Spot pit module and pump module. 0.0 0.0 19:30 21:30 Note:Weather conditions improving, decreased to phase 1 on all main roads,phase 2 on all CPF 1 &2 Drill sites and access roads,and phase 3 on all CPF 3 Drill sites and access roads at 21:30 hrs. 2/26/2017 2/26/2017 1.75 MIRU MOVE MOB P Spot motor complex and rock washer. 0.0 0.0 21:30 23:15 2/26/2017 2/27/2017 0.75 MIRU MOVE MOB P Spot pipeshed. 0.0 0.0 23:15 00:00 2/27/2017 2/27/2017 4.50 MIRU MOVE RURD P Hook up lines steam,water and air 0.0 0.0 00:00 04:30 lines in interconnects.Set stairs around rig and berm cellar.Hook up mud lines between pits and pumps. Spot truck shop and parts house. Send steam to sub base and mud pits. Released trucks @ 2:30 am Note:Weather conditions improving, decreased to phase 1 field wide for main roads and phase 2 fieldwide for drill sites and access roads. 2/27/2017 2/27/2017 2.50 MIRU MOVE RURD P Cont to work on rig acceptance 0.0 0.0 04:30 07:00 checklist.Hook up electric lines,install beaver slide and pipe skate ramp.Set cuttings box and install containment at the end of the diverter vent line. Rig Accepted @ 07:00 hours. 2/27/2017 2/27/2017 5.00 MIRU MOVE NUND P Nipple up riser to diverter and torque 0.0 0.0 07.00 12:00 all connections. Hook up accumulator lines to diverter and function test. SIMOPS-Load,strap,and tally 5"DP in pipe shed. Note:Hold pre-spud with oncoming crew. 2/27/2017 2/27/2017 4.50 MIRU MOVE RURD P Continue loading,strapping,and 0.0 0.0 12:00 16:30 tallying 5"DP.SIMOPS-Install mousehole,change out split master bushings,organize rig floor,and work on PM's. 2/27/2017 2/27/2017 1.25 MIRU MOVE BOPE P Perform diverter test,witnessed by 0.0 0.0 16:30 17:45 AOGCC rep Brian Bixby.Test all gas alarms, PVT alarms,surface annular, and knife valve-good tests.Annular closing time=22 seconds.Knife opening time=7 seconds.Perform koomey drawdown test, Initial pressure=3000 psi, Manifold pressure= 1500 psi.System pressure after functioning annular=1950 psi. Build 200 psi in 14 seconds using 2 x electric pumps.Continue building pressure with 2 x electric and 2 x air pumps to full system pressure in 72 seconds.Average pressure of 6 x nitrogen backup bottles=2725 psi. Page 2/29 Report Printed: 4/17/2017 v i3 Operations Summary (with Timeloggepths) " .: 3R-102 ''.. 'Cxx taco [ itiipd Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/27/2017 2/28/2017 6.25 MIRU MOVE PULD P Pick up 1 x stand 5"DP and RIH to 93' 0.0 0.0 17:45 00:00 without tagging up.Rack back stand and continue making up 5"DP stands out of the mousehole,racking back total of 47 x stands 5"19.5#S-135 NC50 drill pipe. 2/28/2017 2/28/2017 1.50 MIRU MOVE BHAH P Mobilize short BHA components to rig 0.0 0.0 00:00 01:30 floor to warm up before P/U BHA. 2/28/2017 2/28/2017 5.50 MIRU MOVE PULD P Cont to pick up 5"DP via mouse hole 0.0 0.0 01:30 07:00 and stand back in derrick,42 stands. Picked up a total of 89 stands of 5" DP. 2/28/2017 2/28/2017 2.00 MIRU MOVE PULD P Pick up 5 stands of 5"HWDP and Jar 0.0 0.0 07:00 09:00 stand,stand back in derrick. 2/28/2017 2/28/2017 3.00 MIRU MOVE BHAH P PU,MU and Rack back 2-7"Non Mag 0.0 0.0 09:00 12:00 Drill Collars and 1 joint of 5"HWDP 2/28/2017 2/28/2017 1.50 MIRU MOVE BHAH P MU 13-1/2 Surface hole BHA and RIH 0.0 97.0 12:00 13:30 to 97-ft,MU UBHO and X-O, MU Top Drive to the 7"NM DC assembly and PT surface lines to 3,500 psi-Good Test. 2/28/2017 2/28/2017 4.50 SURFAC DRILL DDRL P RIH and start Drilling 13-1/2"Surface 97.0 478.0 13:30 18:00 hole from 115-ft to 478-ft MD,478-ft TVD at 490 gpm at 1000 psi with 14% return flow. Rotating at 60 rpm's at 4k TQ w/20K WOB. Off Bottom PSI= 823 psi. 80K Up wt,90K Dn Wt,84K Rot Wt. 2k Free TQ,MW @ 9.1 ppg, AST=.7,ART=1.88,ADT=2.58,Bit hrs=2.58,Jar Hrs=2.58 2/28/2017 3/1/2017 6.00 SURFAC DRILL DDRL P Continue Drilling 13-1/2"Surface hole 478.0 1,000.0 18:00 00:00 from 478-ft to 1,000-ft MD,993-ft TVD at 600 gpm at 1447 psi with 17% return flow. Rotating at 70 rpm's at 4k TQ w/20K WOB. Off Bottom PSI= 1118 psi. 88K Up wt, 102K Dn Wt, 96K Rot Wt. 2k Free TQ,MW @ 9.1+ ppg,AST=1.80,ART=1.39,ADT= 3.19,Bit hrs=5.22 Jar Hrs=5.22 3/1/2017 3/1/2017 6.00 SURFAC DRILL DDRL P Continue Drilling 13-1/2"Surface hole 1,000.0 1,477.0 00:00 06:00 from 1000'MD to 1477'MD,TVD= 1450'.AST=1.93,ART=1.71,ADT= 3.64,Bit hours=8.86,Total jar hours= 8.86.Pump @ 550 gpm=1200 psi w/ 17%flow out.Rotate @ 70 rpm's w/ 5K Tq on,2K Tq off.WOB 22K.P/U= 98K,S/O=98K,ROT=102K Note: 01:20 hrs to 02:42 hrs At 1,136-ft survey showed within 30-ft at 1,031-ft,Decision was made to pull back to recent survey depth and verify due to Anti-Collision concerns. These concerns were caused by The earths magnetic field changes interferences. The post surveys were different,so we continued to drill forward from 1,136-ft. Page 3/29 Report Printed: 4/17/2017 • 0 „ Operations Summary (with TimeloMPepths) 3R-102 ConocoPhftlip}s .. Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time+ Our(Mr) Phase Op Code Activity Code Time P-T-X Operation (ftl6) End Depth(ftKB) 3/1/2017 3/1/2017 5.75 SURFAC DRILL DDRL P Continue Drilling 13-1/2"Surface hole 1,477.0 2,015.0 06:00 11:45 from 1477'MD to 2015'MD,TVD= 1935'.AST=3.08,ART=.60,ADT= 3.68,Bit hours=12.54,Total jar hours= 12.54.Pump @ 550 gpm= 1484 psi w/18%flow out.Rotate @ 70 rpms w/5K Tq on,2K Tq off.WOB 22-26K. P/U=111K,S/O=108K, ROT=113K 3/1/2017 3/1/2017 1.25 SURFAC DRILL RGRP T Repair broken drag chain in mud pits, 2,015.0 2,015.0 11:45 13:00 repair chain and install 2 new paddles. Pump @ 63 gpm=316 psi,slowly work drill pipe.P/U=113K,S/0=111K 3/1/2017 3/1/2017 3.50 SURFAC DRILL DDRL P Continue Drilling 13-1/2"Surface hole 2,015.0 2,301.0 13:00 16:30 from 2,015-ft MD,????-ft TVD to 2,301-ft MD,2,176-ft TVD at 700 gpm at 2,013 psi with 21%return flow. Rotating at 80 rpm's at 5K TQ w/7- 22K WOB. Off Bottom PSI= 1,946 psi. 121K Up wt, 116K Dn Wt, 117K Rot Wt. 3k Free TQ,MW @ 9.4 ppg, AST=1.21,ART=.64,ADT=???, Bit hrs=14.39,Jar Hrs=14.39 3/1/2017 3/1/2017 1.25 SURFAC CASING CIRC P Rotate and reciprocate from 2,301-ft 2,301.0 2,177.0 16:30 17:45 to 2,177-ft at 750 gpm at 2,144 psi with 20%return flow,while rotating at 80 rpm's with 3k torque. Total strokes circulated=13,643. 3/1/2017 3/1/2017 0.50 SURFAC CASING OWFF P Monitor well for flow(Static) 2,177.0 2,177.0 17:45 18:15 3/1/2017 3/1/2017 1.50 SURFAC CASING BKRM P BROOH from 2,177-ft to 1,900-ft at 2,177.0 1,900.0 18:15 19:45 700 gpm at 1,870 psi with 20%return flow. while rotating at 60 rpm's with 2k torque. 121K Up wt, 112K Dn wt,and 117K ROT wt. 3/1/2017 3/1/2017 2.75 SURFAC CASING BKRM P BROOH from 1,900-ft to 760-ft at 500 1,900.0 760.0 19:45 22:30 gpm at 1,040 psi with 13%return flow. while rotating at 60 rpm's with 2k torque. 111K Up wt, 108K Dn wt,and 113K ROT wt. 3/1/2017 3/1/2017 1.00 SURFAC CASING BKRM T Seen heavy cuttings at shaker,trip 760.0 760.0 22:30 23:30 back to 850-ft and BROOH from 850-ft to 760-ft at 500 gpm at 912 psi with 15%return flow. while rotating at 60 rpm's with 1k torque. 85K Up wt,96K Dn wt,and 89K ROT wt. Total Strkes =4500 3/1/2017 3/2/2017 0.50 SURFAC CASING TRIP P POOH on elevators from 760-ft to 104 760.0 104.0 23:30 00:00 -ft MD standing back HWDP and 7" NMDC. Monitored displacement via trip tank 3/2/2017 3/2/2017 4.00 SURFAC CASING BHAH P Break down DrIg BHA assembly#1, 104.0 0.0 00:00 04:00 send BHA components down from rig floor and clean and clear rig floor.Bit grade on VM-1 1-1-WT-A-E-1-NO-TD. 3/2/2017 3/2/2017 2.00 SURFAC CASING RURD P Bring casing running equipment to rig 0.0 0.0 04:00 06:00 floor.R/U GBR Volant CRT,bail extentions,elevators and slips.M/U XO to floor valve. Page 4/29 Report Printed: 4/17/2017 0;.; . Operations Summary (with Timelo e the p9, p ) 3R-102 Conoco' hiiiips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/2/2017 3/2/2017 6.25 SURFAC CASING PUTB P M/U TopCo float shoe,shoe track, 0.0 1,835.0 06:00 12:15 Topco float collar and joint#4.Install one bow spring centralizer 10'up from casing shoe,around collar and 10' down from float collar. Test floats, good.Continue to RIH w/10-3/4" 45.5#,L-80,Hydril 563 casing from surface to 1835'MD.P/U=118K, SIO=97K. 3/2/2017 3/2/2017 1.25 SURFAC CASING CIRC P CBU,stage pumps up to 5 bpm=105 1,835.0 1,835.0 12:15 13:30 psi with 6%flow out. 3/2/2017 3/2/2017 0.75 SURFAC CASING PUTB P Continue to RIH w/10-3/4" 45.5#,L- 1,835.0 2,206.0 13:30 14:15 80,Hydril 563 casing from 1835'MD to 2206'MD.P/U=124K,S/O=109K. 3/2/2017 3/2/2017 0.50 SURFAC CASING CIRC P Establish circulation on the last joint of 2,206.0 2,240.0 14:15 14:45 casing @ 2206'MD and wash down to 2240'MD.Staging pumps up to 5 bpm= 110 psi with 6%flow out. SIMOPS, R/U GBR power tongs to M/U hanger. 3/2/2017 3/2/2017 0.25 SURFAC CASING HOSO P M/U Vetco casing hanger and landing 2,240.0 2,291.0 14:45 15:00 joint,RIH to 2291'MD and land casing on landing ring. 3/2/2017 3/2/2017 5.00 SURFAC CEMENT CIRC P Stage up to 300 GPM @ 107 psi with 2,291.0 2,291.0 15:00 20:00 9.6+ppg 123 visc w/35 YP and returning 9.6+215 visc,Continue to circulate till visc was below 20 YP, while reciprocating. Mixed red dye and Nut plug M in suction pit and pumped as a maker,observed Nut plug @ shakers @ 4000 stroke,no red dye was observed. Field went Phase III driving conditions on pads and access and Phase II on main roads @ 15:30 hrs - Was able to raise to Phase II on 3R Pad allowing rig operations to continue. 3/2/2017 3/2/2017 0.25 SURFAC CEMENT SFTY P Held PJSM with all involved 2,291.0 2,291.0 20:00 20:15 3/2/2017 3/3/2017 3.75 SURFAC CEMENT CMNT P Prime up pump units and RU for 2,291.0 2,291.0 20:15 00:00 Surface cement job. Pressure test lines @ 3,500 psi.-Good Test.Pump 40 bbls of CW100,followed 80 bbls Mud Push II,Drop plug and chase with 424.2 bbls of lead cmt,followed by 61.9 bbls of 12.0 ppg Tail cement, flush lines with 10.4 bbls of fresh water,drop wiper plug and displace cement with 201 bbls of 9.6+ppg spud mud. Page 5/29 Report Printed: 4/17/2017 operations Summary (with Timelo Depths) 3R-102 Conoo:Ohillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/3/2017 3/3/2017 0.50 SURFAC CEMENT CMNT P Prime up pump units and RU for 2,291.0 2,291.0 00:00 00:30 Surface cement job. Pressure test lines @ 3,500 psi.-Good Test. Pump 40 bbls of CW100,followed 80 bbls Mud Push II,Drop plug and chase with 424.2 bbls of lead cmt,followed by 61.9 bbls of 12.0 ppg Tail cement, flush lines with 10.4 bbls of fresh water,drop wiper plug and displace cement with 201 bbls of 9.6+ppg spud mud.up till midnight and After midnight Plug was Bumped and pressure up 500 psi over FCP to 900 psi for 5 min,bleed off and check floats,good. Returned 172 bbls of cement to surface with full returns the whole job. Cement in place @ 00:30 hrs. 3/3/2017 3/3/2017 3.50 SURFAC CEMENT RURD P Rig down Cementers,flush diverter 0.0 0.0 00:30 04:00 and circulating system with black water pills. Empty rock washer and rig pits of contaminated cement. Lay down landing joint and function Diverter. 3/3/2017 3/3/2017 8.00 SURFAC CEMENT RURD P Continue to clean pits in preparation 0.0 0.0 04:00 12:00 for mud swap. Sim Ops-Clear rig floor of casing running tools. Clean out cement in the conductor valves, cement manifold valves and the rock washer. Sim Ops-Cleaning pits to accept the 9.2 ppg LSND 3/3/2017 3/3/2017 1.00 SURFAC CEMENT SVRG P Complete Rig PM's and Housekeeping 0.0 0.0 12:00 13:00 3/3/2017 3/3/2017 8.00 SURFAC CEMENT NUND P Nipple down Diverter pipe and surface 0.0 0.0 13:00 21:00 riser. Lay down mouse hole,remove all studs from the Annular flange, Knife valve"T"and Vetco Gray Diverter Adapter.Remove all diverter equipment Sim Ops-Change out Upper rams to 7-5/8 Solid Bodies,Continue to Clean pits and mud pump suctions on both pumps. Fill pits with 9.2 ppg LSND Drlg fluid for next hole section. 3/3/2017 3/4/2017 3.00 SURFAC WHDBOP NUND P NU Vetco Gray Wellhead MB 222A as 0.0 0.0 21:00 00:00 per Valve and HandWheel Oreintation Sketch and Test seal to 2,000 psi for 10 minutes. Good test. 3/4/2017 3/4/2017 2.00 SURFAC WHDBOP NUND P Install sweeping 90 and valve on the 0.0 0.0 00:00 02:00 'OA'port of the well head. Multi bowl Unihead orientation was verified by the DSO. Re-oriented the valve for handle placement,torque up flanges. 3/4/2017 3/4/2017 5.50 SURFAC WHDBOP NUND P Set Spacer spools,followed by BOP 0.0 0.0 02:00 07:30 stack. Install choke,kill and accumulator hoses. Torque all flange bolts and set riser. Page 6/29 Report Printed: 4/17/2017 4"' Operations Summary (with Timelogepths) 3R-102 ConocaPhiiiips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log StartDepth Start Time End Time Dur(hrj Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(EKE) 3/4/2017 3/4/2017 0.50 SURFAC WHDBOP RURD T R/U to test BOPE, install test plug 0.0 0.0 07:30 08:00 with 5"test joint and fill stack. Found IA valve to leak-SN: IJ00040000-0743 2-1/16"5M Valve- for inspection and repair Swap with replacement valve. 3/4/2017 3/4/2017 7.00 SURFAC WHDBOP BOPE P 24 hr Notice for AOGCC Witness was 0.0 0.0 08:00 15:00 sent on 3-1-17 @ 21:30 hrs for the Initial BOP Test. The BOPE was tested on 3/4/17 with 5"and 7-5/8" test joint to 250/3500 psi.Guy Cook of AOGCC witnessed test. Test Sequence as follows: With 7-5/8 Test joint 1)Annular, Mud Manifold valves 1,12,13, 14,and 4"Kill line,4-1/2"IF Dart Valve 2)Upper Rams,Mud Manifold valves 9, 11 and Mezz Kill line,4-1/2"IF Full Open Safety Valve 3)Upper Rams,Mud Manifold valves 8,10 and HCR Kill line 4)Upper Rams,Mud Manifold valves 6,7 and HCR Kill line 5)Manually Operated Choke 6)Super Choke 7)Manual Kill, Mud Manifold valves 2 and 5 8)HCR Choke 9)Manual Choke With 5"Test Joint 10)Annular,and Upper IBOP 11)LPR's with 3-1/2 x 6"VBR's,and Lower IBOP 12)Blinds,Mud Manifold valves 3,4, and 6 System Pressure=3,075 psi PSI after closure=1,850 psi 200 psi Attained=15 seconds Full Pressure attained=91 seconds N2=6 each @ 2,441 psi Pass/Fails H2S sensor in pits-change filter Well head IA valve failed-replace 3/4/2017 3/4/2017 0.50 SURFAC WHDBOP RURD P Install 4.96-ft long x 12-3/8"ID x 13- 0.0 0.0 15:00 15:30 5/16"Wear ring in lower profile. 3/4/2017 3/5/2017 8.50 SURFAC CEMENT TRIP T MU Baker 8"OD magnet and RIH on 0.0 2,199.0 15:30 00:00 5"Drill pipe to 2,199-ft. POOH with No Fish. PU Reverse cirulating Junk basket and RIH on 5"Drill Pipe and function RCJB @ 3 bpm @ 2,300 psi. Core 2-ft from 2,199-ft to 2,201-ft in cement. Page 7/29 Report Printed: 4/17/2017 • K :;;::illft,.::,,,,,,,, o0 Summary (with Timelog Depths) eat 3R-102 c.c:W ilrps • Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time Pi-T-X Operation (ftKB) End Depth(ftKB) 3/5/2017 3/5/2017 1.00 SURFAC CEMENT FISH T Cont to wash down with reverse 2,199.0 2,201.0 00:00 01:00 circulating junk basket to 2201'MD @ 3 bpm=2340 psi,30 rpm's,4-5K Tq. CBU @ 2200.50'MD 3bpm=1430 psi. Observed pressure drop @ 850 strokes,test surface lines,good.P/U= 106K,S/0=101K. 3/5/2017 3/5/2017 0.25 SURFAC CEMENT TRIP T Stand back one stand,blow down top 2,201.0 2,179.0 01:00 01:15 drive and install stripping rubber. 3/5/2017 3/5/2017 1.00 SURFAC CEMENT TRIP T POOH f/2179'MD to surface.Monitor 2,179.0 0.0 01:15 02:15 hole on trip tank,good. 3/5/2017 3/5/2017 0.50 SURFAC CEMENT BHAH T Recovered D-Ring inside reverse 0.0 0.0 02:15 02:45 circulating junk basket.Service break junk basket and clean and rig floor. 3/5/2017 3/5/2017 1.00 SURFAC CEMENT BHAH P Mobilize SLB BHA components to rig 0.0 0.0 02:45 03:45 floor via beaver slide.Hold PJSM on picking up BHA. 3/5/2017 3/5/2017 3.00 SURFAC CEMENT BHAH P Make up BHA#2 as per SLB 0.0 403.0 03:45 06:45 DD/MWD to 403'MD. 3/5/2017 3/5/2017 1.00 SURFAC CEMENT PULD P L/D 11 joints of 5"HWDP out of 403.0 403.0 06:45 07:45 derrick and change out 6-1/4" Mechanical jars for 6-1/4"hydraulic jars. 3/5/2017 3/5/2017 1.50 SURFAC CEMENT TRIP P RIH w/BHA#2 f/403'MD to 2106' 403.0 2,106.0 07:45 09:15 MD, Filled 5"DP @ 2000'MD.Monitor well on trip tank when RIH. P/U= 108K,S/O=102K. 3/5/2017 3/5/2017 1.50 SURFAC CEMENT PRTS P RU and Test(10-3/4",45.5#,L-80, 2,106.0 2,106.0 09:15 10:45 80%Burst=4,168 psi)to 3,000 psi.- Good Test,took 30 stks to pressure up to 3,000 psi 3/5/2017 3/5/2017 0.50 SURFAC CEMENT SVRG P Service rig 2,106.0 2,106.0 10:45 11:15 3/5/2017 3/5/2017 0.50 SURFAC CEMENT DHEQ P conduct shallow hole test on MWD 2,106.0 2,106.0 11:15 11:45 tools @ 500 gpm at 840 psi 3/5/2017 3/5/2017 2.75 SURFAC CEMENT DRLG P Drill out floats and float equipment 2,106.0 2,210.0 11:45 14:30 from 2,207-ft to 2,210-ft @ 455 gpm @810 psi with 14%return flow,while rotating @ 70 rpm's with 4 to 6k TQ and 10 to 25K WOB. 111K Up wt, 103K Dn wt,and 110K Rot wt. 3/5/2017 3/5/2017 0.50 SURFAC CEMENT DRLG P Drill out cement from 2,210-ft to 2,298- 2,210.0 2,298.0 14:30 15:00 ft @ 455 gpm @ 6630 psi with 14% return flow while rotating @ 80 rpm's with 3 to 8K TQ with 2K WOB. 3/5/2017 3/5/2017 1.50 SURFAC CEMENT DRLG P Drill out float shoe from 2,289-ft to 2,298.0 2,293.0 15:00 16:30 2,293-ft @ 455 gpm @ 630 psi with 14%return flow while rotating @ 80 rpm's with 3 to 8K TQ with 7K WOB. 3/5/2017 3/5/2017 1.00 SURFAC CEMENT RGRP T Change out swab and liner on MP#2, 2,293.0 2,293.0 16:30 17:30 along with saver sub on Top drive Page 8/29 Report Printed: 4/17/2017 • Operations Summary (with Timeloggg!epths) Ws Wells 3R-1 02 Conoimlmps p' Rig: Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log StartDepth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/5/2017 3/5/2017 2.00 SURFAC CEMENT DDRL P Drill out 10-ft of rat plus 20-ft of"New" 2,293.0 2,321.0 17:30 19:30 open hole to 2,321-ft at 453 gpm @ 653 psi with 14%return flow while rotating @ 80 rpm's with 4K TQ with 1K WOB. Rotate and reciprocate from 2321-ft to 2,200-ft @ 655 gpm@ 1,276 psi with 17%return flow while rotating @ 60 rpm's and 4K TQ.4,713 -Total stks pumped 3/5/2017 3/5/2017 2.25 SURFAC CEMENT LOT P Blow down top drive and RU for fit @ 2,264.0 2,264.0 19:30 21:45 2,264-ft Pressured up 400 psi and bled back to 375 psi equivalent to 12.8 ppg. 5 stks to pressure up and .6 bbls returned. Blow down lines and RD circulating equipment 3/5/2017 3/5/2017 0.25 INTRM1 DRILL TRIP P RIH f/2,264-ft to 2,321-ft Up wt= 2,264.0 2,321.0 21:45 22:00 111K, Dn wt= 103K 3/5/2017 3/6/2017 2.00 INTRM1 DRILL DDRL P Drill 9-7/8 Intermediate hole from 2321 2,321.0 2,469.0 22:00 00:00 -ft MD/2195-ft TVD to 2469-ft MD/ 2,304-ft TVD @ 612 gpm @ 832 psi with 14%return flow while rotating @ 60 rpm's with 4 to 5K TQ with 4 to 5K WOB. ECD's=9.97 ppg,Off Bottom PSI=810, Up wt= 111K, Dn wt= 103K, ROT wt=110K with 3K TQ. MW=9.2 ppg,ADT=1.67, Bit hrs= 1.67,Jar Hrs= 107.9,Sim ops= Displace spud mud with 9.2 ppg LSND. SPR's @ 2,386-ft MD/2,243-ft TVD with 9.2 PPG MW @ 23:00 hrs MP#1 20 SPM @ 100 psi /30 SPM @110 psi MP#2 20 SPM @ 80 psi/30 SPM @ 100 psi 3/6/2017 3/6/2017 6.00 INTRM1 DRILL DDRL P Drill 9-7/8 Intermediate hole from 2,469.0 3,233.0 00:00 06:00 2469-ft MD/2,304-ft TVD to 3233-ft MD/2740-ft TVD @ 700 gpm @ 1225 psi with 18%return flow while rotating @ 100 rpm's with 4 to 8K TQ with 2 to 4K WOB. ECD's= 10.26 ppg,Off Bottom PSI=1200, Up wt= 124K,Dn wt= 107K,ROT wt=112K. MW=9.2 ppg,ADT=3.89,Bit hrs=5.56,Jar Hrs= 110.98 SPR's @ 2958-ft MD/2623-ft TVD with 9.2 PPG MW MP#1 20 SPM @ 100 psi /30 SPM @ 120 psi MP#2 20 SPM @ 90 psi/30 SPM @ 110 psi Page 9/29 Report Printed: 4/17/2017 o0 perations Summary (with Timeloltepths) 3R-102 ConocoPhiirps Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code ActivityCode Time P-T-X Operation (ftKB) End Depth(ftKB) 3/6/2017 3/6/2017 6.00 INTRM1 DRILL DDRL P Drill 9-7/8 Intermediate hole from 3,233.0 4,001.0 06:00 12:00 3233-ft MD/2740-ft TVD to 4001-ft MD/2860-ft TVD©775 gpm @ 1580 psi with 20%return flow while rotating @ 160 rpm's with 5 to 9K TQ with 2 to 6K WOB. ECD's= 10.41 ppg,Off Bottom PSI=1500,Up wt= 124K,Dn wt=98K,ROT wt=110 K. MW=9.2 ppg,ADT=3.8,Bit hrs=9.36,Jar Hrs =114.78 SPR's @ 3623-ft MD/2802-ft TVD with 9.2 PPG MW MP#1 30 SPM @ 110 psi /40 SPM @ 140 psi MP#2 30 SPM @ 100 psi/40 SPM @ 140 psi Pumping weighted sweeps every 500' w/100%to 200%increase in cuttings. 3/6/2017 3/6/2017 6.00 INTRM1 DRILL DDRL P Drill 9-7/8 Intermediate hole from 4,001.0 4,665.0 12:00 18:00 4,001-ft MD/2,860-ft TVD to 4,665-ft MD/2,959-ft TVD @ 770 gpm @ 1,728 psi with 20%return flow while rotating @ 150 rpm's with 7 to 9K TQ with 2 to 3K WOB. ECD's=10.53 ppg,Off Bottom PSI=122,Up wt= 122K, Dn wt=96K,ROT wt=113K with 7-9K TQ. MW=9.2+ppg,ADT =4.21, Bit hrs=13.57,Jar Hrs= 118.99, SPR's @4,093-ft MD/2,874-ft TVD with 9.2 PPG MW©1250 hrs MP#1 20 SPM @ 140 psi /30 SPM @ 160 psi MP#2 20 SPM @ 130 psi/30 SPM @ 160 psi 3/6/2017 3/7/2017 6.00 INTRM1 DRILL DDRL P Drill 9-7/8 Intermediate hole from 4,665.0 5,401.0 18:00 00:00 4,665-ft MD/2,959-ft TVD to 5,401-ft MD/3,084-ft TVD @ 777 gpm @ 1,850 psi with 19%return flow while rotating @ 150 rpm's with?to?K TQ with 8 to 4K WOB. ECD's=10.57 ppg,Off Bottom PSI=1,850,Up wt= 130K,Dn wt=96K,ROT wt=114K with 8K TQ. MW=9.2 ppg,ADT= 4.29, Bit hrs= 17.86,Jar Hrs= 123.28, SPR's @ 5,323-ft MD/3070-ft TVD with 9.2 PPG MW @ 2300 hrs MP#1 20 SPM©160 psi /30 SPM @ 200 psi MP#2 20 SPM @ 160 psi/30 SPM @ 190 psi Page 10/29 Report Printed: 4/17/2017 Operations Summary (with Timelog5epths) 3R-102 ConocoPhillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth : . Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/7/2017 3/7/2017 0.25 INTRM1 DRILL DDRL P Drill 9-7/8 Intermediate hole from 5,401.0 5,441.0 00:00 00:15 5,401'MD/3,084'-ft TVD to 5,441-ft MD/3,109'-ft TVD @777gpm @ 1,850 psi with 19%return flow while rotating @ 150 rpm's with?to?K TQ with 8 to 4K WOB. ECD's= 10.57 ppg,Off Bottom PSI=1,850,Up wt= 130K,Dnwt=96K,ROTwt=114K with 8K TQ. MW=9.2 ppg,ADT= 4.29,Bit hrs=17.86,Jar Hrs= 123.28, SPR's @ 5,323-ft MD/3070-ft TVD with 9.2 PPG MW @ 2300 hrs MP#1 20 SPM @ 160 psi /30 SPM ©200 psi MP#2 20 SPM @ 160 psi/30 SPM @ 190 psi 3/7/2017 3/7/2017 4.00 INTRM1 DRILL RGRP T Drag chain parted. Pulled one stand 5,441.0 5,441.0 00:15 04:15 and circulating min rate to stay warm. 3/7/2017 3/7/2017 1.75 INTRM1 DRILL DDRL P Drill 9-7/8 Intermediate hole from 5,441.0 5,643.0 04:15 06:00 5,441'MD/3,109"-ft TVD to 5,643'-ft MD/3,135"-ft TVD @777gpm @ 1,850 psi with 19%return flow while rotating @ 150 rpm's with?to?K TQ with 8 to 4K WOB. ECD's=10.57 ppg,Off Bottom PSI=1,850,Up wt= 130K, Dn wt=96K,ROT wt=114K with 8K TQ. MW=9.2 ppg,ADT= 4.29,Bit hrs=17.86,Jar Hrs= 123.28, SPR's @ 5,323-ft MD/3070-ft TVD with 9.2 PPG MW @ 2300 hrs MP#1 20 SPM @ 160 psi /30 SPM @ 200 psi MP#2 20 SPM @ 160 psi/30 SPM @ 190 psi Drag chain repaired.Twice. 3/7/2017 3/7/2017 6.00 INTRM1 DRILL DDRL P Drill 9-7/8 Intermediate hole from 5,643.0 6,290.0 06:00 12:00 5,441'MD/3,109"-ft TVD to 6,290'-ft MD/3,240'-ft TVD @ 775 gpm @ 1,850 psi with 20%return flow while rotating @ 160 rpm's with 9 to 12K TQ with 8 to 4K WOB. ECD's=10.57 ppg,Off Bottom PSI=1,850,Up wt= 147K,Dn wt=90K,ROT wt=116K with 8K TQ. MW=9.2 ppg,ADT= 4.21,Bit hrs=23.58,Jar Hrs=129 hrs Pumped 11.2#sweeps at 5,515'& 5,895'MD, SPR's @ 5,892-ft MD/3169'-ft TVD with 9.2 PPG MW©2300 hrs MP#1 20 SPM @ 200 psi /30 SPM @ 220 psi MP#2 20 SPM @ 200 psi/30 SPM @ 220 psi Page 11/29 Report Printed: 4/17/2017 • , —0:::`,,,,,,,,,,'',',,--,?:;.::,./4 Operations Summary (with Timelog Depths) 4 `4 3R-102 onocoPtiitlips C '., Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X - Operation (ftKE) End Depth(#tKE) 3/7/2017 3/7/2017 6.00 INTRM1 DRILL DDRL P Drill 9-7/8 Intermediate hole from 6,290.0 6,941.0 12:00 18:00 6,290'MD/3,240"-ft TVD to 6,941-ft MD/3,334'-ft TVD @ 750 gpm @ 2,006 psi with 20%return flow while rotating @ 160 rpm's with 9 to 12K TQ with 8 to 4K WOB. ECD's=10.83 ppg, Up wt=153K,Dn wt=82K, ROT wt=118K with 10K TQ. MW=9.2 ppg,ADT=4.40,Bit hrs= 27.88,Jar Hrs=133.3, SPR's @ 6,365-ft MD/3,253-ft TVD with 9.2 PPG MW @ 1300 hrs MP#1 20 SPM @ 170 psi /30 SPM @ 200 psi MP#2 20 SPM @ 180 psi/30 SPM @ 200 psi 3/7/2017 3/8/2017 6.00 INTRM1 DRILL DDRL P Drill 9-7/8 Intermediate hole from 6,941.0 7,411.0 18:00 00:00 6,941'MD/3,334"-ft TVD to 7,411 -ft MD/3,404'-ft TVD @ 777 gpm @ 1,850 psi with 20%return flow while rotating @ 170 rpm's with 9 to 15K TQ with 8 to 4K WOB. ECD's=10.71 ppg,Up wt= 150K,Dn wt=92K,ROT wt=118K with 10K TQ. MW=9.2 ppg, ADT=3.24,Bit hrs=31.12,Jar Hrs= 136.54, 2100-2130 changed out swab&liner on MP#1. SPR's @ 7,032-ft MD/3,345'-ft TVD with 9.2 PPG MW @ 1915 hrs MP#1 20 SPM @ 200 psi /30 SPM @ 240 psi MP#2 20 SPM @ 200 psi/30 SPM @ 230 psi 3/8/2017 3/8/2017 6.00 INTRM1 DRILL DDRL P Drill 9-7/8 Intermediate hole from 7,411.0 7,805.0 00:00 06:00 7,411'MD/3,404"-ft TVD to7,805-ft MD/3,465'-ft TVD @ 750 gpm @ 2,180 psi with 19%return flow while rotating©170 rpm's with 11 to 13K TQ ECD's=11.04 ppg,Up wt= 158K,Dn wt=84K,ROT wt=126K with 11K TQ. MW=9.2 ppg,ADT= 4.23,Bit hrs=35.35,Jar Hrs= 140.77, SPR's @ 7,595-ft MD/3,436'-ft TVD with 9.2 PPG MW @ 0120 hrs MP#1 20 SPM @ 240 psi /30 SPM @ 280 psi MP#2 20 SPM @ 240 psi/30 SPM @ 280 psi Page 12/29 Report Printed: 4/17/2017 • S ` Operations Summary (with Timelog Depths) rte. 3R-102 ConocoPhiflipos Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dor(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/8/2017 3/8/2017 6.00 INTRM1 DRILL DDRL P Drill 9-7/8 Intermediate hole from 7,805.0 8,168.0 06:00 12:00 7,805'MD/3,465"-ft TVD to 8,168-ft MD/3,512'-ft TVD @775gpm@ 2,410 psi with 20%F/O @ 170 rpm's with 12 to 15K TQ. ECD's=11 ppg, Up wt= 159K,Dn wt=88K,ROT wt= 127K with 10K TQ. MW=9.2 ppg, ADT=4.78, Bit hrs=40.13,Jar Hrs= 145.55, SPR's @ 8,070-ft MD/3,501'-ft TVD with 9.2 PPG MW @ 1057 hrs MP#1 20 SPM @ 210 psi /30 SPM @ 280 psi MP#2 20 SPM @210 psi/30 SPM @ 280 psi 3/8/2017 3/8/2017 4.00 INTRM1 DRILL DDRL P Drill 9-7/8 Intermediate hole from 8,168.0 8,602.0 12:00 16:00 8,168'MD/3,512"-ft TVD to 8,602'-ft MD/3,565'-ft TVD @ 775 gpm @ 2,518 psi with 20%F/O @ 170 rpm's with 12 to 15K TQ ECD's=11.29 ppg,Up wt=157K,Dn wt=92K,ROT wt= 120K with 10K TQ. MW=9.2 ppg, ADT=2.73,Bit hrs=42.86,Jar Hrs= 148.28, SPR's @ 8,600'-ft MD/3,565'-ft TVD with 9.2 PPG MW @ 1600 hrs MP#1 20 SPM @ 260 psi /30 SPM @ 310 psi MP#2 20 SPM @ 260 psi/30 SPM @ 310 psi 3/8/2017 3/8/2017 1.25 INTRM1 CASING CIRC P Rotate and recipricate from 8,602 MD 8,602.0 8,602.0 16:00 17:15 -8,545'MD w 775 GPM 2,518 DPP, 20%F/O 170 RPM 12-15K TQ. ECD =11.15 P/U= 156K,S/O=90K. ROT 118K 10K TQ. Gather slow pump rates. TD called. 3/8/2017 3/8/2017 0.50 INTRM1 CASING OWFF P Observe well fo rlow whit rotating at 5 8,602.0 8,602.0 17:15 17:45 RPM 7K torque. Well static. Prepare to BROOH. 3/8/2017 3/9/2017 6.25 INTRM1 CASING BKRM P BROOH from 8,600'MD to 6,752'MD. 8,602.0 6,752.0 17:45 00:00 @ 775 GPM 2,260 PSI DPP. 20% F/O. 160-170 RPM with 10-14 TQ. ROT 107K. 3/9/2017 3/9/2017 11.25 INTRM1 CASING BKRM P Cont to BROOH from 6,752'-2,286' 6,752.0 2,286.0 00:00 11:15 MD. 775 GPM @ 1,700 PSI 20%F/O. 160 RPM. 4-7K TQ,700 FPH. ECD=10.31. UP WT 105K DWN= 104K. ROT=104K. 3/9/2017 3/9/2017 1.75 INTRM1 CASING CIRC P Circulating while rotate+reciprocate 2,286.0 2,286.0 11:15 13:00 from 2,286'to 2,199'MD @ 650 GPM 1,130 PSI DPP. 18%F/O.3K TQ. 10.15 PPG ECD.9.3 MWI/9.35 MWO. Circulate until 9.3 PPG all around. 3/9/2017 3/9/2017 0.25 INTRM1 CASING OWFF P Observe well for flow while blowing 2,286.0 2,286.0 13:00 13:15 down top drive. Prep to POOH on elevators. Page 13/29 Report Printed: 4/17/2017 • • 0:r.i, Operations Summary (with Timelog Depths) 0o 3R-102 Conocc:Whillips • m.,,,,,, Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time.P-T-X r Operation (ftKE) End Depth(ftKB) 3/9/2017 3/9/2017 2.00 INTRM1 CASING TRIP P POOH from 2,199'to 403'MD. 2,286.0 403.0 13:15 15:15 UP=65K. DWN 65K. Monitor well at HWDP for flow. 3/9/2017 3/9/2017 0.25 INTRM1 CASING SFTY P Pre job safety meeting for laying down 403.0 403.0 15:15 15:30 BHA and HWDP. 3/9/2017 3/9/2017 2.00 INTRM1 CASING BHAH P LD BHA#2.Per DD. Pictures in S 403.0 0.0 15:30 17:30 drive of wear. Monitor fluid level. 3/9/2017 3/9/2017 1.00 INTRM1 CASING BHAH P Flear and clean rig floor. LD all BHA 0.0 0.0 17:30 18:30 tools and handeling equpment. Sim ops for running 7 5/8"casing. 3/9/2017 3/9/2017 1.00 INTRM1 CASING WWWH P Rig up single stand and stack washing 0.0 0.0 18:30 19:30 tool to clean BOP's. Flush at 850 BPM,85 PSI and 50 RPM. Blow down and rig down BOP washing tool. 3/9/2017 3/9/2017 2.00 INTRM1 CASING RURD P Pull wear bushing.Install Bail 0.0 0.0 19:30 21:30 extensions,Bring up to floor casing tongs and all GBR equipment. Reset rig tongs for 7 5/8 casing. 3/9/2017 3/9/2017 1.50 INTRM1 CASING PUTB P Pick up 7 5/8"shoe track/floats and 0.0 160.0 21:30 23:00 Baker Lock first four joints Shoe jt, float,etc.. Pre-job safety meet.RIH: On joint 4 check floats 25 BBLS (PASSED). 3/9/2017 3/10/2017 1.00 INTRM1 CASING PUTB P Continue to RIH with 7 5/8"29.7# 160.0 496.0 23:00 00:00 Hydril 563 dopeless casing form160' to 496'MD. Up WT 55K DWN=50K. Monitor disp via pits. Fill on the fly with Volant tool. 7 5/8"casing MKUT = 12.4K. 3/10/2017 3/10/2017 3.00 INTRM1 CASING PUTB P Continue to RIH with 7 5/8"29.7#L-80 496.0 2,279.0 00:00 03:00 casing Hydril 563 from 496'to 2,279' MD. Fill up every 10 joints. 12.4 FT/LBS makeup torque. 3/10/2017 3/10/2017 0.50 INTRM1 CASING CIRC P Circulate at 8 BPM 200 PSI, 13%F/O. 2,279.0 2,279.0 03:00 03:30 MW in&Out=9.25. Total strokes pumped= 1450. Up WT= 102K, DWN=103K. 3/10/2017 3/10/2017 4.75 INTRM1 CASING PUTB P Continue to RIH with 7 5/8"casing, 2,279.0 5,507.0 03:30 08:15 dopeless 563 from 2279'MD to 5507' MD Monitor DISP via pits. Fill on the fly&top off every 10 joints. 12.4K FT/LBS. 3/10/2017 3/10/2017 1.00 INTRM1 CASING CIRC P Circulate while reciprocate f 5,507'to 5,507.0 5,507.0 08:15 09:15 5,467'MD. Stage up to 8 BPM 405 PSI. 12%F/O. MW in/out 9.25/9.3 PPG. Total strokes pumped=3,030. 2,538 STKS after reaching 5 BPM. {U = 158K. DWN wT=88K. 3/10/2017 3/10/2017 5.25 INTRM1 CASING PUTB P Continue to RIH with 7 5/8"29.7#563 5,507.0 8,553.0 09:15 14:30 dopeless casing from 5,507-7,327' MD. Fill on the fly and top off every ten joints. Utilizing 12.4K torque for 7 5/8"563 casing. 3/10/2017 3/10/2017 1.00 INTRM1 CASING PUTB P MU landing joint and wash down from 8,553.0 8,594.0 14:30 15:30 8553'to 8594'MD. UP WT-208K. Down WT=63K./ Stage up pumps to 4 BPM @ 400 PSI DPP. Hold pre-job while reciprocating up an down. Page 14/29 Report Printed: 4/17/2017 '., ;. • • Operations Summary (with Timelog Depths) 0 3R-102 illips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKS) 3/10/2017 3/10/2017 4.00 INTRM1 CEMENT CIRC P Circulate while reciprocating from 8,594.0 8,594.0 15:30 19:30 8,595-8,570'MD staging up pump to 8 BPM 630 PSI DPP. Conditioning mud. 4 BPM=460 PSI,5 BPM=575 PSI,6 BPM=555 PSI,7 BPM=600 PSI. Hold PJSM for cement program. MW in=9.3 MW out=9.4 3/10/2017 3/10/2017 3.00 INTRM1 CEMENT CMNT P Flood lines with water to test SLB. 8,594.0 8,594.0 19:30 22:30 Test surface lines to 4K PSI. Pump 40.1 BBLS of 12.5 PPG mud push, Drop bottom plug and pump 178.1 BBLS of 15.8 PPG class G cement. Drop top plug and follow up with 10 BBLS of water and chase with rig pumps for 3,761 STKS. DPP up as high as 1300 PSI for @ 5 min. Lost slack off Wt before cement reached shoe. Parked casing for cement program on hanger. CIP @ 22:21 hrs. 3/10/2017 3/10/2017 1.00 INTRM1 CEMENT PRTS P TEst casing to 3,500 PSI for 30 min 8,594.0 8,594.0 22:30 23:30 (PASSED). Lost 10 PSI in 30 min. PUmped 5.8 BBLS total and bled off 4 BBLS. Check floats and holding. 3/10/2017 3/11/2017 0.50 INTRM1 CEMENT RURD , P Rig down all cement equipment. 8,594.0 23:30 00:00 3/11/2017 3/11/2017 1.25 INTRM1 CEMENT RURD P Clean rig floor of all casing running 00:00 01:15 equipment. Back out landing joint and change out elevators. Blow down top drive and drain stack. 3/11/2017 3/11/2017 1.25 INTRM1 CEMENT WWSP P Pick up test joint and install 7 5/8" 01:15 02:30 packoff. RILDS and test packoff to 5,000 PSI(PASSED). Continue to clean rig floor and washout cement valves/lines. 3/11/2017 3/11/2017 3.00 INTRMI CEMENT PULD P LD 5"DP via mousehole(75)joints 02:30 05:30 SIM ops while rig up test lines for OA. 3/11/2017 3/11/2017 0.50 INTRM1 CEMENT LOT P LOT of 7 5/8"X 10 3/4"casing annuli. 05:30 06:00 13.1 PPG EWM. 3/11/2017 3/11/2017 1.00 INTRM1 CEMENT FRZP P Flush 7 5/8"X 10 3/4"Annulas with 06:00 07:00 100 BBLS fresh water using rig pumps. Switch to Little Red services for injection of 99 BBLS of Isotherm. 3 BPM @ 700 PSI. Casing pressure 800 PSI after fresh water flush-FCP=1250 PSI after isotherm injected. 3/11/2017 3/11/2017 7.25 INTRM1 CEMENT PULD P Continue to lay down 5"DP out of 07:00 14:15 derrick via mousehole SIM ops change out 2 liners on MP#1 OA pressure at 0930=635 PSI 3/11/2017 3/11/2017 5.25 INTRM1 CEMENT RURD P Break out cross overs on FOSV, 14:15 19:30 Change out saver sub.Change out roughneck dies and elevotors. Load pipe shed with 4"DP strap and install super sliders. 3/11/2017 3/12/2017 4.50 INTRM1 CEMENT PULD P Pick up and rack back HWDP via 19:30 00:00 mouse hole(31 stands(2899'). OA pressure at 2323 hrs=140 PSI. Page 15/29 Report Printed: 4/17/2017 xY• • • Operations Summary (with Timelog Depths) z z 3R-102 Phillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/12/2017 3/12/2017 11.25 INTRMI CEMENT PULD P Make up 84 STDs of 4"DP with Super 00:00 11:15 Sliders via mouse hole. Install super sliders in shed on the fly for first 58 stands. Verify pipe count in shed. 3/12/2017 3/12/2017 9.00 INTRM1 WHDBOP BOPE P PU&Make up BOP test joint install 11:15 20:15 test plug and flood stack. Test BOPE.to 250/3500 PSI. Test witness waived by Chuck Scheve on 3/11/2017 at 1319 hrs. BD top drive. OA pressure=120 PSI at 1030 AM. 3/12/2017 3/12/2017 0.25 INTRM1 WHDBOP RURD P Blow down all lines and prep to pull 20:15 20:30 test plug. 3/12/2017 3/12/2017 0.75 INTRM1 WHDBOP RURD P Pull test plug and install 12.25"wear 20:30 21:15 ring. 3/12/2017 3/13/2017 2.75 INTRM1 CEMENT BHAH P Pick up 6 3/4"production DD BHA and 0.0 177.0 21:15 00:00 make up same. 6 3/4"X516 PDC bit, 475 Power DriveX6w/6-5/8"Stabilized Control collar, PD Receiver Sub,4 3/4" PeriScope,ImPulse tool,SonicScope 475 w/6"Stabilizer,proVISION 475, ADN-4 w/5 7/8"Stabilizer,Float Sub (ported"GA"float ser#0038),4 3/4" Flex NMDC,6 5/8"NM Stabilizer (ported"GA"float ser#0025),4 3/4" Flex NMDC,4 3/4"Flex NMDC,4 3/4"Flex NMDC,Saver Sub (Corrosion Ring),XO,4"HWDP(2 joints),4 3/4"Hydraulic Jars,4"HWDP (2 joints),4"15.70 DPS,Premium. 3/13/2017 3/13/2017 1.75 INTRM1 CEMENT BHAH P Continue to PU production BHA as per 177.0 468.0 00:00 01:45 DD/MWD/from 177'MD to 468'MD UP WT 54K DWN 65K. 3/13/2017 3/13/2017 1.25 INTRMI CEMENT PULD P RIH picking up 30 joints of 4"DP from 468.0 1,410.0 01:45 03:00 468'to 1,410'MD monitor displacement into pit 1. 3/13/2017 3/13/2017 0.50 INTRM1 CEMENT DHEQ P Fill pipe and shallow hole test MWD 1,410.0 1,410.0 03:00 03:30 with 221 PSI, 1,040 PSI 7%F/O (Good)BD top drive. 3/13/2017 3/13/2017 1.00 INTRM1 CEMENT PULD P RIH picking up singles from 1,410'- 1,410.0 2,388.0 03:30 04:30 2,388'MD 93K up. 83K DWN. 3/13/2017 3/13/2017 1.25 INTRM1 CEMENT QEVL P Downlink sonicscope T/Logging mode 2,388.0 2,673.0 04:30 05:45 Free Pipe interval&log in the hole from 2,388'to 2,673'MD. 3/13/2017 3/13/2017 2.00 INTRM1 CEMENT PULD P Continue to pick up 4"DP singles out 2,673.0 4,200.0 05:45 07:45 of shed from 2,673'-4,200'MD. Fill pipe every 10 as per program. 3/13/2017 3/13/2017 7.50 INTRM1 CEMENT QEVL P RIH logging cement at 15 FPM-900 4,200.0 7,847.0 07:45 15:15 FPH from 4,200'-7847'MD. UP wt 138K DWN=56K. 3/13/2017 3/13/2017 0.25 INTRM1 CEMENT QEVL T POOH from 7,847-7472'MD due to 7,847.0 7,472.0 15:15 15:30 Schlumberger footage tracker off. reset.RBIH 3/13/2017 3/13/2017 2.50 INTRM1 CEMENT QEVL P RIH logging from 7472'to 8452'MD at 7,472.0 8,452.0 15:30 18:00 900 FPH. UPwt 138K DWN 47K. (tag cement stringer. Page 16/29 Report Printed: 4/17/2017 • Operations Summary (with Timelog Depths) We 3R-102 ConocoPhi lips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB): 3/13/2017 3/13/2017 4.00 INTRM1 CEMENT DRLG P Wash and ream from 8,452'to 8509' 8,452.0 8,622.0 18:00 22:00 where we drillied out plug,float collar &cement+20'of new hole to 8622' MD 3,564'TVD 252 GPM 2148 PSI DPP 7%F/O 80 RPM with 9.5K TQ. 11.44 ECD.2K on bit. ADT=.22,Jar hours 48.42. 3/13/2017 3/14/2017 2.00 INTRM1 CEMENT SRVY P Survey,circulate and condition mud 8,622.0 8,622.0 22:00 00:00 for FIT test. PU into shoe standing back one stand at 200 GPM, 1,380 PSI DPP,7%F/O 30 RPM.9.5K TQ. RT WT 90K. 3/14/2017 3/14/2017 0.50 INTRM1 CEMENT CIRC P Continue to circulate and condition 8,622.0 8,622.0 00:00 00:30 mud for FIT test. Pumping 200 GPM, 1,320 PSI DPP,6%F/0 30 RPM. 9.5K TQ.RT WT 90K. Reciprocate f/8600'to 8520'.Mud weight 9.3 ppg.Pumped 667 bbls. PU wt 147k,SO wt none,Rot weight 92k. 3/14/2017 3/14/2017 0.50 INTRM1 CEMENT RURD P Lay down a single.Blow down the top 8,622.0 8,622.0 00:30 01:00 drive.Rig up to perform FIT. 3/14/2017 3/14/2017 1.00 INTRM1 CEMENT FIT P With bit @ 8575',perform FIT w/9.3 8,622.0 8,622.0 01:00 02:00 ppg mud in and out.FIT of 14.2 ppg w/900 psi.Shoe @ 8595'MD(3563' TVD). Hole drilled to 8622'MD(3565' TVD). Pick up single of 4"dp. 3/14/2017 3/14/2017 1.75 PROD1 DRILL DDRL P Make connection.Displace to 9.2 ppg 8,622.0 8,699.0 02:00 03:45 FloPro while drilling ahead f/8622'to 8699'. Pumping 250 gpm w/1845 psi and 9% flow out.Rotate 80 rpm w/5k ft/lbs of torque.Weight on bit 1k.ECD 10.43 PP9. Note:Concretion f/8661'-8666' 3/14/2017 3/14/2017 2.25 PROD1 DRILL DDRL P DDrill 6-3/4"hole f/8699'to 8848'MD, 8,699.0 8,848.0 03:45 06:00 3580'TVD,w/250 gpm, 1795 psi, 10%F/O,80 rpm,5k Tq,3k WOB, ECD 10.4,PUW 113k,SOW 85k, ROT 95k w/7k Tq,MW 9.2 ppg,Max gas 480 units,ADT 2.55,Bit hrs 2.77, Jar hrs 50.97. SPRs @ 8694'MD 3579'TVD, MW=9.20 ppg,03:50 hours MP#1:20 spm=340 psi,30 spm=550 psi. MP#2:20 spm=340 psi,30 spm=550 psi. Page 17/29 Report Printed: 4/17/2017 11/ 4111 Operations Summary (with Timelog Depths) 3R-102 ConocoPhillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/14/2017 3/14/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"hole f/8848'to 9364'MD, 8,848.0 9,364.0 - 06:00 12:00 3584'TVD,w/250 gpm, 1950 psi, 10%F/O, 150 rpm,6-8k Tq,4k WOB, ECD 10.82,PUW 113k,SOW 75k, ROT 91k w/7k Tq, MW 9.2 ppg,Max gas 1300 units,ADT 4.36,Bit hrs 7.13,Jar hrs 55.33. SPRs @ 9266'MD 3585'TVD, MW=9.20 ppg, 11:10 hours MP#1:20 spm=440 psi,30 spm=680 psi. MP#2:20 spm=460 psi,30 spm=680 psi. 3/14/2017 3/14/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"hole f/9364'to 9784'MD, 9,364.0 9,784.0 12:00 18:00 3571'TVD,w/250 gpm,2071 psi,7% F/O, 110 rpm,9k Tq,6k WOB,ECD 11.07,PUW 117k,SOW 69k,ROT 93k w/7.5k Tq, MW 9.2 ppg,Max gas 2014 units,ADT 3.72,Bit hrs 10.85, Jar hrs 59.05. SPRs @ 9838'MD 3570'TVD, MW=9.25 ppg, 19:40 hours MP#1:20 spm=540 psi,30 spm=760 psi. MP#2:20 spm=500 psi,30 spm=700 psi. Note:Concretions at 9515'-9522', 9607'-9614',9641'-9650',9662'- 9669',and 9783' 3/14/2017 3/15/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"hole f/9784'to 10120' 9,784.0 10,120.0 18:00 00:00 MD,3550'TVD,w/250 gpm,2168 psi, 8%F/O, 100 rpm,9.5k Tq,3k WOB, ECD 11.46,Off btm SPP 2155 psi, PUW 117k,SOW 58k,ROT 93k w/8k Tq,MW 9.2 ppg,Max gas 1349 units, ADT 4.23,Bit hrs 15.08,Jar hrs 63.28. SPRs @ 9838'MD 3570'TVD, MW=9.25 ppg, 19:40 hours MP#1:20 spm=540 psi,30 spm=760 psi. MP#2:20 spm=500 psi,30 spm=700 psi. SPRs @ 10121'MD 3550'TVD, MW=9.20 ppg,23:45 hours MP#1:20 spm=630 psi,30 spm=880 psi. MP#2:20 spm=640 psi,30 spm=880 psi. OA pressure at midnight=240 psi. Note:Concretions at 9784'-9787', 9807'-9814',9944'-9950',and 9955' -9961'. Page 18/29 Report Printed: 4/17/2017 • Operations Summary (with Timelog Depths) 3R-102 ConocciPhillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/15/2017 3/15/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"hole f/10120'to 10450' 10,120.0 10,450.0 00:00 06:00 MD,3561'TVD,w/260 gpm,2335 psi, 9%F/O, 180 rpm,8-9k Tq,5k WOB, ECD 11.53,PUW 118k,SOW 60k, ROT 93k w/8k Tq,MW 9.25 ppg,Max gas 450 units,ADT 4.02,Bit hrs 19.1, Jar hrs 67.3. Note:Exited out top of West Sak D at 10141'.Observed well start breathing back on connections after 10150', confirmed decreasing trend w/time to fill vis cup quickly decreasing from 7 seconds to 30 seconds.Re-entered West Sak Dat 10305'. Concretions drilled f/10378'-10385', 10426'-10430',and 10445'-10450'. 3/15/2017 3/15/2017 5.75 PROD1 DRILL DDRL P DDrill 6-3/4"hole f/10450'to 10917' 10,450.0 10,917.0 06:00 11:45 MD,3563'TVD,w/260 gpm,2315 psi, 8%F/O, 105 rpm,9-10.5k Tq,5k WOB,ECD 11.63,PUW 122k,SOW 48k,ROT 96k w/9k Tq,MW 9.2 ppg, Max gas 1500 units,ADT 4.05,Bit hrs 23.15,Jar hrs 71.35. SPRs @ 10744'MD 3562'TVD, MW=9.20 ppg, 10:30 hours MP#1:20 spm=680 psi,30 spm=920 psi. MP#2:20 spm=690 psi,30 spm=880 psi. Note:Encountered unexpected 24' throw fault at 10862'and exited bottom of West Sak D. Concretions drilled f/10491'-10495', 10519'-10533', 10555'-10562',and 10578'-10583' 3/15/2017 3/15/2017 0.25 PROD1 DRILL SVRG P Service rig.Tighten belt on cuttings 10,917.0 10,917.0 11:45 12:00 drag chain. 3/15/2017 3/15/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"hole f/10917'to 11507' 10,917.0 11,507.0 12:00 18:00 MD,3566'TVD,w/260 gpm,2475 psi, 9%F/O, 150 rpm,9k Tq,3.5k WOB, ECD 11.88,PUW 121k,SOW 47k, ROT 94k w/8.5k Tq,MW 9.2 ppg, Max gas 1160 units,ADT 3.97,Bit hrs 27.12,Jar hrs 75.32. Note:Re-entered West Sak D at 11061'.Turned on proVISION NMR tool at 11,500'with good indication of tool working properly.Control ROP at 100 ft/hr while logging zones of interest per Geologist.Tool has a memory limit of 100 hours of pumping time once turned on. Concretions drilled f/11062'-11066' and 11418'-11420'. Page 19/29 Report Printed: 4/17/2017 • • = Operations Summary (with Timelog Depths) . � 3R-102 Conoco Clips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time` End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKS) 3/15/2017 3/16/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"hole f/11507'to 11919' 11,507.0 11,919.0 18:00 00:00 MD,3559'TVD,w/260 gpm,2507 psi, 8%F/O, 100 rpm,9.5k Tq,6k WOB, ECD 11.79,PUW 122k, Unable to obtain SOW from 11800'onward,ROT 95k w/9k Tq,MW 9.25 ppg,Max gas 606 units,ADT 4.64,Bit hrs 31.76,Jar hrs 79.96. SPRs @ 11540'MD 3566'TVD, MW=9.20 ppg, 18:25 hours MP#1:20 spm=790 psi,30 spm=1000 psi. MP#2:20 spm=720 psi,30 spm=950 psi. OA pressure at midnight=250 psi Note:Total losses for 24 hours=195 bbls. Concretion drilled f/11868'-11871'. 3/16/2017 3/16/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"hole f/11919'to 12205' 11,919.0 12,205.0 00:00 06:00 MD,3550'TVD,w/260 gpm,2475 psi, 8%F/O, 100 rpm, 10.5k Tq, 10k WOB,ECD 11.83,PUW 132k, Unable to obtain SOW,ROT 95k w/9.5k Tq, MW 9.2 ppg,Max gas 623 units,ADT 4.75,Bit hrs 36.51,Jar hrs 84.71. SPRs @ 12110'MD 3548'TVD, MW=9.20 ppg,04:10 hours MP#1:20 spm=840 psi,30 spm=1030 psi. MP#2:20 spm=770 psi,30 spm=1000 psi. Concretions drilled f/11948'-11960' and 12181'-12185'. 3/16/2017 3/16/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"hole f/12205'to 12477' 12,205.0 12,477.0 06:00 12:00 MD,3552'TVD,w/260 gpm,2455 psi, 8%F/O, 100 rpm, 10k Tq,8-9k WOB, ECD 11.71,PUW 132k,Unable to obtain SOW,ROT 95k w/9.5k Tq, MW 9.2 ppg,Max gas 546 units,ADT 4.29,Bit hrs 40.80,Jar hrs 89.0. Concretions drilled f/12245'-12249', 12322'-12325', 12355'-12369',and 12475'-12477'. Page 20/29 Report Printed: 4/17/2017 • Operations Summary (with Timelogtepths) 0 3R-102 ConacoPhillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P T X Operation MKS) End Depth(ftKS)j, 3/16/2017 3/16/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"hole f/12477'to 12763' 12,477.0 12,763.0 12:00 18:00 MD,3547'TVD,w/260 gpm,2564 psi, 8%F/O, 100 rpm, 10k Tq,8k WOB, ECD 11.93,PUW 132k,Unable to obtain SOW,ROT 97k w/9k Tq,MW 9.2 ppg,Max gas 478 units,ADT 5.34, Bit hrs 46.14,Jar hrs 94.34. Note:Crossed large down-throw fault at 12630',exiting out bottom of WestSak D formation. Concretions drilled f/12477'-12492', 12557'-12568',and 12587'-12596'. 3/16/2017 3/17/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"hole f/12763'to 13249' 12,763.0 13,249.0 18:00 00:00 MD,3499'TVD,w/260 gpm,2721 psi, 9%F/O, 150 rpm, 11k Tq,8k WOB, ECD 12.55,PUW 135k,Unable to obtain SOW,ROT 90k w/8.5k Tq, MW 9.2 ppg,Max gas 162 units,ADT 3.51,Bit hrs 49.65,Jar hrs 97.85. SPRs @ 12950'MD 3535'TVD, MW=9.20 ppg, 19:50 hours MP#1:20 spm=980 psi,30 spm=1180 psi. MP#2:20 spm=920 psi,30 spm=1120 psi. Concretion drilled f/13243'-13249' OA pressure at midnight= 150 psi Total losses for 24 hours= 135 bbls 3/17/2017 3/17/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"hole f/13249'to 13686' 13,249.0 13,686.0 00:00 06:00 MD,3447'TVD,w/260 gpm,2825 psi, 9%F/O, 160 rpm,9-11k Tq,7.5k WOB,ECD 12.73,PUW 139k,Unable to obtain SOW,ROT 88k w/8.5k Tq, MW 9.25 ppg,Max gas 152 units, ADT 4.66,Bit hrs 54.31,Jar hrs 102.51. SPRs @ 13499'MD 3471'TVD, MW=9.25 ppg,02:45 hours MP#1:20 spm=920 psi,30 spm=1180 psi. MP#2:20 spm=900 psi,30 spm=1180 psi. Concretions drilled f/13249'-13240' and 13546'-13552'. Note:Re-entered WestSak D target at 13330'. Page 21/29 Report Printed: 4/17/2017 DurilWag Operations Summary (with Timelogg'epths) .-, &WeUs 3R-102 ConocoPhillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/17/2017 3/17/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"hole f/13686'to 14145' 13,686.0 14,145.0 06:00 12:00 MD,3412'TVD,w/260 gpm,2936 psi, 9%F/O, 150 rpm, 10.5k Tq,5k WOB, ECD 13.09,PUW 146k,Unable to obtain SOW,ROT 96k w/9.5k Tq, MW 9.2 ppg,Max gas 208 units,ADT 4.68,Bit hrs 58.99,Jar hrs 107.19. SPRs @ 14054'MD 3414'TVD, MW=9.20 ppg, 10:55 hours MP#1:20 spm=1060 psi,30 spm=1260 psi. MP#2:20 spm=1000 psi,30 spm=1200 psi. Concretion drilled f/13696'-13705' 3/17/2017 3/17/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"hole f/14145'to 14761' 14,145.0 14,761.0 12:00 18:00 MD,3397'TVD,w/260 gpm,3145 psi, 9%F/O, 150 rpm, 12k Tq,6.5k WOB, ECD 13.18, PUW 163k, Unable to obtain SOW, ROT 97k w/11k Tq,MW 9.25 ppg, Max gas 308 units,ADT 4.43, Bit hrs 63.42,Jar hrs 111.62. Concretion drilled f/14400'-14403'. 3/17/2017 3/17/2017 2.25 PROD1 DRILL DDRL P DDrill 6-3/4"hole f/14761'to TD of 14,761.0 14,950.0 18:00 20:15 14950'MD,3385'TVD,w/260 gpm, 3075 psi,9%F/O, 150 rpm, 12k Tq, 6.5k WOB, ECD 13.06,PUW 164k, Unable to obtain SOW,ROT 100k w/ 10.5k Tq,MW 9.25 ppg, Max gas 627 units,ADT 1.63,Bit hrs 65.05,Jar hrs 113.25. Note:Perform 290 bbl mud dilution from 14800'to TD.TD called early and MDT logging program canceled due to reservoir being water wet on other side of fault block from 12630' onwards. Total of 31 x concretions drilled throughout interval at 6.8 ft average thickness. 3/17/2017 3/17/2017 1.75 PROD1 CASING CIRC P Circulate 1 x bottoms up reciprocating 14,950.0 14,881.0 20:15 22:00 pipe from 14950'-14881'w/260 gpm, 3054 psi,9%F/O, 150 rpm, 11k Tq, ECD 13.00.Obtain final survey at TD, SPR's,and torque/drag parameters. Downlink and turn off proVISION NMR tool and put powerdrive in neutral. Final PUW 164k,Unable to obtain SOW,ROT 100k w/10k Tq. SPRs @ 14950'MD 3385'TVD, MW=9.20 ppg,21:30 hours MP#1:20 spm=1080 psi,30 spm=1320 psi. MP#2:20 spm=980 psi,30 spm=1240 psi. Page 22/29 Report Printed: 4/17/2017 Operations Summary (with TimelogDepths) ,24 . 3R-102 ConocoPhiliips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P T X Operation (ftKB) End Depth(ftKB) 3/17/2017 3/17/2017 0.25 PROD1 CASING OWFF P Rack back stand,drop 2.1"OD hollow 14,881.0 14,881.0 22:00 22:15 rabbit w/110'wire on HWDP stand #26,and monitor well for flow- confirm wellbore breathing with initial time of 5 seconds to fill vis cup decreasing to 65 seconds. 3/17/2017 3/18/2017 1.75 PROD1 CASING BKRM P Backream OOH f/14881'-14333'w/ 14,881.0 14,333.0 22:15 00:00 260 gpm,2805 psi,7%F/O, 150-125 rpm, 10k Tq,ECD 12.18,700 ft/hr pulling speed. OA pressure at midnight=220 psi. Total losses for 24 hrs=200 bbls. 3/18/2017 3/18/2017 6.00 PROD1 CASING BKRM P Backream OOH f/14333'-12295'w/ 14,333.0 12,295.0 00:00 06:00 260 gpm,2600 psi,9%F/O,ECD 12.00, 120-150 rpm,9k Tq,ROT 87k, 700 ft/hr pulling speed.Clean/inspect super sliders. Note:Perform 290 bbl dilution with new fluid turning bit at 12,600'while backreaming OOH.Slow pulling speed to 500 fUhr when top stabilizer crossed fault showing slight increase in pump pressure.Continue at 500 ft/hr until bit on other side of fault and then resume 700 ft/hr. 3/18/2017 3/18/2017 4.25 PROD1 CASING BKRM P Backream OOH f/12295'-10786'w/ 12,295.0 10,786.0 06:00 10:15 260 gpm,2400 psi,9%F/O, ECD 11.51, 100-150 rpm,6-8k Tq,ROT 90k,700 fUhr pulling speed.Clean/ inspect super sliders. 3/18/2017 3/18/2017 0.50 PROD1 CASING TRIP T Trip in hole from 10786'-11164'with 10,786.0 11,164.0 10:15 10:45 no pumps/no rotary to simulate running liner through out-of-zone section.PUW 122k,SOW 62-64k. 3/18/2017 3/18/2017 2.50 PROD1 CASING BKRM P Backream OOH f/11164'-10120'w/ 11,164.0 10,120.0 10:45 13:15 260 gpm,2344 psi,7%ECD 11.44, 100-130 rpm,6-8k Tq,700-1000 ft/hr pulling speed.Clean/inspect super sliders. Note:Pulled 1000 ft/hr through section that had already been backreamed. 3/18/2017 3/18/2017 0.25 PROD1 CASING TRIP T Trip in hole from 10120'-10310'with 10,120.0 10,310.0 13:15 13:30 no pumps/no rotary to simulate running liner through out-of-zone section.PUW 117k,SOW 62k. 3/18/2017 3/18/2017 4.25 PROD1 CASING BKRM P Backream OOH f/10310'-8595' 10,310.0 8,595.0 13:30 17:45 inside 7-5/8"shoe w/260 gpm,2170 psi,7%F/O,ECD 10.9,80-150 rpm, slowing flow rate to 220gpm once inside casing for SLB tools and adjusting rpm to reduce shocks. Clean/inspect super sliders. 3/18/2017 3/18/2017 2.00 PROD1 CASING CIRC P Circulate and condition hole clean with 8,595.0 8,513.0 17:45 19:45 2 x bottoms up at 220 gpm, 1640 psi, 8%F/O,60-80 rpm,6.5k Tq, reciprocating from 8595'-8513'. Page 23/29 Report Printed: 4/17/2017 :,,,, .., Operations Summary (with TimelogDepths) 0 0 3R-102 Conoco hifllpss Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-x Operation (ftKB) End Depth(ftKB) 3/18/2017 3/18/2017 0.75 PROD1 CASING OWFF P Monitor well for flow-observe well 8,513.0 8,513.0 19:45 20:30 breathing back initially and then taper off to static.Prep for slip/cut drill line. 3/18/2017 3/18/2017 2.00 PROD1 CASING SLPC P Slip/cut 102'drilling line and calibrate 8,513.0 8,513.0 20:30 22:30 amphion system. 3/18/2017 3/19/2017 1.50 PROD1 CASING TRIP P Pull OOH on elevators f/8513'-7940' 8,513.0 7,940.0 22:30 00:00 per trip schedule, PUW 130k,SOW 78k.Clean/inspect super sliders. OA pressure at midnight-130 psi Total losses for 24 hours=70 bbls. Overall losses for section=560 bbls. 3/19/2017 3/19/2017 4.75 PROD1 CASING TRIP P Pull OOH on elevators f/7940'-468' 7,940.0 468.0 00:00 04:45 per trip schedule.Clean/inspect super sliders. Note:Overall,observe large amount of wear on super slider stop rings, some with 1"-1.5"of aluminum worn off. 3/19/2017 3/19/2017 0.25 PROD1 CASING OWFF P Monitor well for flow at top of HWDP- 468.0 468.0 04:45 05:00 well static. 3/19/2017 3/19/2017 3.50 PROD1 CASING BHAH P PJSM.Lay down 4"HWDP and BHA 468.0 0.0 05:00 08:30 per SLB.Secure and lay down source. Bit graded: 1-2-BT-S-X-0-WT-TD Powerdrive 6-5/8"stabilizer was 1/16" undergauge SonicScope 6"stabilizer showed moderate wear and was 1/8" undergauge Top 6-5/8"stabilizer was undercut and was 1/8"undergauge proVISION NMR tool had small amount of metal debris around magnet sections 3/19/2017 3/19/2017 0.50 PROD1 CASING BHAH P Clear rig floor of remaining BHA subs 0.0 0.0 08:30 09:00 and clean floor. 3/19/2017 3/19/2017 1.50 COMPZN CASING RURD P Change out handling equipment and 0.0 0.0 09:00 10:30 rig up to run liner with GBR power tongs. 3/19/2017 3/19/2017 5.50 COMPZN CASING PUTB P PJSM.RIH with 4-1/2"lower 0.0 4,082.0 10:30 16:00 completion per tally,installing free- floating 6-1/2"centralizers on pin-end of 6-3/8"swell packers and 6-1/8" centralizers on all other joints, including pin-end of 6"swell packers. Average MUT 4000 ft-lbs,using JetLube Run-N-Seal thread compound.Monitor displacement on trip tank. Total of 104 x 4-1/2"x 6-1/8" centralizers and 4 x 4-1/2"x 6-1/2" centralizers and 2 x stop rings run in hole. Page 24/29 Report Printed: 4/17/2017 A l • • Operations Summary (with Timelog Depths) 3R-102 Ccincicoehillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB), 3/19/2017 3/19/2017 1.25 COMPZN CASING OTHR P Change out elevators and make up 4,082.0 4,149.0 16:00 17:15 sealbore extension and liner hanger/packer assembly per Baker, filling tieback sleeve with Xan-Plex D. PUW 78k,SOW 74k. 3/19/2017 3/19/2017 0.50 COMPZN CASING RURD P Rig down casing equipment and rig up 4,149.0 4,149.0 17:15 17:45 to run in on 4"DP. 3/19/2017 3/19/2017 2.75 COMPZN CASING RUNL P RIH liner on 4"DP with super sliders 4,149.0 8,500.0 17:45 20:30 installed f/4149'-8500',allowing pipe to self-fill and running in at 90 ft/min per Baker.PUW 105k,SOW 74k. Monitor displacement on trip tank. 3/19/2017 3/19/2017 0.50 COMPZN CASING CIRC P Circulate/condition mud at 7-5/8" 8,500.0 8,500.0 20:30 21:00 shoe,staging up to 5 bpm,488 psi. Circulate total 130 bbls, PUW 105k, SOW 78k.Blow down top drive. 3/19/2017 3/19/2017 1.50 COMPZN CASING RUNL P RIH liner on 4"DP with super sliders 8,500.0 9,734.0 21:00 22:30 installed f/8500'-9734",allowing pipe to self-fill.Observe string start taking 10-15k weight at 8950'.Vary running speed as hole dictates, 10-25 fUmin. Monitor displacement on trip tank. 3/19/2017 3/20/2017 1.50 COMPZN CASING RUNL P RIH liner on 4"HWDP with super 9,734.0 10,560.0 22:30 00:00 sliders installed f/9734'-10560', allowing pipe to self-fill.Vary running speed as hole dictates, 10-25 ft/min. Continue to see 10-25k drag.Monitor displacement on trip tank. Calculated Displacement=54.7 bbls Actual Displacement=47.3 bbls OA pressure at midnight=95 psi 3/20/2017 3/20/2017 3.00 COMPZN CASING RUNL P RIH liner on 4"HWDP f/10560'- 10,560.0 12,582.0 00:00 03:00 12582',allowing pipe to self-fill.Vary running speed as hole dictates, 10-50 ft/min,seeing 10-30k drag.Monitor displacement on trip tank.Pick up 4" DP single to place on depth in tension. PUW 156k,SOW 90k. Final Calculated Displacement=73.3 bbls Final Actual Displacement=63.6 bbls 3/20/2017 3/20/2017 0.75 COMPZN CASING CIRC P Circulate through string per Baker for 12,582.0 12,582.0 03:00 03:45 90 bbls,staging up pumps to 5 bpm, 934 psi,6%F/0.Blow down top drive. Page 25/29 Report Printed: 4/17/2017 =` pOperations Summary (with Timelogepths) 7',07., 3R-102 ConocoPh Clips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKB)`.. 3/20/2017 3/20/2017 1.50 COMPZN CASING CIRC P Rig up to cement line,drop ball,and 12,582.0 12,582.0 03:45 05:15 pump down at 3 bpm,586 psi, decreasing to 1.5 bpm,400 psi after 50 bbls.Ball on seat at 589 strokes (16.5 bbls early).Set hanger/packer per Baker. Pressure up to 1700 psi and slack off 40k weight to set hanger. Pressure up to 2500 psi(pusher tool sheared at 2200 psi)and hold for 5 minutes to function pusher tool and set packer.Pressure up to 4200 psi and hold for 1 minute to release from liner. Bleed off pressure and pick up- observe 150k PUW.L/D single and pump in-sub and blowdown cement line.Pick up 7ft to expose dogs and slack off 60k onto liner top packer and confirm dog subs tagging up,PUW 148k,SOW 108k. Pick up,rotate at 15 rpm,6k Tq,and set down 70k on liner top to confirm packer set. 3/20/2017 3/20/2017 0.75 COMPZN CASING PRTS P Line up to pump down IA,purge air, 12,582.0 8,445.0 05:15 06:00 close bag,and pressure test IA to 3500 psi/10 minutes-charted.Good test.Bleed off pressure and blowdown manifold. 3/20/2017 3/20/2017 0.75 COMPZN WELLPR CIRC P Pressure up drill string to 300 psi,pick 8,445.0 8,445.0 06:00 06:45 up 10'to pull out of packoff and observe pressure dump. Roll pump at 0.5 bpm,300 psi and continue pulling out total 35',leaving bottom of string 5' inside tieback sleeve.Stage up to 5 bpm,855 psi and circulate while holding PJSM for displacement. 3/20/2017 3/20/2017 1.25 COMPZN WELLPR DISP P Displace well to 9.4ppg NaCI filtered 8,445.0 8,445.0 06:45 08:00 brine per mud engineer.Pump 30 bbls Hi-vis spacer,35 bbls 3%Safe Surf W soap pill/,and 352 bbls 9.4ppg NaCI filtered brine until clean brine seen at surface. Pumped brine down at 6 bpm, 1340 psi and once brine turned the corner,picked up to high circulation rate point per Baker and increased rate to 12 bpm,3950 psi, 15%F/O 3/20/2017 3/20/2017 1.00 COMPZN WELLPR CRIH P Rack back stand to allow pump 8,445.0 8,437.0 08:00 09:00 corrosion inhibiter per mud engineer. Reciprocate stand and pump 20 bbls 1.3%Congor 303 corrosion inhibitor pill.Spot in place with 86 bbls 9.4ppg NaCI brine at 12 bpm,3900 psi, 14% F/O.Blow down top drive. 3/20/2017 3/20/2017 1.25 COMPZN WELLPR OWFF P Monitor well for flow-initially observe 8,437.0 8,437.0 09:00 10:15 small amount of flow decreasing to static. Page 26/29 Report Printed: 4/17/2017 • 66 - 6. Operations Summary (with Timelog Depths) 3R-102 ConocoPhiiiiips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKE) End Depth(ftK6) 3/20/2017 3/20/2017 9.25 COMPZN WELLPR PULD P Pull OOH sideways f/8437'to 40', 8,437.0 40.0 10:15 19:30 laying down 4"HWDP/4"DP and removing super sliders in pipe shed. Monitor well on trip tank.Observe well taking small amount of fluid,-1 bbl/hr Calculated displacement=61.4 bbls Actual displacement=72.3 bbls 3/20/2017 3/20/2017 0.50 COMPZN WELLPR BHAH P Lay down Baker liner running tools 40.0 0.0 19:30 20:00 and clear floor-observe good indication that dog sub sheared. 3/20/2017 3/21/2017 4.00 COMPZN WELLPR PULD P Install mousehole and lay down 35 x 0.0 0.0 20:00 00:00 stands 4"DP from derrick. OA pressure at midnight=90 psi 3/21/2017 3/21/2017 3.25 COMPZN WELLPR PULD P Lay down 32 x stands 4"DP from 0.0 0.0 00:00 03:15 derrick. 3/21/2017 3/21/2017 1.25 COMPZN RPCOMP WWWH P Pull wearbushing,rig up stack washer, 0.0 0.0 03:15 04:30 and jet stack and wellhead.Lay down last two joints of 4"DP. 3/21/2017 3/21/2017 1.00 COMPZN RPCOMP RURD P Clean/clear rig floor.Change out 0.0 0.0 04:30 05:30 handling equipment and rig up GBR single-stack tongs for running 4-1/2" tubing.Hold PJSM for running upper completion. 3/21/2017 3/21/2017 1.00 COMPZN RPCOMP PUTB P Run 4-1/2"12.6ppf L-80 TXP-m upper 0.0 0.0 05:30 06:30 completion per tally.Torque connections to 7400 ft-lbs and use JetLube Run-N-Seal thread compound.Run Halliburton mirage plug below wellhead,rig up head pin and test pump,and pressure test tubing to 1000 psi/5 min-good test. Make up GLM w/SOOV,run below wellhead,rig up head pin and test pump,and pressure test tubing to 1000 psi/5 min-good test. 3/21/2017 3/21/2017 8.75 COMPZN RPCOMP PUTB P Continue RIH w/4-1/2"12.6ppf L-80 0.0 8,494.0 06:30 15:15 TXP-m upper completion per tally, filling pipe on the fly with fill-up hose and topping off every 10 x joints. Torque connections to 7400 ft-lbs and use JetLube Run-N-Seal thread compound.RIH and slowly sting into sealbore and tag no-go at 8497'MD (13'in on jt#204).PUW 98k,SOW 64k.Pick up to 3'off fully-located.No remakes/rejects 3/21/2017 3/21/2017 2.75 COMPZN RPCOMP HOSO P Rig up and test IA to 500 psi/5 min- 8,494.0 8,494.0 15:15 18:00 good test.Bleed off pressure and test tubing to 3500 psi/5 min-good test. Bleed down tubing to 2000 psi and test IA to 3500 psi/30 min-charted. Good test.Bleed down IA to 0 psi and then tubing to 0 psi.Rig down and blow down lines. 3/21/2017 3/21/2017 0.50 COMPZN RPCOMP HOSO P Lay down joints#204,203,and 202. 8,494.0 8,447.0 18:00 18:30 Make up 1.86'spaceout pup and joint #202. Page 27/29 Report Printed: 4/17/2017 • Operations Summary (with Timelog epths) Aoa z° 3R-102 ConocoPhitlip+s T Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Tithe End Time Dur(hr) Prase. Op Code Activity Code Time P-T-X - Operation (EKE) End Depth(ftKD) 3/21/2017 3/21/2017 0.75 COMPZN RPCOMP THGR P Make up Vetco tubing hanger and 8,447.0 8,493.2 18:30 19:15 landing joint in mouse hole.Make up to string,run in using tuggers to help centralize hanger through BOP stack, and land off in wellhead,placing locater 4.29'off no-go. 3/21/2017 3/21/2017 1.25 COMPZN RPCOMP THGR P Run in lockdown screws and test 8,493.2 0.0 19:15 20:30 hanger upper and lower hanger seals to 5000 psi/15 min each,witnessed by CPAI-good tests. 3/21/2017 3/22/2017 3.50 COMPZN WHDBOP NUND P Layout mouse hole and riser. Nipple 0.0 0.0 20:30 00:00 down BOPE stack and spacer spool. SIMOPS Change out saver sub to 4- 1/2"IF. 3/22/2017 3/22/2017 2.25 COMPZN WHDBOP NUND P Nipple up tree in correct orientation, 0.0 0.0 00:00 02:15 confirmed by DSO.Pressure test void to 5000 psi/15 min,witnessed by CPAI-good test. 3/22/2017 3/22/2017 0.25 COMPZN WHDBOP MPSP P Pull H-type BPV,install HP-type BPV, 0.0 0.0 02:15 02:30 and convert to two-way check. SIMOPS rig up manifold for pressure testing. 3/22/2017 3/22/2017 2.00 COMPZN WHDBOP PRTS P Line up test pump,fill tree with diesel, 0.0 0.0 02:30 04:30 purge out air,and pressure test to 250/5000 psi 15/15 min each, charted-good test. 3/22/2017 3/22/2017 0.50 COMPZN WHDBOP MPSP P Convert two-way check to BPV and 0.0 0.0 04:30 05:00 pull HP-type BPV and install tree cap. Rig up to test tubing. 3/22/2017 3/22/2017 2.50 COMPZN WHDBOP PRTS P Line up mud pump#1 and pressure 0.0 0.0 05:00 07:30 test tubing to 3500 psi/30 min, charted-good test.Bleed tubing pressure to 2000 psi,line up and test IA/tubing hanger to 3500 psi/30 min,charted-good test.Bleed off IA to 0 psi and then bleed off tubing to 0 psi. 3/22/2017 3/22/2017 1.25 COMPZN WHDBOP PRTS P Line up to IA with tubing and pressure 0.0 0.0 07:30 08:45 up w/1.5 bpm to 2900 psi.Kill pump and observe pressure slowly bleed off to 0 psi,receiving returns up tubing. Circulate down IA at 1 bpm and see high pressure,-3200 psi.Line up and pressure up on tubing to 3500 psi- pressure held with no returns up IA. Line up and pump down IA at 3 bpm, 3000 psi,reducing rate to 3/4 bpm and observing pressure slowly falling off to 2450 psi,taking returns up tubing. 3/22/2017 3/22/2017 0.25 COMPZN WHDBOP CIRC P Line up and pressure up tubing to 0.0 0.0 08:45 09:00 shear Mirage plug-plug sheared at 4100 psi w/9.4ppg NaCI brine in well. Bullhead 10 bbls down tubing at 1.5 bpm,313 psi confirming injection pressure. Page 28/29 Report Printed: 4/17/2017 • • lehriThrosk Operations Summary (with Timelog Depths) &Welles 3R-102 ConocoPhillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/22/2017 3/22/2017 2.50 COMPZN WHDBOP FRZP P Rig up Little Red and freeze protect 0.0 0.0 09:00 11:30 well to 2077'MD/2000'TVD. Pump 54 bbls diesel down IA taking returns up tubing at 3/4 bpm, 1400 psi.Shut down and line up on tubing. Little Red bullhead 32 bbl diesel down tubing at 1.5 bpm, 1700 psi. Blow down and rig down equipment. 3/22/2017 3/22/2017 2.50 COMPZN WHDBOP MPSP P Observe 500 psi on tubing. Rig up 0.0 0.0 11:30 14:00 Vetco lubricator and install H-type BPV. L/D lubricator. Install flanges on tree and cap 4-1/6"x 1502 connection off manual master valve and secure well.SIMOPS-prep for rig release. 3/22/2017 3/22/2017 2.00 DEMOB MOVE MOB P Disconnect high-pressure mud lines, 0.0 0.0 14:00 16:00 clean up cellar,clear rig floor,off-load rockwasher,lay down skate,and disconnect service lines. Rig released @ 16:00 hrs. Page 29/29 Report Printed: 4/17/2017 • • NADConversion Kuparuk River Unit Kuparuk 3R Pad 3R-102 NAD 27 Definitive Survey Report 28 March, 2017 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Site: Kuparuk 3R Pad MD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Well: 3R-102 North Reference: True Wellbore: 3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102 Database: OAKE DM P2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 3R-102 Well Position +N/-S 0.00 usft Northing: 6,031,703.85 usft Latitude: 70°29'51.993 N +E/-W 0.00 usft Easting: 520,635.69 usft Longitude: 149°49'52.491 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 9.90 usft Wellbore 3R-102 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (1 (nT) BGGM2016 2/25/2017 17.78 81.04 57,552 Design 3R-102 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.10 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 39.10 0.00 0.00 290.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 48.00 743.00 3R-102 Srvy 1-SLB_NSG+SSHOT(3R- GYD-GC-SS Gyrodata gyro single shots 2/28/2017 8:58:1 766.58 2,215.65 3R-102 Srvy 2-SLB_MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/28/2017 9:06:1 2,259.63 2,259.63 3R-102 Srvy 3-SLB_INC+Filler(3R-102 INC+TREND Inclinometer+known azi trend 3/9/2017 2:29:01 2,328.59 8,541.76 3R-102 Srvy 4-SLB_MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/5/2017 10:09:C 8,638.78 14,890.02 3R-102 Srvy 5-SLB_MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/13/2017 3:20:1 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/m0w) (ft) Survey Tool Name 39.10 0.00 0.00 39.10 -9.90 0.00 0.00 6,031,703.85 520,635.69 0.00 0.00 UNDEFINED 48.00 0.24 109.51 48.00 -1.00 -0.01 0.02 6,031,703.84 520,635.71 2.70 -0.02 GYD-GC-SS(1) 88.00 0.28 92.52 88.00 39.00 -0.04 0.19 6,031,703.81 520,635.88 0.22 -0.20 GYD-GC-SS(1) 115.00 0.30 96.07 115.00 66.00 -0.05 0.33 6,031,703.80 520,636.02 0.09 -0.33 NOT an Actual Survey 20"x 24" 185.00 0.35 103.46 185.00 136.00 -0.12 0.72 6,031,703.73 520,636.41 0.09 -0.72 GYD-GC-SS(1) 278.00 0.20 171.69 278.00 229.00 -0.34 1.02 6,031,703.51 520,636.71 0.36 -1.08 GYD-GC-SS(1) 369.00 1.46 267.60 368.99 319.99 -0.55 -0.12 6,031,703.30 520,635.57 1.64 -0.08 GYD-GC-SS(1) 393.00 1.74 268.51 392.98 343.98 -0.57 -0.79 6,031,703.28 520,634.91 1.17 0.54 GYD-GC-SS(1) 486.00 3.42 271.16 485.88 436.88 -0.55 -4.97 6,031,703.28 520,630.72 1.81 4.48 GYD-GC-SS(1) 579.00 4.97 277.90 578.63 529.63 0.06 -11.74 6,031,703.87 520,623.96 1.75 11.05 GYD-GC-SS(1) 3/28/2017 9:53:45AM Page 2 COMPASS 5000.1 Build 74 . • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Site: Kuparuk 3R Pad MD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Well: 3R-102 North Reference: True Wellbore: 3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) 0100') (ft) Survey Tool Name 671.00 7.55 284.91 670.07 621.07 2.16 -21.53 6,031,705.95 520,614.16 2.92 20.97 GYD-GC-SS(1) 743.00 9.62 287.07 741.26 692.26 5.14 -31.85 6,031,708.90 520,603.83 2.91 31.69 GYD-GC-SS(1) 766.58 10.24 288.31 764.49 715.49 6.38 -35.72 6,031,710.13 520,599.95 2.78 35.75 MWD+IFR-AK-CAZ-SC(2) 861.59 11.22 289.99 857.84 808.84 12.19 -52.43 6,031,715.90 520,583.24 1.08 53.43 MWD+IFR-AK-CAZ-SC(2) 957.11 11.09 291.85 951.55 902.55 18.79 -69.69 6,031,722.44 520,565.96 0.40 71.91 MWD+IFR-AK-CAZ-SC(2) 1,051.84 12.51 291.92 1,044.28 995.28 26.01 -87.66 6,031,729.61 520,547.97 1.50 91.27 MWD+IFR-AK-CAZ-SC(2) 1,145.75 17.49 291.29 1,134.96 1,085.96 34.94 -110.26 6,031,738.48 520,525.34 5.31 115.56 MWD+IFR-AK-CAZ-SC(2) 1,241.18 18.15 291.47 1,225.81 1,176.81 45.58 -137.45 6,031,749.05 520,498.12 0.69 144.75 MWD+IFR-AK-CAZ-SC(2) 1,336.00 17.88 292.20 1,315.98 1,266.98 56.49 -164.67 6,031,759.88 520,470.88 0.37 174.06 MWD+IFR-AK-CAZ-SC(2) 1,429.78 17.41 291.84 1,405.35 1,356.35 67.15 -191.03 6,031,770.46 520,444.50 0.51 202.47 MWD+IFR-AK-CAZ-SC(2) 1,525.57 16.21 292.49 1,497.05 1,448.05 77.59 -216.68 6,031,780.83 520,418,81 1.27 230.15 MWD+IFR-AK-CAZ-SC(2) 1,619.63 18.31 294.96 1,586.87 1,537.87 88.85 -242.21 6,031,792.02 520,393.26 2.36 257.99 MWD+IFR-AK-CAZ-SC(2) 1,714.79 18.75 295.27 1,677.09 1,628.09 101.69 -269.59 6,031,804.78 520,365.84 0.47 288.11 MWD+IFR-AK-CAZ-SC(2) 1,809.56 23.39 297.30 1,765.50 1,716.50 116.83 -300.10 6,031,819.83 520,335.30 4.96 321.96 MWD+IFR-AK-CAZ-SC(2) 1,903.92 26.23 299.98 1,851.15 1,802.15 135.84 -334.81 6,031,838.75 520,300.53 3.24 361.08 MWD+IFR-AK-CAZ-SC(2) 1,998.35 31.13 304.42 1,933.98 1,884.98 160.08 -373.05 6,031,862.88 520,262.23 5.66 405.31 M1ND+IFR-AK-CAZ-SC(2) 2,093.16 34.11 305.46 2,013.83 1,964.83 189.37 -414.93 6,031,892.05 520,220.27 3.20 454,68 MWD+IFR-AK-CAZ-SC(2) 2,188.51 37.42 306.80 2,091.18 2,042.18 222.24 -459.92 6,031,924.79 520,175.20 3.57 508.19 MWD+IFR-AK-CAZ-SC(2) 2,215.65 39.83 307.03 2,112.39 2,063.39 232.42 -473.46 6,031,934.93 520,161.63 8.90 524.40 MWD+IFR-AK-CAZ-SC(2) 2,259.63 40.99 307.51 2,145.87 2,096.87 249.68 -496.15 6,031,952.13 520,138.90 2.73 551.63 INC+TREND(3) 2,291.00 41.11 307.84 2,169.53 2,120.53 262.27 -512.46 6,031,964.67 520,122.56 0.80 571.25 NOT an Actual Survey 10 3/4"x 13 1/2" 2,328.59 41.26 308.24 2,197.82 2,148,82 277.53 -531.95 6,031,979.87 520,103.02 0.80 594.79 MWD+IFR-AK-CAZ-SC(4) 2,423.80 42.44 312.17 2,268.75 2,219.75 318.53 -580.43 6,032,020.74 520,054.44 3.02 654.37 MWD+IFR-AK-CAZ-SC(4) 2,519.56 43.80 317.78 2,338.67 2,289.67 364.79 -626.66 6,032,066.86 520,008.08 4.25 713.64 MWD+IFR-AK-CAZ-SC(4) 2,615.24 44.72 323.22 2,407.22 2,358.22 416.29 -669.09 6,032,118.24 519,965.52 4.08 771.11 MWD+IFR-AK-CAZ-SC(4) 2,709.20 48.84 326.03 2,471.56 2,422.56 472.13 -708.66 6,032,173.96 519,925.79 4.90 827.40 MWD+IFR-AK-CAZ-SC(4) 2,803.34 52.75 328.78 2,531.06 2,482.06 533.59 -747.90 6,032,235.31 519,886.38 4.73 885.30 MWD+IFR-AK-CAZ-SC(4) 2,898.93 57.01 330.25 2,586.04 2,537.04 600.97 -787.54 6,032,302,57 519,846.57 4.63 945.59 MWD+IFR-AK-CAZ-SC(4) 2,993.29 60.25 330.81 2,635.16 2,586.16 671.10 -827.16 6,032,372.59 519,806.75 3.47 1,006.81 MWD+IFR-AK-CAZ-SC(4) 3,088.91 65.24 331.43 2,678.93 2,629.93 745.52 -868.19 6,032,446.88 519,765.52 5.25 1,070.82 MWD+IFR-AK-CAZ-SC(4) 3,182.44 70.24 332.52 2,714.35 2,665,35 821.91 -908.84 6,032,523.15 519,724.66 5.45 1,135.14 MWD+IFR-AK-CAZ-SC(4) 3,277.72 75.07 334.34 2,742.75 2,693.75 903.23 -949.49 6,032,604.35 519,683.79 5.39 1,201.15 MWD+IFR-AK-CAZ-SC(4) 3,372.75 78.58 336.64 2,764.41 2,715.41 987.41 -987.85 6,032,688.41 519,645.20 4.38 1,265.99 MWD+IFR-AK-CAZ-SC(4) 3,467.06 81.98 338.97 2,780.33 2,731.33 1,073.46 -1,022.95 6,032,774.36 519,609.87 4.35 1,328.40 MWD+IFR-AK-CAZ-SC(4) 3,562.28 81.65 338.70 2,793.89 2,744.89 1,161.35 -1,056.98 6,032,862.15 519,575.60 0.45 1,390.44 MWD+IFR-AK-CAZ-SC(4) 3,656.27 81.44 337.98 2,807.71 2,758.71 1,247.76 -1,091.29 6,032,948.45 519,541.04 0.79 1,452.24 MWD+IFR-AK-CAZ-SC(4) 3,751.53 81.48 337.36 2,821.85 2,772.85 1,334.89 -1,127.09 6,033,035.48 519,505.02 0.65 1,515.67 MWD+IFR-AK-CAZ-SC(4) 3,845.60 81.48 336.69 2,835.79 2,786.79 1,420.55 -1,163.40 6,033,121.02 519,468.47 0.70 1,579.09 MWD+IFR-AK-CAZ-SC(4) 3,941.30 81.28 337.61 2,850.14 2,801.14 1,507,74 -1,200.14 6,033,208.10 519,431.49 0.97 1,643.44 MWD+IFR-AK-CAZ-SC(4) 3/282017 9:53:45AM Page 3 COMPASS 5000.1 Build 74 III • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Site: Kuparuk 3R Pad MD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Well: 3R-102 North Reference: True Wellbore: 3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/1001 (ft) Survey Tool Name 4,036.63 81.21 337.59 2,864.65 2,815.65 1,594.85 -1,236.04 6,033,295.10 519,395.35 0.08 1,706.97 MWD+IFR-AK-CAZ-SC(4) 4,131.07 81.37 338.38 2,878.95 2,829.95 1,681.39 -1,271.04 6,033,381.54 519,360.12 0.84 1,769.45 MWD+IFR-AK-CAZ-SC(4) 4,226.09 81.48 338.22 2,893.11 2,844.11 1,768.69 -1,305.78 6,033,468.73 519,325.14 0.20 1,831.96 MWD+IFR-AK-CAZ-SC(4) 4,320.22 81.57 339.18 2,906.99 2,857.99 1,855.43 -1,339.60 6,033,555.37 519,291.08 1.01 1,893.40 MWD+IFR-AK-CAZ-SC(4) 4,415.08 81.42 340.00 2,921.02 2,872.02 1,943.36 -1,372.31 6,033,643.20 519,258.12 0.87 1,954.22 MWD+IFR-AK-CAZ-SC(4) 4,510.35 81.34 340.67 2,935.30 2,886,30 2,032.06 -1,404.01 6,033,731.80 519,226.18 0.70 2,014.34 MWD+IFR-AK-CAZ-SC(4) 4,604.35 80.84 341.13 2,949.86 2,900.86 2,119.81 -1,434.40 6,033,819.46 519,195.55 0.72 2,072.91 MWD+IFR-AK-CAZ-SC(4) 4,699.95 80.34 340.51 2,965.49 2,916.49 2,208.89 -1,465.38 6,033,908.44 519,164,33 0.83 2,132.49 MWD+IFR-AK-CAZ-SC(4) 4,794.44 80.46 340.31 2,981.24 2,932.24 2,296.66 -1,496.62 6,033,996.12 519,132.85 0.24 2,191.87 MWD+IFR-AK-CAZ-SC(4) 4,889.65 80.83 339.34 2,996.72 2,947.72 2,384.84 -1,529.02 6,034,084.20 519,100.21 1.08 2,252.47 MWD+IFR-AK-CAZ-SC(4) 4,983.31 80.49 338.90 3,011.92 2,962.92 2,471.19 -1,561.96 6,034,170.45 519,067.03 0.59 2,312.96 MWD+IFR-AK-CAZ-SC(4) 5,077.70 80.53 337.97 3,027.48 2,978.48 2,557.77 -1,596.18 6,034,256.92 519,032.58 0.97 2,374.73 MWD+IFR-AK-CAZ-SC(4) 5,172.82 80.23 337.04 3,043.38 2,994.38 2,644.42 -1,632.06 6,034,343.46 518,996.46 1.01 2,438.08 MWD+IFR-AK-CAZ-SC(4) 5,267.22 80.03 336.06 3,059.56 3,010.56 2,729.74 -1,669.07 6,034,428.67 518,959.22 1.04 2,502.04 MWD+IFR-AK-CAZ-SC(4) 5,362.10 79.88 335.84 3,076.11 3,027.11 2,815.05 -1,707.14 6,034,513.87 518,920.91 0.28 2,566.99 MWD+IFR-AK-CAZ-SC(4) 5,457.08 80.16 335.68 3,092.57 3,043.57 2,900.35 -1,745.55 6,034,599.05 518,882.27 0.34 2,632.26 MWD+IFR-AK-CAZSC(4) 5,551.85 79.91 335.39 3,108.97 3,059.97 2,985.31 -1,784.20 6,034,683.90 518,843.38 0.40 2,697.64 MWD+IFR-AK-CAZ-SC(4) 5,646.54 79.97 335.85 3,125.51 3,076.51 3,070.23 -1,822.69 6,034,768.70 518,804.67 0.48 2,762.85 MWD+IFR-AK-CAZ-SC(4) 5,741.01 79.94 336.37 3,141.99 3,092.99 3,155.28 -1,860.36 6,034,853.64 518,766.76 0.54 2,827.34 MWD+IFR-AK-CAZ-SC(4) 5,836.02 80.01 337.12 3,158.53 3,109.53 3,241.24 -1,897.30 6,034,939.48 518,729.59 0.78 2,891.45 MWD+IFR-AK-CAZ-SC(4) 5,930.60 79.48 337.27 3,175.37 3,126.37 3,327.03 -1,933.37 6,035,025.17 518,693.28 0.58 2,954.69 MWD+IFR-AK-CAZ-SC(4) 6,024.99 79.20 338.35 3,192.83 3,143.83 3,412.92 -1,968.41 6,035,110.95 518,658.01 1.16 3,016.98 MWD+IFR-AK-CAZ-SC(4) 6,119.39 79.90 338.90 3,209.95 3,160.95 3,499.37 -2,002.24 6,035,197.30 518,623.94 0.94 3,078.35 MWD+IFR-AK-CAZ-SC(4) 6,214.91 80.12 338.63 3,226.52 3,177.52 3,587.05 -2,036.31 6,035,284.88 518,589.63 0.36 3,140.35 MWD+IFR-AK-CAZ-SC(4) 6,309.08 80.58 337.85 3,242.31 3,193.31 3,673.27 -2,070.73 6,035,370.99 518,554.98 0.95 3,202.18 MWD+IFR-AK-CAZ-SC(4) 6,403.68 81.37 337.21 3,257.15 3,208.15 3,759.61 -2,106.44 6,035,457.22 518,519.03 1.07 3,265.27 MWD+IFR-AK-CAZ-SC(4) 6,498.44 81.67 334.31 3,271.12 3,222.12 3,845.06 -2,144.91 6,035,542.56 518,480.32 3.04 3,330.65 MWD+IFR-AK-CAZ-SC(4) 6,593.92 81.06 332.28 3,285.46 3,236.46 3,929.38 -2,187.33 6,035,626.75 518,437.67 2.20 3,399.35 MWD+IFR-AK-CAZ-SC(4) 6,688.48 81.26 328.95 3,299.99 3,250.99 4,010.78 -2,233.17 6,035,708.02 518,391.61 3.49 3,470.27 MWD+IFR-AK-CAZ-SC(4) 6,783.31 82.22 326.73 3,313.62 3,264.62 4,090.22 -2,283.13 6,035,787.31 518,341.45 2.53 3,544.38 MWD+IFR-AK-CAZ-SC(4) 6,834.32 83.15 325.68 3,320.11 3,271.11 4,132.27 -2,311.27 6,035,829.28 518,313.19 2.74 3,585.20 MWD+IFR-AK-CAZSC(4) 6,877.51 83.25 324.80 3,325.23 3,276.23 4,167.50 -2,335.72 6,035,864.44 518,288.64 2.04 3,620.23 MWD+IFR-AK-CAZ-SC(4) 6,972.07 83.41 322.66 3,336.21 3,287.21 4,243.22 -2,391.28 6,035,939.99 518,232.88 2.25 3,698.33 MWD+IFR-AK-CAZ-SC(4) 7,017.74 82.78 321.84 3,341.70 3,292.70 4,279.07 -2,419.03 6,035,975.76 518,205.03 2.25 3,736.68 MWD+IFR-AK-CAZ-SC(4) 7,067.39 82.20 320.11 3,348.19 3,299.19 4,317.31 -2,450.03 6,036,013.91 518,173.93 3.65 3,778.88 MWD+IFR-AK-CAZSC(4) 7,104.15 81.81 318.29 3,353.31 3,304.31 4,344.86 -2,473.81 6,036,041.40 518,150.07 5.02 3,810.65 MWD+IFR-AK-CAZ-SC(4) 7,160.22 81.84 316.89 3,361.28 3,312.28 4,385.84 -2,511.24 6,036,082.26 518,112.53 2.47 3,859.84 MWD+IFR-AK-CAZ-SC(4) 7,208.88 81.39 314.39 3,368.38 3,319.38 4,420.25 -2,544.90 6,036,116.58 518,078.79 5.17 3,903.24 MWD+IFR-AK-CAZ-SC(4) 7,256.01 80.40 312.46 3,375.84 3,326.84 4,452.24 -2,578.69 6,036,148.47 518,044.91 4.56 3,945.93 MWD+IFR-AK-CAZ-SC(4) 7,304.32 79.61 310.09 3,384.22 3,335.22 4,483.63 -2,614.44 6,036,179.75 518,009.07 5.10 3,990.26 MWD+IFR-AK-CAZ-SC(4) 3/28/2017 9:53:45AM Page 4 COMPASS 5000.1 Build 74 • . Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Site: Kuparuk 3R Pad MD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Well: 3R-102 North Reference: True Wellbore: 3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (1100') (ft) Survey Tool Name 7,350.36 79.13 307.93 3,392.72 3,343.72 4,512.11 -2,649.60 6,036,208.14 517,973.84 4.73 4,033.04 MWD+IFR-AK-CAZ-SC(4) 7,399.84 79.41 304.55 3,401.93 3,352.93 4,540.84 -2,688.81 6,036,236.76 517,934.56 6.74 4,079.71 MWD+IFR-AK-CAZ-SC(4) 7,445.17 79.82 301.49 3,410.10 3,361.10 4,565.14 -2,726.19 6,036,260.95 517,897.11 6.70 4,123.15 MWD+IFR-AK-CAZ-SC(4) 7,496.96 80.51 299.41 3,418.95 3,369.95 4,590.99 -2,770.18 6,036,286.68 517,853.06 4.18 4,173.33 MWD+IFR-AK-CAZ-SC(4) 7,539.35 81.33 299.56 3,425.64 3,376.64 4,611.60 -2,806.61 6,036,307.18 517,816.57 1.97 4,214.61 MWD+IFR-AK-CAZ-SC(4) 7,634.94 81.68 297.10 3,439.76 3,390.76 4,656.46 -2,889.82 6,036,351.80 517,733.24 2.57 4,308.15 MWD+IFR-AK-CAZ-SC(4) 7,730.93 82.36 294.45 3,453.09 3,404.09 4,697.79 -2,975.42 6,036,392.89 517,647.54 2.82 4,402.72 MWD+IFR-AK-CAZ-SC(4) 7,824.08 82.41 291.59 3,465.44 3,416.44 4,733.89 -3,060.39 6,036,428.75 517,562.48 3.04 4,494.91 MWD+IFR-AK-CAZ-SC(4) 7,919.11 82.13 286.29 3,478.23 3,429.23 4,764.44 -3,149.42 6,036,459.06 517,473.37 5.53 4,589.02 MWD+IFR-AK-CAZ-SC(4) 8,012.75 82.45 282.19 3,490.80 3,441.80 4,787.26 -3,239.34 6,036,481.62 517,383.39 4.35 4,681.33 MWD+IFR-AK-CAZ-SC(4) 8,065.51 82.91 280.19 3,497.52 3,448.52 4,797.42 -3,290.68 6,036,491.64 517,332.04 3.86 4,733.04 MWD+IFR-AK-CAZ-SC(4) 8,107.62 83.00 278.75 3,502.68 3,453.68 4,804.29 -3,331.90 6,036,498.40 517,290.80 3.40 4,774.12 MWD+IFR-AK-CAZ-SC(4) 8,202.76 82.37 274.13 3,514.80 3,465.80 4,814.88 -3,425.64 6,036,508.72 517,197.04 4.86 4,865.83 MWD+IFR-AK-CAZ-SC(4) 8,297.70 81.86 269.64 3,527.84 3,478.84 4,817.97 -3,519.61 6,036,511.55 517,103.07 4.72 4,955.19 MWD+IFR-AK-CAZ-SC(4) 8,392.36 82.74 265.38 3,540.52 3,491.52 4,813.89 -3,613.30 6,036,507.21 517,009.40 4.56 5,041.84 MWD+IFR-AK-CAZ-SC(4) 8,487.18 83.77 265.54 3,551.66 3,502.66 4,806.44 -3,707.17 6,036,499.50 516,915.56 1.10 5,127.50 MWD+IFR-AK-CAZ-SC(4) 8,541.76 83.79 265.37 3,557.57 3,508.57 4,802.14 -3,761.26 6,036,495.05 516,861.49 0.31 5,176.85 MWD+IFR-AK-CAZ-SC(4) 8,594.00 83.72 264.36 3,563.26 3,514.26 4,797.49 -3,812.98 6,036,490.26 516,809.79 1.92 5,223.87 NOT an Actual Survey 75/8"x97/8 8,638.78 83.66 263.50 3,568.18 3,519.18 4,792.79 -3,857.24 6,036,485.43 516,765.55 1.92 5,263.85 MWD+IFR-AK-CAZ-SC(5) 8,671.52 84.90 262.76 3,571.44 3,522.44 4,788.89 -3,889.58 6,036,481.45 516,733.22 4.40 5,292.91 MWD+IFR-AK-CAZ-SC(5) 8,703.61 86.14 264.28 3,573.95 3,524.95 4,785.28 -3,921.36 6,036,477.75 516,701.45 6.10 5,321.54 MWD+IFR-AK-CAZ-SC(5) 8,733.13 87.10 265.71 3,575.69 3,526.69 4,782.71 -3,950.72 6,036,475.10 516,672.10 5.83 5,348.25 MWD+IFR-AK-CAZ-SC(5) 8,765.80 87.73 266.95 3,577.16 3,528.16 4,780.62 -3,983.29 6,036,472.92 516,639.54 4.25 5,378.14 MWD+IFR-AK-CAZ-SC(5) 8,797.18 87.82 267.13 3,578.38 3,529.38 4,779.00 -4,014.60 6,036,471.21 516,608.23 0.64 5,407.01 MWD+IFR-AK-CAZ-SC(5) 8,828.00 88.09 269.81 3,579.48 3,530.48 4,778.18 -4,045.39 6,036,470.31 516,577.45 8.73 5,435.66 MWD+IFR-AK-CAZ-SC(5) 8,924.07 88.04 270.16 3,582.73 3,533.73 4,778.16 -4,141.41 6,036,470.01 516,481.45 0.37 5,525.87 MWD+IFR-AK-CAZ-SC(5) 9,018.79 89.82 269.32 3,584.49 3,535.49 4,777.73 -4,236.10 6,036,469.32 516,386.76 2.08 5,614.71 MWD+IFR-AK-CAZ-SC(5) 9,113.14 90.05 268.69 3,584.60 3,535.60 4,776.09 -4,330.44 6,036,467.42 516,292.44 0.71 5,702.80 MWD+IFR-AK-CAZ-SC(5) 9,208.72 89.95 267.85 3,584.60 3,535.60 4,773.20 -4,425.97 6,036,464.27 516,196.92 0.89 5,791.59 MWD+IFR-AK-CAZ-SC(5) 9,303.05 90.12 270.04 3,584.54 3,535.54 4,771.46 -4,520.28 6,036,462.27 516,102.63 2.33 5,879.61 MWD+IFR-AK-CAZ-SC(5) 9,397.06 91.08 272.78 3,583.56 3,534.56 4,773.78 -4,614.25 6,036,464.32 516,008.67 3.09 5,968.70 MWD+IFR-AK-CAZ-SC(5) 9,490.90 91.22 275.30 3,581.68 3,532.68 4,780.39 -4,707.83 6,036,470.67 515,915.08 2.69 6,058.90 MWD+IFR-AK-CAZ-SC(5) 9,584.52 91.24 274.35 3,579.67 3,530.67 4,788.26 -4,801.09 6,036,478.29 515,821.80 1.01 6,149.23 MWD+IFR-AK-CAZ-SC(5) 9,681.00 92.62 272.67 3,576.42 3,527.42 4,794.16 -4,897.33 6,036,483.92 515,725.55 2.25 6,241.69 MWD+IFR-AK-CAZ-SC(5) 9,773.86 93.38 267.36 3,571.55 3,522.55 4,794.19 -4,990.03 6,036,483.69 515,632.87 5.77 6,328.81 MWD+IFR-AK-CAZ-SC(5) 9,869.63 93.48 266.30 3,565.82 3,516.82 4,788.90 -5,085.48 6,036,478.14 515,537.44 1.11 6,416.69 MWD+IFR-AK-CAZ-SC(5) 9,965.16 93.65 265.40 3,559.88 3,510.88 4,782.00 -5,180.58 6,036,470.98 515,442.37 0.96 6,503.69 MWD+IFR-AK-CAZ-SC(5) 10,058.11 93.03 266.21 3,554.47 3,505.47 4,775.22 -5,273.12 6,036,463.93 515,349.86 1.10 6,588.33 MWD+IFR-AK-CAZ-SC(5) 10,154.55 91.08 266.50 3,551.01 3,502.01 4,769.09 -5,369,30 6,036,457.54 515,253.71 2.04 6,676.61 MWD+IFR-AK-CAZ-SC(5) 3/28/2017 9:53:45AM Page 5 COMPASS 5000.1 Build 74 II I i Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Site: Kuparuk 3R Pad MD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Well: 3R-102 North Reference: True Wellbore: 3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102 Database: OAKE D M P2 Survey Map Map Vertical MD Inc Azi TVD 1VDSS +N!-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 10,248.93 88.57 265.92 3,551.30 3,502.30 4,762.85 -5,463.46 6,036,451.04 515,159.57 2.73 6,762.97 MWD+IFR-AK-CAZ-SC(5) 10,342.27 86.74 265.64 3,555.12 3,506.12 4,755.99 -5,556.47 6,036,443.92 515,066.59 1.98 6,848.02 MWD+IFR-AK-CAZ-SC(5) 10,437.85 90.02 266.75 3,557.82 3,508.82 4,749.65 -5,651.78 6,036,437.32 514,971.30 3.62 6,935.42 MWD+IFR-AK-CAZ-SC(5) 10,533.00 89.08 266.56 3,558.57 3,509.57 4,744.10 -5,746.77 6,036,431.50 514,876.35 1.01 7,022.77 MWD+IFR-AK-CAZ-SC(5) 10,627.38 89.33 269.07 3,559.87 3,510.87 4,740.50 -5,841.06 6,036,427.65 514,782.07 2.67 7,110.15 MWD+IFR-AK-CAZ-SC(5) 10,720.67 89.47 271.40 3,560.85 3,511.85 4,740.88 -5,934.34 6,036,427.77 514,688.80 2.50 7,197.93 MWD+IFR-AK-CAZ-SC(5) 10,816.39 89.47 271.47 3,561.74 3,512.74 4,743.28 -6,030.03 6,036,429.90 514,593.12 0.07 7,288.67 MWD+IFR-AK-CAZ-SC(5) 10,911.11 88.80 271.14 3,563.17 3,514.17 4,745.44 -6,124.71 6,036,431.79 514,498.44 0.79 7,378.38 MWD+IFR-AK-CAZ-SC(5) 11,006.68 89.79 270.27 3,564.34 3,515.34 4,746.61 -6,220.26 6,036,432.70 514,402.89 1.38 7,468.57 MWD+IFR-AK-CAZ-SC(5) 11,099.59 92.28 270.83 3,562.67 3,513.67 4,747.50 -6,313.15 6,036,433.34 514,310.02 2.75 7,556.16 MWD+IFR-AK-CAZ-SC(5) 11,193.48 91.15 272.58 3,559.86 3,510.86 4,750.30 -6,406.95 6,036,435.87 514,216.22 2.22 7,645.26 MWD+IFR-AK-CAZ-SC(5) 11,289.46 89.40 271.78 3,559.39 3,510.39 4,753.95 -6,502.85 6,036,439.25 514,120.31 2.00 7,736.63 MWD+IFR-AK-CAZ-SC(5) 11,384.81 88.29 272.77 3,561.32 3,512.32 4,757.73 -6,598.11 6,036,442.77 514,025.06 1.56 7,827,43 MWD+IFR-AK-CAZ-SC(5) 11,478.98 88.32 272.54 3,564.10 3,515.10 4,762.09 -6,692.13 6,036,446.87 513,931.03 0.25 7,917.28 MWD+IFR-AK-CAZ-SC(5) 11,573.63 89.57 272.42 3,565.84 3,516.84 4,766.19 -6,786.68 6,036,450.70 513,836.48 1.33 8,007.52 MWD+IFR-AK-CAZ-SC(5) 11,669.26 90.14 271.75 3,566.09 3,517.09 4,769.67 -6,882.24 6,036,453.92 513,740.92 0.92 8,098.51 MWD+IFR-AK-CAZ-SC(5) 11,763.98 92.00 269.81 3,564.32 3,515.32 4,770.96 -6,976.93 6,036,454.94 513,646.24 2.84 8,187.93 MWD+IFR-AK-CAZ-SC(5) 11,857.55 92.52 268,51 3,560.63 3,511.63 4,769.58 -7,070.41 6,036,453.31 513,552.77 1.50 8,275.31 MWD+IFR-AK-CAZ-SC(5) 11,953.14 93.10 268.11 3,555.94 3,506.94 4,766.77 -7,165.85 6,036,450.23 513,457.35 0.74 8,364.02 MWD+IFR-AK-CAZ-SC(5) 12,048.52 92.43 268.67 3,551.34 3,502.34 4,764.09 -7,261.08 6,036,447.29 513,362.14 0.92 8,452.60 MWD+IFR-AK-CAZ-SC(5) 12,142.97 89.65 268.19 3,549.63 3,500.63 4,761.51 -7,355.47 6,036,444.44 513,267.77 2.99 8,540.41 MWD+IFR-AK-CAZ-SC(5) 12,237.59 89.67 267.91 3,550.19 3,501.19 4,758.29 -7,450.03 6,036,440.96 513,173.22 0.30 8,628.17 MWD+IFR-AK-CAZ-SC(5) 12,332.05 89.74 268.48 3,550.67 3,501.67 4,755.31 -7,544.44 6,036,437.73 513,078.83 0.61 8,715.87 MWD+IFR-AK-CAZ-SC(5) 12,426.14 89.62 268.02 3,551.20 3,502.20 4,752.44 -7,638.48 6,036,434.59 512,984.80 0.51 8,803.26 MWD+IFR-AK-CAZ-SC(5) 12,518.51 91.69 267.95 3,550.14 3,501.14 4,749.19 -7,730.79 6,036,431.09 512,892.52 2.24 8,888.88 MWD+IFR-AK-CAZ-SC(5) 12,582.00 90.99 268.34 3,548.66 3,499.66 4,747.13 -7,794.23 6,036,428.85 512,829.09 1.26 8,947.79 NOT an Actual Survey 4 112"x 6 314" 12,608.99 90.69 268.50 3,548.26 3,499.26 4,746.39 -7,821.20 6,036,428.04 512,802.12 1.26 8,972.89 MWD+IFR-AK-CAZ-SC(5) 12,701.93 91.20 267.69 3,546.73 3,497.73 4,743.30 -7,914.08 6,036,424.69 512,709.26 1.03 9,059.10 MWD+IFR-AK-CAZ-SC(5) 12,796.93 93.31 266.71 3,542.99 3,493.99 4,738.66 -8,008.88 6,036,419.79 512,614.48 2.45 9,146.61 MWD+IFR-AK-CAZ-SC(5) 12,890.26 95.83 264.32 3,535.56 3,486.56 4,731.39 -8,101.62 6,036,412.26 512,521.77 3.72 9,231.26 MWD+IFR-AK-CAZ-SC(5) 12,982.92 96.10 263.20 3,525.93 3,476.93 4,721.38 -8,193.23 6,036,401.99 512,430.20 1.24 9,313.92 MWD+IFR-AK-CAZ-SC(5) 13,071.76 96.03 262.96 3,516.54 3,467.54 4,710.73 -8,280.93 6,036,391.11 512,342.54 0.28 9,392.69 MWD+IFR-AK-CAZ-SC(5) 13,164.19 96.09 261.85 3,506.78 3,457.78 4,698.58 -8,372.03 6,036,378.71 512,251.48 1.20 9,474.15 MWD+IFR-AK-CAZ-SC(5) 13,257.05 96.10 259.00 3,496.92 3,447.92 4,683.23 -8,463.07 6,036,363.10 512,160.49 3.05 9,554.44 MWD+IFR-AK-CAZ-SC(5) 13,349.20 96.20 256.03 3,487.05 3,438.05 4,663.42 -8,552.52 6,036,343.05 512,071.11 3.21 9,631.72 MWD+IFR-AK-CAZ-SC(5) 13,441.20 96.13 254.45 3,477.17 3,428.17 4,640.12 -8,640.96 6,036,319.50 511,982.74 1.71 9,706.86 MWD+IFR-AK-CAZ-SC(5) 13,533.72 96.13 252.93 3,467.29 3,418.29 4,614.29 -8,729.25 6,036,293.43 511,894.53 1.63 9,780.99 MWD+IFR-AK-CAZ-SC(5) 13,624.70 96.13 249.42 3,457.57 3,408.57 4,585.10 -8,814.86 6,036,264.01 511,809.02 3.84 9,851.45 MWD+IFR-AK-CAZ-SC(5) 13,715.41 96.00 247.11 3,447.98 3,398.98 4,551.70 -8,898.64 6,036,230.38 511,725.33 2.54 9,918.76 MWD+IFR-AK-CAZ-SC(5) 3/28/2017 9:53:45AM Page 6 COMPASS 5000.1 Build 74 i • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Site: Kuparuk 3R Pad MD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Well: 3R-102 North Reference: True Wellbore: 3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102 Database: OAKE D M P2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1900) (ft) Survey Tool Name 13,808.53 96.27 246.29 3,438.03 3,389.03 4,515.08 -8,983.67 6,036,193.52 511,640.41 0.92 9,986.14 MWD+IFR-AK-CAZ-SC(5) 13,900.76 96.17 245.73 3,428.04 3,379.04 4,477.80 -9,067.44 6,036,156.02 511,556.76 0.61 10,052.11 MWD+IFR-AK-CAZ-SC(5) 13,993.20 95.61 247.20 3,418.55 3,369.55 4,441.09 -9,151.74 6,036,119.07 511,472.57 1.69 10,118.76 MWD+IFR-AK-CAZ-SC(5) 14,085.29 91.50 247.79 3,412.84 3,363.84 4,405.91 -9,236.64 6,036,083.67 511,387.78 4.51 10,186.51 MWD+IFR-AK-CAZ-SC(5) 14,176.85 89.79 246.05 3,411.81 3,362.81 4,370.02 -9,320.86 6,036,047.55 511,303.67 2.66 10,253.38 MWD+IFR-AK-CAZ-SC(5) 14,269.99 89.87 244.97 3,412.09 3,363.09 4,331.42 -9,405.62 6,036,008.71 511,219.02 1.16 10,319.82 MWD+IFR-AK-CAZ-SC(5) 14,361.44 90.84 244.72 3,411.52 3,362.52 4,292.54 -9,488.39 6,035,969.61 511,136.36 1.10 10,384.31 MWD+IFR-AK-CAZSC(5) 14,453.76 92.68 246.48 3,408.69 3,359.69 4,254.43 -9,572.42 6,035,931.26 511,052.45 2.76 10,450.23 MWD+IFR-AK-CAZ-SC(5) 14,545.65 92.18 248.52 3,404.79 3,355.79 4,219.30 -9,657.23 6,035,895.90 510,967.74 2.28 10,517.91 MWD+IFR-AK-CAZ-SC(5) 14,635.90 92.38 247.74 3,401.20 3,352.20 4,185.71 -9,740.92 6,035,862.08 510,884.16 0.89 10,585.07 MWD+IFR-AK-CAZ-SC(5) 14,729.03 93.00 248.92 3,396.83 3,347.83 4,151.35 -9,827.37 6,035,827.49 510,797.81 1.43 10,654.55 MWD+IFR-AK-CAZ-SC(5) 14,820.59 92.90 249.47 3,392.12 3,343.12 4,118.88 -9,912.85 6,035,794.78 510,712.43 0.61 10,723.77 MWD+IFR-AK-CAZ-SC(5) 14,890.02 92.86 252.82 3,388.63 3,339.63 4,096.47 -9,978.46 6,035,772.20 510,646.89 4.82 10,777.76 MWD+IFR-AK-CAZ-SC(5) 14,950.00 92.86 252.82 3,385.63 3,336.63 4,078.78 -10,035.69 6,035,754.34 510,589.71 0.00 10,825.49 PROJECTED to TD 3/28/2017 9:53:45AM Page 7 COMPASS 5000.1 Build 74 • • Miffing Cement Detail Report e &Wen 3R-102 Chilii ps ' String: CONDUCTOR CEMENT Job: DRILLING ORIGINAL, 2/25/2017 16:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name CONDUCTOR CEMENT 12/16/2016 17:00 12/16/2016 17:30 3R-102 Comment AFC poured 5-1/2 sacks portland cement down backside to cement conductor.Ambient temperature of-10°F. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? CONDUCTOR CEMENT Cement conductor in 39.0 119.0 No No No place Q Pump Init(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment AFC poured 5-1/2 sacks portland cement down backside to cement conductor.Ambient temperature of-10°F. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 4/17/2017 • • n' Miffing Cement Detail Report &wens 3R-102 gehitlaps String: 10-3/4" SURFACE CEMENT Job: DRILLING ORIGINAL, 2/25/2017 16:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name 10-3/4"SURFACE CEMENT 3/2/2017 20:45 3/3/2017 00:30 3R-102 Comment Prime up pump units and RU for Surface cement job. Pressure test lines @ 3,500 psi.-Good Test. Pump 40 bbls of CW100,followed 80 bbls Mud Push II, Drop plug and chase with 424.2 bbls of lead cmt,followed by 61.9 bbls of 12.0 ppg Tail cement,flush lines with 10.4 bbls of fresh water,drop wiper plug and displace cement with 201 bbls of 9.6+ppg spud mud. up till midnight and After midnight Plug was Bumped and pressure up 500 psi over FCP to 900 psi for 5 min,bleed off and check floats,good.Returned 172 bbls of cement to surface with full returns the whole job. Cement in place @ 00:30 hrs. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? 10-3/4-SURFACE 41.6 2,291.5 Yes 172.0 Yes Yes CEMENT JOB Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 7 7 350.0 900.0 Yes 10.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement surface casing to surface Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) CW100 0.0 0.0 40.0 Yield(ff/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MudPush II 0.0 0.0 67.3 Yield(fta/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 41.0 1,801.0 1,274 Litecrete 420.3 Yield(fta/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.85 6.22 11.0 Additives Additive Type Concentration Conc Unit label D177 0.01 gal/sx Additive Type Concentration Conc Unit label D185 0.06 gal/sx Additive Type Concentration Conc Unit label D46 0.2 %BWOC Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 1,801.0 2,301.0 215 Litecrete 61.9 Yield(fta/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.62 5.47 12.0 Additives Additive Type Concentration Conc Unit label 0046 0.2 %BWOC Additive Type Concentration Conc Unit label D177 0.11 gal/sx Additive Type Concentration Conc Unit label D230 0.01 gal/sx Page 1/1 Report Printed: 4/17/2017 • D0 l Cement Detail Report ri otaWells 3R-102 ConocoPhillhps String: 7-5/8" INTERMEDIATE CEMENT Job: DRILLING ORIGINAL, 2/25/2017 16:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name 7-5/8"INTERMEDIATE CEMENT 3/10/2017 19:30 3/10/2017 22:30 3R-102 Comment Flood lines with water to test SLB. Test surface lines to 4K PSI. Pump 40.1 BBLS of 12.5 PPG mud push, Drop bottom plug and pump 178.1 BBLS of 15.8 PPG class G cement. Drop top plug and follow up with 10 BBLS of water and chase with rig pumps for 3,761 STKS. DPP up as high as 1300 PSI for @ 5 min. Lost slack off Wt before cement reached shoe. Parked casing for cement program on hanger after rig displaced 120 bbls of mud(48.75 bbls before MudPush at the shoe,88.75 bbls before cement at the shoe). CIP @ 22:21 hrs. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? 7-5/8"INTERMEDIATE Cement 7-5/8"casing 4,060.0 8,602.0 Yes Yes Yes CEMENT Q Pump'nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 3 800.0 1,350.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Flood lines with water to test SLB. Test surface lines to 4K PSI. Pump 40.1 BBLS of 12.5 PPG mud push, Drop bottom plug and pump 178.1 BBLS of 15.8 PPG class G cement. Drop top plug and follow up with 10 BBLS of water and chase with rig pumps for 3,761 STKS. DPP up as high as 1300 PSI for @ 5 min. Lost slack off Wt before cement reached shoe. Parked casing for cement program on hanger after rig displaced 120 bbls of mud(48.75 bbls before MudPush at the shoe,88.75 bbls before cement at the shoe). CIP @ 22:21 hrs. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 5,308.0 8,602.0 862 G 178.1 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.11 15.80 6.25 Additives Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 Dispersant 0.3 %BWOC Additive Type Concentration Conc Unit label D255 Fluid Loss 0.4 %BWOC Additive Type Concentration Conc Unit label D177 Retarder 0.03 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MudPush II 4,559.0 5,308.0 40.1 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 4/17/2017 410 CA 21 61 57 RECEIVED ,, 2 8 1 3 5 No APR 13 2017 Con€ oPhiHH1 AOGCC TRANSMITTAL DATA LOGGED `t/l+t/201 I M K. BENDER FROM: Sandra D. Lemke, ATO07-704 TO: Makana Bender ConocoPhiiiips Alaska, Inc. AOGCC P.O. Box 100360 Anchorage Pouch Mail Anchorage AK 99510-0360 RE: 3R-102 DATE:04/12/2017 T - smitted: Kuparuk River Unit, Alaska 3R-102 1 CD of final report hardcopy and digital w/digital loci images and 1 color hardcopy print each loci I Halliburton Surface Data Logging-End of well report for 3R-102; 03/19/2017; general information, daily summary, days vs. depth,after action review, mud record, bit record, morning reports, survey reports; color log presentations, one set each for wellbore. 1 Formation Evaluation log-MD Gas ratio-MD Drilling Engineering Log-MD i CD contains Final log files, End of well report, final LAS exports, log viewers I Please promptly sign,scan and return electronically to Sandra.D.Lemkec 1COP.crrm 6 i CC: 3R-102 transmittal folder, production well files,eSearch Receipt:/L/ Wit_` _ .` 4 ' ,(0-. e: 1 � GIS-Technical Data M ; { f =`-;= res Alaska Pk 907.26S.6947 21 61 57 RESEIVED • 28 1 2 6 APR 1 1 201/ Schlumberg er AOG//��++ Transmittal#: 10APR17-SPO1 V�jrilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery 1(/12/201? M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender I Well No: 3R-102 Date Dispatched: 10-Apr-17 Job#: 17AKA0004 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Contents on CD N/A VISION Resistivity 2"MD x x VISION Resistivity 2"TVD x x VISION Resistivity 5"MD x x VISION Resistivity 5"TVD x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: 1 om.Osterkamp(a)conocophilIips.com AlaskaPTSPrintCenter(a)slb.com Tom Osterkamp Attn:Stephanie Pacillo 907-263-4795 Received By: ()"),/agr)../frukd f5_e..i,txezt • S 216157 28126 RECEIVED APR 1 1 2017 FINAL AOGCC OG C NADConversion Kuparuk River Unit Kuparuk 3R Pad 3R-102 NAD 27 Definitive Survey Report 28 March, 2017 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Site: Kuparuk 3R Pad MD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Well: 3R-102 North Reference: True Wellbore: 3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 3R-102 Well Position +N/-S 0.00 usft Northing: 6,031,703.85 usft Latitude: 70°29'51.993 N +E/-W 0.00 usft Easting: 520,635.69 usft Longitude: 149°49'52.491 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 9.90 usft Wellbore 3R-102 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2016 2/25/2017 17.78 81.04 57,552 Design 3R-102 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.10 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 39.10 0.00 0.00 290.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 48.00 743.00 3R-102 Srvy 1-SLB_NSG+SSHOT(3R- GYD-GC-SS Gyrodata gyro single shots 2/28/2017 8:58: 766.58 2,215.65 3R-102 Srvy 2-SLB_MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/28/2017 9:06: 2,259.63 2,259.63 3R-102 Srvy 3-SLB_INC+Filler(3R-102 INC+TREND Inclinometer+known azi trend 3/9/2017 2:29:0 2,328.59 8,541.76 3R-102 Srvy 4-SLB_MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/5/2017 10:09:( 8,638.78 14,890.02 3R-102 Srvy 5-SLB_MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/13/2017 3:20: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 39.10 0.00 0.00 39.10 -9.90 0.00 0.00 6,031,703.85 520,635.69 0.00 0.00 UNDEFINED 48.00 0.24 109.51 48.00 -1.00 -0.01 0.02 6,031,703.84 520,635.71 2.70 -0.02 GYD-GC-SS(11 88.00 0.28 92.52 88.00 39.00 -0.04 0.19 6,031,703.81 520,635.88 0.22 -0.20 GYD-GC-SS(1) 115.00 0.30 96.07 115.00 66.00 -0.05 0.33 6,031,703.80 520,636.02 0.09 -0.33 NOT an Actual Survey 20"x 24" 185.00 0.35 103.46 185.00 136.00 -0.12 0.72 6,031,703.73 520,636.41 0.09 -0.72 GYD-GC-SS(1) 278.00 0.20 171.69 278.00 229.00 -0.34 1.02 6,031,703.51 520,636.71 0.36 -1.08 GYD-GC-SS(1) 369.00 1.46 267.60 368.99 319.99 -0.55 -0.12 6,031,703.30 520,635.57 1.64 -0.08 GYD-GC-SS(1) 393.00 1.74 268.51 392.98 343.98 -0.57 -0.79 6,031,703.28 520,634.91 1.17 0.54 GYD-GC-SS(1) 486.00 3.42 271.16 485.88 436.88 -0.55 -4.97 6,031,703.28 520,630.72 1.81 4.48 GY0-GC-SS(1) 579.00 4.97 277.90 578.63 529.63 0.06 -11.74 6,031,703.87 520,623.96 1.75 11.05 GYD-GC-SS(1) 3/28/2017 9:53:45AM Page 2 COMPASS 5000.1 Build 74 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Site: Kuparuk 3R Pad MD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Well: 3R-102 North Reference: True Wellbore: 3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102 Database: OAKE DM P2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 671.00 7.55 284.91 670.07 621.07 2.16 -21.53 6,031,705.95 520,614.16 2.92 20.97 GYD-GC-SS(1) 743.00 9.62 287.07 741.26 692.26 5.14 -31.85 6,031,708.90 520,603.83 2.91 31.69 GYD-GC-SS(1) 766.58 10.24 288.31 764.49 715.49 6.38 -35.72 6,031,710.13 520,599.95 2.78 35.75 MWD+IFR-AK-CAZ-SC(2) 861.59 11.22 289.99 857.84 808.84 12.19 -52.43 6,031,715.90 520,583.24 1.08 53.43 MWD+IFR-AK-CAZ-SC(2) 957.11 11.09 291.85 951.55 902.55 18.79 -69.69 6,031,722.44 520,565.96 0.40 71.91 MWD+IFR-AK-CAZ-SC(2) 1,051.84 12.51 291.92 1,044.28 995.28 26.01 -87.66 6,031,729.61 520,547.97 1.50 91.27 MWD+IFR-AK-CAZ-SC(2) 1,145.75 17.49 291.29 1,134.96 1,085.96 34.94 -110.26 6,031,738.48 520,525.34 5.31 115.56 MWD+IFR-AK-CAZ-SC(2) 1,241.18 18.15 291.47 1,225.81 1,176.81 45.58 -137.45 6,031,749.05 520,498.12 0.69 144.75 MWD+IFR-AK-CAZ-SC(2) 1,336.00 17.88 292.20 1,315.98 1,266.98 56.49 -164.67 6,031,759.88 520,470.88 0.37 174.06 MWD+IFR-AK-CAZ-SC(2) 1,429.78 17.41 291.84 1,405.35 1,356.35 67.15 -191.03 6,031,770.46 520,444.50 0.51 202.47 MWD+IFR-AK-CAZ-SC(2) 1,525.57 16.21 292.49 1,497.05 1,448.05 77.59 -216.68 6,031,780.83 520,418.81 1.27 230.15 MWD+IFR-AK-CAZ-SC(2) 1,619.63 18.31 294.96 1,586.87 1,537.87 88.85 -242.21 6,031,792.02 520,393.26 2.36 257.99 MWD+IFR-AK-CAZ-SC(2) 1,714.79 18.75 295.27 1,677.09 1,628.09 101.69 -269.59 6,031,804.78 520,365.84 0.47 288.11 MWD+IFR-AK-CAZ-SC(2) 1,809.56 23.39 297.30 1,765.50 1,716.50 116.83 -300.10 6,031,819.83 520,335.30 4.96 321.96 MWD+IFR-AK-CAZ-SC(2) 1,903.92 26.23 299.98 1,851.15 1,802.15 135.84 -334.81 6,031,838.75 520,300.53 3.24 361.08 MWD+IFR-AK-CAZ-SC(2) 1,998.35 31.13 304.42 1,933.98 1,884.98 160.08 -373.05 6,031,862.88 520,262.23 5.66 405.31 MWD+IFR-AK-CAZ-SC(2) 2,093.16 34.11 305.46 2,013.83 1,964.83 189.37 -414.93 6,031,892.05 520,220.27 3.20 454.68 MWD+IFR-AK-CAZ-SC(2) 2,188.51 37.42 306.80 2,091.18 2,042.18 222.24 -459.92 6,031,924.79 520,175.20 3.57 508.19 MWD+IFR-AK-CAZ-SC(2) 2,215.65 39.83 307.03 2,112.39 2,063.39 232.42 -473.46 6,031,934.93 520,161.63 8.90 524.40 MWD+IFR-AK-CAZ-SC(2) 2,259.63 40.99 307.51 2,145.87 2,096.87 249.68 -496.15 6,031,952.13 520,138.90 2.73 551.63 INC+TREND(3) 2,291.00 41.11 307.84 2,169.53 2,120.53 262.27 -512.46 6,031,964.67 520,122.56 0.80 571.25 NOT an Actual Survey 10 3/4"x 13 1/2" 2,328.59 41.26 308.24 2,197.82 2,148,82 277.53 -531.95 6,031,979.87 520,103.02 0.80 594.79 MWD+IFR-AK-CAZ-SC(4) 2,423.80 42.44 312.17 2,268.75 2,219.75 318.53 -580.43 6,032,020.74 520,054.44 3.02 654.37 MWD+IFR-AK-CAZ-SC(4) 2,519.56 43.80 317.78 2,338.67 2,289.67 364.79 -626.66 6,032,066.86 520,008.08 4.25 713.64 MWD+IFR-AK-CAZ-SC(4) 2,615.24 44.72 323.22 2,407.22 2,358.22 416.29 -669.09 6,032,118.24 519,965.52 4.08 771.11 MWD+IFR-AK-CAZ-SC(4) 2,709.20 48.84 326.03 2,471.56 2,422.56 472.13 -708.66 6,032,173.96 519,925.79 4.90 827.40 MWD+IFR-AK-CAZ-SC(4) 2,803.34 52.75 328.78 2,531.06 2,482.06 533.59 -747.90 6,032,235.31 519,886.38 4.73 885.30 MWD+IFR-AK-CAZ-SC(4) 2,898.93 57.01 330.25 2,586.04 2,537.04 600.97 -787.54 6,032,302.57 519,8.46.57 4.63 945.59 MWD+IFR-AK-CAZ-SC(4) 2,993.29 60.25 330.81 2,635.16 2,586.16 671.10 -827.16 6,032,372.59 519,806.75 3.47 1,006.81 MWD+IFR-AK-CAZ-SC(4) 3,088.91 65.24 331.43 2,678.93 2,629.93 745.52 -868.19 6,032,446.88 519,765.52 5.25 1,070.82 MWD+IFR-AK-CAZ-SC(4) 3,182.44 70.24 332.52 2,714.35 2,665.35 821.91 -908.84 6,032,523.15 519,724.66 5.45 1,135.14 MWD+IFR-AK-CAZ-SC(4) 3,277.72 75.07 334.34 2,742.75 2,693.75 903.23 -949,49 6,032,604.35 519,683.79 5.39 1,201.15 MWD+IFR-AK-CAZ-SC(4) 3,372.75 78,58 336.64 2,764.41 2,715.41 987.41 -987.85 6,032,688.41 519,645.20 4.38 1,265.99 MWD+IFR-AK-CAZ-SC(4) 3,467.06 81.98 338.97 2,780.33 2,731.33 1,073.46 -1,022.95 6,032,774.36 519,609.87 4.35 1,328.40 MWD+IFR-AK-CAZ-SC(4) 3,562.28 81.65 338.70 2,793.89 2,744.89 1,161.35 -1,056.98 6,032,862.15 519,575.60 0.45 1,390.44 MWD+IFR-AK-CAZ-SC(4) 3,656.27 81.44 337.98 2,807.71 2,758.71 1,247.76 -1,091.29 6,032,948.45 519,541.04 0.79 1,452.24 MWD+IFR-AK-CAZ-SC(4) 3,751.53 81.48 337.36 2,821.85 2,772.85 1,334.89 -1,127.09 6,033,035.48 519,505.02 0.65 1,515.67 MWD+IFR-AK-CAZ-SC(4) 3,845.60 81.48 336.69 2,835.79 2,786.79 1,420.55 -1,163.40 6,033,121.02 519,468.47 0.70 1,579.09 MWD+IFR-AK-CAZ-SC(4) 3,941.30 81.28 337.61 2,850.14 2,801.14 1,507.74 -1,200.14 6,033,208.10 519,431.49 0.97 1,643.44 MWD+IFR-AK-CAZ-SC(4) 3/28/2017 9:53:45AM Page 3 COMPASS 5000.1 Build 74 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Site: Kuparuk 3R Pad MD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Well: 3R-102 North Reference: True Wellbore: 3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,036.63 81.21 337.59 2,864.65 2,815.65 1,594.85 -1,236.04 6,033,295.10 519,395.35 0.08 1,706.97 MWD+IFR-AK-CAZ-SC(4) 4,131.07 81.37 338.38 2,878.95 2,829.95 1,681.39 -1,271.04 6,033,381.54 519,360.12 0.84 1,769.45 MWD+IFR-AK-CAZ-SC(4) 4,226.09 81.48 338.22 2,893.11 2,844.11 1,768.69 -1,305.78 6,033,468.73 519,325.14 0.20 1,831.96 MWD+IFR-AK-CAZ-SC(4) 4,320.22 81.57 339.18 2,906.99 2,857.99 1,855.43 -1,339.60 6,033,555.37 519,291.08 1.01 1,893.40 MWD+IFR-AK-CAZ-SC(4) 4,415.08 81.42 340.00 2,921.02 2,872.02 1,943.36 -1,372.31 6,033,643.20 519,258.12 0.87 1,954.22 MWD+IFR-AK-CAZ-SC(4) 4,510.35 81.34 340.67 2,935.30 2,886.30 2,032.06 -1,404.01 6,033,731.80 519,226.18 0.70 2,014.34 MWD+IFR-AK-CAZ-SC(4) 4,604.35 80.84 341.13 2,949.86 2,900.86 2,119.81 -1,434.40 6,033,819.46 519,195.55 0.72 2,072.91 MWD+IFR-AK-CAZ-SC(4) 4,699.95 80.34 340.51 2,965.49 2,916.49 2,208.89 -1,465.38 6,033,908.44 519,164.33 0.83 2,132.49 MWD+IFR-AK-CAZ-SC(4) 4,794.44 80.46 340.31 2,981.24 2,932.24 2,296.66 -1,496.62 6,033,996.12 519,132.85 0.24 2,191.87 MWD+IFR-AK-CAZ-SC(4) 4,889.65 80.83 339.34 2,996.72 2,947.72 2,384.84 -1,529.02 6,034,084.20 519,100.21 1.08 2,252.47 MWD+IFR-AK-CAZ-SC(4) 4,983.31 80.49 338.90 3,011.92 2,962.92 2,471.19 -1,561.96 6,034,170.45 519,067.03 0.59 2,312.96 MWD+IFR-AK-CAZ-SC(4) 5,077.70 80.53 337.97 3,027.48 2,978.48 2,557.77 -1,596.18 6,034,256.92 519,032.58 0.97 2,374.73 MWD+IFR-AK-CAZ-SC(4) 5,172.82 80.23 337.04 3,043.38 2,994.38 2,644.42 -1,632.06 6,034,343.46 518,996.46 1.01 2,438.08 MWD+IFR-AK-CAZ-SC(4) 5,267.22 80.03 336.06 3,059.56 3,010.56 2,729.74 -1,669.07 6,034,428.67 518,959.22 1.04 2,502.04 MWD+IFR-AK-CAZ-SC(4) 5,362.10 79.88 335.84 3,076.11 3,027.11 2,815.05 -1,707.14 6,034,513.87 518,920.91 0.28 2,566.99 MWD+IFR-AK-CAZ-SC(4) 5,457.08 80.16 335.68 3,092.57 3,043.57 2,900.35 -1,745.55 6,034,599.05 518,882.27 . 0.34 2,632.26 MWD+IFR-AK-CAZ-SC(4) 5,551.85 79.91 335.39 3,108.97 3,059.97 2,985.31 -1,784.20 6,034,683.90 518,843.38 0.40 2,697.64 MWD+IFR-AK-CAZ-SC(4) 5,646.54 79.97 335.85 3,125.51 3,076.51 3,070.23 -1,822.69 6,034,768.70 518,804.67 0.48 2,762.85 MWD+IFR-AK-CAZ-SC(4) 5,741.01 79.94 336.37 3,141.99 3,092.99 3,155.28 -1,860.36 6,034,853.64 518,766.76 0.54 2,827.34 MWD+IFR-AK-CAZ-SC(4) 5,836.02 80.01 337.12 3,158.53 3,109.53 3,241.24 -1,897.30 6,034,939.48 518,729.59 0.78 2,891.45 MWD+IFR-AK-CAZ-SC(4) 5,930.60 79.48 337.27 3,175.37 3,126.37 3,327.03 -1,933.37 6,035,025.17 518,693.28 0.58 2,954.69 MWD+IFR-AK-CAZ-SC(4) 6,024.99 79.20 338.35 3,192.83 3,143.83 3,412.92 -1,968.41 6,035,110.95 518,658.01 1.16 3,016.98 MWD+IFR-AK-CAZ-SC(4) 6,119.39 79.90 338.90 3,209.95 3,160.95 3,499.37 -2,002.24 6,035,197.30 518,623.94 0.94 3,078.35 MWD+IFR-AK-CAZ-SC(4) 6,214.91 80.12 338.63 3,226.52 3,177.52 3,587.05 -2,036.31 6,035,284.88 518,589.63 0.36 3,140.35 MWD+IFR-AK-CAZ-SC(4) 6,309.08 80.58 337.85 3,242.31 3,193.31 3,673.27 -2,070.73 6,035,370.99 518,554.98 0.95 3,202.18 MWD+IFR-AK-CAZ-SC(4) 6,403.68 81.37 337.21 3,257.15 3,208.15 3,759.61 -2,106.44 6,035,457.22 518,519.03 1.07 3,265.27 MWD+IFR-AK-CAZ-SC(4) 6,498.44 81.67 334.31 3,271.12 3,222.12 3,845.06 -2,144.91 6,035,542.56 518,480.32 3.04 3,330.65 MWD+IFR-AK-CAZ-SC(4) 6,593.92 81.06 332.28 3,285.46 3,236.46 3,929.38 -2,187.33 6,035,626.75 518,437.67 2.20 3,399.35 MWD+IFR-AK-CAZ-SC(4) 6,688.48 81.26 328.95 3,299.99 3,250.99 4,010.78 -2,233.17 6,035,708.02 518,391.61 3.49 3,470.27 MWD+IFR-AK-CAZ-SC(4) 6,783.31 82.22 326.73 3,313.62 3,264.62 4,090.22 -2,283.13 6,035,787.31 518,341.45 2.53 3,544.38 MWD+IFR-AK-CAZ-SC(4) 6,834.32 83.15 325.68 3,320.11 3,271.11 4,132.27 -2,311.27 6,035,829.28 518,313.19 2.74 3,585.20 MWD+IFR-AK-CAZ-SC(4) 6,877.51 83.25 324.80 3,325.23 3,276.23 4,167.50 -2,335.72 6,035,864.44 518,288.64 2.04 3,620.23 MWD+IFR-AK-CAZ-SC(4) 6,972.07 83.41 322.66 3,336.21 3,287.21 4,243.22 -2,391.28 6,035,939.99 518,232.88 2.25 3,698.33 MWD+IFR-AK-CAZ-SC(4) 7,017.74 82.78 321.84 3,341.70 3,292.70 4,279.07 -2,419.03 6,035,975.76 518,205.03 2.25 3,736.68 MWD+IFR-AK-CAZ-SC(4) 7,067.39 82.20 320.11 3,348.19 3,299.19 4,317.31 -2,450.03 6,036,013.91 518,173.93 3.65 3,778.88 MWD+IFR-AK-CAZ-SC(4) 7,104.15 81.81 318.29 3,353.31 3,304.31 4,344.86 -2,473.81 6,036,041.40 518,150.07 5.02 3,810.65 MWD+IFR-AK-CAZ-SC(4) 7,160.22 81.84 316.89 3,361.28 3,312.28 4,385.84 -2,511.24 6,036,082.26 518,112.53 2.47 3,859.84 MWD+IFR-AK-CAZ-SC(4) 7,208.88 81.39 314.39 3,368.38 3,319.38 4,420.25 -2,544.90 6,036,116.58 518,078.79 5.17 3,903.24 MWD+IFR-AK-CAZ-SC(4) 7,256.01 80.40 312.46 3,375.84 3,326.84 4,452.24 -2,578.69 6,036,148.47 518,044.91 4.56 3,945.93 MWD+IFR-AK-CAZ-SC(4) 7,304.32 79.61 310.09 3,384.22 3,335.22 4,483.63 -2,614.44 6,036,179.75 518,009.07 5.10 3,990.26 MWD+IFR-AK-CAZ-SC(4) 3/28/2017 9:53:45AM Page 4 COMPASS 5000.1 Build 74 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Site: Kuparuk 3R Pad MD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Well: 3R-102 North Reference: True Wellbore: 3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100) (ft) Survey Tool Name 7,350.36 79.13 307.93 3,392.72 3,343.72 4,512.11 -2,649.60 6,036,208.14 517,973.84 4.73 4,033.04 MWD+IFR-AK-CAZ-SC(4) 7,399.84 79.41 304.55 3,401.93 3,352.93 4,540.84 -2,688.81 6,036,236.76 517,934.56 6.74 4,079.71 MWD+IFR-AK-CAZ-SC(4) 7,445.17 79.82 301.49 3,410.10 3,361.10 4,565.14 -2,726.19 6,036,260.95 517,897.11 6.70 4,123.15 MWD+IFR-AK-CAZ-SC(4) 7,496.96 80.51 299.41 3,418.95 3,369.95 4,590.99 -2,770.18 6,036,286.68 517,853.06 4.18 4,173.33 MWD+IFR-AK-CAZ-SC(4) 7,539.35 81.33 299.56 3,425.64 3,376.64 4,611.60 -2,806.61 6,036,307.18 517,816.57 1.97 4,214.61 MWD+IFR-AK-CAZ-SC(4) 7,634.94 81.68 297.10 3,439.76 3,390.76 4,656.46 -2,889.82 6,036,351.80 517,733.24 2.57 4,308.15 MWD+IFR-AK-CAZ-SC(4) 7,730.93 82.36 294.45 3,453.09 3,404.09 4,697.79 -2,975.42 6,036,392.89 517,647.54 2.82 4,402.72 MWD+IFR-AK-CAZ-SC(4) 7,824.08 82.41 291.59 3,465.44 3,416.44 4,733.89 -3,060.39 6,036,428.75 517,562.48 3.04 4,494.91 MWD+IFR-AK-CAZ-SC(4) 7,919.11 82.13 286.29 3,478.23 3,429.23 4,764.44 -3,149.42 6,036,459.06 517,473.37 5.53 4,589.02 MWD+IFR-AK-CAZ-SC(4) 8,012.75 82.45 282.19 3,490.80 3,441.80 4,787.26 -3,239.34 6,036,481.62 517,383.39 4.35 4,681.33 MWD+IFR-AK-CAZ-SC(4) 8,065.51 .82.91 280.19 3,497.52 3,448.52 4,797.42 -3,290.68 6,036,491.64 517,332.04 3.86 4,733.04 MWD+IFR-AK-CAZ-SC(4) 8,107.62 83.00 278.75 3,502.68 3,453.68 4,804.29 -3,331.90 6,036,498.40 517,290.80 3.40 4,774.12 MWD+IFR-AK-CAZ-SC(4) 8,202.76 82.37 274.13 3,514.80 3,465.80 4,814.88 -3,425.64 6,036,508.72 517,197.04 4.86 4,865.83 MWD+IFR-AK-CAZ-SC(4) 8,297.70 81.86 269.64 3,527.84 3,478.84 4,817.97 -3,519.61 6,036,511.55 517,103.07 4.72 4,955.19 MWD+IFR-AK-CAZ-SC(4) 8,392.36 82.74 265.38 3,540.52 3,491.52 4,813.89 -3,613.30 6,036,507.21 517,009.40 4.56 5,041.84 MWD+IFR-AK-CAZ-SC(4) 8,487.18 83.77 265.54 3,551.66 3,502.66 4,806.44 -3,707.17 6,036,499.50 516,915.56 1.10 5,127.50 MWD+IFR-AK-CAZ-SC(4) 8,541.76 83.79 265.37 3,557.57 3,508.57 4,802.14 -3,761.26 6,036,495.05 516,861.49 0.31 5,176.85 MWD+IFR-AK-CAZ-SC(4) 8.594.00 83.72 264.36 3,563.26 3,514.26 4,797.49 -3,812.98 6,036,490.26 516,809.79 1.92 5,223.87 NOT an Actual Survey 7 5/8"x 9 7/8 8,638.78 83.66 263.50 3,568.18 3,519.18 4,792.79 -3,857.24 6,036,485.43 516,765.55 1.92 5,263.85 MWD+IFR-AK-CAZ-SC(5) 8,671.52 84.90 262.76 3,571.44 3,522.44 4,788.89 -3,889.58 6,036,481.45 516,733.22 4.40 5,292.91 MWD+IFR-AK-CAZ-SC(5) 8,703.61 86.14 264.28 3,573.95 3,524.95 4,785.28 -3,921.36 6,036,477.75 516,701.45 6.10 5,321.54 MWD+IFR-AK-CAZ-SC(5) 8,733.13 87.10 265.71 3,575.69 3,526.69 4,782.71 -3,950.72 6,036,475.10 516,672.10 5.83 5,348.25 MWD+IFR-AK-CAZ-SC(5) 8,765.80 87.73 266.95 3,577.16 3,528.16 4,780.62 -3,983.29 6,036,472.92 516,639.54 4.25 5,378.14 MWD+IFR-AK-CAZ-SC(5) 8,797.18 87.82 267.13 3,578.38 3,529.38 4,779.00 -4,014.60 6,036,471.21 516,608.23 0.64 5,407.01 MWD+IFR-AK-CAZ-SC(5) 8,828.00 88.09 269.81 3,579.48 3,530.48 4,778.18 -4,045.39 6,036,470.31 516,577.45 8.73 5,435.66 MWD+IFR-AK-CAZ-SC(5) 8,924.07 88.04 270.16 3,582.73 3,533.73 4,778.16 -4,141.41 6,036,470.01 516,481.45 0.37 5,525.87 MWD+IFR-AK-CAZ-SC(5) 9,018.79 89.82 269.32 3,584.49 3,535.49 4,777.73 -4,236.10 6,036,469.32 516,386.76 2.08 5,614.71 MWD+IFR-AK-CAZ-SC(5) 9,113.14 90.05 268.69 3,584.60 3,535.60 4,776.09 -4,330.44 6,036,467.42 516,292.44 0.71 5,702.80 MWD+IFR-AK-CAZ-SC(5) 9,208.72 89.95 267.85 3,584.60 3,535.60 4,773.20 -4,425.97 6,036,464.27 516,196.92 0.89 5,791.59 MWD+IFR-AK-CAZ-SC(5) 9,303.05 90.12 270.04 3,584.54 3,535.54 4,771.46 -4,520.28 6,036,462.27 516,102.63 2.33 5,879.61 MWD+IFR-AK-CAZ-SC(5) 9,397.06 91.08 272.78 3,583.56 3,534.56 4,773.78 -4,614.25 6,036,464.32 516,008.67 3.09 5,968.70 MWD+IFR-AK-CAZ-SC(5) 9,490.90 91.22 275.30 3,581.68 3,532.68 4,780.39 -4,707.83 6,036,470.67 515,915.08 2.69 6,058.90 MWD+IFR-AK-CAZ-SC(5) 9,584.52 91.24 274.35 3,579.67 3,530.67 4,788.26 -4,801.09 6,036,478.29 515,821.80 1.01 6,149.23 MWD+IFR-AK-CAZ-SC(5) 9,681.00 92.62 272.67 3,576.42 3,527.42 4,794.16 -4,897.33 6,036,483.92 515,725.55 2.25 6,241.69 MWD+IFR-AK-CAZ-SC(5) 9,773.86 93.38 267.36 3,571.55 3,522.55 4,794.19 -4,990.03 6,036,483.69 515,632.87 5.77 6,328.81 MWD+IFR-AK-CAZ-SC(5) 9,869.63 93.48 266.30 3,565.82 3,516.82 4,788.90 -5,085.48 6,036,478.14 515,537.44 1.11 6,416.69 MWD+IFR-AK-CAZ-SC(5) 9,965.16 93.65 265.40 3,559.88 3,510.88 4,782.00 -5,180.58 6,036,470.98 515,442.37 0.96 6,503.69 MWD+IFR-AK-CAZ-SC(5) 10,058.11 93.03 266.21 3,554.47 3,505.47 4,775.22 -5,273.12 6,036,463.93 515,349.86 1.10 6,588.33 MWD+IFR-AK-CAZ-SC(5) 10,154.55 91.08 266.50 3,551.01 3,502.01 4,769.09 -5,369.30 6,036,457.54 515,253.71 2.04 6,676.61 MWD+IFR-AK-CAZ-SC(5) 3/28/2017 9:53:45AM Page 5 COMPASS 5000.1 Build 74 III • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Site: Kuparuk 3R Pad MD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Well: 3R-102 North Reference: True Wellbore: 3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 10.248.93 88.57 265.92 3,551.30 3,502.30 4,762.85 -5,463.46 6,036,451.04 515,159.57 2.73 6,762.97 MWD+IFR-AK-CAZ-SC(5) 10,342.27 86.74 265.64 3,555.12 3,506.12 4,755.99 -5,556.47 6,036,443.92 515,066.59 1.98 6,848.02 MWD+IFR-AK-CAZ-SC(5) 10,437.85 90.02 266.75 3,557.82 3,508.82 4,749.65 -5,651.78 6,036,437.32 514,971.30 3.62 6,935.42 MWD+IFR-AK-CAZ-SC(5) 10,533.00 89.08 266.56 3,558.57 3,509.57 4,744.10 -5,746.77 6,036,431.50 514,876.35 1.01 7,022.77 MWD+IFR-AK-CAZ-SC(5) 10,627.38 89.33 269.07 3,559.87 3,510.87 4,740.50 -5,841.06 6,036,427.65 514,782.07 2.67 7,110.15 MWD+IFR-AK-CAZ-SC(5) 10,720.67 89.47 271.40 3,560.85 3,511.85 4,740.88 -5,934.34 6,036,427.77 514,688.80 2.50 7,197.93 MWD+IFR-AK-CAZ-SC(5) 10,816.39 89.47 271.47 3,561.74 3,512.74 4,743.28 -6,030.03 6,036,429.90 514,593.12 0.07 7,288.67 MWD+IFR-AK-CAZ-SC(5) 10,911.11 88.80 271.14 3,563.17 3,514.17 4,745.44 -6,124.71 6,036,431.79 514,498.44 0.79 7,378.38 MWD+IFR-AK-CAZ-SC(5) 11,006.68 89.79 270.27 3,564.34 3,515.34 4,746.61 -6,220.26 6,036,432.70 514,402.89 1.38 7,468.57 MWD+IFR-AK-CAZ-SC(5) 11,099.59 92.28 270.83 3,562.67 3,513.67 4,747.50 -6,313.15 6,036,433.34 514,310.02 2.75 7,556.16 MWD+IFR-AK-CAZ-SC(5) 11,193.48 91.15 272.58 3,559.86 3,510.86 4,750.30 -6,406.95 6,036,435.87 514,216.22 2.22 7,645.26 MWD+IFR-AK-CAZ-SC(5) 11,289.46 89.40 271.78 3,559.39 3,510.39 4,753.95 -6,502.85 6,036,439.25 514,120.31 2.00 7,736.63 MWD+IFR-AK-CAZ-SC(5) 11,384.81 88.29 272.77 3,561.32 3,512.32 4,757.73 -6,598.11 6,036,442.77 514,025.06 1.56 7,827.43 MWD+IFR-AK-CAZ-SC(5) 11,478.98 88.32 272.54 3,564.10 3,515.10 4,762.09 -6,692.13 6,036,446.87 513,931.03 0.25 7,917.28 MWD+IFR-AK-CAZ-SC(5) 11,573.63 89.57 272.42 3,565.84 3,516.84 4,766.19 -6,786.68 6,036,450.70 513,836.48 1.33 8,007.52 MWD+IFR-AK-CAZ-SC(5) 11,669.26 90.14 271.75 3,566.09 3,517.09 4,769.67 -6,882.24 6,036,453.92 513,740.92 0.92 8,098.51 MWD+IFR-AK-CAZ-SC(5) 11,763.98 92.00 269.81 3,564.32 3,515.32 4,770.96 -6,976.93 6,036,454.94 513,646.24 2.84 8,187.93 MWD+IFR-AK-CAZ-SC(5) 11,857.55 92.52 268.51 3,560.63 3,511.63 4,769.58 -7,070.41 6,036,453.31 513,552.77 1.50 8,275.31 MWD+IFR-AK-CAZ-SC(5) 11,953.14 93.10 268.11 3,555.94 3,506.94 4,766.77 -7,165.85 6,036,450.23 513,457.35 0.74 8,364.02 MWD+IFR-AK-CAZ-SC(5) 12,048.52 92.43 268.67 3,551.34 3,502.34 4,764.09 -7,261.08 6,036,447.29 513,362.14 0.92 8,452.60 MWD+IFR-AK-CAZ-SC(5) 12,142.97 89.65 268.19 3,549.63 3,500.63 4,761.51 -7,355.47 6,036,444.44 513,267.77 2.99 8,540.41 MWD+IFR-AK-CAZ-SC(5) 12,237.59 89.67 267.91 3,550.19 3,501.19 4,758.29 -7,450.03 6,036,440.96 513,173.22 0.30 8,628.17 MWD+IFR-AK-CAZ-SC(5) 12,332.05 89.74 268.48 3,550.67 3,501.67 4,755.31 -7,544.44 6,036,437.73 513,078.83 0.61 8,715.87 MWD+IFR-AK-CAZ-SC(5) 12,426.14 89.62 268.02 3,551.20 3,502.20 4,752.44 -7,638.48 6,036,434.59 512,984.80 0.51 8,803.26 MWD+IFR-AK-CAZ-SC(5) 12,518.51 91.69 267.95 3,550.14 3,501.14 4,749.19 -7,730.79 6,036,431.09 512,892.52 2.24 8,888.88 MWD+IFR-AK-CAZ-SC(5) 12,582.00 90.99 268.34 3,548.66 3,499.66 4,747.13 -7,794.23 6,036,428.85 512,829.09 1.26 8,947.79 NOT an Actual Survey 4 1/2"x 6 3/4" 12,608.99 90.69 268.50 3,548.26 3,499.26 4,746.39 -7,821.20 6,036,428.04 512,802.12 1.26 8,972.89 MWD+IFR-AK-CAZ-SC(5) 12,701.93 91.20 267.69 3,546.73 3,497.73 4,743.30 -7,914.08 6,036,424.69 512,709.26 1.03 9,059.10 MWD+IFR-AK-CAZ-SC(5) 12,796.93 93.31 266.71 3,542.99 3,493.99 4,738.66 -8,008.88 6,036,419.79 512,614.48 2.45 9,146.61 MWD+IFR-AK-CAZ-SC(5) 12,890.26 95.83 264.32 3,535.56 3,486.56 4,731.39 -8,101.62 6,036,412.26 512,521.77 3.72 9,231.26 MWD+IFR-AK-CAZ-SC(5) 12,982.92 96.10 263.20 3,525.93 3,476.93 4,721.38 -8,193.23 6,036,401.99 512,430.20 1.24 9,313.92 MWD+IFR-AK-CAZ-SC(5) 13,071.76 96.03 262.96 3,516.54 3,467.54 4,710.73 -8,280.93 6,036,391.11 512,342.54 0.28 9,392.69 MWD+IFR-AK-CAZ-SC(5) 13,164.19 96.09 261.85 3,506.78 3,457.78 4,698.58 -8,372.03 6,036,378.71 512,251.48 1.20 9,474.15 MWD+IFR-AK-CAZ-SC(5) 13,257.05 96.10 259.00 3,496.92 3,447.92 4,683.23 -8,463.07 6,036,363.10 512,160.49 3.05 9,554.44 MWD+IFR-AK-CAZ-SC(5) 13,349.20 96.20 256.03 3,487.05 3,438.05 4,663.42 -8,552.52 6,036,343.05 512,071.11 3.21 9,631.72 MWD+IFR-AK-CAZ-SC(5) 13,441.20 96.13 254.45 3,477.17 3,428.17 4,640.12 -8,640.96 6,036,319.50 511,982.74 1.71 9,706.86 MWD+IFR-AK-CAZ-SC(5) 13,533.72 96.13 252.93 3,467.29 3,418.29 4,614.29 -8,729.25 6,036,293.43 511,894.53 1.63 9,780.99 MWD+IFR-AK-CAZ-SC(5) 13,624.70 96.13 249.42 3,457.57 3,408.57 4,585.10 -8,814.86 6,036,264.01 511,809.02 3.84 9,851.45 MWD+IFR-AK-CAZ-SC(5) 13,715.41 96.00 247.11 3,447.98 3,398.98 4,551.70 -8,898.64 6,036,230.38 511,725.33 2.54 9,918.76 MWD+IFR-AK-CAZ-SC(5) 3/28/2017 9:53:45AM Page 6 COMPASS 5000 1 Build 74 0 i Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Site: Kuparuk 3R Pad MD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Well: 3R-102 North Reference: True Wellbore: 3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/10(Y) (ft) Survey Tool Name 13,808.53 96.27 246.29 3,438.03 3,389.03 4,515.08 -8,983.67 6,036,193.52 511,640.41 0.92 9,986.14 MWD+IFR-AK-CAZ-SC(5) 13,900.76 96.17 245.73 3,428.04 3,379.04 4,477.80 -9,067.44 6,036,156.02 511,556.76 0.61 10,052.11 MWD+IFR-AK-CAZ-SC(5) 13,993.20 95.61 247.20 3,418.55 3,369.55 4,441.09 -9,151.74 6,036,119.07 511,472.57 1.69 10,118.76 MWD+IFR-AK-CAZ-SC(5) 14,085.29 91.50 247.79 3,412.84 3,363.84 4,405.91 -9,236.64 6,036,083.67 511,387.78 4.51 10,186.51 MWD+IFR-AK-CAZ-SC(5) 14,176.85 89.79 246.05 3,411.81 3,362.81 4,370.02 -9,320.86 6,036,047.55 511,303.67 2.66 10,253.38 MWD+IFR-AK-CAZ-SC(5) 14,269.99 89.87 244.97 3,412.09 3,363.09 4,331.42 -9,405.62 6,036,008.71 511,219.02 1.16 10,319.82 MWD+IFR-AK-CAZ-SC(5) 14,361.44 90.84 244.72 3,411.52 3,362.52 4,292.54 -9,488.39 6,035,969.61 511,136.36 1.10 10,384.31 MWD+IFR-AK-CAZ-SC(5) 14,453.76 92.68 246.48 3,408.69 3,359.69 4,254.43 -9,572.42 6,035,931.26 511,052.45 2.76 10,450.23 MWD+IFR-AK-CAZ-SC(5) 14,545.65 92.18 248.52 3,404.79 3,355.79 4,219.30 -9,657.23 6,035,895.90 510,967.74 2.28 10,517.91 MWD+IFR-AK-CAZ-SC(5) 14,635.90 92.38 247.74 3,401.20 3,352.20 4,185.71 -9,740.92 6,035,862.08 510,884.16 0.89 10,585.07 MWD+IFR-AK-CAZ-SC(5) 14,729.03 93.00 248.92 3,396.83 3,347.83 4,151.35 -9,827.37 6,035,827.49 510,797.81 1.43 10,654.55 MWD+IFR-AK-CAZ-SC(5) 14,820.59 92.90 249.47 3,392.12 3,343.12 4,118.88 -9,912.85 6,035,794.78 510,712.43 0.61 10,723.77 MWD+IFR-AK-CAZ-SC(5) 14,890.02 92.86 252.82 3,388.63 3,339.63 4,096.47 -9,978.46 6,035,772.20 510,646.89 4.82 10,777.76 MWD+IFR-AK-CAZ-SC(5) 14,950.00 92.86 252.82 3,385.63 3,336.63 4,078.78 -10,035.69 6,035,754.34 510,589.71 0.00 10,825.49 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets arxllor well position objectives have been achieved.l Yat . ) No I have checked to the best of my ability that the following data Is correct: j Surface Coordinates C Declination & Convergence GRS Survey Corrections 71 Survey Tool Codes �, o� SLB DE: L 152 Landon Temple r BSL'm 3/2.8//7 atrtimmircre Client Representative: Kelsey Hallford Kelsey Hallford a'».�;`.-:;n'° 't"' Date: 3128/17 3/28/2017 9:53:45AM Page 7 COMPASS 5000.1 Build 74 • • 216157 28 126 RECEIVED APR 1 1 2017 AOGCC FINAL ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3R Pad 3R-102 NAD 83 Definitive Survey Report 28 March, 2017 • • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Site: Kuparuk 3R Pad MD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Well: 3R-102 North Reference: True Wellbore: 3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102 Database: OAKE DM P2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well 3R-102 Well Position +N/-S 0.00 usft Northing: 6,031,455.90 usft Latitude: 70°29'50.952 N +E/-W 0.00 usft Easting: 1,660,667.09 usft Longitude: 149°50'3.816 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 9.90 usft Wellbore 3R-102 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2016 2/25/2017 17.78 81.04 57,552 Design 3R-102 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.10 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 39.10 0.00 0.00 290.00 Survey Program Date 3/27/2017 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 48.00 743.00 3R-102 Srvy 1-SLB_NSG+SSHOT(3R- GYD-GC-SS Gyrodata gyro single shots 2/28/2017 8:58: 766.58 2,215.65 3R-102 Srvy 2-SLB_MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/28/2017 9:06: 2,259.63 2,259.63 3R-102 Srvy 3-SLB_INC+Filler(3R-102 INC+TREND Inclinometer+known azi trend 3/9/2017 2:29:0 2,328.59 8,541.76 3R-102 Srvy 4-SLB_MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/5/2017 10:09:2 8,638.78 14,890.02 3R-102 Srvy 5-SLB_MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/13/2017 3:20: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 39.10 0.00 0.00 39.10 -9.90 0.00 0.00 6,031,455.90 1,660,667.09 0.00 0.00 UNDEFINED 48.00 0.24 109.51 48.00 -1.00 -0.01 0.02 6,031,455.90 1,660,667.11 2.70 -0.02 GYD-GC-SS(1) 88.00 0.28 92.52 88.00 39.00 -0.04 0.19 6,031,455.87 1,660,667.28 0.22 -0.20 GYD-GC-SS(1) 115.00 0.30 96.07 115.00 66.00 -0.05 0.33 6,031,455.86 1,660,667.42 0.09 -0.33 NOT an Actual Survey 20"x 24" 185.00 0.35 103.46 185.00 136.00 -0.12 0.72 6,031,455.79 1,660,667.81 0.09 -0.72 GYD-GC-SS(1) 278.00 0.20 171.69 278.00 229.00 -0.34 1.02 6,031,455.56 1,660,668.11 0.36 -1.08 GYD-GC-SS(1) 369.00 1.46 267.60 368.99 319.99 -0.55 -0.12 6,031,455.35 1,660,666.97 1.64 -0.08 GYD-GC-SS(1) 393.00 1.74 268.51 392.98 343.98 -0.57 -0.79 6,031,455.33 1,660,666.30 1.17 0.54 GYD-GC-SS(1) 486.00 3.42 271.16 485.88 436.88 -0.55 -4.97 6,031,455.34 1,660,662.12 1.81 4.48 GYD-GC-SS(1) 579.00 4.97 277.90 578.63 529.63 0.06 -11.74 6,031,455.93 1,660,655.36 1.75 11.05 GYD-GC-SS(1) 3/28/2017 8:08:34AM Page 2 COMPASS 5000.1 Build 74 . • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Site: Kuparuk 3R Pad MD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Well: 3R-102 North Reference: True Wellbore: 3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 671.00 7.55 284.91 670.07 621.07 2.16 -21.53 6,031,458.01 1,660,645.56 2.92 20.97 GYD-GC-SS(1) 743.00 9.62 287.07 741.26 692.26 5.14 -31.85 6,031,460.96 1,660,635.23 2.91 31.69 GYD-GC-SS(1) 766.58 10.24 288.31 764.49 715.49 6.38 -35.72 6,031,462.19 1,660,631.35 2.78 35.75 MWD+IFR-AK-CAZ-SC(2) 861.59 11.22 289.99 857.84 808.84 12.19 -52.43 6,031,467.95 1,660,614.64 1.08 53.43 MWD+IFR-AK-CAZ-SC(2) 957.11 11.09 291.85 951.55 902.55 18.79 -69.69 6,031,474.50 1,660,597.36 0.40 71.91 MWD+IFR-AK-CAZ-SC(2) 1,051.84 12.51 291.92 1,044.28 995.28 26.01 -87.66 6,031,481.67 1,660,579.37 1.50 91.27 MWD+IFR-AK-CAZ-SC(2) 1,145.75 17.49 291.29 1,134.96 1,085.96 34.94 -110.26 6,031,490.54 1,660,556.75 5.31 115.56 MWD+IFR-AK-CAZ-SC(2) 1,241.18 18.15 291.47 1,225.81 1,176.81 45.58 -137.45 6,031,501.11 1,660,529.53 0.69 144.75 MWD+IFR-AK-CAZ-SC(2) 1,336.00 17.88 292.20 1,315.98 1,266.98 56.49 -164.67 6,031,511.94 1,660,502.28 0.37 174.06 MWD+IFR-AK-CAZ-SC(2) 1,429.78 17.41 291.84 1,405.35 1,356.35 67.15 -191.03 6,031,522.53 1,660,475.90 0.51 202.47 MWD+IFR-AK-CAZ-SC(2) 1,525.57 16.21 292.49 1,497.05 1,448.05 77.59 -216.68 6,031,532.90 1,660,450.22 1.27 230.15 MWD+IFR-AK-CAZ-SC(2) 1,619.63 18.31 294.96 1,586.87 1,537.87 88.85 -242.21 6,031,544.09 1,660,424.66 2.36 257.99 MWD+IFR-AK-CAZ-SC(2) 1,714.79 18.75 295.27 1,677.09 1,628.09 101.69 -269.59 6,031,556.85 1,660,397.25 0.47 288.11 MWD+IFR-AK-CAZ-SC(2) 1,809.56 23.39 297.30 1,765.50 1,716.50 116.83 -300.10 6,031,571.90 1,660,366.70 4.96 321.96 MWD+IFR-AK-CAZ-SC(2) 1,903.92 26.23 299.98 1,851.15 1,802.15 135.84 -334.81 6,031,590.82 1,660,331.94 3.24 361.08 MWD+IFR-AK-CAZ-SC(2) 1,998.35 31.13 304.42 1,933.98 1,884.98 160.08 -373.05 6,031,614.96 1,660,293.64 5.66 405.31 MWD+IFR-AK-CAZ-SC(2) 2,093.16 34.11 305.46 2,013.83 1,964.83 189.37 -414.93 6,031,644.12 1,660,251.68 3.20 454.68 MWD+IFR-AK-CAZ-SC(2) 2,188.51 37.42 306.80 2,091.18 2,042.18 222.24 -459.92 6,031,676.87 1,660,206.61 3.57 508.19 MWD+IFR-AK-CAZ-SC(2) 2,215.65 39.83 307.03 2,112.39 2,063.39 232.42 -473.46 6,031,687.01 1,660,193.04 8.90 524.40 MWD+IFR-AK-CAZ-SC(2) 2,259.63 40.99 307.51 2,145.87 2,096.87 249.68 -496.15 6,031,704.21 1,660,170.31 2.73 551.63 INC+TREND(3) 2,291.00 41.11 307.84 2,169.53 2,120.53 262.27 -512.46 6,031,716.75 1,660,153.97 0.80 571.25 NOT an Actual Survey 10 3/4"x 13 1/2" 2,328.59 41.26 308.24 2,197.82 2,148.82 277.53 -531.95 6,031,731.95 1,660,134.44 0.80 594.79 MWD+IFR-AK-CAZ-SC(4) 2,423.80 42.44 312.17 2,268.75 2,219.75 318.53 -580.43 6,031,772.82 1,660,085.85 3.02 654.37 MWD+IFR-AK-CAZ-SC(4) 2,519.56 43.80 317.78 2,338.67 2,289.67 364.79 -626.66 6,031,818.95 1,660,039.50 4.25 713.64 MWD+IFR-AK-CAZ-SC(4) 2,615.24 44.72 323.22 2,407.22 2,358.22 416.29 -669.09 6,031,870.33 1,659,996.94 4.08 771.11 MWD+IFR-AK-CAZ-SC(4) 2,709.20 48.84 326.03 2,471.56 2,422.56 472.13 -708.66 6,031,926.05 1,659,957.21 4.90 827.40 MWD+IFR-AK-CAZ-SC(4) 2,803.34 52.75 328.78 2,531.06 2,482.06 533.59 -747.90 6,031,987.40 1,659,917.81 4.73 885.30 MWD+IFR-AK-CAZ-SC(4) 2,898.93 57.01 330.25 2,586.04 2,537.04 600.97 -787.54 6,032,054.66 1,659,878.00 4.63 945.59 MWD+IFR-AK-CAZ-SC(4) 2,993.29 60.25 330.81 2,635.16 2,586.16 671.10 -827.16 6,032,124.68 1,659,838.18 3.47 1,006.81 MWD+IFR-AK-CAZ-SC(4) 3,088.91 65.24 331.43 2,678.93 2,629.93 745.52 -868.19 6,032,198.98 1,659,796.95 5.25 1,070.82 MWD+IFR-AK-CAZ-SC(4) 3,182.44 70.24 332.52 2,714.35 2,665.35 821.91 -908.84 6,032,275.25 1,659,756.11 5.45 1,135.14 MWD+IFR-AK-CAZ-SC(4) 3,277.72 75.07 334.34 2,742.75 2,693.75 903.23 -949.49 6,032,356.45 1,659,715.24 5.39 1,201.15 MWD+IFR-AK-CAZ-SC(4) 3,372.75 78.58 336.64 2,764.41 2,715.41 987.41 -987.85 6,032,440.52 1,659,676.65 4.38 1,265.99 MWD+IFR-AK-CAZ-SC(4) 3,467.06 81.98 338.97 2,780.33 2,731.33 1,073.46 -1,022.95 6,032,526.47 1,659,641.32 4.35 1,328.40 MWD+IFR-AK-CAZ-SC(4) 3,562.28 81.65 338.70 2,793.89 2,744.89 1,161.35 -1,056.98 6,032,614.26 1,659,607.05 0.45 1,390.44 MWD+IFR-AK-CAZ-SC(4) 3,656.27 81.44 337.98 2,807.71 2,758.71 1,247.76 -1,091.29 6,032,700.56 1,659,572.51 0.79 1,452.24 MWD+IFR-AK-CAZ-SC(4) 3,751.53 81.48 337.36 2,821.85 2,772.85 1,334.89 -1,127.09 6,032,787.59 1,659,536.48 0.65 1,515.67 MWD+IFR-AK-CAZ-SC(4) 3,845.60 81.48 336.69 2,835.79 2,786.79 1,420.55 -1,163.40 6,032,873.13 1,659,499.94 0.70 1,579.09 MWD+IFR-AK-CAZ-SC(4) 3,941.30 81.28 337.61 2,850.14 2,801.14 1,507.74 -1,200.14 6,032,960.22 1,659,462.97 0.97 1,643.44 MWD+IFR-AK-CAZ-SC(4) 3/28/2017 8:08:34AM Page 3 COMPASS 5000.1 Build 74 411) • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Site: Kuparuk 3R Pad MD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Well: 3R-102 North Reference: True Wellbore: 3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102 Database: OAKE DM P2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,036.63 81.21 337.59 2,864.65 2,815.65 1,594.85 -1,236.04 6,033,047.22 1,659,426.83 0.08 1,706.97 MWD+IFR-AK-CAZ-SC(4) 4,131.07 81.37 338.38 2,878.95 2,829.95 1,681.39 -1,271.04 6,033,133.66 1,659,391.60 0.84 1,769.45 MWD+IFR-AK-CAZ-SC(4) 4,226.09 81.48 338.22 2,893.11 2,844.11 1,768.69 -1,305.78 6,033,220.86 1,659,356.63 0.20 1,831.96 MWD+IFR-AK-CAZ-SC(4) 4,320.22 81.57 339.18 2,906.99 2,857.99 1,855.43 -1,339.60 6,033,307.50 1,659,322.58 1.01 1,893.40 MWD+IFR-AK-CAZ-SC(4) 4,415.08 81.42 340.00 2,921.02 2,872.02 1,943.36 -1,372.31 6,033,395.32 1,659,289.62 0.87 1,954.22 MWD+IFR-AK-CAZ-SC(4) 4,510.35 81.34 340.67 2,935.30 2,886.30 2,032.06 -1,404.01 6,033,483.93 1,659,257.69 0.70 2,014.34 MWD+IFR-AK-CAZ-SC(4) 4,604.35 80.84 341.13 2,949.86 2,900.86 2,119.81 -1,434.40 6,033,571.59 1,659,227.06 0.72 2,072.91 MWD+IFR-AK-CAZ-SC(4) 4,699.95 80.34 340.51 2,965.49 2,916.49 2,208.89 -1,465.38 6,033,660.57 1,659,195.84 0.83 2,132.49 MWD+IFR-AK-CAZ-SC(4) 4,794.44 80.46 340.31 2,981.24 2,932.24 2,296.66 -1,496.62 6,033,748.25 1,659,164.37 0.24 2,191.87 MWD+IFR-AK-CAZ-SC(4) 4,889.65 80.83 339.34 2,996.72 2,947.72 2,384.84 -1,529.02 6,033,836.33 1,659,131.73 1.08 2,252.47 MWD+IFR-AK-CAZ-SC(4) 4,983.31 80.49 338.90 3,011.92 2,962.92 2,471.19 -1,561.96 6,033,922.58 1,659,098.56 0.59 2,312.96 MWD+IFR-AK-CAZ-SC(4) 5,077.70 80.53 337.97 3,027.48 2,978.48 2,557.77 -1,596.18 6,034,009.06 1,659,064.11 0.97 2,374.73 MWD+IFR-AK-CAZ-SC(4) 5,172.82 80.23 337.04 3,043.38 2,994.38 2,644.42 -1,632.06 6,034,095.60 1,659,027.99 1.01 2,438.08 MWD+IFR-AK-CAZ-SC(4) 5,267.22 80.03 336.06 3,059.56 3,010.56 2,729.74 -1,669.07 6,034,180.81 1,658,990.76 1.04 2,502.04 MWD+IFR-AK-CAZ-SC(4) 5,362.10 79.88 335.84 3,076.11 3,027.11 2,815.05 -1,707.14 6,034,266.01 1,658,952.45 0.28 2,566.99 MWD+IFR-AK-CAZ-SC(4) 5,457.08 80.16 335.68 3,092.57 3,043.57 2,900.35 -1,745.55 6,034,351.20 1,658,913.82 0.34 2,632.26 MWD+IFR-AK-CAZ-SC(4) 5,551.85 79.91 335.39 3,108.97 3,059.97 2,985.31 -1,784.20 6,034,436.04 1,658,874.94 0.40 2,697.64 MWD+IFR-AK-CAZ-SC(4) 5,646.54 79.97 335.85 3,125.51 3,076.51 3,070.23 -1,822.69 6,034,520.85 1,658,836.22 0.48 2,762.85 MWD+IFR-AK-CAZ-SC(4) 5,741.01 79.94 336.37 3,141.99 3,092.99 3,155.28 -1,860.36 6,034,605.79 1,658,798.32 0.54 2,827.34 MWD+IFR-AK-CAZ-SC(4) 5,836.02 80.01 337.12 3,158.53 3,109.53 3,241.24 -1,897.30 6,034,691.64 1,658,761.16 0.78 2,891.45 MWD+IFR-AK-CAZ-SC(4) 5,930.60 79.48 337.27 3,175.37 3,126.37 3,327.03 -1,933.37 6,034,777.32 1,658,724.85 0.58 2,954.69 MWD+IFR-AK-CAZ-SC(4) 6,024.99 79.20 338.35 3,192.83 3,143.83 3,412.92 -1,968.41 6,034,863.11 1,658,689.59 1.16 3,016.98 MWD+IFR-AK-CAZ-SC(4) 6,119.39 79.90 338.90 3,209.95 3,160.95 3,499.37 -2,002.24 6,034,949.46 1,658,655.52 0.94 3,078.35 MWD+IFR-AK-CAZ-SC(4) 6,214.91 80.12 338.63 3,226.52 3,177.52 3,587.05 -2,036.31 6,035,037.04 1,658,621.21 0.36 3,140.35 MWD+IFR-AK-CAZ-SC(4) 6,309.08 80.58 337.85 3,242.31 3,193.31 3,673.27 -2,070.73 6,035,123.16 1,658,586.57 0.95 3,202.18 MWD+IFR-AK-CAZ-SC(4) 6,403.68 81.37 337.21 3,257.15 3,208.15 3,759.61 -2,106.44 6,035,209.38 1,658,550.63 1.07 3,265.27 MWD+IFR-AK-CAZ-SC(4) 6,498.44 81.67 334.31 3,271.12 3,222.12 3,845.06 -2,144.91 6,035,294.72 1,658,511.92 3.04 3,330.65 MWD+IFR-AK-CAZ-SC(4) 6,593.92 81.06 332.28 3,285.46 3,236.46 3,929.38 -2,187.33 6,035,378.92 1,658,469.28 2.20 3,399.35 MWD+IFR-AK-CAZ-SC(4) 6,688.48 81.26 328.95 3,299.99 3,250.99 4,010.78 -2,233.17 6,035,460.19 1,658,423.22 3.49 3,470.27 MWD+IFR-AK-CAZ-SC(4) 6,783.31 82.22 326.73 3,313.62 3,264.62 4,090.22 -2,283.13 6,035,539.49 1,658,373.06 2.53 3,544.38 MWD+IFR-AK-CAZ-SC(4) 6,834.32 83.15 325.68 3,320.11 3,271.11 4,132.27 -2,311.27 6,035,581.45 1,658,344.80 2.74 3,585.20 MWD+IFR-AK-CAZ-SC(4) 6,877.51 83.25 324.80 3,325.23 3,276.23 4,167.50 -2,335.72 6,035,616.61 1,658,320.26 2.04 3,620.23 MWD+IFR-AK-CAZ-SC(4) 6,972.07 83.41 322.66 3,336.21 3,287.21 4,243.22 -2,391.28 6,035,692.17 1,658,264.50 2.25 3,698.33 MWD+IFR-AK-CAZ-SC(4) 7,017.74 82.78 321.84 3,341.70 3,292.70 4,279.07 -2,419.03 6,035,727.94 1,658,236.65 2.25 3,736.68 MWD+IFR-AK-CAZ-SC(4) 7,067.39 82.20 320.11 3,348.19 3,299.19 4,317.31 -2,450.03 6,035,766.09 1,658,205.55 3.65 3,778.88 MWD+IFR-AK-CAZ-SC(4) 7,104.15 81.81 318.29 3,353.31 3,304.31 4,344.86 -2,473.81 6,035,793.58 1,658,181.70 5.02 3,810.65 MWD+IFR-AK-CAZ-SC(4) 7,160.22 81.84 316.89 3,361.28 3,312.28 4,385.84 -2,511.24 6,035,834.45 1,658,144.16 2.47 3,859.84 MWD+IFR-AK-CAZ-SC(4) 7,208.88 81.39 314.39 3,368.38 3,319.38 4,420.25 -2,544.90 6,035,868.77 1,658,110.41 5.17 3,903.24 MWD+IFR-AK-CAZ-SC(4) 7,256.01 80.40 312.46 3,375.84 3,326.84 4,452.24 -2,578.69 6,035,900.66 1,658,076.54 4.56 3,945.93 MWD+IFR-AK-CAZ-SC(4) 7,304.32 79.61 310.09 3,384.22 3,335.22 4,483.63 -2,614.44 6,035,931.94 1,658,040.70 5.10 3,990.26 MWD+IFR-AK-CAZ-SC(4) 3/28/2017 8:08:34AM Page 4 COMPASS 5000.1 Build 74 • • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Site: Kuparuk 3R Pad MD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Well: 3R-102 North Reference: True Wellbore: 3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,350.36 79.13 307.93 3,392.72 3,343.72 4,512.11 -2,649.60 6,035,960.33 1,658,005.47 4.73 4,033.04 MWD+IFR-AK-CAZ-SC(4) 7,399.84 79.41 304.55 3,401.93 3,352.93 4,540.84 -2,688.81 6,035,988.95 1,657,966.19 6.74 4,079.71 MWD+1FR-AK-CAZ-SC(4) 7,445.17 79.82 301.49 3,410.10 3,361.10 4,565.14 -2,726.19 6,036,013.14 1,657,928.75 6.70 4,123.15 MWD+IFR-AK-CAZ-SC(4) 7,496.96 80.51 299.41 3,418.95 3,369.95 4,590.99 -2,770.18 6,036,038.88 1,657,884.69 4.18 4,173.33 MWD+IFR-AK-CAZ-SC(4) 7,539.35 81.33 299.56 3,425.64 3,376.64 4,611.60 -2,806.61 6,036,059.38 1,657,848.20 1.97 4,214.61 MWD+IFR-AK-CAZ-SC(4) 7,634.94 81.68 297.10 3,439.76 3,390.76 4,656.46 -2,889.82 6,036,104.01 1,657,764.88 2.57 4,308.15 MWD+IFR-AK-CAZ-SC(4) 7,730.93 82.36 294.45 3,453.09 3,404.09 4,697.79 -2,975.42 6,036,145.10 1,657,679.18 2.82 4,402.72 MWD+IFR-AK-CAZ-SC(4) 7,824.08 82.41 291.59 3,465.44 3,416.44 4,733.89 -3,060.39 6,036,180.97 1,657,594.12 3.04 4,494.91 MWD+IFR-AK-CAZ-SC(4) 7,919.11 82.13. 286.29 3,478.23 3,429.23 4,764.44 -3,149.42 6,036,211.27 1,657,505.01 5.53 4,589.02 MWD+IFR-AK-CAZ-SC(4) 8,012.75 82.45 282.19 3,490.80 3,441.80 4,787.26 -3,239.34 6,036,233.85 1,657,415.04 4.35 4,681.33 MWD+1FR-AK-CAZ-SC(4) 8,065.51 82.91 280.19 3,497.52 3,448.52 4,797.42 -3,290.68 6,036,243.86 1,657,363.68 3.86 4,733.04 MWD+IFR-AK-CAZ-SC(4) 8,107.62 83.00 278.75 3,502.68 3,453.68 4,804.29 -3,331.90 6,036,250.62 1,657,322.45 3.40 4,774.12 MWD+IFR-AK-CAZ-SC(4) 8,202.76 82.37 274.13 3,514.80 3,465.80 4,814.88 -3,425.64 6,036,260.95 1,657,228.68 4.86 4,865.83 MWD+IFR-AK-CAZ-SC(4) 8,297.70 81.86 269.64 3,527.84 3,478.84 4,817.97 -3,519.61 6,036,263.79 1,657,134.72 4.72 4,955.19 MWD+IFR-AK-CAZ-SC(4) 8,392.36 82.74 265.38 3,540.52 3,491.52 4,813.89 -3,613.30 6,036,259.46 1,657,041.05 4.56 5,041.84 MWD+IFR-AK-CAZ-SC(4) 8,487.18 83.77 265.54 3,551.66 3,502.66 4,806.44 -3,707.17 6,036,251.75 1,656,947.21 1.10 5,127.50 MWD+IFR-AK-CAZ-SC(4) 8,541.76 83.79 265.37 3,557.57 3,508.57 4,802.14 -3,761.26 6,036,247.30 1,656,893.14 0.31 5,176.85 MWD+IFR-AK-CAZ-SC(4) 8,594.00 83.72 264.36 3,563.26 3,514.26 4,797.49 -3,812.98 6,036.242.51 1,656,841 44 1.92 5,223.87 NOT an Actual Survey 7 5/8"x 9 7/8 8,638.78 83.66 263.50 3,568.18 3,519.18 4,792.79 -3,857.24 6,036,237.69 1,656,797.19 1.92 5,263.85 MWD+IFR-AK-CAZ-SC(5) 8,671.52 84.90 262.76 3,571.44 3,522.44 4,788.89 -3,889.58 6,036,233.70 1,656,764.87 4.40 5,292.91 MWD+IFR-AK-CAZ-SC(5) 8,703.61 86.14 264.28 3,573.95 3,524.95 4,785.28 -3,921.36 6,036,230.01 1,656,733.09 6.10 5,321.54 MWD+IFR-AK-CAZ-SC(5) 8,733.13 87.10 265.71 3,575.69 3,526.69 4,782.71 -3,950.72 6,036,227.36 1,656,703.75 5.83 5,348.25 MWD+1FR-AK-CAZ-SC(5) 8,765.80 87.73 266.95 3,577.16 3,528.16 4,780.62 -3,983.29 6,036,225.18 1,656,671.19 4.25 5,378.14 MWD+1FR-AK-CAZ-SC(5) 8,797.18 87.82 267.13 3,578.38 3,529.38 4,779.00 -4,014.60 6,036,223.48 1,656,639.88 0.64 5,407.01 MWD+IFR-AK-CAZ-SC(5) 8,828.00 88.09 269.81 3,579.48 3,530.48 4,778.18 -4,045.39 6,036,222.57 1,656,609.10 8.73 5,435.66 MWD+IFR-AK-CAZ-SC(5) 8,924.07 88.04 270.16 3,582.73 3,533.73 4,778.16 -4,141.41 6,036,222.28 1,656,513.09 0.37 5,525.87 MWD+IFR-AK-CAZ-SC(5) 9,018.79 89.82 269.32 3,584.49 3,535.49 4,777.73 -4,236.10 6,036,221.60 1,656,418.41 2.08 5,614.71 MWD+IFR-AK-CAZ-SC(5) 9,113.14 90.05 268.69 3,584.60 3,535.60 4,776.09 -4,330.44 6,036,219.70 1,656,324.09 0.71 5,702.80 MWD+IFR-AK-CAZ-SC(5) 9,208.72 89.95 267.85 3,584.60 3,535.60 4,773.20 -4,425.97 6,036,216.56 1,656,228.57 0.89 5,791.59 MWD+IFR-AK-CAZ-SC(5) 9,303.05 90.12 270.04 3,584.54 3,535.54 4,771.46 -4,520.28 6,036,214.56 1,656,134.28 2.33 5,879.61 MWD+IFR-AK-CAZ-SC(5) 9,397.06 91.08 272.78 3,583.56 3,534.56 4,773.78 -4,614.25 6,036,216.62 1,656,040.31 3.09 5,968.70 MWD+1FR-AK-CAZ-SC(5) 9,490.90 91.22 275.30 3,581.68 3,532.68 4,780.39 -4,707.83 6,036,222.97 1,655,946.72 2.69 6,058.90 MWD+IFR-AK-CAZ-SC(5) 9,584.52 91.24 274.35 3,579.67 3,530.67 4,788.26 -4,801.09 6,036,230.59 1,655,853.45 1.01 6,149.23 MWD+IFR-AK-CAZ-SC(5) 9,681.00 92.62 272.67 3,576.42 3,527.42 4,794.16 -4,897.33 6,036,236.23 1,655,757.20 2.25 6,241.69 MWD+IFR-AK-CAZ-SC(5) 9,773.86 93.38 267.36 3,571.55 3,522.55 4,794.19 -4,990.03 6,036,236.00 1,655,664.51 5.77 6,328.81 MWD+IFR-AK-CAZ-SC(5) 9,869.63 93.48 266.30 3,565.82 3,516.82 4,788.90 -5,085.48 6,036,230.46 1,655,569.09 1.11 6,416.69 MWD+IFR-AK-CAZ-SC(5) 9,965.16 93.65 265.40 3,559.88 3,510.88 4,782.00 -5,180.58 6,036,223.30 1,655,474.02 0.96 6,503.69 MWD+IFR-AK-CAZ-SC(5) 10,058.11 93.03 266.21 3,554.47 3,505.47 4,775.22 -5,273.12 6,036,216.26 1,655,381.51 1.10 6,588.33 MWD+IFR-AK-CAZ-SC(5) 10,154.55 91.08 266.50 3,551.01 3,502.01 4,769.09 -5,369.30 6,036,209.87 1,655,285.35 2.04 6,676.61 MWD+IFR-AK-CAZ-SC(5) 3/2872017 8:08:34AM Page 5 COMPASS 5000.1 Build 74 i • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Site: Kuparuk 3R Pad MD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Well: 3R-102 North Reference: True Wellbore: 3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 10,248.93 88.57 265.92 3,551.30 3,502.30 4,762.85 -5,463.46 6,036,203.38 1,655,191.22 2.73 6,762.97 MWD+IFR-AK-CAZ-SC(5) 10,342.27 86.74 265.64 3,555.12 3,506.12 4,755.99 -5,556.47 6,036,196.26 1,655,098.24 1.98 6,848.02 MWD+IFR-AK-CAZ-SC(5) 10,437.85 90.02 266.75 3,557.82 3,508.82 4,749.65 -5,651.78 6,036,189.67 1,655,002.95 3.62 6,935.42 MWD+IFR-AK-CAZ-SC(5) 10,533.00 89.08 266.56 3,558.57 3,509.57 4,744.10 -5,746.77 6,036,183.86 1,654,907.99 1.01 7,022.77 MWD+IFR-AK-CAZ-SC(5) 10,627.38 89.33 269.07 3,559.87 3,510.87 4,740.50 -5,841.06 6,036,180.00 1,654,813.72 2.67 7,110.15 MWD+IFR-AK-CAZ-SC(5) 10,720.67 89.47 271.40 3,560.85 3,511.85 4,740.88 -5,934.34 6,036,180.13 1,654,720.45 2.50 7,197.93 MWD+IFR-AK-CAZ-SC(5) 10,816.39 89.47 271.47 3,561.74 3,512.74 4,743.28 -6,030.03 6,036,182.27 1,654,624.76 0.07 7,288.67 MWD+IFR-AK-CAZ-SC(5) 10,911.11 88.80 271.14 3,563.17 3,514.17 4,745.44 -6,124.71 6,036,184.17 1,654,530.08 0.79 7,378.38 MWD+IFR-AK-CAZ-SC(5) 11,006.68 89.79 270.27 3,564.34 3,515.34 4,746.61 -6,220.26 6,036,185.08 1,654,434.54 1.38 7,468.57 MWD+IFR-AK-CAZ-SC(5) 11,099.59 92.28 270.83 3,562.67 3,513.67 4,747.50 -6,313.15 6,036,185.72 1,654,341.66 2.75 7,556.16 MWD+IFR-AK-CAZ-SC(5) 11,193.48 91.15 272.58 3,559.86 3,510.86 4,750.30 -6,406.95 6,036,188.26 1,654,247.86 2.22 7,645.26 MWD+IFR-AK-CAZ-SC(5) 11,289.46 89.40 271.78 3,559.39 3,510.39 4,753.95 -6,502.85 6,036,191.65 1,654,151.96 2.00 7,736.63 MWD+IFR-AK-CAZ-SC(5) 11,384.81 88.29 272.77 3,561.32 3,512.32 4,757.73 -6,598.11 6,036,195.17 1,654,056.70 1.56 7,827.43 MWD+IFR-AK-CAZ-SC(5) 11,478.98 88.32 272.54 3,564.10 3,515.10 4,762.09 -6,692.13 6,036,199.27 1,653,962.67 0.25 7,917.28 MWD+IFR-AK-CAZ-SC(5) 11,573.63 89.57 272.42 3,565.84 3,516.84 4,766.19 -6,786.68 6,036,203.11 1,653,868.13 1.33 8,007.52 MWD+IFR-AK-CAZ-SC(5) 11,669.26 90.14 271.75 3,566.09 3,517.09 4,769.67 -6,882.24 6,036,206.33 1,653,772.56 0.92 8,098.51 MWD+IFR-AK-CAZ-SC(5) 11,763.98 92.00 269.81 3,564.32 3,515.32 4,770.96 -6,976.93 6,036,207.36 1,653,677.88 2.84 8,187.93 MWD+IFR-AK-CAZ-SC(5) 11,857.55 92.52 268.51 3,560.63 3,511.63 4,769.58 -7,070.41 6,036,205.73 1,653,584.41 1.50 8,275.31 MWD+IFR-AK-CAZ-SC(5) 11,953.14 93.10 268.11 3,555.94 3,506.94 4,766.77 -7,165.85 6,036,202.66 1,653,489.00 0.74 8,364.02 MWD+IFR-AK-CAZ-SC(5) 12,048.52 92.43 268.67 3,551.34 3,502.34 4,764.09 -7,261.08 6,036,199.72 1,653,393.78 0.92 8,452.60 MWD+IFR-AK-CAZ-SC(5) 12,142.97 89.65 268.19 3,549.63 3,500.63 4,761.51 -7,355.47 6,036,196.88 1,653,299.41 2.99 8,540.41 MWD+IFR-AK-CAZ-SC(5) 12,237.59 89.67 267.91 3,550.19 3,501.19 4,758.29 -7,450.03 6,036,193.40 1,653,204.87 0.30 8,628.17 MWD+IFR-AK-CAZ-SC(5) 12,332.05 89.74 268.48 3,550.67 3,501.67 4,755.31 -7,544.44 6,036,190.17 1,653,110.47 0.61 8,715.87 MWD+IFR-AK-CAZ-SC(5) 12,426.14 89.62 268.02 3,551.20 3,502.20 4,752.44 -7,638.48 6,036,187.04 1,653,016.45 0.51 8,803.26 MWD+IFR-AK-CAZ-SC(5) 12,518.51 91.69 267.95 3,550.14 3,501.14 4,749.19 -7,730.79 6,036,183.54 1,652,924.16 2.24 8,888.88 MWD+IFR-AK-CAZ-SC(5) 12,582.00 90.99 268.34 3,548.66 3,499.66 4,747.13 -7,794.23 6,036,181.31 1,652,860.74 1.26 8,947.79 NOT an Actual Survey 4 1/2"x 6 3/4" 12,608.99 90.69 268.50 3,548.26 3,499.26 4,746.39 -7,821.20 6,036,180.49 1,652,833.76 1.26 8,972.89 MWD+IFR-AK-CAZ-SC(5) 12,701.93 91.20 267.69 3,546.73 3,497.73 4,743.30 -7,914.08 6,036,177.15 1,652,740.91 1.03 9,059.10 MWD+IFR-AK-CAZ-SC(5) 12,796.93 93.31 266.71 3,542.99 3,493.99 4,738.66 -8,008.88 6,036,172.26 1,652,646.12 2.45 9,146.61 MWD+IFR-AK-CAZ-SC(5) 12,890.26 95.83 264.32 3,535.56 3,486.56 4,731.39 -8,101.62 6,036,164.74 1,652,553.42 3.72 9,231.26 MWD+IFR-AK-CAZ-SC(5) 12,982.92 96.10 263.20 3,525.93 3,476.93 4,721.38 -8,193.23 6,036,154.47 1,652,461.84 1.24 9,313.92 MWD+IFR-AK-CAZ-SC(5) 13,071.76 96.03 262.96 3,516.54 3,467.54 4,710.73 -8,280.93 6,036,143.59 1,652,374.18 0.28 9,392.69 MWD+IFR-AK-CAZ-SC(5) 13,164.19 96.09 261.85 3,506.78 3,457.78 4,698.58 -8,372.03 6,036,131.19 1,652,283.12 1.20 9,474.15 MWD+IFR-AK-CAZ-SC(5) 13,257.05 96.10 259.00 3,496.92 3,447.92 4,683.23 -8,463.07 6,036,115.59 1,652,192.13 3.05 9,554.44 MWD+IFR-AK-CAZ-SC(5) 13,349.20 96.20 256.03 3,487.05 3,438.05 4,663.42 -8,552.52 6,036,095.55 1,652,102.75 3.21 9,631.72 MWD+IFR-AK-CAZ-SC(5) 13,441.20 96.13 254.45 3,477.17 3,428.17 4,640.12 -8,640.96 6,036,072.00 1,652,014.38 1.71 9,706.86 MWD+IFR-AK-CAZ-SC(5) 13,533.72 96.13 252.93 3,467.29 3,418.29 4,614.29 -8,729.25 6,036,045.93 1,651,926.17 1.63 9,780.99 MWD+IFR-AK-CAZ-SC(5) 13,624.70 96.13 249.42 3,457.57 3,408.57 4,585.10 -8,814.86 6,036,016.52 1,651,840.65 3.84 9,851.45 MWD+IFR-AK-CAZ-SC(5) 13,715.41 96.00 247.11 3,447.98 3,398.98 4,551.70 -8,898.64 6,035,982.89 1,651,756.97 2.54 9,918.76 MWD+IFR-AK-CAZ-SC(5) 3/28/2017 8.08:34AM Page 6 COMPASS 5000.1 Build 74 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Site: Kuparuk 3R Pad MD Reference: 3R-102:39.10+9.9 @ 49.00usft(D142) Well: 3R-102 North Reference: True Wellbore: 3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) 0100') (ft) Survey Tool Name 13,808.53 96.27 246.29 3,438.03 3.389.03 4,515.08 -8,983.67 6.035,946.04 1,651,672.04 0.92 9,986.14 MWD+IFR-AK-CAZ-SC(5) 13,900.76 96.17 245.73 3,428.04 3,379.04 4,477.80 -9,067.44 6,035,908.54 1,651,588.39 0.61 10,052.11 MWD+IFR-AK-CAZ-SC(5) 13,993.20 95.61 247.20 3,418.55 3,369.55 4,441.09 -9,151.74 6,035,871.60 1,651,504.19 1.69 10,118.76 MWD+IFR-AK-CAZ-SC(5) 14,085.29 91.50 247.79 3,412.84 3,363.84 4,405.91 -9,236.64 6,035,836.20 1,651,419.40 4.51 10,186.51 MWD+IFR-AK-CAZ-SC(5) 14,176.85 89.79 246.05 3,411.81 3,362.81 4,370.02 -9,320.86 6,035,800.08 1,651,335.29 2.66 10,253.38 MWD+IFR-AK-CAZ-SC(5) 14,269.99 89.87 244.97 3,412.09 3,363.09 4,331.42 -9,405.62 6,035,761.25 1,651,250.65 1.16 10,319.82 MWD+IFR-AK-CAZ-SC(5) 14,361.44 90.84 244.72 3,411.52 3,362.52 4,292.54 -9,488.39 6,035,722.16 1,651,167.99 1.10 10,384.31 MWD+IFR-AK-CAZ-SC(5) 14,453.76 92.68 246.48 3,408.69 3,359.69 4,254.43 -9,572.42 6,035,683.81 1,651,084.07 2.76 10,450.23 MWD+IFR-AK-CAZ-SC(5) 14,545.65 92.18 248.52 3,404.79 3,355.79 4,219.30 -9,657.23 6,035,648.46 1,650,999.36 2.28 10,517.91 MWD+IFR-AK-CAZ-SC(5) 14,635.90 92.38 247.74 3,401.20 3,352.20 4,185.71 -9,740.92 6,035,614.64 1,650,915.77 0.89 10,585.07 MWD+IFR-AK-CAZ-SC(5) 14,729.03 93.00 248.92 3,396.83 3,347.83 4,151.35 -9,827.37 6,035,580.06 1,650,829.42 1.43 10,654.55 MWD+IFR-AK-CAZ-SC(5) 14,820.59 92.90 249.47 3,392.12 3,343.12 4,118.88 -9,912.85 6,035,547.35 1,650,744.05 0.61 10,723.77 MWD+IFR-AK-CAZ-SC(5) 14,890.02 92.86 252.82 3,388.63 3,339.63 4,096.47 -9,978.46 6,035,524.77 1,650,678.50 4.82 10,777.76 MWD+IFR-AK-CAZ-SC(5) 14,950.00 92.86 252.82 3,385.63 3,336.63 4,078.78 -10,035.69 6,035,506.92 1,650,621.32 0.00 10,825.49 PROJECTED to TD Final Definitive Survey Verified and Signed-off NI tappets and/or wail position objectives have been achieved 71 Yes ❑ No I have checked to the bast of my ability that the following data Is correct E Surface Coordinates ) Declination & Convergence O GRS Survey Corrections O Survey Tool Codes SLB DE. Brandon Temple eugAchkii.%glnr a6 3/ZB/j7 "",,��``Cb"1"``1'w"''' Client Representative. Kelsey Hallford Kelsey Ha Ilford , .7,...,'----- , Date: 3128117 .3/28/2017 8:08:34AM Page 7 COMPASS 5000.1 Build 74 pF T • • - gwP\��)yy��s� THE STATE Alaska Oil and Gas �, �y-►ia0 ffT AS Conservation Commission ill€ 4 == =_ 2 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ' Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU 3R-102 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-157 revised Surface Location: 1658.7' FNL, 2949.57' FEL, T13N,R9E, S9,U Bottomhole Location: 3075.79' FNL, 3020.26' FEL, T13N, R9E, S6, U Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. Per Statute AS 31.05.030(d)(2)(B)and Regulation 20 AAC 25.071,composite curves for well logs run must be submitted to the AOGCC within 90 days after completion,suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition,the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05,Title 20,Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy . Foerster y� Chair DATED this I7' day of February, 2017. 'iCI,CI V CIJ ' STATE OF ALASKA FEB 0 17 A OIL AND GAS CONSERVATION COMM ON , ,t_ °,/ I ' '%`'' PERMIT TO DRILA G 20 AAC 25.005 1 a.Type of Work: lb. Proposed Well Class: Development-Oil ❑ Service- Winj Q i Single Zone ❑✓ lc.Specify if well is proposed for: Drill Q, Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply pp y ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket ❑✓ , Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc ' Bond No. 59-52-180 • KRU 3R-102 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 15,508 • TVD: •3317 Kuparuk River Field ' 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1658.7'FNL,2949.57'FEL, T 13N,R 9E,S 9, U ' ADL 355023,ADL 373301,ADL 355024 West Sak Oil Pool • Top of Productive Horizon: 8. Land Use Permit: 13.Approximate Spud Date: 2156'FNL, 1544'FEL, T 13N,R 9E,S 5, U 931695 2/17/2017 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 3075.79'FNL,3020.26'FEL, T 13N,R 9E,S 6,U 3255,677,1800 2156 ft 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 48.9 , feet 15.Distance to Nearest Well Open Surface: x- 520636 y- 6031704 Zone-4 , GL Elevation above MSL: 9.9 • feet to Same Pool: 2860'MD(ENI well) 16.Deviated wells: Kickoff depth: 350 feet • 17. Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 98.1 degrees • Downhole: 1590 psi • Surface: 1258 psi 4- 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" 94# H40 Welded 80 10 10 90 90 200 cf of ArcticCRETE 13.5" 10.75" 45.5# L-80 Hydril 563 2327 10 10 2337 2199 1229 sx DeepCRETE Lead,139 sx DeepCRETE Tail 9.875" 7.625" 29.7# L-80 H563 8858 10 10 8868 3564 1160 sx Class'G' 6.75" 4.5" 11.6# L-80 IBTM 3832 8868 3540 12700 3489 Slotted Liner Completion(no cement) 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 Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat BOP Sketch Drilling Program Time v.Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Datet,,f 'V4,01/6/2017 22. I hereby certify that the foregoing is true and correct. Contact Kelsey Hallford @ 265-1577 Email kelsey.hallford(ccop.com Printed Name G.Alvord Title Alaska Drilling Manager Signature /46 L2k Phone 265-6120 Date 2`CO (z0(7 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number:z,f♦Le_16-7 revved 50-02.1...2_3 572- oa-00 Date: i 2,.•2. I CR requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane gas hydrates,or gas contained in shales: [� Other: /�c p -,--1-571- to 35-co n �2 c/,� �Sammpplles req'd: YesVNo1110 Mud log req'd:Yes❑ No[]/ (!�✓lam n v C aY l)Yec�y va�t v' l f I Z °�(74- easures: Yes No❑ Directional svy req'd:Yes V. / No❑ .,svdt d V-t7 ftp,.)1 C Cr ti riy-L. b-4?3j acin exception req'd: Yes [� [� f C( p 9 p ❑ No Inclination-only svy req'd:Yes❑ No r l v e ie' fv v ✓✓tri CO 1,2V-et(5!c.,-1 a v1 c( vvt v 5 t post 11,7$t�a f r dnClt,C1? /P r62af 4(-- Wr1tfrIn 1Ioti /ic4ffo-vi to CN-4 rvif /14f7re‘tcl V(51.1 2F frjeCtlY1 pew odd 4-4e 25 . 4- 62-(c)(3) . APPROVED BY Approved by0 ,4,____(.4 � COMMISSIONER THE COMMISSION Date2'�Z.-4? b ��7 Eubrrii rm ncV Form 1 40 evised 10/2012 rs r r r f months fr th date of approval(20 AAC 25.005(g)) Attachments in Duplicate \\) • Revised Application for Permit to Drill,Well 3R-102 Saved:6-Feb-17 February 6,2017 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for Revised Permit to Drill Well 3R-102,A West Sak D Sand Pre-Produced Injector Dear Commissioner: ConocoPhillips Alaska, Inc.hereby applies for a revised permit to drill an onshore grassroots pre-produced injector well from the 3R pad. The expected spud date for this well is February 17, 2017. It is planned to use rig Doyon 142. ✓ Revisions include, rig change and subsequent RKB depth adjustment. 3R-102 is planned to be a horizontal well in the West Sak D sand. The surface section will be drilled with 13-1/2"bit and run 10-3/4"casing to+/-2,337 MD/2,199 TVD. The intermediate section will be drilled with 9-7/8"bit run 7-5/8" casing to 8,868'MD/3,564'TVD. The production hole will be drilled with 6-3/4"bit to 15,508' MD/3,317' TVD for logging purposes and run 4-1/2"slotted liner to+/- 12,700'MD/3,489'TVD. The upper completion will be run with 4- 1/2"tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment,diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Kelsey Hallford at 265-1577 (kelsey.hallford(&conocophillips.com)or Chip Alvord at 265-6120. Sincerely, /4-6. 0,e9 Chip Alvord Drilling Manager • • Application for Permit to Drill Document Kuparuk Well 3R-102 conocoPt,,,ps Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 3R-102 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth: Location at Surface 1658.7' FNL, 2949.6' FEL, Sec 9, T 13N,R009E,UM NGS Coordinates _ RKB Elevation 48.9'AMSL Northings: 6,031,703.98' Eastings: 520,635.80' Pad Elevation 9.9'AMSL , Location at Top of 2156' FNL, 1544 FEL, Sec 5,T13N,R009E,UM Productive Interval(West Sak D Sand) NGS Coordinates Measured Depth, RKB: 8,580' Northings: 6,036,476' Eastings:516,736.43' Total Vertical Depth, RKB: 3,548' Total Vertical Depth, SS: 3,499' Location at Total Depth 3075.8'FNL, 3020.3' FEL, Sec 6,T13N,R009E,UM NGS Coordinates Measured Depth, RKB: 15,508' Northings: 6,035,544.13' Eastings: 509,985.7' Total Vertical Depth, RKB: 3,317' Total Vertical Depth, SS: 3,268' and (D)other information required by 20;JAC 23.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment: Directional Plan And (2)for all wells within 200 feet of the proposed wellbore (.A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail:or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must he accompanied by each of the following items,except for an item already on file with the connnission and identified in the application: (3)a diagram and description of the blowout prevention equipment MOPE)as required by 20 AAC 25.035,20 AAC:25.036.or 20 AAC 25.037,as applicable; Please reference BOP schematics on file for Doyon 142. • • Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application,for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards, including (A)the rnaxinwm downhole pressure that may be encountered,criteria used to determine it.and maximum potential surface pressure based on a methane gradient; The maximum potential surface pressure (MPSP) while drilling 3R-102 is calculated using an estimated maximum reservoir pressure of 1,590 psi (based on Kigun 1 MDT pressure of 1660 psi and corrected to planned depth), a gas gradient of 0.10 psi/ft, and the estimated depth of the West Sak D sand at 3,317' TVD (WP09): A Sand Estimated. BHP = 1,590 psi A Sand estimated depth(WP09) =3,317' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 332 psi (3,317' TVD * 0.10 psi/ft) MPSP =BHP—gas column = 1,258 psi (1,590 psi—332psi) (B)data on potential gas zones; The well bore is not expected to penetrate any shallow gas zones. And (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones.and zones that have a propensity for differential sticking: See attached 3R-102 Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting,formation integrity tests,as required under 20 AAC 25.030 ; A procedure is on file with the commission for performing LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the,following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre-perforated liner. or screen to he installed Casing and Cement Program Casing and Cementing Program Csg/Tbg OD Hole weight Length Top MD/TVD Btm MD/TVD (in) Size (lb/ft) Grade Conn. (ft) (ft) (ft ) Cement Program (in) 20 42 94 H-40 Welded 80 Surf 90/90 Existing Hydril Cement to Surface with 10-3/4 13-1/2 45.5 L-80 563 2,327 Surf 2,337/2,199 1,229 sx DeepCRETE Lead 11.0 ppg, 139sx DeepCrete Tail 12 ppg 7-5/8 9-7/8 29.7 L-80 Hydril 8,858 Surf 8 868/3 564 1,160 sx Class G at 15.8ppg 563w/TOC at 4,463 4 1/2 6-3/4 11.6 L-80 IBTM 4,032 8,668/3,550 12,700/3,500 Slotted Liner • • 10-3/4" Surface casing run to 2,337' MD/2,199' TVD Cement from 2337' MD to 1836'(500' of tail)with 12 ppg,and from 1837'to surface with 11 ppg DeepCrete.Assume 250%excess annular volume in permafrost and 50%excess below the permafrost(1778' MD),zero excess in 20" conductor. Lead slurry from 2,452' MD to surface with Arctic Lite Crete @ 11 ppg Conductor (80'—0')X 1.339 ft3/ft X 1.0 (0%excess) = 107 ft3 Permafrost to Conductor (1,778'—80') X 0.3637 ft3/ft X 3.5 (250%excess) =2,162 ft3 Top of Tail to Permafrost (1,836—1,778')X 0.3637 ft3/ft X 1.5 (50%excess) =32 ft3 Total Volume= 154+2,162+32 =2,348 ft3=> 1,229 sx of 11 ppg DeepCrete @ 1.91 ft3/sk Tail slurry from 2,337' MD to 1,836' MD with 12 ppg DeepCrete Shoe to Top of Tail (2,337—1,836')X 0.3637 ft3/ft X 1.50(50%excess) =273 ft3 Shoe Joint (80')X 0.5400 ft3/ft X 1.0(0%excess) =43 ft3 Total Volume=273+43=316 ft3=> 139 sx of 12 ppg DeepCrete @ 2.28 ft3/sk 7-5/8"Intermediate casing run to 8,868'MD/3,564' TVD Single stage slurry is designed to be at 4,463' MD,which is 500' above the Ugnu B;40%excess annular volume. Slurry from 9,400' MD to 7,324' MD with 15.8ppg Class G+additives Shoe to Top of Cement (8,868—4,463')X 0.2148 ft3/ft X 1.40 (40%excess) = 1,325 ft3 Shoe Joint (80')X 0.2577 ft3/ft X 1.0(0%excess) =21 ft3 Total Volume= 1,325+21 = 1346 ft3=> 1,160 sx of 15.8 ppg Class G+GasBLOK @ 1.16 ft3/sk Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must he accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035,unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematic on file for Doyon 142.J Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items.except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 MC 25.033; Mud Program Summary Surface Intermediate Production 9-7/8"x 11" 13-1/2" Hole Hole 6-3/4" Hole 10-3/4"Casing 7-5/8" Casing 4-1/2" Liner Spud LSND FlowPro Mud System (WBM) (WBM) (WBM) Density 8.8-9.5 9.0-10.0 9.0-9.5 PV ALAP ALAP ALAP YP 30-80 20-30 15-20 250-300 Permafrost Base Funnel Viscosity 100-150 to TD N/A N/A Initial Gel 30-50 9- 11 7- 11 10 minute Gel 30-50 <20 8-16 API Filtrate NC <6 <6 HTHP Fluid Loss at 160 F N/A < 10 < 10 pH 10.8-11.2 9.5- 10.0 9.5- 10.0 Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A -Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items.except for an item already onfile with the commission and identified in the application: The proposed drilling program is listed below. Please refer to attachment for proposed well schematic 1. Move in/rig up Doyon Rig 142. Install Annular with 16"diverter line and function test. 2. Spud and directionally drill 13.5"hole to casing point at+/-2,336' MD/2,198' TVD as per directional plan.Run MWD tools and required for directional monitoring(gamma ray,resistivity,drop gyro). 3. Run and cement 10.75",45.5#,L80,Hyd-563 casing to surface. Displace cement with mud and check floats upon bumping plug.Perform top job if required. 4. Remove diverter system,install and test 13-5/8"x 5,000 psi BOP's to 3500 psi(annular preventer to 3500 psi). Notify AOGCC 24 hrs before test. 5. PU 9.875"bit and 6.75"drilling assembly,with MWD(gamma ray,resistivity,density,porosity).RIH,clean out cement to top of float equipment and test casing to 3,000 psi for 30 min. 6. Drill out cement and,between 20' and 50' of new hole.Perform formation integrity test to 12.0ppg EMW, recording results. 7. Displace to LSND water based drilling fluid. 8. Directionally drill to 7-5/8"casing point at 8,868' MD/3,564' TVD. Back ream out of hole to the surface casing shoe. 9. Run 7.625"29.7#L80,Hydril 563 casing to surface.(Top of cement to be 4,463' MD/2,920' TVD which corresponds to 500' above the Ugnu B formation.) 10. Install wellhead x 7.625"packoff and test to 3500 psi. 11. Flush 10.75"x 7.625"annulus with water,followed by isotherm. 12. PU 6.75"PDC Bit and 4.5"drilling assembly with MWD and LWD logging tools(gamma ray,resistivity, density,porosity,periscope,sonic,NMR).RIH,performing MAD pass with sonic tool in memory mode to log cement. 13. Clean out cement to top of float equipment.Test casing to 3500 psi for 30 minutes. 14. Drill out cement and 20'-50' of new hole.Displace hole to lateral drilling Flo-Pro WBM system.Perform formation integrity test to 12.5 EMW,recording results. 15. Directionally drill 6.75"hole in West Sak D sand to TD at+/- 15,508' MD/3,317' TVD as per directional plan. 16. Back ream out of hole to 7.625"shoe. Circulate to clean up casing and POOH on elevators. 17. If pay is across fault bock to west,PU MDT wireline tool and TIH on DP to the intermediate casing shoe. 18. Pump down TLC-H wireline, ensure MDT tool is communicating before going into open hole with wireline through a side entry sub on the DP. 19. TIH to zones of interest 13,670- 14,100' MD and 14,930'- 15,370' MD and take MDT damples. 20. POOH on elevators. 21. PU and run 4.5"slotted liner. 22. Make up liner hanger running tool. 23. Finish running liner to 12,700' MD to land liner. 24. Set liner hanger @+/-8,718' MD,set liner top packer and test.POOH. 25. PU 4.5"tubing as required and TIH to depth.Land tubing. Set BPV. 26. Nipple down BOPE,nipple up tree and test.Pull BPV. S 27. Freeze protect well with diesel by pumping into 4.5"x 7.625"annulus,taking returns from tubing and allowing to equalize. (If the schedule and equipment availability allows,the Wells Group will freeze protect the well post rig). 28. Set BPV and move off rig. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill music be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authori_ation under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (DS 1B CRI)or Prudhoe DS-4. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well,or stored,tested for hazardous substances,and(if free of hazardous substances)used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 AOR Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 Well Schematic Attachment 5 Diverter Layout Diagram Attachment 1 AOR Well Name Status Top of West Sak D TOC(MD/TVD) TOC Determined By Reservoir Status Zonal Isolation Cement Operations Summary Sand(MD/TVD) Column of cementto be 3R-102 Proposed Injector 8,427'/3,528' 5,044'/3,020' Sonic LWD Not Yet Drilled 500 above Ugnu B @ Well does not exist yet 5,044'MD/3,020 ND Calculated with Perfs open for Column of cement from 240 bbls 15.8ppgtail pumped in second OP21ww01 Water Producer 3,883'/3,516' 2,960'/2,865 40%washout,no production in 3,826 MD to TOC @ 2,960' stage cement job for 9-5/8" losses during job Ivishak MD,isolating West Sak. intermediate casing string. Perfs open for Surface csg set below WS DSand @4,020'MD/ 609 bbls 11.2ppg ALC,68bbl 12.5ppg tail, 0P22ww03 Water Producer 3,815/3,523' Surface Returns to surface production in 3,728'TVD,and cemented plugs bumped and cement returns to Ivishak to surface. surface. M 0 11 3R-1 02wp09 7 . 178 Plan Summary T3 Base Pfrost K15 Top Ugnu A Top West Sak D _ ,._. I . I ,' Base West Sak DTDP West Sak D . •5- ` I ,' Top Ugnu C I Top N Sands . L 1 -5 ` 1 I 1 Fault L 1 g -. ` •,- Top Ugnu B ' 'I LL I .-.. - rn , ` I I I CO - 1 I I f--�- 1g I _ I - TD / r I 1 0 c I I I I I 1 I I f tI f ' r, I' 1 0 � ; ---1\0".2\- 4i A. 0 ' 3500 7000 1050D 14000 120"x 42"1 110 3/4"x 13-1/21 Measured Depth 7-5/8"x 9-7/8" 14 1/2"x 6-3/4"1 1 o-`__ 20 x 42" Geodetic Daum: -\\ J0° Depth Reference: Plan:39+9.9 @ 48.90usft(Doyon142) 10o 110 3/4"x 13-1/1 Rig: Doyon142 • �` NIIIN1106.„ LO -C),.:0$4. 17-5/8"x,9-7/8"1 4 1/T x 63/4"1 _.. o O 0 O 11 �O g oo 0 0` 00 \ Uhl. ,., -"11%''"-• O n 0 \Noo 0 ,comm 1 o 3430 -4000 0 1500 3000 4500 6000 7508 9000 c'10508 1 00 13500 0 4000 -4580 Horizontal Departure 123 I 4580 -5150 330 ... .......... 30 5150 - 5730 3R 101wp13 --- -.--.-- .:;:�� 3R loutapl3 5730 -6300 C ....i .. 3R-101L1wp13 I I 0��`IN 6300 - 7450 :��gt 2 kV. ll. 7450 -8600 .«•, ,: ,� vim, . _ � x :.� � a - 3F-1 C ,a 0„..,,;?:.....-- 60 8600 - 9750 o _ \•� `\\3R QA •Cballen!Jing ,,..,,4,. 9750 - 10900 • 2 03 • . moo: 10900 - 12060 - 011ktck Point Stato-9 - I41��(1^Ha1 Pam Sae 112060 13210 U 30 i; 41�, ,,��' 13210 -'"- 14360 • Orientation i'il+t r; ►..' ) 14360 - 15506 .-. I ;all,)1,,,.. 15508 "" 13370 N `00W7704 '•'0 x.47•Iffy 13370 - 13560 U 8�� Y 0 1 i .. 4.4 1`1Ei,,�;'� �n® 13560 - 13740 I I I I I f ` I I I I 1 I 1 I I I I I I I I I -- �" �y'. 13740 - 13930 0 2000 4000 6000 8000 10000 12000 14000 240 • �t'�'�>>i,�i�4leers�!�7 120 13930 - 14120 SURVEY PROGRAM tjr 14120 - 14400 Surface Location _136-1101 14x00 - 14500 Iepth From Depth To Survey/Plan Tool North/Y: 14500- 14540 East/X: -{38-12x1 39.00 600.00 3R-102wp09(Plan:3R-102) 'NCI-TREND Pad Elevation:9.90 210 . yr. 1806 14540- 14580 600.00 1600.00 3R-102wp09(Plan:3R-102) MWD 13F-,nol 14580 14550 600.00 2336.36 3R-102wp09(Plan:3R-102) MWD+IFR-AK-CAZ-SC 180 39.00 700.00 3R-102wp09(Plan:3R-102) GYD-GC-SS CASING DETAILS 14550 - 14650 2336.36 3836.36 3R-102wp09(Plan:3R-102) MWD ND MD Name 14650 - 143,911 2336.36 8868.00 3R-102wp09(Plan:3R-102) MWD+IFR-AK-CAZ-SC 117.90 117.90 20"x 42" Magnetic Model: BCGM2016 T 8868.00 10372.55 3R-102wp09(Plan:3R-102) MWD 2198.90 2336.79 10 3/4"x 13-1/2 Magnetic Model Date: 25-Feb-17 A 8868.00 15507.88 3R-102wp09(Plan:3R-102) MWD+IFR-AK-CAZ-SC 3563.90 8868.02 7-5/8"x 9-7/8" Magnetic Declination: 17.78° 3500.36 12700.00 4 1/2"x 6-3/4" To convert a Magnetic Direction to a True Direction,Add 17.78°East SECTc3 DETAILS - Sec MO Inc Ali ND ♦WS cEJ-W Oleg TFem 05ea Target 14601849, -16{6013 1 39.00 0.00 0.00 3900 0.00 0.00 0.00 0.00 0.00 -17 do 2 950.00 0.00 0.00 35000 0.00 0.00 0.00 0.00 0.00 KOP:Sad 1.5/107 DI$290•TF,br 250.18 3 600.18 3.75 290.00 60000 2.80 -7.70 1.50 290.00 8.19 Start 2/102 OLS,0•TF.kr 1134.73' 4 1734.91 2605 290.00 16889.40 103.24 -28386 2.00 0.00 301.88 Hold br 111.62 5 1846.59 28.5 290.00 1788.40 120.26 -330.40 0.00 0.00 351.60 Stat 40102 D1S,573.TF,b 490.19 Base Ptrost 6 2336.79 4026 315.97 219890 272.97 -545.16 4.00 5730 60565 03010,80 7 23..79 4026 315.97 2214.16 28227 554.14 0.00 0.00 61727 Slat 47106 015,32A9•TF,41096.35' 8 3453.14 8006 338.17 275311 1072.41 -1024.32 4.00 32.49 1331.04 Had b 27685 -1956.9 9 221.64 8006 338.17 323180 360680-203836 0.00 000 3149.72 Slat 3000018.-9028•TF.br 2255.75 10 8477.36 8600 270.16 354190 476290-3784.45 3.00 -90.36 5192.07 39-W021.Top 001081614W 04087F607for 2658' 11 858394 56.80 270.16 3543.57 478297 3810.88 300 0.00 5217.02 Hold for 360.62 12 886460 8620 270.16 3563.71 478335 4171.07 000 0.00 5555.73 9813%109 018,O'TF,b 302 13 836802 8690 270.16 3563.90 478196 4174.49 300 0.00 5558.95 3R-1032.11e01103116100 040 b 3' 14 888802 8690 270.16 3561.95 476402 4194.46 0.00 0.00 5577.73 O3121103 13LS,0°TF,fa 73.64' 15 896166 8827 270.16 356802 478422 4268.03 2.00 0.00 56466.94 Had b 179.98' 16 9141.64 8827 270.16 3573.13 4784.71 4447.94 0.00 0.00 5816.16 9812%109 015,1 W TF,la 68.64' 17 921028 8700 270.16 3575.90 478439 451652 200 180.00 559287 31-123.T210116MW Adjust T0 lo 0•,for 29232 18 941220 9125 270.16 957935 4785.45 471877 2.00 0.00 6070.91 Hat kr 18882 19 9601.42 9105 270.16 9575.90 4713596 4907.56 000 0.00 831849 33-1024.13169116 MW S312T10001S,VTR.,"3038 20 9631.78 9185 270.16 3575.19 476604-4837.91 220 000 6277.04 Had b 22731' 21 905930 91.88 270.16 3569.63 4788.88-516533 0.00 0.00 6490.96 Start 2/100018,01 TF.for 6732' K15 22 9928.61 9300 270.18 3566.90 478325-5232.59 2.00 0.00 655422 3R-1025.14103116680 Moat 70b-19°,27126 23 9997.98 9137 270.16 8583.05 478704-530389 2.00 18000 662129 Had b 120.48 24 1011844 9137 270.16 35.75 478727-5424.31 0.00 0.00 673436 58827108 DL5,0•TF,Mr 71.33' 25 1018980 9300 21016 355630 478788-5495.61 200 000 6801.88 3R-1926.T51031181a1W Adjust TFb-1®•,tor 7938 26 10889.08 91.41 270.16 355335 4787.78-5574.81 200-180.00 8876.13 Had lo-159.87. 27 10428.94 91.41 270.16 354990 478821 -573421 0.00 0.00 7028.48 30-1027.76103116MW Sat 2/102 01S,0•TF,la 26.63' 28 10455.53 9195 270.16 3549.12 478829-576125 200 000 7051.50 Hold b 193.13' 29 10648.74 9135 210.18 3512.55 478831 -5954.32 020 0.00 7283.10 Slat 2T109012.180°TF fa 9727 90 10746.11 9020 370.16 354030 478820-6051.67 2.03 180.00 7324.67 35-1038.T7103116MW 0401TF10 V.b0' 31 10746.11 90.00 270.16 354090 47..08-6051.67 2.00 0.00 7324.67 Adjust TFb 0720' 32 11037.14 9000 270.16 354090 478887-6312.70 0.00 000 7598.42 Had b 291.81' 33 11037.14 9000 270.16 354090 478987-6342.70 2.00 0.00 7598.42 36-1029.18103118 MW Had 2291.00' 34 11085.83 9037 270.16 3510.49 479000-6391.33 2.00 0.04 761421 58129100'DM,0•T0,140 7 -2772.5 35 11272.51 9097 270.16 3537.31 478031 -657804 0.00 000 7819.78 Adjust TF b 0011 1a 48.69 38 1132120 90.00 270.15 3538.90 479084-662672 2.00 -179.60 7869.58 35-10210.T9103116 MW 1.132 b 188.88' 37 11330.80 89.81 270.12 3536.32 479087-663632 2.00 -171.73787461 54427100015,-179.6°TF,2048.89 38 1149627 89.81 27012 3537.46 479102-6801.69 0.00 0.00 803031 Mjua TF1-171.73•,109.8 Top Ugnu C 39 1180124 9130 270.30 3535.90 4791.41 -6906.75 2.00 4.88 8128.98 3R-10211.710183116 MW Had b 16537 40 11888.40 93.63 27052 3531.70 479203-699381 200 7.17 821099 513129132 DIS,4.86'.T0,2010480 41 11785.44 93.83 270.52 352555 4792.30-7090.64 0.00 0.00 830229 Adjust TFb7.17°,fa 87.12 -3014.4 42 11683.69 9180 269.80 359390 4793.18 7188.77 2.00-158.58 839460 3R-10212.T11103116 MW Had for 87.05 43 11973.69 9013 989.12 351938 47233-7278.75 200-15702 8478.69 son 3/100 DES.-1..58°TF.for 9925 44 12175.94 9013 289.12 351891 478822-748098 0.00 0.00 8667.84 Adjust TF1-15782°,298 45 12258.82 9130 268.00 351790 4787.19-756183 200 43.83 8743.11 311-10213 T12103116 MW Had b 202.22 Top Ugnu B 46 12335.84 9239 388.85 351536 478384-7640.72 200 48.56 8816.01 5.25100 015,43.83°7F,b 8088' 47 12658.12 9239 288.88 350194 478338 796223 0.00 000 9112.11 Ma.716-46..1.79.01' 48 12713.98 9180 265.90 3499.90 47223 8017.94 200-121.83 916325 911-1214.T13103116 MW Had b 32228' 491279819 9097 284.44 349787 475524-610189 200-11969 928865 58127106 DLS,-121.fi9•TF,lot.86 -3246.0 50 12966.39 9097 934.44 349520 4740.01 825926 000 0.00 903234 Adjust TF to 119.69°,for 842T 51 1317227 8430 257.75 3481.90 4706.88 847214 300 -61.98 9570.98 33-10215.T14109116 MW Hold b 1582 _§ 13809!Bak D 52 1332807 9522 255.93 3483.17 469400-8526.28 3.50 -68.29 9617.52 TO:1295839 NO.34952'TVD 53 1333180 9522 255.93 3470.73 466889 862648 000 0.00 970309 Stat DLS 300 TFO-88.01 - #6099n6193401.3un0Aed26212lhavepseninbmed ]` BB �tl ], B 4•,6.0 9 BBmSpByo9]38 2r4„R i6 Ti518J116' o �„M.�,..,.o Tf..BB.L,M 55B 4304618801,,av3darcepenes0elo2l,Nea.aI p090,1 4 l^4S'`23 �6d p dr6 •ea0406 0*"3' n3!244hO!S4,211&9e�Rlla2a31e0,Oa1a1104037103]3' berate. ' 9'93 06790 068 d �ta13TLWD15,35.01°TFb 30.92' S7.1425L9b..bRQP-- b--9477,2Z.-.2.011--LflL2bJD;k7.4Z..39:tVZ1Z.I1bJA 116 Mw -./.QiygLlF.q:bISA:.Y[77RZ@ 1 Prepared by: Checked by: Accepted by: Approved by: B.Temple N.Beck E.Sterk K.Hallford i • Spider View • • 12:00,February 06 2017 I , I Easting(3000 usft/in) :e:o� � 010704 `OPO%'1::;.:;ca r I S-06PB2 PB1 OPO-07P6 P03-'$5L1 - 7-02 •e .,r?,j — Oliktok•'nt I- _ OP16-03 0111 .1 0P03-'05PB. 0120-07 OP16-03L1 •PO. r•�'';sa-W I2 OP16-03L1P61 - Oliktok•• I- •62 0120-07PB 0111-0 ':1 II nPO=04L1•i.1 - A O•:. iSP.• 1 OP21-W 01 - •• • •:1 Oliktok Point I-1 •12Oliktok P. ��\W i. 0P03-Pi 5PB Ilik.k Point State 1 0-� PB7 30-10 .i 1°6w01 `�•._ L. / 30-00 vaID;�P4fdQ.�05wp02 — OP05-06PB1 H _ 3R-102wp09 _�1 �� z o to M 6-10 w 0 0 c— o - 3R-10A t 3R-15 e. c _ z _ — 3Q-03AL1 Oliktok'T 2A • 3Q-03 Kuparuk 3R Pad _��:::::: 3R-12A ` - rr 1 1ilok PT 2 R-25 (� 3* 01 -OS 3Q-04 3R-22 3•-20 3R-26PB1 30-08A 3R 19 � -6IV:E3 -10 `1 30-15 -�—� a.)or" -01 30-01 • r 3C=03 ==*�1e Kuparuk 30 Pa Z •§/,LI P 1-26 3•'-08L1-03 _ , 4,011411:.-• _ - 30-08L r .. • ' `ti QL1Q9Y7 ` _ Easting(3000 usft/in) Plan View • 0 3R-102wp09 Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 3R-102 17.T16 103116 MW 3R-102 12.T11 103116 M 3R-102 4.T3 103116 MW 3R-10 ,15.T14 103116 MW 3R-102 11. T10 103116 MW 3R-102 2. Heel 103116 MIN 3R 102 14.T13 103116 MW 3R-102 10.T9 103116 MW" 6000— , 3R-102 3. T2 103116 MW -A 3R-W02 1.Top D 010816 MSN o 4 1/2"x 6-3/, - .P .D .: .:'.: • : ;-.= :: 4500— T 'Vb. • \ , 'a0 3000 3R-102 13.T12 103116 MW ', '3R-102 5.T4 103116 MW + 3R-102 16.T15 103116 MW ' 3R-1b2 6. T5 103116 MW '30'3° Z 3R-102 18.T17 103116 MW 3R-102 7.T6 103116 MW 0500— 3R-102 19.TD 103116 MW 3R-102 8.T7 103116 MW L 0 3R-102 9.T8 103116 MW 00 0 10 3/4"x '' °13-1/2- 440- 20"x 42" -1500— I I I I I I 1 I 1 1 -12000 -10500 -9000 -7500 -6000 -4500 -3000 -1500 0 1500 West(-)/East(+) (1500 usft/in) Section View • • 3R-102wp09 Section View 3R-102 11.T10 103116 MN 3R-102 13.T12 103116 M$N3R-102 15.T14 103116 Mi/V3R-102 17.T16 103116 Min/ -1500- 3R-102 12.T11 103116 MfR-102,14.T13 103116 MW3R-102 16.T15 103116 Mit3R-102 18.T17 103116 ON 0– 20"x 42" • 3Rr1102 19,s TD 103116 MW "C7) 0° 0 o T3 100 10 3/4"x 13-1/2 L 1500–,' Base Pfrost - wT o0 o K1 5\ - be 0 7-5/8"x 9-7/8 \4 1/2"x 6-3/4" , Top Ugnu G�,`b o 00 0 Top Ugnu B o 0 0,'� > 3000 Top Ugnu n c � rnrn H Top Top N Sands ,. - — `. --:o `Q o 9 J-' o IR-102 19.TD 1/4 Mils Base West Sak D �' - o 4500– 3R-102 10.19 103116 MW Fault - — Top West Sak D 3R-102 9.T8 103116 MW 6000- 3R-102 2. Heel 103116 MW3R-1 Q2 3.T2 103116 M -102 5.T4 103116 M' 3R-102 7.T6 10311644 3R-W02 1.Top D 010816 N 3R-102 2.Heel 1/4 Mil:3R-102 4.T3 103116 M 3R-102 6.T5 103116 M 3R-102 8.T7 103116 M I I I I I I I I I 0 1500 3000 4500 6000 7500 9000 10500 12000 Vertical Section at 290.00°(1500 usft/in) Plan Report FE • • ` ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3R Pad Plan: 3R-102 Plan: 3R-102 Tier Challenging 2Orientation Plan: 3R-102wp09 4 Standard Proposal Report II p p 10 January, 2017 0, 4 4s 0 • Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan:3R-102 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan 39+9.9 @ 48.90usft(Doyon142) Project: Kuparuk River Unit MD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Site: Kuparuk 3R Pad North Reference: True Well: Plan:3R-102 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3R-102 Design: 3R-102wp09 Project Kuparuk River Unit,North Slope Alaska,United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 3R Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.16 ° Well Plan:3R-102 Well Position +N/-S 0.00 usft Northing: Latitude: +E/-W 0.00 usft Easting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 9.90 usft Wellbore Plan:3R-102 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1 (1 (nT) BGGM2016 2/1/2017 17.82 81.04 57,553 Design 3R-102wp09 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section Depth From(TVD) +N/-S +E/-WDirection ,. ...4_ _.. . i (usft) (usft) (usft) (°) _ 39.00 0.00 0.00 290.00 1/10/2017 1:11:18PM Page 2 COMPASS 5000.1 Build 74 S • ,„,„,„ ., ,, , , „,,, Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan:3R-102 kl Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Project: Kuparuk River Unit MD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Site: Kuparuk 3R Pad North Reference: True Well: Plan:3R-102 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3R-102 Design: 3R-102wp09 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +EI-W Rate Rate Rate Tool Face (usft) (0) (°) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) 39.00 0.00 0.00 39.00 -9.90 0.00 0.00 0.00 0.00 0.00 0.00 350.00 0.00 0.00 350.00 301.10 0.00 0.00 0.00 0.00 0.00 0.00 600.18 3.75 290.00 600.00 551.10 2.80 -7.70 1.50 1.50 0.00 290.00 1,734.91 26.45 290.00 1,688.40 1,639.50 103.24 -283.66 2.00 2.00 0.00 0.00 1,846.59 26.45 290.00 1,788.40 1,739.50 120.26 -330.40 0.00 0.00 0.00 0.00 2,336.79 40.26 315.97 2,198.90 2,150.00 272.97 -545.16 4.00 2.82 5.30 57.50 2,356.79 40.26 315.97 2,214.16 2,165.26 282.27 -554.14 0.00 0.00 0.00 0.00 3,453.14 80.06 338.17 2,753.71 2,704.81 1,077.41 -1,024.32 4.00 3.63 2.02 32.49 6,221.64 80.06 338.17 3,231.60 3,182.70 3,608.80 -2,038.36 0.00 0.00 0.00 0.00 8,477.36 86.00 270.16 3,541.90 3,493.00 4,782.90 -3,784.45 3.00 0.26 -3.02 -90.26 8,503.94 86.80 270.16 3,543.57 3,494.67 4,782.97 -3,810.98 3.00 3.00 0.00 0.00 8,864.60 86.80 270.16 3,563.71 3,514.81 4,783.95 -4,171.07 0.00 0.00 0.00 0.00 8,868.02 86.90 270.16 3,563.90 3,515.00 4,783.96 -4,174.49 3.00 2.97 0.00 0.00 8,888.02 86.90 270.16 3,564.98 3,516.08 4,784.02 -4,194.46 0.00 0.00 0.00 0.00 8,961.66 88.37 270.16 3,568.02 3,519.12 4,784.22 -4,268.03 2.00 2.00 0.00 0.00 9,141.64 88.37 270.16 3,573.13 3,524.23 4,784.71 -4,447.94 0.00 0.00 0.00 0.00 9,210.28 87.00 270.16 3,575.90 3,527.00 4,784.89 -4,516.52 2.00 -2.00 0.00 180.00 9,412.60 91.05 270.16 3,579.35 3,530.45 4,785.45 -4,718.77 2.00 2.00 0.00 0.00 9,601.42 91.05 270.16 3,575.90 3,527.00 4,785.96 -4,907.56 0.00 0.00 0.00 0.00 9,631.78 91.65 270.16 3,575.19 3,526.29 4,786.04 -4,937.91 2.00 1.99 0.00 0.00 9,859.30 91.65 270.16 3,568.63 3,519.73 4,786.66 -5,165.33 0.00 0.00 0.00 0.00 9,926.61 93.00 270.16 3,565.90 3,517.00 4,786.85 -5,232.59 2.00 2.00 0.00 0.00 9,997.98 91.57 270.16 3,563.05 3,514.15 4,787.04 -5,303.89 2.00 -2.00 0.00 -180.00 10,118.44 91.57 270.16 3,559.75 3,510.85 4,787.37 -5,424.31 0.00 0.00 0.00 0.00 10,189.80 93.00 270.16 3,556.90 3,508.00 4,787.56 -5,495.61 2.00 2.00 0.00 0.00 10,269.06 91.41 270.16 3,553.85 3,504.95 4,787.78 -5,574.81 2.00 -2.00 0.00 -180.00 10,428.94 91.41 270.16 3,549.90 3,501.00 4,788.21 -5,734.64 0.00 0.00 0.00 0.00 10,455.56 91.95 270.16 3,549.12 3,500.22 4,788.29 -5,761.25 2.00 2.00 0.00 0.00 10,648.74 91.95 270.16 3,542.55 3,493.65 4,788.81 -5,954.32 0.00 0.00 0.00 0.00 10,746.11 90.00 270.16 3,540.90 3,492.00 4,789.08 -6,051.67 2.00 -2.00 0.00 180.00 10,746.11 90.00 270.16 3,540.90 3,492.00 4,789.08 -6,051.67 2.00 0.00 0.00 0.00 11,037.14 90.00 270.16 3,540.90 3,492.00 4,789.87 -6,342.70 0.00 0.00 0.00 0.00 11,037.14 90.00 270.16 3,540.90 3,492.00 4,789.87 -6,342.70 2.00 0.00 0.00 0.00 11,085.83 90.97 270.16 3,540.49 3,491.59 4,790.00 -6,391.38 2.00 2.00 0.00 0.04 11,272.51 90.97 270.16 3,537.31 3,488.41 4,790.51 -6,578.04 0.00 0.00 0.00 0.00 11,321.20 90.00 270.15 3,536.90 3,488.00 4,790.64 -6,626.72 2.00 -2.00 -0.01 -179.60 11,330.80 89.81 270.12 3,536.92 3,488.02 4,790.67 -6,636.32 2.00 -1.98 -0.29 -171.73 11,496.37 89.81 270.12 3,537.46 3,488.56 4,791.02 -6,801.89 0.00 0.00 0.00 0.00 11,601.24 91.90 270.30 3,535.90 3,487.00 4,791.41 -6,906.75 2.00 1.99 0.17 4.86 11,688.40 93.63 270.52 3,531.70 3,482.80 4,792.03 -6,993.80 2.00 1.98 0.25 7.17 11,785.44 93.63 270.52 3,525.55 3,476.65 4,792.90 -7,090.64 0.00 0.00 0.00 0.00 11,883.69 91.80 269.80 3,520.90 3,472.00 4,793.18 -7,188.77 2.00 -1.86 -0.73 -158.58 11,973.69 90.13 269.12 3,519.38 3,470.48 4,792.33 -7,278.75 2.00 -1.85 -0.76 -157.82 12,175.94 90.13 269.12 3,518.91 3,470.01 4,789.22 -7,480.98 0.00 0.00 0.00 0.00 12,256.82 91.30 268.00 3,517.90 3,469.00 4,787.19 -7,561.83 2.00 1.44 -1.39 -43.83 12,335.84 92.39 266.85 3,515.36 3,466.46 4,783.64 -7,640.72 2.00 1.37 -1.45 -46.56 12,658.12 92.39 266.85 3,501.94 3,453.04 4,765.96 -7,962.23 0.00 0.00 0.00 0.00 12,713.98 91.80 265.90 3,499.90 3,451.00 4,762.43 -8,017.94 2.00 -1.05 -1.70 ,-121.63 1/10/2017 1:11:18PM Page 3 COMPASS 5000.1 Build 74 • 0 Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan:3R-102 Company: . ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Project: Kuparuk River Unit MD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Site: Kuparuk 3R Pad North Reference: True ii Well: Plan:3R-102 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3R-102 Design: 3R-102wp09 12,798.19 90.97 264.44 3,497.87 3,448.97 4,755.34 -8,101.83 2.00 -0.99 -1.74 -119.69 12,956.39 90.97 264.44 3,495.20 3,446.30 4,740.01 -8,259.26 0.00 0.00 0.00 0.00 13,172.27 94.50 257.75 3,484.90 3,436.00 4,706.66 -8,472.14 3.50 1.64 -3.10 -61.98 13,228.07 95.22 255.93 3,480.17 3,431.27 4,694.00 -8,526.28 3.50 1.29 -3.27 -68.29 13,331.80 95.22 255.93 3,470.73 3,421.83 4,668.89 -8,626.48 0.00 0.00 0.00 0.00 13,362.72 95.30 255.00 3,467.90 3,419.00 4,661.16 -8,656.28 3.00 0.26 -3.00 -85.01 13,635.50 95.59 246.78 3,441.98 3,393.08 4,572.35 -8,912.65 3.00 0.11 -3.01 -87.59 14,062.09 95.59 246.78 3,400.43 3,351.53 4,404.99 -9,302.84 0.00 0.00 0.00 0.00 14,251.49 92.00 248.00 3,387.90 3,339.00 4,332.36 -9,477.27 2.00 -1.89 0.64 161.28 14,348.09 90.09 248.31 3,386.14 3,337.24 4,296.43 -9,566.91 2.00 -1.97 0.33 170.63 14,862.79 90.09 248.31 3,385.29 3,336.39 4,106.24 -10,045.18 0.00 0.00 0.00 0.00 14,939.04 92.00 248.32 3,383.90 3,335.00 4,078.08 -10,116.02 2.50 2.50 0.01 0.16 15,181.35 98.06 248.32 3,362.67 3,313.77 3,988.94 -10,340.22 2.50 2.50 0.00 -0.04 15,507.88 98.06 248.32 3,316.90 3,268.00 3,869.48 -10,640.65 0.00 0.00 0.00 0.00 1/10/2017 1:11.18PM Page 4 COMPASS 5000.1 Build 74 II 0 Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan:3R-102 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Project: Kuparuk River Unit MD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Site: Kuparuk 3R Pad North Reference: True Well: Plan:3R-102 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3R-102 Design: 3R-102wp09 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (0) (0) (usft) usft (usft) (usft) (usft) (usft) -9.90 39.00 0.00 0.00 39.00 -9.90 0.00 0.00 6,031,455.90 1,660,667.09 0.00 0.00 100.00 0.00 0.00 100.00 51.10 0.00 0.00 6,031,455.90 1,660,667.09 0.00 0.00 117.90 0.00 0.00 117.90 69.00 0.00 0.00 6,031,455.90 1,660,667.09 0.00 0.00 20"x 42" 200.00 0.00 0.00 200.00 151.10 0.00 0.00 6,031,455.90 1,660,667.09 0.00 0.00 300.00 0.00 0.00 300.00 251.10 0.00 0.00 6,031,455.90 1,660,667.09 0.00 0.00 350.00 0.00 0.00 350.00 301.10 0.00 0.00 6,031,455.90 1,660,667.09 0.00 0.00 KOP:Start 1.5°/100'DLS,290°TF,for 250.18' 400.00 0.75 290.00 400.00 351.10 0.11 -0.31 6,031,456.02 1,660,666.78 1.50 0.33 500.00 2.25 290.00 499.96 451.06 1.01 -2.77 6,031,456.90 1,660,664.32 1.50 2.94 600.00 3.75 290.00 599.82 550.92 2.80 -7.69 6,031,458.68 1,660,659.40 1.50 8.18 600.18 3.75 290.00 600.00 551.10 2.80 -7.70 6,031,458.68 1,660,659.39 1.50 8.19 Start 2°/100'DLS,0°TF,for 1134.73' 700.00 5.75 290.00 699.47 650.57 5.63 -15.46 6,031,461.49 1,660,651.61 2.00 16.46 800.00 7.75 290.00 798.78 749.88 9.65 -26.51 6,031,465.48 1,660,640.56 2.00 28.21 900.00 9.75 290.00 897.61 848.71 14.85 -40.80 6,031,470.64 1,660,626.25 2.00 43.42 1,000.00 11.75 290.00 995.85 946.95 21.23 -58.33 6,031,476.97 1,660,608.71 2.00 62.07 1,100.00 13.75 290.00 1,093.38 1,044.48 28.78 -79.06 6,031,484.46 1,660,587.96 2.00 84.14 1,200.00 15.75 290.00 1,190.08 1,141.18 37.48 -102.98 6,031,493.10 1,660,564.01 2.00 109.59 1,300.00 17.75 290.00 1,285.83 1,236.93 47.34 -130.06 6,031,502.88 1,660,536.91 2.00 138.41 1,400.00 19.75 290.00 1,380.52 1,331.62 58.33 -160.27 6,031,513.79 1,660,506.68 2.00 170.55 1,500.00 21.75 290.00 1,474.03 1,425.13 70.45 -193.55 6,031,525.82 1,660,473.36 2.00 205.98 1,600.00 23.75 290.00 1,566.24 1,517.34 83.67 -229.89 6,031,538.94 1,660,437.00 2.00 244.64 1,700.00 25.75 290.00 1,657.05 1,608.15 97.99 -269.23 6,031,553.15 1,660,397.62 2.00 286.51 1,734.91 26.45 290.00 1,688.40 1,639.50 103.24 -283.66 6,031,558.36 1,660,383.18 2.00 301.86 Hold for 111.69' 1,735.91 26.45 290.00 1,689.30 1,640.40 103.40 -284.08 6,031,558.52 1,660,382.76 0.00 302.31 T3 1,790.75 26.45 290.00 1,738.40 1,689.50 111.75 -307.03 6,031,566.81 1,660,359.79 0.00 326.73 Base Pfrost 1,800.00 26.45 290.00 1,746.68 1,697.78 113.16 -310.90 6,031,568.20 1,660,355.91 0.00 330.85 1,846.59 26.45 290.00 1,788.40 1,739.50 120.26 -330.40 6,031,575.25 1,660,336.40 0.00 351.60 Start 4°/100'DLS,57.5°TF,for 490.19' 1,900.00 27.65 293.88 1,835.97 1,787.07 129.34 -352.91 6,031,584.27 1,660,313.86 4.00 375.86 2,000.00 30.16 300.34 1,923.52 1,874.62 151.43 -395.82 6,031,606.24 1,660,270.89 4.00 423.75 2,038.81 31.21 302.58 1,956.90 1,908.00 161.77 -412.71 6,031,616.53 1,660,253.98 4.00 443.15 K15 2,100.00 32.94 305.84 2,008.75 1,959.85 180.05 -439.56 6,031,634.74 1,660,227.08 4.00 474.63 2,200.00 35.92 310.55 2,091.24 2,042.34 215.06 -483.91 6,031,669.62 1,660,182.65 4.00 528.28 2,300.00 39.07 314.62 2,170.58 2,121.68 256.28 -528.65 6,031,710.72 1,660,137.80 4.00 584.42 2,336.79 40.26 315.97 2,198.90 2,150.00 272.97 -545.16 6,031,727.36 1,660,121.24 4.00 605.65 Hold for 20'-10 3/4"x 13-1/2 2,356.79 40.26 315.97 2,214.16 2,165.26 282.27 -554.14 6,031,736.63 1,660,112.23 0.00 617.27 Start 4°/100'DLS,32.49°TF,for 1096.35' 2,400.00 41.73 317.37 2,246.78 2,197.88 302.89 -573.59 6,031,757.20 1,660,092.73 4.00 642.59 1/10/2017 1:11:18PM Page 5 COMPASS 5000.1 Build 74 • 0 , „ ,,,_„,,, _ _ ____ _ Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan 3R-102 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Project: Kuparuk River Unit MD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Site: Kuparuk 3R Pad North Reference: True Well: Plan:3R-102 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3R-102 Design: 3R-102wp09 Planned Survey z .,'�- ns as' '� � ' zAr---_'11- .r-ro -'ate,�,.r`i4#! =.u.,,. -. ... j Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-5 +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 2,270.47 2,500.00 45.18 320.31 2,319.37 2,270.47 354.68 -618.80 6,031,808.86 1,660,047.39 4.00 702.79 2,600.00 48.70 322.91 2,387.64 2,338.74 411.96 -664.12 6,031,866.01 1,660,001.92 4.00 764.96 2,700.00 52.27 325.25 2,451.27 2,402.37 474.44 -709.33 6,031,928.36 1,659,956.54 4.00 828.82 2,800.00 55.88 327.37 2,509.93 2,461.03 541.82 -754.21 6,031,995.61 1,659,911.48 4.00 894.04 2,900.00 59.53 329.31 2,563.35 2,514.45 613.76 -798.55 6,032,067.43 1,659,866.95 4.00 960.31 3,000.00 63.20 331.11 2,611.27 2,562.37 689.93 -842.12 6,032,143.47 1,659,823.18 4.00 1,027.30 3,100.00 66.90 332.80 2,653.45 2,604.55 769.95 -884.71 6,032,223.36 1,659,780.37 4.00 1,094.70 3,200.00 70.61 334.40 2,689.68 2,640.78 853.43 -926.13 6,032,306.72 1,659,738.73 4.00 1,162.16 3,300.00 74.34 335.93 2,719.79 2,670.89 939.95 -966.15 6,032,393.13 1,659,698.48 4.00 1,229.37 3,400.00 78.07 337.40 2,743.63 2,694.73 1,029.11 -1,004.60 6,032,482.17 1,659,659.79 4.00 1,295.99 3,453.14 80.06 338.17 2,753.71 2,704.81 1,077.41 -1,024.32 6,032,530.41 1,659,639.94 4.00 1,331.04 Hold for 2768.5' 3,500.00 80.06 338.17 2,761.80 2,712.90 1,120.26 -1,041.49 6,032,573.21 1,659,622.66 0.00 1,361.83 3,561.98 80.06 338.17 2,772.50 2,723.60 1,176.93 -1,064.19 6,032,629.82 1,659,599.80 0.00 1,402.55 Top Ugnu C 3,600.00 80.06 338.17 2,779.06 2,730.16 1,211.70 -1,078.11 6,032,664.54 1,659,585.79 0.00 1,427.52 3,700.00 80.06 338.17 2,796.32 2,747.42 1,303.13 -1,114.74 6,032,755.86 1,659,548.91 0.00 1,493.21 3,800.00 80.06 338.17 2,813.59 2,764.69 1,394.57 -1,151.37 6,032,847.19 1,659,512.04 0.00 1,558.90 3,900.00 80.06 338.17 2,830.85 2,781.95 1,486.00 -1,188.00 6,032,938.52 1,659,475.17 0.00 1,624.59 4,000.00 80.06 338.17 2,848.11 2,799.21 1,577.44 -1,224.63 6,033,029.84 1,659,438.29 0.00 1,690.29 4,100.00 80.06 338.17 2,865.37 2,816.47 1,668.87 -1,261.25 6,033,121.17 1,659,401.42 0.00 1,755.98 4,200.00 80.06 338.17 2,882.63 2,833.73 1,760.31 -1,297.88 6,033,212.49 1,659,364.55 0.00 1,821.67 4,300.00 80.06 338.17 2,899.89 2,850.99 1,851.74 -1,334.51 6,033,303.82 1,659,327.67 0.00 1,887.36 4,400.00 80.06 338.17 2,917.15 2,868.25 1,943.18 -1,371.14 6,033,395.15 1,659,290.80 0.00 1,953.05 4,500.00 80.06 338.17 2,934.42 2,885.52 2,034.61 -1,407.76 6,033,486.47 1,659,253.93 0.00 2,018.75 4,600.00 80.06 338.17 2,951.68 2,902.78 2,126.05 -1,444.39 6,033,577.80 1,659,217.05 0.00 2,084.44 4,700.00 80.06 338.17 2,968.94 2,920.04 2,217.48 -1,481.02 6,033,669.12 1,659,180.18 0.00 2,150.13 4,800.00 80.06 338.17 2,986.20 2,937.30 2,308.92 -1,517.65 6,033,760.45 1,659,143.31 0.00 2,215.82 4,900.00 80.06 338.17 3,003.46 2,954.56 2,400.36 -1,554.28 6,033,851.78 1,659,106.43 0.00 2,281.51 4,963.36 80.06 338.17 3,014.40 2,965.50 2,458.29 -1,577.48 6,033,909.64 1,659,083.07 0.00 2,323.14 Top Ugnu B 5,000.00 80.06 338.17 3,020.72 2,971.82 2,491.79 -1,590.90 6,033,943.10 1,659,069.56 0.00 2,347.20 5,100.00 80.06 338.17 3,037.99 2,989.09 2,583.23 -1,627.53 6,034,034.43 1,659,032.69 0.00 2,412.90 5,200.00 80.06 338.17 3,055.25 3,006.35 2,674.66 -1,664.16 6,034,125.76 1,658,995.81 0.00 2,478.59 5,300.00 80.06 338.17 3,072.51 3,023.61 2,766.10 -1,700.79 6,034,217.08 1,658,958.94 0.00 2,544.28 5,400.00 80.06 338.17 3,089.77 3,040.87 2,857.53 -1,737.42 6,034,308.41 1,658,922.07 0.00 2,609.97 5,500.00 80.06 338.17 3,107.03 3,058.13 2,948.97 -1,774.04 6,034,399.73 1,658,885.19 0.00 2,675.66 5,600.00 80.06 338.17 3,124.29 3,075.39 3,040.40 -1,810.67 6,034,491.06 1,658,848.32 0.00 2,741.35 5,700.00 80.06 338.17 3,141.56 3,092.66 3,131.84 -1,847.30 6,034,582.39 1,658,811.45 0.00 2,807.05 5,800.00 80.06 338.17 3,158.82 3,109.92 3,223.27 -1,883.93 6,034,673.71 1,658,774.58 0.00 2,872.74 5,900.00 80.06 338.17 3,176.08 3,127.18 3,314.71 -1,920.56 6,034,765.04 1,658,737.70 0.00 2,938.43 6,000.00 80.06 338.17 3,193.34 3,144.44 3,406.14 -1,957.18 6,034,856.37 1,658,700.83 0.00 3,004.12 6,100.00 80.06 338.17 3,210.60 3,161.70 3,497.58 -1,993.81 6,034,947.69 1,658,663.96 0.00 3,069.81 6,200.00 80.06 338.17 3,227.86 3,178.96 3,589.02 -2,030.44 6,035,039.02 1,658,627.08 0.00 3,135.50 1/10/2017 1:11:18PM Page 6 COMPASS 5000.1 Build 74 • • Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan:3R-102 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Project: Kuparuk River Unit MD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Site: Kuparuk 3R Pad North Reference: True Well: Plan:3R-102 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3R-102 Design: 3R-102wp09 `" ---------- -Planned Survey 1 W .,::;. ate .a e,'F"'N a : ;?W- - 7 -`r. ,- ;"' ' 'ti. V4 -. v Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section ' (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 3,182.70 6,221.64 80.06 338.17 3,231.60 3,182.70 3,608.80 -2,038.36 6,035,058.78 1,658,619.10 0.00 3,149.72 Start 3°/100'DLS,-90.26°TF,for 2255.73' 6,300.00 80.06 335.78 3,245.13 3,196.23 3,679.83 -2,068.55 6,035,129.72 1,658,588.73 3.00 3,202.38 6,305.05 80.06 335.63 3,246.00 3,197.10 3,684.37 -2,070.60 6,035,134.25 1,658,586.67 3.00 3,205.85 Top Ugnu A 6,400.00 80.08 332.74 3,262.38 3,213.48 3,768.55 -2,111.32 6,035,218.31 1,658,545.72 3.00 3,272.91 6,500.00 80.13 329.69 3,279.57 3,230.67 3,854.88 -2,158.75 6,035,304.50 1,658,498.06 3.00 3,347.01 6,600.00 80.20 326.65 3,296.65 3,247.75 3,938.58 -2,210.71 6,035,388.05 1,658,445.87 3.00 3,424.46 6,700.00 80.31 323.61 3,313.58 3,264.68 4,019.43 -2,267.06 6,035,468.74 1,658,389.32 3.00 3,505.06 6,719.75 80.33 323.01 3,316.90 3,268.00 4,035.04 -2,278.69 6,035,484.32 1,658,377.64 3.00 3,521.33 TD-TD 6,800.00 80.44 320.57 3,330.31 3,281.41 4,097.20 -2,327.63 6,035,546.34 1,658,328.54 3.00 3,588.58 6,842.24 80.50 319.28 3,337.30 3,288.40 4,129.08 -2,354.45 6,035,578.14 1,658,301.63 3.00 3,624.69 Top West Sak D 6,900.00 80.60 317.53 3,346.79 3,297.89 4,171.69 -2,392.27 6,035,620.64 1,658,263.70 3.00 3,674.80 7,000.00 80.78 314.49 3,362.97 3,314.07 4,242.68 -2,460.80 6,035,691.44 1,658,194.99 3.00 3,763.48 7,100.00 80.99 311.46 3,378.82 3,329.92 4,309.98 -2,533.03 6,035,758.54 1,658,122.58 3.00 3,854.37 7,157.70 81.12 309.72 3,387.80 3,338.90 4,347.06 -2,576.30 6,035,795.50 1,658,079.21 3.00 3,907.72 Top N Sands 7,200.00 81.22 308.44 3,394.30 3,345.40 4,373.41 -2,608.76 6,035,821.75 1,658,046.69 3.00 3,947.22 7,300.00 81.48 305.41 3,409.34 3,360.44 4,432.79 -2,687.78 6,035,880.92 1,657,967.51 3.00 4,041.79 7,400.00 81.76 302.39 3,423.93 3,375.03 4,487.97 -2,769.88 6,035,935.86 1,657,885.27 3.00 4,137.81 7,500.00 82.06 299.38 3,438.01 3,389.11 4,538.78 -2,854.84 6,035,986.44 1,657,800.18 3.00 4,235.02 7,600.00 82.38 296.37 3,451.55 3,402.65 4,585.10 -2,942.41 6,036,032.51 1,657,712.49 3.00 4,333.16 7,698.32 82.72 293.41 3,464.30 3,415.40 4,626.13 -3,030.83 6,036,073.30 1,657,623.96 3.00 4,430.28 Base West Sak D 7,700.00 82.73 293.36 3,464.51 3,415.61 4,626.79 -3,032.36 6,036,073.95 1,657,622.43 3.00 4,431.94 7,800.00 83.09 290.36 3,476.86 3,427.96 4,663.74 -3,124.45 6,036,110.65 1,657,530.26 3.00 4,531.12 7,900.00 83.48 287.37 3,488.56 3,439.66 4,695.84 -3,218.42 6,036,142.49 1,657,436.21 3.00 4,630.40 7,990.91 83.84 284.65 3,498.60 3,449.70 4,720.76 -3,305.26 6,036,167.17 1,657,349.31 3.00 4,720.53 Fault 8,000.00 83.88 284.38 3,499.57 3,450.67 4,723.02 -3,314.01 6,036,169.41 1,657,340.55 3.00 4,729.52 8,100.00 84.29 281.39 3,509.88 3,460.98 4,745.19 -3,410.96 6,036,191.31 1,657,243.55 3.00 4,828.21 8,200.00 84.73 278.41 3,519.44 3,470.54 4,762.30 -3,509.01 6,036,208.15 1,657,145.46 3.00 4,926.20 8,300.00 85.18 275.43 3,528.25 3,479.35 4,774.29 -3,607.89 6,036,219.88 1,657,046.57 3.00 5,023.21 8,400.00 85.64 272.45 3,536.26 3,487.36 4,781.14 -3,707.32 6,036,226.45 1,656,947.13 3.00 5,118.99 8,477.36 86.00 270.16 3,541.90 3,493.00 4,782.90 -3,784.45 6,036,228.00 1,656,870.00 3.00 5,192.07 Adjust TF to 0°,for 26.58' 8,500.00 86.68 270.16 3,543.35 3,494.45 4,782.96 -3,807.04 6,036,228.00 1,656,847.41 3.00 5,213.32 8,503.94 86.80 270.16 3,543.57 3,494.67 4,782.97 -3,810.98 6,036,228.00 1,656,843.48 3.00 5,217.02 Hold for 360.66' 8,579.69 86.80 270.16 3,547.80 3,498.90 4,783.18 -3,886.61 6,036,228.00 1,656,767.85 0.00 5,288.16 Top West Sak D 8,600.00 86.80 270.16 3,548.93 3,500.03 4,783.23 -3,906.89 6,036,228.00 1,656,747.58 0.00 5,307 23 8,700.00 86.80 270.16 3,554.52 3,505.62 4,783.51 -4,006.73 6,036,228.00 1,656,647.74 0.00 5,401.15 1/10/2017 1:11:18PM Page 7 COMPASS 5000.1 Build 74 II • Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan:3R-102 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:39+9.9©48.90usft(Doyon142) Project: Kuparuk River Unit MD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Site: Kuparuk 3R Pad North Reference: True Well: Plan:3R-102 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3R-102 Design: 3R-102wp09 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 3,511.20 8,800.00 86.80 270.16 3,560.10 3,511.20 4,783.78 -4,106.57 6,036,228.00 1,656,547.91 0.00 5,495.06 8,864.60 86.80 270.16 3,563.71 3,514.81 4,783.95 -4,171.07 6,036,228.00 1,656,483.42 0.00 5,555.73 Start 3°/100'DLS,0°TF,for 3.42' 8,868.02 86.90 270.16 3,563.90 3,515.00 4,783.96 -4,174.49 6,036,228.00 1,656,480.00 2.97 5,558.95 Hold for 20'-7-5/8"x 9-7/8" 8,888.02 86.90 270.16 3,564.98 3,516.08 4,784.02 -4,194.46 6,036,228.00 1,656,460.03 0.00 5,577.73 Start 2°/100'DLS,0°TF,for 73.64' 8,900.00 87.14 270.16 3,565.60 3,516.70 4,784.05 -4,206.42 6,036,228.00 1,656,448.07 2.00 5,588.98 8,961.66 88.37 270.16 3,568.02 3,519.12 4,784.22 -4,268.03 6,036,228.00 1,656,386.46 2.00 5,646.94 Hold for 179.98' 9,000.00 88.37 270.16 3,569.11 3,520.21 4,784.32 -4,306.36 6,036,228.00 1,656,348.14 0.00 5,682.99 9,100.00 88.37 270.16 3,571.95 3,523.05 4,784.59 -4,406.32 6,036,228.00 1,656,248.19 0.00 5,777.01 9,141.64 88.37 270.16 3,573.13 3,524.23 4,784.71 -4,447.94 6,036,228.00 1,656,206.58 0.00 5,816.16 Start 2°/100'DLS,180°TF,for 68.64' 9,200.00 87.21 270.16 3,575.38 3,526.48 4,784.87 -4,506.25 6,036,228.00 1,656,148.26 2.00 5,871.02 9,210.28 87.00 270.16 3,575.90 3,527.00 4,784.89 -4,516.52 6,036,228.00 1,656,138.00 2.00 5,880.67 Adjust TF to 0°,for 202.32' 9,300.00 88.79 270.16 3,579.19 3,530.29 4,785.14 -4,606.18 6,036,228.00 1,656,048.35 2.00 5,965.00 9,400.00 90.79 270.16 3,579.55 3,530.65 4,785.41 -4,706.17 6,036,228.00 1,655,948.37 2.00 6,059.06 9,412.60 91.05 270.16 3,579.35 3,530.45 4,785.45 -4,718.77 6,036,228.00 1,655,935.77 2.00 6,070.91 Hold for 188.82' 9,500.00 91.05 270.16 3,577.75 3,528.85 4,785.68 -4,806.15 6,036,228.00 1,655,848.39 0.00 6,153.11 9,600.00 91.05 270.16 3,575.93 3,527.03 4,785.96 -4,906.14 6,036,228.00 1,655,748.42 0.00 6,247.15 9,601.42 91.05 270.16 3,575.90 3,527.00 4,785.96 -4,907.56 6,036,228.00 1,655,747.00 0.00 6,248.49 Start 2°/100'DLS,0°TF,for 30.36' 9,631.78 91.65 270.16 3,575.19 3,526.29 4,786.04 -4,937.91 6,036,228.00 1,655,716.65 1.99 6,277.04 Hold for 227.51' 9,700.00 91.65 270.16 3,573.22 3,524.32 4,786.23 -5,006.10 6,036,228.00 1,655,648.47 0.00 6,341.18 9,800.00 91.65 270.16 3,570.34 3,521.44 4,786.50 -5,106.06 6,036,228.00 1,655,548.52 0.00 6,435.20 9,859.30 91.65 270.16 3,568.63 3,519.73 4,786.66 -5,165.33 6,036,228.00 1,655,489.25 0.00 6,490.96 Start 2°/100'DLS,0°TF,for 67.32' 9,900.00 92.46 270.16 3,567.17 3,518.27 4,786.77 -5,206.01 6,036,228.00 1,655,448.58 2.00 6,529.22 9,926.61 93.00 270.16 3,565.90 3,517.00 4,786.85 -5,232.59 6,036,228.00 1,655,422.00 2.01 6,554.22 Adjust TF to-180°,for 71.36' 9,997.98 91.57 270.16 3,563.05 3,514.15 4,787.04 -5,303.89 6,036,228.00 1,655,350.70 2.00 6,621.29 Hold for 120.46' 10,000.00 91.57 270.16 3,563.00 3,514.10 4,787.05 -5,305.92 6,036,228.00 1,655,348.68 0.00 6,623.20 10,100.00 91.57 270.16 3,560.25 3,511.35 4,787.32 -5,405.88 6,036,228.00 1,655,248.73 0.00 6,717.22 10,118.44 91.57 270.16 3,559.75 3,510.85 4,787.37 -5,424.31 6,036,228.00 1,655,230.30 0.00 6,734.56 Start 2°/100'DLS,0°TF,for 71.36' 10,189.80 93.00 270.16 3,556.90 3,508.00 4,787.56 -5,495.61 6,036,228.00 1,655,159.00 2.00 6,801.63 Adjust TF to-180°,for 79.26' 10,200.00 92.80 270.16 3,556.38 3,507.48 4,787.59 -5,505.80 6,036,228.00 1,655,148.82 2.00 6,811.21 10,269.06 91.41 270.16 3,553.85 3,504.95 4,787.78 -5,574.81 6,036,228.00 1,655,079.81 2.00 6,876.13 Hold for 159.87' 10,300.00 91.41 270.16 3,553.08 3,504.18 4,787.86 -5,605.74 6,036,228.00 1,655,048.88 0.00 6,905.22 1/10/2017 1:11:18PM Page 8 COMPASS 5000.1 Build 74 • • Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan:3R-102 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:39+9.9©48.90usft(Doyon142) Project: Kuparuk River Unit MD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Site: Kuparuk 3R Pad North Reference: True Well: Plan:3R-102 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3R-102 Design: 3R-102wp09 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +EI-W Northing Easting DLS Vert Section (usft) (°) (0) (usft) usft (usft) (usft) (usft) (usft) 3,501.71 10,400.00 91.41 270.16 3,550.61 3,501.71 4,788.13 -5,705.71 6,036,228.00 1,654,948.92 0.00 6,999.25 10,428.94 91.41 270.16 3,549.90 3,501.00 4,788.21 -5,734.64 6,036,228.00 1,654,920.00 0.00 7,026.46 Start 2°/100'DLS,0°TF,for 26.63' 10,455.56 91.95 270.16 3,549.12 3,500.22 4,788.29 -5,761.25 6,036,228.00 1,654,893.39 2.00 7,051.50 Hold for 193.18' 10,500.00 91.95 270.16 3,547.61 3,498.71 4,788.41 -5,805.66 6,036,228.00 1,654,848.98 0.00 7,093.27 10,600.00 91.95 270.16 3,544.21 3,495.31 4,788.68 -5,905.61 6,036,228.00 1,654,749.05 0.00 7,187.28 10,648.74 91.95 270.16 3,542.55 3,493.65 4,788.81 -5,954.32 6,036,228.00 1,654,700.34 0.00 7,233.10 Start 2°/100'DLS,180°TF,for 97.37' 10,700.00 90.92 270.16 3,541.27 3,492.37 4,788.95 -6,005.56 6,036,228.00 1,654,649.10 2.00 7,281.30 10,746.11 90.00 270.16 3,540.90 3,492.00 4,789.08 -6,051.67 6,036,228.00 1,654,603.00 2.00 7,324.67 Adjust TF to 0°,for 0' 10,800.00 90.00 270.16 3,540.90 3,492.00 4,789.22 -6,105.56 6,036,228.00 1,654,549.12 0.00 7,375.36 10,900.00 90.00 270.16 3,540.90 3,492.00 4,789.50 -6,205.56 6,036,228.00 1,654,449.13 0.00 7,469.42 11,000.00 90.00 270.16 3,540.90 3,492.00 4,789.77 -6,305.56 6,036,228.00 1,654,349.14 0.00 7,563.48 11,037.14 90.00 270.16 3,540.90 3,492.00 4,789.87 -6,342.70 6,036,228.00 1,654,312.00 0.00 7,598.42 Hold for 291.03' 11,085.83 90.97 270.16 3,540.49 3,491.59 4,790.00 -6,391.38 6,036,228.00 1,654,263.32 2.00 7,644.21 Start 2°/100'DLS,0°TF,for 0' 11,100.00 90.97 270.16 3,540.25 3,491.35 4,790.04 -6,405.55 6,036,228.00 1,654,249.15 0.00 7,657.54 11,200.00 90.97 270.16 3,538.55 3,489.65 4,790.32 -6,505.54 6,036,228.00 1,654,149.17 0.00 7,751.59 11,272.51 90.97 270.16 3,537.31 3,488.41 4,790.51 -6,578.04 6,036,228.00 1,654,076.68 0.00 7,819.78 Adjust IF to 0.04°,for 48.69' 11,300.00 90.42 270.15 3,536.98 3,488.08 4,790.59 -6,605.52 6,036,228.00 1,654,049.20 2.00 7,845.64 11,321.20 90.00 270.15 3,536.90 3,488.00 4,790.64 -6,626.72 6,036,228.00 1,654,028.00 2.00 7,865.58 Hold for 186.68' 11,330.80 89.81 270.12 3,536.92 3,488.02 4,790.67 -6,636.32 6,036,228.00 1,654,018.40 2.00 7,874.61 Start 2°/100'DLS,-179.6°TF,for 48.69' 11,400.00 89.81 270.12 3,537.15 3,488.25 4,790.81 -6,705.52 6,036,227.96 1,653,949.21 0.00 7,939.69 11,496.37 89.81 270.12 3,537.46 3,488.56 4,791.02 -6,801.89 6,036,227.90 1,653,852.85 0.00 8,030.31 Adjust TF to-171.73°,for 9.6' 11,500.00 89.88 270.13 3,537.47 3,488.57 4,791.03 -6,805.52 6,036,227.90 1,653,849.22 2.00 8,033.73 11,600.00 91.88 270.30 3,535.94 3,487.04 4,791.40 -6,905.51 6,036,228.00 1,653,749.24 2.00 8,127.81 11,601.24 91.90 270.30 3,535.90 3,487.00 4,791.41 -6,906.75 6,036,228.00 1,653,748.00 2.00 8,128.98 Hold for 165.57' 11,688.40 93.63 270.52 3,531.70 3,482.80 4,792.03 -6,993.80 6,036,228.38 1,653,660.96 2.00 8,210.99 Start 2°/100'DLS,4.86°TF,for 104.88' 11,700.00 93.63 270.52 3,530.96 3,482.06 4,792.13 -7,005.37 6,036,228.46 1,653,649.38 0.00 8,221.90 11,785.44 93.63 270.52 3,525.55 3,476.65 4,792.90 -7,090.64 6,036,229.00 1,653,564.12 0.00 8,302.29 Adjust TF to 7.17°,for 87.15' 11,800.00 93.36 270.41 3,524.67 3,475.77 4,793.02 -7,105.17 6,036,229.07 1,653,549.59 2.00 8,315.99 11,883.69 91.80 269.80 3,520.90 3,472.00 4,793.18 -7,188.77 6,036,229.00 1,653,466.00 2.00 8,394.60 Hold for 97.05' 11,900.00 91.50 269.68 3,520.43 3,471.53 4,793.10 -7,205.08 6,036,228.88 1,653,449.70 2.00 8,409.89 11,973.69 90.13 269.12 3,519.38 3,470.48 4,792.33 -7,278.75 6,036,227.91 1,653,376.04 2.00 8,478.86 Start 2°/100'DLS,-158.58°TF,for 98.25' 1/10/2017 1:11:18PM Page 9 COMPASS 5000.1 Build 74 • • Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan:3R-102 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Project: Kuparuk River Unit MD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Site: Kuparuk 3R Pad North Reference: True Well: Plan:3R-102 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3R-102 Design: 3R-102wp09 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (0) (°) (usft) usft (usft) (usft) (usft) (usft) 3,470.42 12,000.00 90.13 269.12 3,519.32 3,470.42 4,791.92 -7,305.06 6,036,227.43 1,653,349.73 0.00 8,503.45 12,100.00 90.13 269.12 3,519.09 3,470.19 4,790.39 -7,405.05 6,036,225.62 1,653,249.76 0.00 8,596.88 12,175.94 90.13 269.12 3,518.91 3,470.01 4,789.22 -7,480.98 6,036,224.25 1,653,173.83 0.00 8,667.84 Adjust TF to-157.82°,for 90' 12,200.00 90.48 268.79 3,518.78 3,469.88 4,788.78 -7,505.03 6,036,223.75 1,653,149.78 2.00 8,690.29 12,256.82 91.30 268.00 3,517.90 3,469.00 4,787.19 -7,561.83 6,036,222.00 1,653,093.00 2.00 8,743.11 Hold for 202.26' 12,300.00 91.89 267.37 3,516.70 3,467.80 4,785.45 -7,604.95 6,036,220.14 1,653,049.89 2.00 8,783.04 12,335.84 92.39 266.85 3,515.36 3,466.46 4,783.64 -7,640.72 6,036,218.24 1,653,014.13 2.00 8,816.03 Start 2°/100'DLS,-43.83°TF,for 80.88' 12,400.00 92.39 266.85 3,512.69 3,463.79 4,780.12 -7,704.73 6,036,214.54 1,652,950.13 0.00 8,874.98 12,500.00 92.39 266.85 3,508.52 3,459.62 4,774.64 -7,804.49 6,036,208.79 1,652,850.40 0.00 8,966.84 12,600.00 92.39 266.85 3,504.36 3,455.46 4,769.15 -7,904.25 6,036,203.03 1,652,750.66 0.00 9,058.71 12,658.12 92.39 266.85 3,501.94 3,453.04 4,765.96 -7,962.23 6,036,199.68 1,652,692.69 0.00 9,112.11 Adjust TF to-46.56°,for 79.01' 12,700.00 91.95 266.14 3,500.36 3,451.46 4,763.40 -8,004.01 6,036,197.01 1,652,650.93 2.00 9,150.49 4 1/2"x 6-3/4" 12,713.98 91.80 265.90 3,499.90 3,451.00 4,762.43 -8,017.94 6,036,196.00 1,652,637.00 2.00 9,163.25 Hold for 322.28' 12,798.19 90.97 264.44 3,497.87 3,448.97 4,755.34 -8,101.83 6,036,188.68 1,652,553.14 2.00 9,239.65 Start 2°/100'DLS,-121.63°TF,for 55.86' 12,800.00 90.97 264.44 3,497.84 3,448.94 4,755.16 -8,103.63 6,036,188.50 1,652,551.34 0.00 9,241.28 12,900.00 90.97 264.44 3,496.15 3,447.25 4,745.47 -8,203.15 6,036,178.54 1,652,451.86 0.00 9,331.48 12,956.39 90.97 264.44 3,495.20 3,446.30 4,740.01 -8,259.26 6,036,172.92 1,652,395.77 0.00 9,382.34 Adjust TF to-119.69°,for 84.21' 13,000.00 91.68 263.09 3,494.19 3,445.29 4,735.27 -8,302.60 6,036,168.07 1,652,352.45 3.50 9,421.45 13,100.00 93.32 259.99 3,489.83 3,440.93 4,720.58 -8,401.40 6,036,153.11 1,652,253.69 3.50 9,509.27 13,172.27 94.50 257.75 3,484.90 3,436.00 4,706.66 -8,472.14 6,036,139.00 1,652,183.00 3.50 9,570.98 Hold for 158.2' 13,200.00 94.86 256.84 3,482.64 3,433.74 4,700.59 -8,499.10 6,036,132.85 1,652,156.06 3.50 9,594.24 13,228.07 95.22 255.93 3,480.17 3,431.27 4,694.00 -8,526.28 6,036,126.20 1,652,128.91 3.50 9,617.52 TD:12956.39'MD,3495.2'TVD 13,300.00 95.22 255.93 3,473.63 3,424.73 4,676.59 -8,595.76 6,036,108.59 1,652,059.47 0.00 9,676.86 13,331.80 95.22 255.93 3,470.73 3,421.83 4,668.89 -8,626.48 6,036,100.81 1,652,028.78 0.00 9,703.09 Start DLS 3.00 TFO-85.01 13,362.72 95.30 255.00 3,467.90 3,419.00 4,661.16 -8,656.28 6,036,093.00 1,651,999.00 3.00 9,728.46 Adjust TF to-68.29°,for 55.8' 13,400.00 95.35 253.88 3,464.44 3,415.54 4,651.20 -8,692.04 6,036,082.95 1,651,963.27 3.00 9,758.65 13,500.00 95.46 250.87 3,455.02 3,406.12 4,621.06 -8,786.91 6,036,052.55 1,651,868.50 3.00 9,837.49 13,600.00 95.56 247.85 3,445.42 3,396.52 4,585.98 -8,880.05 6,036,017.21 1,651,775.46 3.00 9,913.01 13,635.50 95.59 246.78 3,441.98 3,393.08 4,572.35 -8,912.65 6,036,003.50 1,651,742.90 3.00 9,938.99 Hold for 103.73' 13,700.00 95.59 246.78 3,435.69 3,386.79 4,547.05 -8,971.65 6,035,978.04 1,651,683.98 0.00 9,985.77 13,800.00 95.59 246.78 3,425.96 3,377.06 4,507.82 -9,063.11 6,035,938.56 1,651,592.63 0.00 10,058.30 13,900.00 95.59 246.78 3,416.22 3,367.32 4,468.58 -9,154.58 6,035,899.09 1,651,501.28 0.00 10,130.84 14,000.00 95.59 246.78 3,406.48 3,357.58 4,429.35 -9,246.04 6,035,859.61 1,651,409.93 0.00 10,203.37 1/10/2017 1:11:18PM Page 10 COMPASS 5000.1 Build 74 • • Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan:3R-102 Company: . ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Project: Kuparuk River Unit MD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Site: Kuparuk 3R Pad North Reference: True Well: Plan:3R-102 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3R-102 Design: 3R-102wp09 Planned Survey . Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (0) (usft) usft (usft) (usft) (usft) (usft) 3,351.53 14,062.09 95.59 246.78 3,400.43 3,351.53 4,404.99 -9,302.84 6,035,835.10 1,651,353.21 0.00 10,248.40 Start 3°/100'DLS,-85.01°TF,for 30.92' 14,100.00 94.87 247.03 3,396.98 3,348.08 4,390.19 -9,337.56 6,035,820.20 1,651,318.53 2.00 10,275.97 14,200.00 92.98 247.67 3,390.13 3,341.23 4,351.77 -9,429.63 6,035,781.53 1,651,226.58 2.00 10,349.34 14,251.49 92.00 248.00 3,387.90 3,339.00 4,332.36 -9,477.27 6,035,762.00 1,651,179.00 2.00 10,387.47 Adjust TF to-87.59°,for 272.78' 14,300.00 91.04 248.16 3,386.61 3,337.71 4,314.26 -9,522.25 6,035,743.77 1,651,134.07 2.00 10,423.56 14,348.09 90.09 248.31 3,386.14 3,337.24 4,296.43 -9,566.91 6,035,725.83 1,651,089.46 2.00 10,459.42 Hold for 426.59' 14,400.00 90.09 248.31 3,386.05 3,337.15 4,277.25 -9,615.15 6,035,706.51 1,651,041.28 0.00 10,498.19 14,500.00 90.09 248.31 3,385.89 3,336.99 4,240.30 -9,708.07 6,035,669.31 1,650,948.47 0.00 10,572.87 14,600.00 90.09 248.31 3,385.72 3,336.82 4,203.34 -9,800.99 6,035,632.11 1,650,855.66 0.00 10,647.55 14,700.00 90.09 248.31 3,385.56 3,336.66 4,166.39 -9,893.92 6,035,594.91 1,650,762.84 0.00 10,722.23 14,800.00 90.09 248.31 3,385.40 3,336.50 4,129.44 -9,986.84 6,035,557.71 1,650,670.03 0.00 10,796.91 14,862.79 90.09 248.31 3,385.29 3,336.39 4,106.24 -10,045.18 6,035,534.36 1,650,611.76 0.00 10,843.80 Start 2°/100'DLS,161.28°TF,for 189.4' 14,900.00 91.02 248.32 3,384.93 3,336.03 4,092.49 -10,079.76 6,035,520.51 1,650,577.22 2.50 10,871.59 14,939.04 92.00 248.32 3,383.90 3,335.00 4,078.08 -10,116.02 6,035,506.00 1,650,541.00 2.50 10,900.74 Adjust TF to 170.63°,for 96.6' 15,000.00 93.52 248.32 3,380.96 3,332.06 4,055.58 -10,172.61 6,035,483.35 1,650,484.49 2.50 10,946.21 15,100.00 96.02 248.32 3,372.64 3,323.74 4,018.77 -10,265.20 6,035,446.29 1,650,392.00 2.50 11,020.63 15,181.35 98.06 248.32 3,362.67 3,313.77 3,988.94 -10,340.22 6,035,416.26 1,650,317.07 2.50 11,080.92 Hold for 514.7' 15,200.00 98.06 248.32 3,360.06 3,311.16 3,982.12 -10,357.38 6,035,409.39 1,650,299.93 0.00 11,094.72 15,300.00 98.06 248.32 3,346.04 3,297.14 3,945.53 -10,449.39 6,035,372.56 1,650,208.03 0.00 11,168.66 15,400.00 98.06 248.32 3,332.02 3,283.12 3,908.95 -10,541.39 6,035,335.73 1,650,116.14 0.00 11,242.61 15,500.00 98.06 248.32 3,318.00 3,269.10 3,872.37 -10,633.40 6,035,298.90 1,650,024.24 0.00 11,316.55 15,507.88 98.06 248.32 3,316.90 3,268.00 3,869.48 -10,640.65 6,035,296.00 1,650,017.00 0.00 11,322.38 Start 2.5°/100'DLS,0.16°TF,for 76.25' 1/10/2017 1:11:18PM Page 11 COMPASS 5000.1 Build 74 • • Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan:3R-102 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Project: Kuparuk River Unit MD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Site: Kuparuk 3R Pad North Reference: True Well: Plan:3R-102 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3R-102 Design: 3R-102wp09 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) 3R-W02 2.Heel 121615 DL 0.00 0.00 3,587.90 5,084.45 -4,341.69 6,036,528.00 1,656,312.00 -plan misses target center by 300.55usft at 9036.67usft MD(3570.15 TVD,4784.42 N,-4343.01 E) -Circle(radius 100.00) 3R-102 14.T13 031116 MW 0.00 0.00 3,560.90 4,775.09 -7,890.90 6,036,209.00 1,652,764.00 -plan misses target center by 56.16usft at 12583.99usft MD(3505.03 TVD,4770.03 N,-7888.29 E) -Circle(radius 100.00) 3R-W02 4.T2 121615 DL 0.00 0.00 3,568.90 5,090.77 -6,661.91 6,036,528.00 1,653,992.00 -plan misses target center by 301.74usft at 11357.13usft MD(3537.00 TVD,4790.72 N,-6662.66 E) -Circle(radius 100.00) 3R-102 12.T11 103116 MW 0.00 0.00 3,520.90 4,793.18 -7,188.77 6,036,229.00 1,653,466.00 -plan hits target center -Circle(radius 100.00) 3R-102 3.T2 031116 MW 0.00 0.00 3,576.90 4,784.81 -4,486.52 6,036,228.00 1,656,168.00 -plan misses target center by 2.41 usft at 9180.34usft MD(3574.49 TVD,4784.81 N,-4486.61 E) -Circle(radius 100.00) 3R-102 13.T12 031116 MW 0.00 0.00 3,566.90 4,792.67 -7,369.79 6,036,228.00 1,653,285.00 -plan misses target center by 47.76usft at 12064.60usft MD(3519.17 TVD,4790.93 N,-7369.66 E) -Circle(radius 100.00) 3R-102 14.T13 103116 MW 0.00 0.00 3,499.90 4,762.43 -8,017.94 6,036,196.00 1,652,637.00 -plan hits target center -Circle(radius 100.00) 3R-102 8.T7 103116 MW 0.00 0.00 3,540.90 4,789.08 -6,051.67 6,036,228.00 1,654,603.00 -plan hits target center -Circle(radius 100.00) 3R-102 15.T14 103116 MW 0.00 0.00 3,484.90 4,706.66 -8,472.14 6,036,139.00 1,652,183.00 -plan hits target center -Circle(radius 100.00) 3R-W02 1.Top D 121615 DL 0.00 0.00 3,554.90 5,082.93 -3,783.63 6,036,528.00 1,656,870.00 -plan misses target center by 300.31 usft at 8478.19usft MD(3541.96 TVD,4782.90 N,-3785.28 E) -Circle(radius 100.00) 3R-W02 2.T2 072715 MW 0.00 0.00 3,570.90 5,331.98 -5,262.11 6,036,773.00 1,655,391.00 -plan misses target center by 545.09usft at 9957.39usft MD(3564.45 TVD,4786.93 N,-5263.33 E) -Circle(radius 100.00) 3R-W02 7.T5-Top WSD 010816 MW 0.00 0.00 3,409.90 4,389.00 -9,342.10 6,035,819.00 1,651,314.00 -plan misses target center by 13.29usft at 14103.75usft MD(3396.66 TVD,4388.73 N,-9341.00 E) -Circle(radius 100.00) 3R-102 10.T9 031116 MW 0.00 0.00 3,565.90 4,790.56 -6,597.72 6,036,228.00 1,654,057.00 -plan misses target center by 28.85usft at 11291.84usft MD(3537.05 TVD,4790.57 N,-6597.37 E) -Circle(radius 100.00) 3R-W02 1.Top D 010816 MW 0.00 0.00 3,541.90 4,782.90 -3,784.45 6,036,228.00 1,656,870.00 -plan hits target center -Circle(radius 100.00) 3R-102 3.T2 103116 MW 0.00 0.00 3,575.90 4,784.89 -4,516.52 6,036,228.00 1,656,138.00 -plan hits target center -Circle(radius 100.00) 3R-102 13.T12 103116 MW 0.00 0.00 3,517.90 4,787.19 -7,561.83 6,036,222.00 1,653,093.00 -plan hits target center -Circle(radius 100.00) 3R-1024.T3 103116 MW 0.00 0.00 3,575.90 4,785.96 -4,907.56 6,036,228.00 1,655,747.00 -.lan hits tar.et center 1/10/2017 1.11:18PM Page 12 COMPASS 5000.1 Build 74 • 0 ,, , ,-, ,_ . „. ,,. Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan:3R-102 - Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Project: Kuparuk River Unit MD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Site: Kuparuk 3R Pad North Reference: True Well: Plan:3R-102 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3R-102 Design: 3R-102wp09 II-Circle(radius 100.00) 3R-102 11.110 031116 MW 0.00 0.00 3,565.90 4,791.34 -6,880.75 6,036,228.00 1,653,774.00 -plan misses target center by 29.25usft at 11574.78usft MD(3536.66 TVD,4791.28 N,-6880.30 E) -Circle(radius 100.00) 3R-102 2.Heel 103116 MW Circle 0.00 0.00 3,563.90 4,783.96 -4,174.49 6,036,228.00 1,656,480.00 -plan hits target center -Circle(radius 1,320.00) 3R-102 11.110 103116 MW 0.00 0.00 3,535.90 4,791.41 -6,906.75 6,036,228.00 1,653,748.00 -plan hits target center -Circle(radius 100.00) 3R-W02 3.T1 121615 DL 0.00 0.00 3,593.90 5,085.59 -4,760.73 6,036,528.00 1,655,893.00 -plan misses target center by 300.42usft at 9455.10usft MD(3578.57 TVD,4785.56 N,-4761.26 E) -Circle(radius 100.00) 3R-W02 1.West Sak D 072715 0.00 0.00 3,555.90 5,330.81 -4,833.07 6,036,773.00 1,655,820.00 -plan misses target center by 545.47usft at 9528.79usft MD(3577.23 TVD,4785.76 N,-4834.94 E) -Circle(radius 100.00) 3R-W02 5.T3 TD Liner 010816 MW 0.00 0.00 3,567.90 4,793.37 -7,625.82 6,036,228.00 1,653,029.00 -plan misses target center by 52.65usft at 12318.51usft MD(3516.04 TVD,4784.56 N,-7623.43 E) -Circle(radius 100.00) 3R-102 2.Heel 031116 MW 0.00 0.00 3,552.90 4,783.49 -4,001.47 6,036,228.00 1,656,653.00 -plan misses target center by 1.32usft at 8694.66usft MD(3554.22 TVD,4783.49 N,-4001.40 E) -Circle(radius 100.00) 3R-102 16.T15 031116 MW 0.00 0.00 3,435.90 4,452.59 -9,189.91 6,035,883.00 1,651,466.00 -plan misses target center by 23.38usft at 13936.67usft MD(3412.65 TVD,4454.20 N,-9188.12 E) -Circle(radius 100.00) 3R-102 19.TD 103116 MW 0.00 0.00 3,316.90 3,869.48 -10,640.65 6,035,296.00 1,650,017.00 -plan hits target center -Circle(radius 100.00) 3R-102 5.T4 031116 MW 0.00 0.00 3,587.90 4,786.80 -5,214.59 6,036,228.00 1,655,440.00 -plan misses target center by 21.09usft at 9907.58usft MD(3566.83 TVD,4786.79 N,-5213.58 E) -Circle(radius 100.00) 3R-102 4.T3 031116 MW 0.00 0.00 3,591.90 4,785.88 -4,878.55 6,036,228.00 1,655,776.00 -plan misses target center by 15.47usft at 9572.13usft MD(3576.43 TVD,4785.88 N,-4878.27 E) -Circle(radius 100.00) 3R-W02 3.T3 072715 MW 0.00 0.00 3,560.90 5,335.56 -6,576.23 6,036,773.00 1,654,077.00 -plan misses target center by 545.56usft at 11271.80usft MD(3537.33 TVD,4790.51 N,-6577.32 E) -Circle(radius 100.00) 3R-W02 8.TD above Nb Sand 121615 DL 0.00 0.00 3,234.90 4,362.10 -10,115.25 6,035,790.00 1,650,541.00 -plan misses target center by 303.55usft at 14833.60usft MD(3385.34 TVD,4117.03 N,-10018.06 E) -Circle(radius 100.00) 3R-102 17.TD 031116 MW 0.00 0.00 3,379.90 4,324.41 -9,495.29 6,035,754.00 1,651,161.00 -plan misses target center by 7.40usft at 14271.38usft MD(3387.27 TVD,4324.92 N,-9495.71 E) -Circle(radius 100.00) 3R-W02 5.T5 072715 MW 0.00 0.00 3,473.90 5,342.09 -8,973.46 6,036,773.00 1,651,680.00 -plan misses target center by 743.19usft at 13457.84usft MD(3459.02 TVD,4634.37 N,-8747.11 E) -Circle(radius 100.00) 3R-102 12.T11 031116 MW 0.00 0.00 3,565.90 4,791.90 -7,088.77 6,036,228.00 1,653,566.00 -plan misses target center by 40.16usft at 11781.01 usft MD(3525.83 TVD,4792.86 N,-7086.22 E) -Circle(radius 100.00) 3R-W02 2 Heel 010816 MW 0.00 0.00 3,578.90 4,784.97 -4,542.52 6,036,228.00 1,656,112.00 -plan misses target center by 1.75usft at 9236.37usft MD(3577.15 TVD,4784.97 N,-4542.59 E) -Circle(radius 100.00) 3R-102 19.TD 103116 MW Circle 0.00 0.00 3,316.90 3,869.48 -10,640.65 6,035,296.00 1,650,017.00 -plan hits target center -Circle(radius 1,320.00) 1/102017 1:11:18PM Page 13 COMPASS 5000.1 Build 74 • • Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan:3R-102 Company: . ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Project: Kuparuk River Unit MD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Site: Kuparuk 3R Pad North Reference: True Well: Plan:3R-102 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3R-102 x Design: ' 3R-102wp09 3R-102 10.T9 103116 MW 0.00 0.00 3,536.90 4,790.64 -6,626.72 6,036,228.00 1,654,028.00 -plan hits target center -Circle(radius 100.00) 3R-102 18.117 103116 MW 0.00 0.00 3,383.90 4,078.08 -10,116.02 6,035,506.00 1,650,541.00 -plan hits target center -Circle(radius 100.00) 3R-102 17.T16 103116 MW 0.00 0.00 3,387.90 4,332.36 -9,477.27 6,035,762.00 1,651,179.00 -plan hits target center -Circle(radius 100.00) 3R-W02 4.T2 010816 MW 0.00 0.00 3,564.90 4,790.74 -6,662.73 6,036,228.00 1,653,992.00 -plan misses target center by 27.90usft at 11357.29usft MD(3537.00 TVD,4790.72 N,-6662.82 E) -Circle(radius 100.00) 3R-102 15.T14 031116 MW 0.00 0.00 3,490.90 4,589.71 -8,860.50 6,036,021.00 1,651,795.00 -plan misses target center by 43.54usft at 13576.11 usft MD(3447.73 TVD,4594.80 N,-8857.97 E) -Circle(radius 100.00) 3R-102 7.T6 103116 MW 0.00 0.00 3,549.90 4,788.21 -5,734.64 6,036,228.00 1,654,920.00 -plan hits target center -Circle(radius 100.00) 3R-W02 6.T4 Begin Toe Pilot 121615 DL 0.00 0.00 3,533.90 4,976.05 -8,603.42 6,036,408.00 1,652,051.00 -plan misses target center by 297.30usft at 13229.41 usft MD(3480.05 TVD,4693.68 N,-8527.57 E) -Circle(radius 100.00) 3R-102 7.T6 031116 MW 0.00 0.00 3,579.90 4,788.13 -5,705.63 6,036,228.00 1,654,949.00 -plan misses target center by 29.27usft at 10399.20usft MD(3550.63 TVD,4788.13 N,-5704.91 E) -Circle(radius 100.00) 3R-102 6.T5 031116 MW 0.00 0.00 3,584.90 4,787.26 -5,386.60 6,036,228.00 1,655,268.00 -plan misses target center by 24.11 usft at 10080.06usft MD(3560.80 TVD,4787.26 N,-5385.94 E) -Circle(radius 100.00) 3R-102 9.T8 103116 MW 0.00 0.00 3,540.90 4,789.87 -6,342.70 6,036,228.00 1,654,312.00 -plan hits target center -Circle(radius 100.00) 3R-W02 6.T6 072715 MW 0.00 0.00 3,433.90 5,346.01 -10,411.60 6,036,773.00 1,650,242.00 -plan misses target center by 1288.33usft at 14745.08usft MD(3385.49 TVD,4149.73 N,-9935.81 E) -Circle(radius 100.00) 3R-102 8.T7 031116 MW 0.00 0.00 3,574.90 4,789.01 -6,027.67 6,036,228.00 1,654,627.00 -plan misses target center by 33.90usft at 10721.83usft MD(3541.00 TVD,4789.01 N,-6027.39 E) -Circle(radius 100.00) 3R-102 5.T4 103116 MW 0.00 0.00 3,565.90 4,786.85 -5,232.59 6,036,228.00 1,655,422.00 -plan hits target center -Circle(radius 100.00) 3R-W02 8.TD above Nb Sand 010816 MW 0.00 0.00 3,255.90 4,062.07 -10,116.07 6,035,490.00 1,650,541.00 -plan misses target center by 128.55usft at 14951.15usft MD(3383.45 TVD,4073.60 N,-10127.27 E) -Circle(radius 100.00) 3R-W02 6.T4 Begin Toe Pilot 010816 MW 0.00 0.00 3,522.90 4,676.02 -8,604.24 6,036,108.00 1,652,051.00 -plan misses target center by 49.85usft at 13303.84usft MD(3473.28 TVD,4675.66 N,-8599.47 E) -Circle(radius 100.00) 3R-W02 4.T4 072715 MW 0.00 0.00 3,551.90 5,340.63 -8,435.41 6,036,773.00 1,652,218.00 -plan misses target center by 620.49usft at 13039.77usft MD(3492.80 TVD,4730.06 N,-8342.00 E) -Circle(radius 100.00) 3R-W02 3.T1 010816 MW 0.00 0.00 3,590.90 4,785.56 -4,761.54 6,036,228.00 1,655,893.00 -plan misses target center by 12.33usft at 9455.16usft MD(3578.57 TVD,4785.56 N,-4761.32 E) -Circle(radius 100.00) 3R-102 6.T5 103116 MW 0.00 0.00 3,556.90 4,787.56 -5,495.61 6,036,228.00 1,655,159.00 -plan hits target center -Circle(radius 100.00) 3R-102 16.T15 103116 MW 0.00 0.00 3,467.90 4,661.16 -8,656.28 6,036,093.00 1,651,999.00 1/10/2017 1:11:18PM Page 14 COMPASS 5000.1 Build 74 S • Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan:3R-102 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Project: Kuparuk River Unit MD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Site: Kuparuk 3R Pad North Reference: True Well: Plan:3R-102 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3R-102 Design: 3R-102wp09 -plan hits target center -Circle(radius 100.00) 3R-W02 7.T4-Top WSD 121615 DL 0.00 0.00 3,412.90 4,689.03 -9,341.28 6,036,119.00 1,651,314.00 -plan misses target center by 276.24usft at 13984.61 usft MD(3407.98 TVD,4435.39 N,-9231.97 E) -Circle(radius 100.00) 3R-W02 7.T7 072715 MW 0.00 0.00 3,370.90 5,350.37 -12,010.75 6,036,773.00 1,648,643.00 -plan misses target center by 2018.20usft at 15507.88usft MD(3316.90 TVD,3869.48 N,-10640.65 E) -Circle(radius 100.00) 3R-W02 5.T3 TD Liner 121615 DL 0.00 0.00 3,574.90 5,093.39 -7,625.00 6,036,528.00 1,653,029.00 -plan misses target center by 314.02usft at 12302.33usft MD(3516.62 TVD,4785.34 N,-7607.28 E) -Circle(radius 100.00) 3R-102 2.Heel 103116 MW 0.00 0.00 3,563.90 4,783.96 -4,174.49 6,036,228.00 1,656,480.00 -plan hits target center -Circle(radius 100.00) 3R-102 9.T8 031116 MW 0.00 0.00 3,569.90 4,789.79 -6,313.69 6,036,228.00 1,654,341.00 -plan misses target center by 29.00usft at 11008.14usft MD(3540.90 TVD,4789.79 N,-6313.69 E) -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 12,700.00 3,500.36 4 1/2"x 6-3/4" 4-1/2 6-3/4 8,868.02 3,563.90 7-5/8"x 9-7/8" 7-5/8 9-7/8 2,336.79 2,198.90 10 3/4"x 13-1/2 10-3/4 13-1/2 117.90 117.90 20"x 42" 20 42 Formations Measured Vertical Vertical -: Dip ` � Depth Depth Depth SS t +. ", Directionn. 1% usft 2i- (usft) ( ) Name �' au.. ._ °,)1 ;. �. (°) 2,038.81 1,956.90 K15 0.00 1,790.75 1,738.40 Base Pfrost 0.00 6,305.05 3,246.00 Top Ugnu A 3,561.98 2,772.50 Top Ugnu C 7,990.91 3,498.60 Fault 6,719.75 3,316.90 TD 4,963.36 3,014.40 Top Ugnu B 8,579.69 3,547.80 Top West Sak D 6,842.24 3,337.30 Top West Sak D 1,735.91 1,689.30 T3 0.00 6,719.75 3,316.90 TD 7,157.70 3,387.80 Top N Sands 7,698.32 3,464.30 Base West Sak D 1/10/2017 1:11:18PM Page/5 COMPASS 5000.1 Build 74 • • Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan:3R-102 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Project: Kuparuk River Unit MD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Site: Kuparuk 3R Pad North Reference: True Well: Plan:3R-102 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3R-102 Design: 3R-102wp09 Plan Annotations ., ., -, A _� h• ,; ,� . Measured Vertical Local Coordinates :....,4,...,„„..„.„:„..,„,....,,.........„,..„, Depth Depth +N/-S +E/-W , ' (usft) (usft) (usft) (usft) Comment 350.00 350.00 0.00 0.00 KOP:Start 1.5°/100'DLS,290°TF,for 250.18' 600.18 600.00 2.80 -7.70 Start 2°/100'DLS,0°TF,for 1134.73' 1,734.91 1,688.40 103.24 -283.66 Hold for 111.69' 1,846.59 1,788.40 120.26 -330.40 Start 4°/100'DLS,57.5°TF,for 490.19' 2,336.79 2,198.90 272.97 -545.16 Hold for 20' 2,356.79 2,214.16 282.27 -554.14 Start 4°/100'DLS,32.49°TF,for 1096.35' 3,453.14 2,753.71 1,077.41 -1,024.32 Hold for 2768.5' 6,221.64 3,231.60 3,608.80 -2,038.36 Start 3°/100'DLS,-90.26°TF,for 2255.73' 8,477.36 3,541.90 4,782.90 -3,784.45 Adjust TF to 0°,for 26.58' 8,503.94 3,543.57 4,782.97 -3,810.98 Hold for 360.66' 8,864.60 3,563.71 4,783.95 -4,171.07 Start 3°/100'DLS,0°TF,for 3.42' 8,868.02 3,563.90 4,783.96 -4,174.49 Hold for 20' 8,888.02 3,564.98 4,784.02 -4,194.46 Start 2°/100'DLS,0°TF,for 73.64' 8,961.66 3,568.02 4,784.22 -4,268.03 Hold for 179.98' 9,141.64 3,573.13 4,784.71 -4,447.94 Start 2°/100'DLS,180°TF,for 68.64' 9,210.28 3,575.90 4,784.89 -4,516.52 Adjust TF to 0°,for 202.32' 9,412.60 3,579.35 4,785.45 -4,718.77 Hold for 188.82' 9,601.42 3,575.90 4,785.96 -4,907.56 Start 2°/100'DLS,0°TF,for 30.36' 9,631.78 3,575.19 4,786.04 -4,937.91 Hold for 227.51' 9,859.30 3,568.63 4,786.66 -5,165.33 Start 2°/100'DLS,0°TF,for 67.32' 9,926.61 3,565.90 4,786.85 -5,232.59 Adjust TF to-180°,for 71.36' 9,997.98 3,563.05 4,787.04 -5,303.89 Hold for 120.46' 10,118.44 3,559.75 4,787.37 -5,424.31 Start 2°/100'DLS,0°TF,for 71.36' 10,189.80 3,556.90 4,787.56 -5,495.61 Adjust TF to-180°,for 79.26' 10,269.06 3,553.85 4,787.78 -5,574.81 Hold for 159.87' 10,428.94 3,549.90 4,788.21 -5,734.64 Start 2°/100'DLS,0°TF,for 26.63' 10,455.56 3,549.12 4,788.29 -5,761.25 Hold for 193.18' 10,648.74 3,542.55 4,788.81 -5,954.32 Start 2°/100'DLS, 180°TF,for 97.37' 10,746.11 3,540.90 4,789.08 -6,051.67 Adjust TF to 0°,for 0' 11,037.14 3,540.90 4,789.87 -6,342.70 Hold for 291.03' 11,085.83 3,540.49 4,790.00 -6,391.38 Start 2°/100'DLS,0°TF,for 0' 11,272.51 3,537.31 4,790.51 -6,578.04 Adjust TF to 0.04°,for 48.69' 11,321.20 3,536.90 4,790.64 -6,626.72 Hold for 186.68' 11,330.80 3,536.92 4,790.67 -6,636.32 Start 2°/100'DLS,-179.6°TF,for 48.69' 11,496.37 3,537.46 4,791.02 -6,801.89 Adjust TF to-171.73°,for 9.6' 11,601.24 3,535.90 4,791.41 -6,906.75 Hold for 165.57' 11,688.40 3,531.70 4,792.03 -6,993.80 Start 2°/100'DLS,4.86°TF,for 104.88' 11,785.44 3,525.55 4,792.90 -7,090.64 Adjust TF to 7.17°,for 87.15' 11,883.69 3,520.90 4,793.18 -7,188.77 Hold for 97.05' 11,973.69 3,519.38 4,792.33 -7,278.75 Start 2°/100'DLS,-158.58°TF,for 98.25' 12,175.94 3,518.91 4,789.22 -7,480.98 Adjust TF to-157.82°,for 90' 12,256.82 3,517.90 4,787.19 -7,561.83 Hold for 202.26' 12,335.84 3,515.36 4,783.64 -7,640.72 Start 2°/100'DLS,-43.83°TF,for 80.88' 12,658.12 3,501.94 4,765.96 -7,962.23 Adjust TF to-46.56°,for 79.01' 12,713.98 3,499.90 4,762.43 -8,017.94 Hold for 322.28' 12,798.19 3,497.87 4,755.34 -8,101.83 Start 2°/100'DLS,-121.63°TF,for 55.86' 12,956.39 3,495.20 4,740.01 -8,259.26 Adjust TF to-119.69°,for 84.21' 13,172.27 3,484.90 4,706.66 -8,472.14 Hold for 158.2' 13,228.07 3,480.17 4,694.00 -8,526.28 TD: 12956.39'MD,3495.2'TVD 13,331.80 3,470.73 4,668.89 -8,626.48 Start DLS 3.00 TFO-85.01 13,362.72 3,467.90 4,661.16 -8,656.28 Adjust TF to-68.29°,for 55.8' 13,635.50 3,441.98 4,572.35 -8,912.65 Hold for 103.73' 14,062.09 3,400.43 4,404.99 -9,302.84 Start 3°/100'DLS,-85.01°TF,for 30.92' 14,251.49 3,387.90 4,332.36 -9,477.27 Adjust TF to-87.59°,for 272.78' 14,348.09 3,386.14 4,296.43 -9,566.91 Hold for 426.59' 14,862.79 3,385.29 4,106.24 -10,045.18 Start 2°/100'DLS,161.28°TF,for 189.4' 14,939.04 3,383.90 4,078.08 -10,116.02 Adjust TF to 170.63°,for 96.6' 15,181.35 3,362.67 3,988.94 -10,340.22 Hold for 514.7' 15,507.88 3,316.90 3,869.48 -10,640.65 Start 2.5°/100'DLS,0.16°TF,for 76.25' 1/10/2017 1.11.18PM Page 16 COMPASS 5000.1 Build 74 AC Summary • • 1. 11 ConocoPhillips (Alaska) Inc. -Kup2 04 I Kuparuk River Unit Kuparuk 3R Pad Plan: 3R-102 Plan: 3R-102 • 50103xxxxx00 3R-102wp09 Tier Challenging 2 orientation Clearance Summary Anticollision Report 11 January,2017 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 3R Pad-Plan:3R-102-Plan:3R-102-3R-102wp09 0Well Coordinates: d 0 0 ° Datum Height: Plan:39+9.9 48.90usft(Doyon142) Scan Range: 0.00 to 15,507.88 usft.Measured Depth. Scan Radius is 1,746.89 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied g Version: 5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference j_ Scan Type: 25.00 F R • • ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 3R-102-3R-102wp09 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design:Kuparuk 3R Pad-Plan:3R-102-Plan:3R-102-3R-102wp09 Scan Range: 0.00 to 15,507.88 usft.Measured Depth. Scan Radius is 1,746.89 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Kuparuk 3R Pad 3R-10-3R-10-3R-10 371.63 59.91 371.63 43.68 375.00 3.692 Centre Distance Pass-Major Risk 3R-10-3R-10-3R-10 494.83 61.83 494.83 40.83 500.00 2.945 Clearance Factor Pass-Major Risk 3R-10-3R-10A-3R-10A 371.63 59.91 371.63 43.68 375.00 3.692 Centre Distance Pass-Major Risk 3R-10-3R-10A-3R-10A 494.83 61.83 494.83 40.83 500.00 2.945 Clearance Factor Pass-Major Risk 3R-11 D-3R-11 D-3R-11D 371.60 84.17 371.60 70.62 375.00 6.209 Centre Distance Pass-Major Risk 3R-11D-3R-11D-3R-11D 494.85 88.16 494.85 68.87 500.00 4.982 Clearance Factor Pass-Major Risk 3R-12D-3R-12A-3R-12A 371.51 108.51 371.51 92.29 375.00 6.687 Centre Distance Pass-Major Risk 3R-12D-3R-12A-3R-12A 567.79 111.55 567.79 87.97 575.00 4.731 Clearance Factor Pass-Major Risk 3R-12D-3R-12D-3R-12D 371.51 108.51 371.51 92.29 375.00 6.687 Centre Distance Pass-Major Risk 3R-12D-3R-12D-3R-12D 567.79 111.55 567.79 87.97 575.00 4.731 Clearance Factor Pass-Major Risk 3R-14-3R-14-3R-14 46.90 225.09 46.90 222.40 50.00 83.890 Centre Distance Pass-Major Risk 3R-14-3R-14-3R-14 515.54 228.90 515.54 206.82 525.00 10.369 Clearance Factor Pass-Major Risk 3R-15-3R-15-3R-15 246.90 250.08 246.90 239.58 250.00 23.822 Centre Distance Pass-Major Risk 3R-15-3R-15-3R-15 538.81 253.56 538.81 230.90 550.00 11.190 Clearance Factor Pass-Major Risk 3R-26-3R-26-3R-26 346.58 198.16 348.58 185.41 350.00 15.537 Centre Distance Pass-Major Risk 3R-26-3R-26-3R-26 442.88 199.63 442.88 183.60 450.00 12.455 Clearance Factor Pass-Major Risk 3R-26-3R-26PB1-3R-26PB1 346.58 198.16 346.58 185.32 350.00 15.424 Centre Distance Pass-Major Risk 3R-26-3R-26PB1-3R-26PB1 442.88 199.63 442.88 183.51 450.00 12.383 Clearance Factor Pass-Major Risk Plan:3R-101-Plan:3R-101-3R-101wp12 475.58 29.42 475.58 12.14 475.00 1.702 Centre Distance Pass-Major Risk Plan:3R-101-Plan:3R-101-3R-101wp12 601.06 30.80 601.06 9.92 600.09 1.475 Clearance Factor Pass-Major Risk Plan:3R-101-Plan:3R-101L1-3R-101L1wp12 474.47 29.42 474.47 12.17 475.00 1.705 Centre Distance Pass-Major Risk Plan:3R-101-Plan:3R-101L1-3R-101L1wp12 599.86 30.77 599.86 9.92 600.00 1.475 Clearance Factor Pass-Major Risk Kuparuk 011ktok Oliktok Point State 1-Oliktok Point State 1-Oliktok Po 409.55 33.52 409.55 18.91 400.00 2.295 Centre Distance Pass-Major Risk Oliktok Point State 1-Oliktok Point State 1-Oliktok Po 483.61 34.19 483.61 17.38 474.96 2.034 Clearance Factor Pass-Major Risk Oliktok Point 11 January.2017- 15:19 Page 2 of 6 COMPASS • • ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 3R-102-3R-1O2wpO9 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 3R Pad-Plan:3R-102-Plan:3R-102-3R-102wp09 Scan Range: 0.00 to 15,507.88 usft.Measured Depth. Scan Radius is 1,746.89 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft 0106-05-0106-05-0106-05 6,891.34 724.31 6,891.34 627.46 3,475.00 7.479 Centre Distance Pass-Major Risk 0106-05-0106-05-0106-05 6,878.16 725.83 6,878.16 625.20 3,525.00 7.213 Clearance Factor Pass-Major Risk 0106-05-0106-05PB1-0106-05PB1 6,891.34 724.31 6,891.34 627.46 3,475.00 7.479 Centre Distance Pass-Major Risk 0106-05-0106-05PB1-0106-05P51 6,878.16 725.83 6,878.16 625.20 3,525.00 7.213 Clearance Factor Pass-Major Risk 0124-08-0124-08-0124-08 11,890.59 746.80 11,890.59 610.35 4,825.00 5.473 Centre Distance Pass-Major Risk 0124-08-0124-08-0124-08 11,927.79 747.99 11,927.79 609.56 4,875.00 5.403 Clearance Factor Pass-Major Risk OPt6-13-OP16-03-OP16-03 10,840.40 949.59 10,840.40 836.77 3,925.00 8.417 Centre Distance Pass-Major Risk OP16-13-OP16-03-OP16-03 11,800.00 968.07 11,800.00 822.85 4,875.00 6.667 Clearance Factor Pass-Major Risk OP16-13-OP16-03L1-OP16-03L1 10,839.66 949.59 10,839.66 836.73 3,925.00 8.414 Centre Distance Pass-Major Risk OP16-13-OP16-03L1-OP16-03L1 11,800.00 968.04 11,800.00 822.73 4,875.00 6.662 Clearance Factor Pass-Major Risk OPt6-13-OP16-03L1 PB1-OP16-03L1PB1 10,839.66 949.59 10,839.66 836.94 3,925.00 8.430 Centre Distance Pass-Major Risk OP16-13-OP16-03L1 PB1-OP16-03L1 P61 11,800.00 968.04 11,800.00 822.94 4,875.00 6.672 Clearance Factor Pass-Major Risk OP17-02-OP17-02-OP17-02 10,039.24 844.99 10,039.24 729.24 3,450.00 7.300 Centre Distance Pass-Major Risk OPt7-02-OP17-02-OP17-02 10,290.05 852.13 10,290.05 719.97 3,725.00 6.448 Clearance Factor Pass-Major Risk OP17-02-OP17-02PB1-OP17-02PB1 10,039.24 844.99 10,039.24 729.10 3,450.00 7.291 Centre Distance Pass-Major Risk OP17-02-OP17-02PB1-OP17-02PB1 10,290.05 852.13 10,290.05 719.84 3,725.00 6.441 Clearance Factor Pass-Major Risk OP19-T1N-OP19-T1N-OP19-T1N 9,065.57 895.17 9,065.57 791.68 3,100.00 8.650 Centre Distance Pass-Major Risk OP19-T1N-OP19-T1N-OP19-T1N 9,077.31 895.30 9,077.31 790.74 3,125.00 8.562 Clearance Factor Pass-Major Risk OP19-T1 N-OP19-T1NPB1-OP19-T1 NPB1 9,065.57 895.17 9,065.57 791.68 3,100.00 8.650 Centre Distance Pass-Major Risk OP19-T1N-OP19-T1NPB1-OP19-T1NPB1 9,077.31 895.30 9,077.31 790.74 3,125.00 8.562 Clearance Factor Pass-Major Risk OP21-VVW01-OP21-WW01-OP21-WW01 8,238.86 454.39 8,238.86 349.63 3,475.00 4.337 Centre Distance Pass-Major Risk OP21-VVW01-OP21-VWV01-OP21-VWV01 8,235.04 455.74 8,235.04 349.47 3,500.00 4.288 Clearance Factor Pass-Major Risk OP22-VVW03-OP22-0WW03-OP22-VWV03 8,989.37 519.87 8,989.37 410.98 3,400.00 4.774 Centre Distance Pass-Major Risk OP22-WVW3-OP22-WW03-OP22-VWV03 9,005.55 521.07 9,005.55 409.68 3,450.00 4.678 Clearance Factor Pass-Major Risk 11 January,2017- 15:19 Page 3 of 6 COMPASS • S ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 3R-102-3R-102wp09 Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 39.00 600.00 3R-102wp09 INC+TREND 600.00 1,600.00 3R-102wp09 MWD 600.00 2,336.36 3R-102wp09 MWD+IFR-AK-CAZ-SC 39.00 700.00 3R-102wp09 GYD-GC-SS 2,336.36 3,836.36 3R-102wp09 MWD 2,336.36 8,868.00 3R-102wp09 MWD+IFR-AK-CAZ-SC 8,868.00 10,372.55 3R-102wp09 MWD 8,868.00 15,507.88 3R-102wp09 MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 11 January,2017- 15:19 Page 4 of 6 COMPASS III • ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 3R-102-3R-1O2wp09 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 3R Pad-Plan:3R-102-Plan:3R-102-3R-102wp09 Scan Range: 0.00 to 15,507.88 usft.Measured Depth. Scan Radius Is 1,748.89 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft 0106-05-0106-05-0106-05 6,891.34 724.31 6,891.34 627.46 3,475.00 7.479 Centre Distance Pass-Major Risk 0106-05-0106-05-0106-05 6,878.16 725.83 6,878.16 625.20 3,525.00 7.213 Clearance Factor Pass-Major Risk 0106-05-0106-05P01-0106-05PB1 6,891.34 724.31 6,891.34 627.46 3,475.00 7.479 Centre Distance Pass-Major Risk 0106-05-0106-05PB1-0106-05PB1 6,878.16 725.83 6,878.16 625.20 3,525.00 7.213 Clearance Factor Pass-Major Risk 0124-08-0124-08-0124-08 11,890.59 746.80 11,890.59 610.35 4,825.00 5.473 Centre Distance Pass-Major Risk 0124-08-0124-08-0124-08 11,927.79 747.99 11,927.79 609.56 4,875.00 5.403 Clearance Factor Pass-Major Risk OP16-13-OP16-03-OP16-03 10,840.40 949.59 10,840.40 836.77 3,925.00 8.417 Centre Distance Pass-Major Risk OP16-13-OP16-03-OP16-03 11,800.00 968.07 11,800.00 822.85 4,875.00 6.667 Clearance Factor Pass-Major Risk OP16-13-OP16-03L1-OP16-03L1 10,839.66 949.59 10,839.66 836.73 3,925.00 8.414 Centre Distance Pass-Major Risk OP16-13-OP16-03L1-OP16-03L1 11,800.00 968.04 11,800.00 822.73 4,875.00 6.662 Clearance Factor Pass-Major Risk OP16-13-OP16-03L1 PB1-OP16-03L1PB1 10,839.66 949.59 10,839.66 836.94 3,925.00 8.430 Centre Distance Pass-Major Risk OP16-13-OP16-03L1 PB1-OP16-03L1 PB1 11,800.00 968.04 11,800.00 822.94 4,875.00 6.672 Clearance Factor Pass-Major Risk OP17-02-OP17-02-OP17-02 10,039.24 844.99 10,039.24 729.24 3,450.00 7.300 Centre Distance Pass-Major Risk OP17-02-OP17-02-OP17-02 10,290.05 852.13 10,290.05 719.97 3,725.00 6.448 Clearance Factor Pass-Major Risk OP17-02-OP17-02PB1-OP17-02PB1 10,039.24 844.99 10,039.24 729.10 3,450.00 7.291 Centre Distance Pass-Major Risk OP17-02-OP17-02PB1-OP17-02PB1 10,290.05 852.13 10,290.05 719.84 3,725.00 6.441 Clearance Factor Pass-Major Risk OP19-T1N-OP19-71N-OP19-T1N 9,065.57 895.17 9,065.57 791.68 3,100.00 8.650 Centre Distance Pass-Major Risk OP19-T1 N-OP19-T1N-OP19-T1 N 9,077.31 895.30 9,077.31 790.74 3,125.00 8.562 Clearance Factor Pass-Major Risk OP19-T1 N-OP19-T1NPB1-OP19-T1 NPBI 9,065.57 895.17 9,065.57 791.68 3,100.00 8.650 Centre Distance Pass-Major Risk OP19-T1N-OP19-T1NPB1-OP19-T1NPB1 9,077.31 895.30 9,077.31 790.74 3,125.00 8.562 Clearance Factor Pass-Major Risk OP21-WW01-OP21-WW01-OP21-VWV01 8,238.86 454.39 8,238.86 349.63 3,475.00 4.337 Centre Distance Pass-Major Risk OP21-VVVW 1-OP21-WVV01-OP21-WW01 8,235.04 455.74 8,235.04 349.47 3,500.00 4.288 Clearance Factor Pass-Major Risk OP22-WWD3-OP22-VWV03-OP22-VVW03 8,989.37 519.87 8,989.37 410.98 3,400.00 4.774 Centre Distance Pass-Major Risk OP22-WVW3-OP22-5W003-OP22-W7/03 9,005.55 521.07 9,005.55 409.68 3,450.00 4.678 Clearance Factor Pass-Major Risk 11 January,2017- 15:19 Page 3 of 6 COMPASS • 111 ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 3R-102-3R-102wp09 Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 39.00 600.00 3R-102wp09 INC+TREND 600.00 1,600.00 3R-102wp09 MWD 600.00 2,336.36 3R-102wp09 MWD+IFR-AK-CAZ-SC 39.00 700.00 3R-102wp09 GYD-GC-SS 2,336.36 3,836.36 3R-102wp09 MWD 2,336.36 8,868.00 3R-102wp09 MWD+IFR-AK-CAZ-SC 8,868.00 10,372.55 3R-102wp09 MWD 8,868.00 15,507.88 3R-102wp09 MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 11 January,2017- 15:19 Page 4 of 6 COMPASS Ladder View • 0 15:20, January 11 2C17 3R-102w 09 Ladder View pThe Reference Well is along the X-axis. rror Ellipses are the Sum of the Reference and Offset Well Errors CO m :§. i- t, aa= n r°5 nye, n 300 1 li III I IpAil . I �Id'�� 11 111 .O •i"I""llllll�l°IIII III �II� r . . _. asas Nillllllllll i!'l!rIII��I " lil I� co lllllllll II 1 ,I II; illi 150 v If o II!,Illl 'I�v m 11 mpAI�IBIl�111 l� ,/ � '^nm DII1� III III U 11111�I�11� III 1 Illilllq�1l /III�I�II�1 Equivelant Magnetic Distance I I I 1 I I I I I I I 1 I 1 1 I 1 I I I I I I I I 1111 1 0 2000 4000 6000 8000 10000 12000 14000 Displayed interval could be less than entire well:Measured Depth 39.00 To 15507.88 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.00 600.00 3R-102wp09 (Plan: 3R-102) INC+TREND 117.90 117.90 20"x 42" 600.00 1600.00 3R-102wp09 (Plan: 3R-102) MWD 2198.936.79 10 3/4"x 13-1/2 600.00 2336.36 3R-102wp09 (Plan: 3R-102) MWD+IFR-AK-CAZ-SC 3563.93868.02 7-5/8"x 9-7/8" 39.00 700.00 3R-102wp09 (Plan: 3R-102) GYD-GC-SS 3500:05'00.00 4 1/2"x 6-3/4" 2336.36 3836.36 3R-102wp09 (Plan: 3R-102) MWD 2336.36 8868.00 3R-102wp09 (Plan: 3R-102) MWD+IFR-AK-CAZ-SC 8868.0010372.55 3R-102wp09 (Plan: 3R-102) MWD 8868.0015507.88 3R-102wp09 (Plan: 3R-102) MWD+IFR-AK-CAZ-SC CO a m t., O 00 M O epi / i l i , kyr, co rf � 35 1' - ll(Jo biod OW _ 4,„ , L . e 1.' U 0 I1 I 1 11 I I I I I I I 111111111 1111 1 1 1 1 1 0 \ 500 1000 1500 2000 2500 3000 3500 Equivelant Magnetic Distance Partial Measured Depth TC View 3430 - 4000 4000 4580 3R-102wp09 1110 Inc Azi TVD Dleg TFace get 39.00 0.00 0.00 39.00 0.00 0.00 4580 "- - 5150 39.00 To 15507.88 350.00 0.00 0.00 350.00 0.00 0.00 5150 5730 600.18 3.75 290.00 600.00 1.50 290.00 1734.91 26.45 290.00 1688.40 2.00 0.00 5730 6300 15:21,January 11 2017 1846.59 26.45 290.00 1788.40 0.00 0.00 2336.79 40.26 315.97 2198.90 4.00 57.50 6300 7450 CASING DETAILS 2356.79 40.26 315.97 2214.16 0.00 0.00 ' 3453.14 80.06 338.17 2753.71 4.00 32.49 7450 8600 TVD MD 117.90 117.90 20" xN42° 6221.69 80.06 338.17 3231.60 0.00 0.00 8600 9750 2196.90 2336.79 10 3/9" x 13-1/2 8477.36 86.00 270.16 3541.90 3.00 -90.26 3R-W02 1. Top D 010816 MW 3563.90 8868.02 7-5/8" x 9-7/8" 8503.94 86.80 270.16 3543.57 3.00 0.00 9750 10900 3500.36 12700.00 4 1/2" x 6-3/4" 8864.60 86.80 270.16 3563.71 0.00 0.00 8868.02 86.90 270.16 3563.90 3.00 0.00 3R-102 2. Heel 103116 MW 10900 12060 sosy.PaWa,P, 8888.02 86.90 270.16 3564.98 0.00 0.00 Depth Prom oetn:a Survey/Plan Tool 8961.66 88.37 270.16 3568.02 2.00 0.00 12060 13210 39 00 600 00 600 00 1600.00 '-os,o? (Plan: 3x-io2i 9141.64 88.37 270.16 3573.13 0.00 0.00 13210 14360 600 00 2336 36 39.00 700.00 aiaz„os i2imf 3aioi -sP 1.119DaTIPA AP CAL-" 9210.28 87.00 270.16 3575.90 2.00 180.00. 3R-102 3. T2 103116 MW 2336 36 8668.00 -2336.36 3836.36 :02,29 man: 3,102) -ns-Cs-sc 9412.60 91.05 270.16 3579.35 2.00 PIM 0.00 0068 00 10372.55 R-3oP.,PP ,Plan: 3._,P„ 14360 15508 0868.00 16607.88 38-102,09 (Plan: 3,102) pro.=P.-AACAE-sC 9601.42 91.05 270.16 3575.90 0.00 0.00 3R-102 4. T3 103116 MW 9631.78 91.65 270.16 3575.19 2.00 0.00 15508 13370 9859.30 91.65 270.16 3568.63 0.00 0.00 9926.61 93.00 270.16 3565.90 2.00 0.00 3R-102 5. T4 103116 MW 13370 13560 9997.98 91.57 270.16 3563.05 2.00 -180.00 13560 13740 10118.44 91.57 270.16 3559.75 0.00 0.00 10189.80 93.00 270.16 3556.90 2.00 0.00 3R-102 6. T5 103116 MW 13740 13930 10269.06 91.41 270.16 3553.85 2.00 -180.00 10428.94 91.41 270.16 3 §3py 0.00 0.00 3R-102 7. T6 103116 MW 13930 -_ 14120 10455.56 91.95 270.16 31U. 2.00 0.00 10648.74 91.95 270.16 3542 1 0.00 0.00 14120 14400 10746.11 90.00 270 :5 180.00 3R-102 8. T7 103116 MW 14400 14500 10746.11 90.0 ' ,70.76 3540 90 2.00 00 -31463014e. 0 27 3540 210 0.0 30 14500 14540 11037.14 90.0 270.16 3540 90 2.00 00 102 9. TB 103116 MW 11065 -3 9!.97 2 3540 195 2..; o.c ` 14540 14580 ii` 2.51 9v.9"' 270.16 - _ .0 00 ,`. . 321 9:.00 5 3536 _ 0 :2.a 179.6., 3R Ita �'A,c L1w 12 14580 14550 11 ,.80 89.8-. 70.12 �u -7., 73 A"' ��`+-� p . %�e�46" '� 14550 14650 1 : 6." 8'..8 l 0.o1 ;iit;�,\ 7. xb.�71�'. 160 .24 1.9 •' - 86;i• Qr��tv., mows, 6 MW 14650 14690 11<•8.4 9 y/.ftp ♦ r ,8 5 44 :diti \��ZA.Ad �� 14690 14600 cs 11.8.. .69 35 00 r -� i �I/�, 60/300 s c c 'MOM( OM 7 /�$i'�' Mw 3.: 7519 321 s �:'aM ��Vi,'/.4 60 14600 14700 122: 268. . 3517 ! .4 i►�� '•'4 1IX.ff14700 14800 9 `! ;s, 41y\� �6Njai.V• /..NNW 14800 14890 3 26G. .• 3501 l.. jAv `• �Lti 1, 31ilris�' i.-4 1 s 2•...9c �i N 3R-- ��`14890 14980 90..,7 .64.• 3497 .•Y��►�� 647-• ��-��i� 12'56 39 90.97 26'.44 ��;,� �16,1r.0 �lenWOO�\oint State 115060 1 ,179.27 9 ,s �� a::' 8 102 ;Iii 15160 k�r�A 0.0 ' t '(�.,' A�160 15250 s .5. '2 25:.93 4 1... pp � y1011041.I) MOP■h,I iA c 9` s9 >4:6. ,8a^rt •� ��i ',`,i .jj /�y !�' X50 15310 I9 95.59 .46.,8 2 00 7"a,,,,,•1401011, ,�1� (VA ,• � :�y 90/270 9 9 01 4 .0 0 a 6 i 9 2 to:�{� �� 1� `�� .) rAr rifiritt,1140,11,41",..4,-,c4,--41 140•2.,I9 3§® 15410 1.43,B.u9 90 09 48. 33 •,• p si--•. 1 48,2. 9 90 79 33.6 ' 7. j��1�'ii(Ik 160,��,•• , ��'1 '''ttai ,w, 15512 99 .9.09 92. 0 248.31 3ti ;'1�_� ��%44 't.' 'figk 111 0111 (� ,,,. 15189 .3' !8.'6 248 32 3�n, - x, •q, �' k,"lift � I I ® 1,50 .88 ..9' 18. _ lintriaIRA40# ii�iel l� � 8. ®� �� g1 //* 8 ;;;;;; ��I;V P��,73± 10 ;1,;'-'''' ,T':.'4 ,��9i�'$4�r .. ,!1�410ee',.A. /�� v��NSAf� -120/240 120\ di ��•.109�,i yilat!�iaf�i'iJi �Arri i 135 =-_' i'ArA�;111t1/� rifPi 150 '7-4.4.1.....40W011,,0 es-.9`%T'& 165 NNP..-�Y /��.yy,i s- 180 �1�:�'R' 11 D a��,• 1 �� -150/210 2sa4ii,' < ://41 •�•, 150 - OU i I?SU AC Wells Only 0 0 11:57,February 06 2017Easting(3000 usft/in) -[AC wells ONLY 0I06-o5 - (NOT a Spider) 10106-05PB1 OP1•-P1702 — - OI24--- - OP19-T1 N OP16-03 - OP16-03L1 OP16-03L1PB1 — \ OP21-W 01 - OP19-T1NPB1 OP22-WW03 Oliktok Paint State 1 _ S- - Z _ o �wo - :R-14 0 —o - 3R-102wp09------- 3R-10 - E, t - ii `\\\ 3R-10A —5 3 \ — Kuparuk 3R Pad = - 3R12A - _ '�; '-12D - - R-11 D - 3R-26PB1 - Kuparuk 3Q Pad - 3R-26 i- iiiiiiiiiiiiiiiiiiiiiiiiiiiiTiiiiiiiiiipiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiTii Easting(3000 usft/in) AC Flipbook 0 0 --J- J IJ- (asi0g Details Survey Regram TVD MD Name Depth From Depth To Survey/Plan Tool 3430 4000 3R_102wpOg 90 117.90 o"xqx" 39.00 600 o0 jRtozwpo9(PIan:3Rrox) INC+TREND W zt98 90 2336.79 w3/q"xi3-t/z 600.00 t600.00 jRtozwpog(PIan:3R-toz) MWD 3563 90 8868.00 7i/8"x9'7/8" 600.00 2700.00 3Rr0xwp09(Flab:30-10x) MWDaIFRAKCAZ-SC 4000 4580 3500.36 12700.00 41/2"x6-3/4" 39.00 700.00 3R ro1wp09(PIao:3R r0z) CYO GC 39.00 To 1000.00 2336.36 3836.36 jRrOxwpoq(PIan3Rmz) MWD 80 1 0 2336.36 8868.00 3Rtozwpog(Plan:jRtOz) MWDaIFR-AK-CAZ-SC 45 5 5 8868.00 /037.00 3R-toiwpog(Plan:30-tax) MWD 8868.00 r55o7.88 3Rt0zwpoq(PIan:3R-tox) MWD,FR AK CAZ SC MD Azi 0 / 360 3R-1o1L1wp12 5150 5730 39.00 0.00 90 5730 6300 350.00 0.00 -30 / 33• 0 3R-1olwp12 6300 7450 600.18 290.00 ,' %� 7450 8600 1734.91 290.00 %� 1846.59 290.00 8600 9750 2336.79 315.97 \�`��` 0 10 00 it 975 9 2356.79 315.97 -60 / 300 � �. . \�A ��►./, 60 9 - V ; - 10 00 12060 3453.14 338.17 / r, 11116N11118./1--� ._ il54- tok Point State 1 1.- .� V �� Iii�f1 12060 1 210 6221.64 338.17 _� Nnwi ;!;///.. 3 8477.36 270.16 �au•,�..,,,.< �:i�� 10 0 3 43 44 8503.94 270.16 . " I�N414360 15508 8864.6o 270.16 tir,...6,,�� 8868.02 0 2 0 � + 90 15508 1 O ' , 3378888.02 270.1 / ids ®,' i 1 70 1 60 33 35 IF& \ ��15�8961.66 270.16W ,h a=l'_"�z 0.16 ,r - 1. --.� <.1��%'' 13560 13740 7 %-4� 1►;. ��...0746.4,--- 9141.64ies`! Ii 9210.28 270.16 (,\ �� ,ft... ®�e 13740 13930 9412.60 270.16 !` p�ka '` ®�� 1 0 1 120 .�� 393 4 9601.42 270.16 -120 / 240 j�1�0 9631.78 270.16 • ii ' 1 ' 1 d�,� , 14120 14400 ` � j 3R-10 14400 14500 9859.30 270.16 .�,� i,�iq.,a S� a-- 9926.61 270.16 fY4. 3R-1oA 14500 14540 9997.98 270.16 -150 / 210 if ,4 150 14540 14580 10118.44 270.16 90 ` 14580 14550 10189.80 270.16 -180 / 180 3R-11D in-)An nr, »n lg. 14550 14650 15:21,January 112017 14650 14690 t.,9».j., Z./NJ.It/ • 0 J IJ- casing Details Survey Program TVD MD Name Depth From Depth To Survey/Plan Tool 3430 4000 3R_iu2wrpo9 90 90 "xx42" 3900 600.00 3R-102wpo9(Nam 3Rtp2) NC.TREND 2198.90 2336]9 t03/4"x1j-1/2 600.00 1600.00 3R lortapo9(PIan:3R 1a2) MWD 35fi3.90 88fi8.00 41/2"06-3/8" 600.00 2336.36 3R-lozwpoq(PIan:3R 102) MD-CC-S-AK-CAZ-SC 4000 ---- 4580 3500.36 12]00.00 41/2"x6-3/4" 39.00 .00 3R.10,wpoq(Plan:3R-102) GOD-GC-SS 1000.00 To 2000.00 335.30 3836.36 3R702wpo9(Plan:3R-1o2) MWD 2336.36 8868.00 3R-102wp09(Plan:3R-102) MWD.IFRAK-CAZ-SC 8868.00 103855 314402wpo9(Pan:3102) MWD 4580 5150 8868.00 15507.88 30-102wpo9(Plan:3R0-102) MWD.IFR-AK.CAZ-SC MD Azi 0 / 360 3R-101L1wpl2 515o 5730 39.00 0.00 90 5730 6300 350.00 0.00 -30 / 33. 6300 7450 600.18 290.00 ".131'_._ 3R-101wp12 1734.91 290.00 7450 8600 1846.59 290.00 60 , 8600 9750 2336.79 315.97 -60 / 300 Arg 6o 9750 10900 2356.79 315.97 10900 12060 3453.14 338.17 9 6221.64 338.17 30 12060 13210 8477.36 270.16 13210 14360 8503.94 270.16 14360 15508 8864.6o 270.16 8868.02 270.16901270 - 90 15508 13370 8888.02 270.16 13370 1356o 8961.66 270.16 9141.64 270.16 30 13560 13740 9210.28 270.16 1374o 13930 9412.60 270.16 13930 - 14120 9601.42 270.16 -120 / 240 120 1412o 14400 9631.78 270.166 0 9859.30 270.16 14400 14500 9926.61 270.16 14500 14540 9997.98 270.16 -150 / 210 /---‘ 14540 14580 10118.44 270.160 9 ______--- 14580 14550 10189.80 270.16 -180 / 180 in,An nti -8-7n ir. 14550 14650 15:23,January 11 2017 14650 14690 • . J 1J- Casing Details Survey Program TVD MD Name Depth From Depth To Survey/Plan Tool 3430 4000 3 11_1 0 2 W 0/� 117.90 117.90 3900 600.00 312-102,09(Plan:30lox) INC.TREND M! 2198.90 2336.79 10 3/4"x131/2 600.00 1600.00 3R.loxwpog(Plan:;R.1ox) MWD 3500.36 8868. 7-5/8"x97/8" 600.00 2336.36 ;Pnoxwpaq(Plan:31 ) M0.CC.S-AK.CAZ-SC 4000 4580 3500.36 12700.00 41/x"x6-3/4" 39.00 700.00 3R-10xwp09(Plan:32.102)2GVD-GC.SS 2000.00 To 15508.00 336.36 3836.36 3R10xwpo9(Plan:3R-10x) MWD 45 5 5 2336.36 8868.00 3R-10xwp09(Plan:3R-102) MWD.IFR-AK-CALSC 8868.60 10372.55 3R-16xwp09(Plan:3R-102) MWD 80 1 0 8858.00 25507.88 3R-lnxwpo9(Plan:30102) MWD.IFR-AK-CAZ-SC MD Azi 0 / 36o 5150 5730 39.00 0.00 go 5730 6300 350.00 0.00 -30 / 33 1 0 6300 7450 600.18 290.00 7450 8600 1734.91 290.00 1846.59 290.00 6 o 8600 9750 2336.79 315.97 _60 00 60 9750 logon / 3 2356.79 315.97 - 10900 12060 3453.14 338.17 6221.64 338.1712060 13210 0 8477.36 270.16 3 13210 14360 8503.94 270.16 14360 15508 8864.6o 270.16 8868.02 270.1690 / 270 90 15508 13370 8888.02 270.16 13370 13560 8961.66 270.16 1356o 13740 9141.64 270.16 30 9210.28 270.16 13740 13930 9412.60 270.16 13930 14120 9601.42 270.16 -120 / 240 120 14-12o - 1 44 00 4 9631.78 270.16 6o 9859.30 270.16 14400 14500 9926.61 270.16 14500 14540 9997.98 270.16 -150 / 210 150 14540 14580 10118.44 270.16 90 10189.80 270.16 14580 14550 180 / 180 1n-Tgn ng -i-7n ,A 14550 14650 15:24,January 11 2017 14650 14690 I.,y.)).i., Lill.IV) -- --- Errors Report S • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3R Pad Plan: 3R-102 Plan: 3R-102 Plan: 3R-102wp09 Errors Report 06 February, 2017 • ID Errors Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Site: Kuparuk 3R Pad MD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp09 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 3R Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.16° Well Plan:3R-102 Well Position +N/-S 0.00 usft Northing: Latitude: +EI-W 0.00 usft Easting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 9.90 usft Wellbore Plan:3R-102 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2016 2/25/2017 17.78 81.04 57,552 Design 3R-102wp09 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.00 0.00 0.00 290.00 Survey Tool Program Date 2/6/2017 From To (usft) (usft) Survey(Wellbore) Tool Name Description 39.00 600.00 3R-102wp09(Plan:3R-102) INC+TREND Inclinometer+known azi trend 600.00 1,600.00 3R-102wp09(Plan:3R-102) MWD MWD-Standard 600.00 2,336.36 3R-102wp09(Plan:3R-102) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 39.00 700.00 3R-102wp09(Plan:3R-102) GYD-GC-SS Gyrodata gyro single shots 2,336.36 3,836.36 3R-102wp09(Plan:3R-102) MWD MWD-Standard 2,336.36 8,868.00 3R-102wp09(Plan:3R-102) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,868.00 10,372.55 3R-102wp09(Plan:3R-102) MWD MWD-Standard 8,868.00 15,507.88 3R-102wp09(Plan:3R-102) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 39.00 0.00 0.00 0.00 -9.90 0.00 0.00 0.00 100.00 1.15 0.00 0.00 51.10 1.15 0.41 0.41 117.90 1.15 0.00 0.00 69.00 1.15 1.60 1.60 20"x 42" 200.00 1.15 0.00 0.00 151.10 1.15 1.60 1.60 300.00 1.15 0.00 0.00 251.10 1.15 2.64 2.64 2/6/2017 11:33:00AM Page 2 COMPASS 5000.1 Build 74 • ! Errors Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Site: Kuparuk 3R Pad MD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp09 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 350.00 1.15 0.00 0.00 301.10 1.15 3.12 3.12 KOP:Start 1.5°/100'DLS,290°TF,for 250.18' 400.00 1.15 0.75 110.23 351.10 1.15 3.46 3.46 500.00 1.16 2.25 110.06 451.06 1.15 4.21 4.05 600.00 1.18 3.75 110.03 550.92 1.16 4.78 4.37 600.18 1.18 3.75 110.03 551.10 1.16 4.78 4.37 Start 2°/100'DLS,0°TF,for 1134.73' 700.00 1.23 5.75 110.01 650.57 1.16 4.79 4.36 800.00 1.29 7.75 109.94 749.88 1.16 4.81 4.35 900.00 1.36 9.75 109.82 848.71 1.16 4.84 4.34 1,000.00 1.45 11.75 109.66 946.95 1.15 4.89 4.33 1,100.00 1.55 13.75 109.47 1,044.48 1.15 4.97 4.32 1,200.00 1.65 15.75 109.30 1,141.18 1.15 5.09 4.30 1,300.00 1.76 17.75 109.16 1,236.93 1.15 5.27 4.29 1,400.00 1.88 19.75 109.06 1,331.62 1.16 5.50 4.28 1,500.00 2.00 21.75 109.01 1,425.13 1.16 5.80 4.27 1,600.00 2.12 23.75 108.99 1,517.34 1.18 6.17 4.27 1,700.00 2.24 25.75 106.61 1,608.15 1.16 5.25 4.18 1,734.91 2.28 26.45 106.48 1,639.50 1.16 5.30 4.17 Hold for 111.69' 1,735.91 2.29 26.45 106.29 1,640.40 1.18 5.39 4.20 T3 1,790.75 2.29 26.45 106.29 1,689.50 1.18 5.39 4.20 Base Pfrost 1,800.00 2.29 26.45 106.29 1,697.78 1.18 5.39 4.20 1,846.59 2.29 26.45 106.18 1,739.50 1.19 5.45 4.22 Start 4°/100'DLS,57.5°TF,for 490.19' 1,900.00 2.37 27.65 106.08 1,787.07 1.20 5.51 4.22 2,000.00 2.54 30.16 106.29 1,874.62 1.22 5.61 4.21 2,038.81 2.74 31.21 106.98 1,908.00 1.23 5.71 4.21 K15 2,100.00 2.74 32.94 106.98 1,959.85 1.23 5.71 4.21 2,200.00 2.97 35.92 108.19 2,042.34 1.26 5.83 4.19 2,300.00 3.22 39.07 109.86 2,121.68 1.28 5.98 4.16 2,336.79 2.05 40.26 115.75 2,150.00 1.58 4.81 3.51 Hold for 20'-10 3/4"x 13-1/2 2,356.79 2.05 40.26 115.90 2,165.26 1.58 4.82 3.51 Start 4°/100'DLS,32.49°TF,for 1096.35' 2,400.00 2.15 41.73 116.73 2,197.88 1.58 4.87 3.49 2,500.00 2.38 45.18 120.81 2,270.47 1.59 5.16 3.44 2,600.00 2.61 48.70 126.23 2,338.74 1.63 5.72 3.39 2,700.00 2.85 52.27 131.20 2,402.37 1.69 6.51 3.36 2,800.00 3.09 55.88 135.12 2,461.03 1.80 7.49 3.34 2,900.00 3.35 59.53 138.15 2,514.45 1.94 8.61 3.34 3,000.00 3.61 63.20 140.55 2,562.37 2.13 9.84 3.37 2/6/2017 11:33:00AM Page 3 COMPASS 5000.1 Build 74 • • Errors Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Site: Kuparuk 3R Pad MD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp09 Database: OAKE DM P2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 3,100.00 3.89 66.90 142.51 2,604.55 2.35 11.14 3.42 3,200.00 4.18 70.61 144.18 2,640.78 2.60 12.51 3.50 3,300.00 4.50 74.34 145.63 2,670.89 2.88 13.92 3.60 3,400.00 4.83 78.07 146.94 2,694.73 3.17 15.35 3.72 3,453.14 5.02 80.06 147.58 2,704.81 3.34 16.13 3.79 Hold for 2768.5' 3,500.00 5.02 80.06 148.10 2,712.90 3.49 16.83 3.94 3,561.98 5.02 80.06 149.06 2,723.60 3.82 18.34 4.25 Top Ugnu C 3,600.00 5.02 80.06 149.06 2,730.16 3.82 18.34 4.25 3,700.00 5.03 80.06 149.85 2,747.42 4.15 19.85 4.58 3,800.00 5.03 80.06 150.53 2,764.69 4.49 21.38 4.91 3,900.00 4.39 80.06 146.67 2,781.95 2.72 9.60 3.09 4,000.00 4.39 80.06 147.61 2,799.21 2.87 10.12 3.23 4,100.00 4.40 80.06 148.42 2,816.47 3.02 10.65 3.38 4,200.00 4.40 80.06 149.12 2,833.73 3.18 11.18 3.53 4,300.00 4.41 80.06 149.74 2,850.99 3.33 11.72 3.68 4,400.00 4.41 80.06 150.29 2,868.25 3.49 12.26 3.83 4,500.00 4.42 80.06 150.78 2,885.52 3.65 12.81 3.99 4,600.00 4.42 80.06 151.21 2,902.78 3.82 13.36 4.15 4,700.00 4.43 80.06 151.60 2,920.04 3.98 13.91 4.31 4,800.00 4.43 80.06 151.95 2,937.30 4.14 14.47 4.47 4,900.00 4.44 80.06 152.26 2,954.56 4.31 15.03 4.63 4,963.36 4.44 80.06 152.55 2,965.50 4.48 15.59 4.79 Top Ugnu B 5,000.00 4.44 80.06 152.55 2,971.82 4.48 15.59 4.79 5,100.00 4.45 80.06 152.81 2,989.09 4.64 16.15 4.96 5,200.00 4.45 80.06 153.05 3,006.35 4.81 16.72 5.12 5,300.00 4.46 80.06 153.27 3,023.61 4.98 17.29 5.29 5,400.00 4.46 80.06 153.47 3,040.87 5.15 17.85 5.45 5,500.00 4.47 80.06 153.65 3,058.13 5.31 18.42 5.62 5,600.00 4.48 80.06 153.82 3,075.39 5.48 19.00 5.79 5,700.00 4.48 80.06 153.98 3,092.66 5.65 19.57 5.96 5,800.00 4.49 80.06 154.13 3,109.92 5.82 20.14 6.13 5,900.00 4.50 80.06 154.27 3,127.18 5.99 20.72 6.30 6,000.00 4.50 80.06 154.40 3,144.44 6.16 21.29 6.47 6,100.00 4.51 80.06 154.52 3,161.70 6.33 21.87 6.64 6,200.00 4.52 80.06 154.63 3,178.96 6.51 22.44 6.81 6,221.64 4.52 80.06 154.65 3,182.70 6.54 22.57 6.85 Start 3°/100'DLS,-90.26"TF,for 2255.73' 6,300.00 4.35 80.06 154.71 3,196.23 6.68 22.98 6.97 6,305.05 4.43 80.06 154.70 3,197.10 6.85 23.36 7.13 Top Ugnu A 6,400.00 4.43 80.08 154.70 3,213.48 6.85 23.36 7.13 6,500.00 4.82 80.13 154.65 3,230.67 7.02 23.69 7.29 2/6/2017 11:33:00AM Page 4 COMPASS 5000.1 Build 74 • • Errors Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Site: Kuparuk 3R Pad MD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp09 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 6,600.00 5.46 80.20 154.54 3,247.75 7.19 23.97 7.46 6,700.00 6.29 80.31 154.37 3,264.68 7.36 24.20 7.63 6,800.00 7.25 80.44 154.14 3,281.41 7.53 24.38 7.81 6,900.00 8.29 80.60 153.86 3,297.89 7.70 24.50 7.99 7,000.00 9.40 80.78 153.53 3,314.07 7.88 24.56 8.16 7,100.00 10.53 80.99 153.15 3,329.92 8.05 24.57 8.34 7,157.70 11.70 81.12 152.73 3,338.90 8.22 24.52 8.52 Top N Sands 7,200.00 11.70 81.22 152.73 3,345.40 8.22 24.52 8.52 7,300.00 12.88 81.48 152.26 3,360.44 8.39 24.41 8.70 7,400.00 14.06 81.76 151.75 3,375.03 8.57 24.24 8.87 7,500.00 15.25 82.06 151.21 3,389.11 8.74 24.01 9.04 7,600.00 16.42 82.38 150.63 3,402.65 8.91 23.73 9.21 7,700.00 17.59 82.73 150.02 3,415.61 9.09 23.38 9.38 7,800.00 18.74 83.09 149.39 3,427.96 9.26 22.98 9.53 7,900.00 19.87 83.48 148.74 3,439.66 9.44 22.52 9.69 8,000.00 20.98 83.88 148.06 3,450.67 9.61 22.01 9.84 8,100.00 22.06 84.29 147.37 3,460.98 9.78 21.45 9.99 8,200.00 23.11 84.73 146.67 3,470.54 9.96 20.84 10.14 8,300.00 24.12 85.18 145.95 3,479.35 10.13 20.18 10.28 8,400.00 25.09 85.64 145.22 3,487.36 10.31 19.47 10.43 8,477.36 25.82 86.00 144.65 3,493.00 10.45 18.90 10.54 Adjust TF to 0°,for 26.58' 8,500.00 25.83 86.68 144.49 3,494.45 10.49 19.01 10.54 8,503.94 25.83 86.80 144.46 3,494.67 10.49 19.03 10.55 Hold for 360.66' 8,580.00 25.83 86.80 143.77 3,498.92 10.66 19.49 10.71 Top West Sak D 8,600.00 25.83 86.80 143.77 3,500.03 10.66 19.49 10.71 8,700.00 25.83 86.80 143.06 3,505.62 10.84 19.98 10.89 8,800.00 25.84 86.80 142.35 3,511.20 11.01 20.47 11.06 8,864.60 25.84 86.80 141.89 3,514.81 11.13 20.79 11.18 Start 3°1100'DLS,0°TF,for 3.42' 8,868.02 25.92 86.90 141.94 3,515.00 11.12 20.81 11.17 Hold for 20'-7-518"x 9-7/8" 8,888.02 25.92 86.90 141.74 3,516.08 11.12 20.95 11.17 Start 2°/100'DLS,0°TF,for 73.64' 8,900.00 25.92 87.14 141.61 3,516.70 11.12 21.04 11.17 8,961.66 25.94 88.37 140.94 3,519.12 11.13 21.51 11.14 Hold for 179.98' 9,000.00 25.94 88.37 140.51 3,520.21 11.13 21.82 11.14 9,100.00 25.94 88.37 139.32 3,523.05 11.16 22.71 11.17 9,141.64 25.94 88.37 138.80 3,524.23 11.17 23.11 11.18 Start 2°/l00'DLS,180°TF,for 68.64' 9,200.00 25.93 87.21 138.04 3,526.48 11.19 23.68 11.23 2/6/2017 11:33:00AM Page 5 COMPASS 5000.1 Build 74 • 110 Errors Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: Plan:39+9.9 @ 48.9ousft(Doyon142) Site: Kuparuk 3R Pad MD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp09 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 9,210.28 25.92 87.00 137.91 3,527.00 11.19 23.78 11.24 Adjust TF to 0°,for 202.32' 9,300.00 25.95 88.79 136.70 3,530.29 11.24 24.72 11.24 9,400.00 25.94 90.79 135.28 3,530.65 11.29 25.85 11.30 9,412.60 25.94 91.05 135.10 3,530.45 11.30 25.99 11.32 Hold for 188.82' 9,500.00 25.94 91.05 133.81 3,528.85 11.36 27.03 11.38 9,600.00 25.95 91.05 132.30 3,527.03 11.44 28.27 11.46 9,601.42 25.95 91.05 132.28 3,527.00 11.45 28.28 11.46 Start 2°/100'DLS,0°TF,for 30.36' 9,631.78 25.94 91.65 131.81 3,526.29 11.47 28.67 11.50 Hold for 227.51' 9,700.00 25.94 91.65 130.75 3,524.32 11.54 29.55 11.57 9,800.00 25.94 91.65 129.20 3,521.44 11.64 30.87 11.67 9,859.30 25.94 91.65 128.27 3,519.73 11.70 31.68 11.73 Start 20/100'DLS,0°TF,for 67.32' 9,900.00 25.93 92.46 127.64 3,518.27 11.75 32.23 11.81 9,926.61 25.92 93.00 127.22 3,517.00 11.78 32.60 11.86 Adjust TF to-180°,for 71.36' 9,997.98 25.95 91.57 126.14 3,514.15 11.87 33.58 11.90 Hold for 120.46' 10,000.00 25.95 91.57 126.11 3,514.10 11.87 33.61 11.90 10,100.00 25.95 91.57 124.58 3,511.35 12.01 35.03 12.03 10,118.44 25.95 91.57 124.31 3,510.85 12.03 35.30 12.06 Start 2°/100'DLS,0°TF,for 71.36' 10,189.80 25.93 93.00 123.25 3,508.00 12.13 36.33 12.21 Adjust TF to-180°,for 79.26' 10,200.00 25.93 92.80 123.10 3,507.48 12.15 36.47 12.22 10,269.06 25.96 91.41 122.12 3,504.95 12.25 37.46 12.28 Hold for 159.87' 10,300.00 25.96 91.41 121.69 3,504.18 12.30 37.91 12.32 10,400.00 25.96 91.41 135.97 3,501.71 11.46 25.34 11.48 10,428.94 25.96 91.41 135.83 3,501.00 11.47 25.44 11.49 Start 2°/100'DLS,0°TF,for 26.63' 10,455.56 25.95 91.95 135.70 3,500.22 11.48 25.54 11.52 Hold for 193.18' 10,500.00 25.95 91.95 135.49 3,498.71 11.50 25.71 11.54 10,600.00 25.96 91.95 135.00 3,495.31 11.55 26.10 11.59 10,648.74 25.96 91.95 134.76 3,493.65 11.57 26.29 11.61 Start 2°l100'DLS,180°TF,for 97.37' 10,700.00 25.97 90.92 134.51 3,492.37 11.60 26.49 11.61 10,746.11 25.98 90.00 134.29 3,492.00 11.62 26.66 11.62 Adjust TF to 0°,for 0' 10,800.00 25.98 90.00 134.02 3,492.00 11.65 26.88 11.65 10,900.00 25.98 90.00 133.51 3,492.00 11.70 27.28 11.70 11,000.00 25.98 90.00 132.99 3,492.00 11.76 27.70 11.76 2/6/2017 11:33:00AM Page 6 COMPASS 5000.1 Build 74 • • Errors Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Site: Kuparuk 3R Pad MD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp09 Data base: OAKE DM P2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 11,037.14 25.99 90.00 132.80 3,492.00 11.78 27.85 11.78 Hold for 291.03' 11,085.83 25.98 90.97 132.54 3,491.59 11.81 28.06 11.83 Start 2°/100'DLS,0°TF,for 0' 11,100.00 25.98 90.97 132.47 3,491.35 11.82 28.12 11.83 11,200.00 25.98 90.97 131.94 3,489.65 11.88 28.54 11.90 11,272.51 25.98 90.97 131.56 3,488.41 11.93 28.85 11.94 Adjust TF to 0.04°,for 48.69' 11,300.00 25.99 90.42 131.42 3,488.08 11.95 28.97 11.95 11,321.20 25.99 90.00 131.31 3,488.00 11.96 29.05 11.96 Hold for 186.68' 11,330.80 26.01 89.81 131.26 3,488.02 11.97 29.08 11.97 Start 2°/100'DLS,-179.6°TF,for 48.69' 11,400.00 26.01 89.81 130.90 3,488.25 12.01 29.38 12.01 11,496.37 26.01 89.81 130.38 3,488.56 12.08 29.80 12.08 Adjust TF to-171.73°,for 9.6' 11,500.00 26.01 89.88 130.36 3,488.57 12.08 29.82 12.08 11,600.00 25.92 91.88 129.82 3,487.04 12.15 30.33 12.19 11,601.24 25.92 91.90 129.81 3,487.00 12.15 30.33 12.19 Hold for 165.57' 11,688.40 25.79 93.63 129.34 3,482.80 12.22 30.81 12.33 Start 2°/100'DLS,4.86°TF,for 104.88' 11,700.00 25.80 93.63 129.28 3,482.06 12.23 30.86 12.33 11,785.44 25.80 93.63 128.81 3,476.65 12.29 31.25 12.40 Adjust TF to 7.17°,for 87.15' 11,800.00 25.85 93.36 128.74 3,475.77 12.30 31.27 12.40 11,883.69 26.15 91.80 128.31 3,472.00 12.37 31.41 12.40 Hold for 97.05' 11,900.00 26.21 91.50 128.23 3,471.53 12.38 31.44 12.41 11,973.69 26.46 90.13 127.84 3,470.48 12.44 31.56 12.44 Start 2°/100'DLS,-158.58°TF,for 98.25' 12,000.00 26.46 90.13 127.70 3,470.42 12.46 31.68 12.46 12,100.00 26.47 90.13 127.15 3,470.19 12.54 32.15 12.54 12,175.94 26.47 90.13 126.73 3,470.01 12.60 32.51 12.61 Adjust TF to-157.82°,for 90' 12,200.00 26.62 90.48 126.60 3,469.88 12.62 32.50 12.63 12,256.82 26.96 91.30 126.29 3,469.00 12.67 32.48 12.70 Hold for 202.26' 12,300.00 27.23 91.89 126.05 3,467.80 12.71 32.45 12.76 12,335.84 27.45 92.39 125.86 3,466.46 12.74 32.43 12.81 Start 2°/100'DLS,-43.83°TF,for 80.88' 12,400.00 27.45 92.39 125.50 3,463.79 12.80 32.74 12.86 12,500.00 27.46 92.39 124.94 3,459.62 12.89 33.22 12.95 12,600.00 27.46 92.39 124.38 3,455.46 12.98 33.71 13.04 12,658.12 27.46 92.39 124.05 3,453.04 13.03 34.00 13.10 Adjust TF to-46.56°,for 79.01' 2/6/2017 11:33:00AM Page 7 COMPASS 5000.1 Build 74 • • Errors Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Site: Kuparuk 3R Pad MD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp09 Database: OAKEDMP2 'Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 12,691.00 27.79 92.04 123.83 3,451.77 13.07 33.94 13.12 Fault 12,700.00 27.79 91.95 123.83 3,451.46 13.07 33.94 13.12 4 1/2"x 6-3/4" 12,713.98 27.90 91.80 123.75 3,451.00 13.09 33.91 13.13 Hold for 322.28' 12,798.19 28.58 90.97 123.31 3,4.48.97 13.17 33.76 13.19 Start 2°1100'DLS,-121.63°TF,for 55.86' 12,800.00 28.58 90.97 123.30 3,448.94 13.17 33.77 13.19 12,900.00 28.58 90.97 122.73 3,447.25 13.26 34.27 13.28 12,956.39 28.59 90.97 122.42 3,446.30 13.32 34.55 13.34 Adjust TF to-119.69°,for 84.21' 13,000.00 29.19 91.68 122.17 3,445.29 13.36 34.25 13.41 13,100.00 30.54 93.32 121.61 3,440.93 13.46 33.52 13.62 13,172.27 31.49 94.50 121.20 3,436.00 13.54 32.95 13.82 Hold for 158.2' 13,200.00 31.86 94.86 121.04 3,433.74 13.56 32.70 13.90 13,228.07 32.24 95.22 120.88 3,431.27 13.59 32.45 13.98 TD:12956.39'MD,3495.2'TVD 13,300.00 32.24 95.22 120.46 3,424.73 13.67 32.82 14.06 13,331.80 32.24 95.22 120.27 3,421.83 13.70 32.98 14.09 Start DLS 3.00 TFO-85.01 13,362.72 32.64 95.30 120.09 3,419.00 13.73 32.74 14.14 Adjust TF to-68.29°,for 55.8' 13,400.00 33.12 95.35 119.88 3,415.54 13.77 32.43 14.20 13,500.00 34.37 95.46 119.31 3,406.12 13.88 31.57 14.37 13,588.00 35.58 95.55 118.73 3,397.68 13.98 30.68 14.54 Base West Sak D 13,600.00 35.58 95.56 118.73 3,396.52 13.98 30.68 14.54 13,635.50 36.00 95.59 118.52 3,393.08 14.02 30.36 14.60 Hold for 103.73' 13,700.00 36.00 95.59 118.14 3,386.79 14.09 30.68 14.66 13,800.00 36.00 95.59 117.53 3,377.06 14.20 31.20 14.77 13,900.00 36.00 95.59 116.91 3,367.32 14.31 31.72 14.88 14,000.00 36.01 95.59 116.30 3,357.58 14.42 32.25 14.99 14,062.09 36.01 95.59 115.93 3,351.53 14.50 32.58 15.06 Start 3°/100'DLS,-85.01°TF,for 30.92' 14,100.00 35.95 94.87 115.72 3,348.08 14.54 32.87 14.99 14,200.00 35.78 92.98 115.22 3,341.23 14.65 33.59 14.86 14,251.49 35.68 92.00 114.97 3,339.00 14.71 33.97 14.83 Adjust TF to-87.59°,for 272.78' 14,300.00 35.64 91.04 114.73 3,337.71 14.77 34.25 14.82 14,348.09 35.59 90.09 114.49 3,337.24 14.83 34.54 14.83 Hold for 426.59' 14,400.00 35.59 90.09 114.21 3,337.15 14.89 34.79 14.89 14,500.00 35.59 90.09 113.63 3,336.99 15.01 35.31 15.01 2/6/2017 11:33.00AM Page 8 COMPASS 5000.1 Build 74 • 0 Errors Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Site: Kuparuk 3R Pad MD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp09 Database: OAKE DM P2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) ) 14,600.00 35.59 90.09 113.05 3,336.82 15.13 35.84 15.13 14,700.00 35.60 90.09 112.47 3,336.66 15.25 36.37 15.26 14,800.00 35.60 90.09 111.90 3,336.50 15.38 36.90 15.38 14,862.79 35.60 90.09 111.54 3,336.39 15.45 37.23 15.46 Start 2°/100'DLS,161.28°TF,for 189.4' 14,900.00 35.58 91.02 111.33 3,336.03 15.50 37.43 15.55 14,939.04 35.55 92.00 111.11 3,335.00 15.55 37.64 15.66 Adjust TF to 170.63°,for 96.6' 15,000.00 35.49 93.52 110.77 3,332.06 15.63 37.96 15.87 15,100.00 35.35 96.02 110.21 3,323.74 15.75 38.50 16.31 15,181.35 35.20 98.06 109.76 3,313.77 15.85 38.94 16.75 Hold for 514.7' 15,200.00 35.20 98.06 109.66 3,311.16 15.88 39.04 16.77 15,300.00 35.20 98.06 109.11 3,297.14 16.00 39.58 16.89 15,400.00 35.20 98.06 108.57 3,283.12 16.13 40.12 17.01 15,426.00 35.20 98.06 108.03 3,279.48 16.26 40.66 17.14 Top West Sak D 15,500.00 35.20 98.06 108.03 3,269.10 16.26 40.66 17.14 15,507.80 35.20 98.06 107.99 3,268.01 16.27 40.70 17.15 TD 15,507.88 35.20 98.06 107.99 3,268.00 16.27 40.70 17.15 Start 2.5°/100'DLS,0.16°TF,for 76.25' 2/6/2017 11:33:00AM Page 9 COMPASS 5000.1 Build 74 0 0 Errors Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Site: Kuparuk 3R Pad MD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp09 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 12,700.00 3,500.36 41/2"x6-3/4" 4-1/2 6-3/4 8,868.02 3,563.90 7-5/8"x 9-7/8" 7-5/8 9-7/8 2,336.79 2,198.90 10 3/4"x 13-1/2 10-3/4 13-1/2 117.90 117.90 20"x 42" 20 42 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (") (") 2,038.81 1,956.90 K15 0.00 1,790.75 1,738.40 Base Pfrost 0.00 6,305.05 3,246.00 Top Ugnu A 0.00 3,561.98 2,772.50 Top Ugnu C 0.00 12,691.00 3,500.67 Fault 0.00 4,963.36 3,014.40 Top Ugnu B 0.00 8,580.00 3,547.82 Top West Sak D 0.00 15,426.00 3,328.38 Top West Sak D 0.00 1,735.91 1,689.30 T3 0.00 15,507.80 3,316.91 TD 0.00 7,157.70 3,387.80 Top N Sands 0.00 13,588.00 3,446.58 Base West Sak D 0.00 2/6/2017 11:33:00AM Page 10 COMPASS 5000.1 Build 74 • 0 Errors Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Site: Kuparuk 3R Pad MD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp09 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C') (") 12,700.00 3,500.36 4 1/2"x 6-3/4" 4-1/2 6-3/4 8,868.02 3,563.90 7-5/8"x 9-7/8" 7-5/8 9-7/8 2,336.79 2,198.90 10 3/4"x 13-1/2 10-3/4 13-1/2 117.90 117.90 20"x 42" 20 42 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (1 (1 2,038.81 1,956.90 K15 0.00 1,790.75 1,738.40 Base Pfrost 0.00 6,305.05 3,246.00 Top Ugnu A 0.00 3,561.98 2,772.50 Top Ugnu C 0.00 12,691.00 3,500.67 Fault 0.00 4,963.36 3,014.40 Top Ugnu B 0.00 8,580.00 3,547.82 Top West Sak D 0.00 15,426.00 3,328.38 Top West Sak D 0.00 1,735.91 1,689.30 T3 0.00 15,507.80 3,316.91 TD 0.00 7,157.70 3,387.80 Top N Sands 0.00 13,588.00 3,446.58 Base West Sak D 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth i-NI-S +E/-W (usft) (usft) (usft) (usft) Comment 350.00 350.00 0.00 0.00 KOP:Start 1.5°/100'DLS,290°TF,for 250.18' 600.18 600.00 2.80 -7.70 Start 2°/100'DLS,0°TF,for 1134.73' 1,734.91 1,688.40 103.24 -283.66 Hold for 111.69' 1,846.59 1,788.40 120.26 -330.40 Start 4°/100'DLS,57.5°TF,for 490.19' 2,336.79 2,198.90 272.97 -545.16 Hold for 20' 2,356.79 2,214.16 282.27 -554.14 Start 4°/100'DLS,32.49°TF,for 1096.35' 3,453.14 2,753.71 1,077.41 -1,024.32 Hold for 2768.5' 6,221.64 3,231.60 3,608.80 -2,038.36 Start 3°/100'DLS,-90.26°TF,for 2255.73' 8,477.36 3,541.90 4,782.90 -3,784.45 Adjust TF to 0°,for 26.58' 8,503.94 3,543.57 4,782.97 -3,810.98 Hold for 360.66' 8,864.60 3,563.71 4,783.95 -4,171.07 Start 3°/100'DLS,0°TF,for 3.42' 8,868.02 3,563.90 4,783.96 -4,174.49 Hold for 20' 8,888.02 3,564.98 4,784.02 -4,194.46 Start 2°/100'DLS,0°TF,for 73.64' 8,961.66 3,568.02 4,784.22 -4,268.03 Hold for 179.98' 9,141.64 3,573.13 4,784.71 -4,447.94 Start 2°/100'DLS,180°TF,for 68.64' 9,210.28 3,575.90 4,784.89 -4,516.52 Adjust TF to 0°,for 202.32' 9,412.60 3,579.35 4,785.45 -4,718.77 Hold for 188.82' 9,601.42 3,575.90 4,785.96 -4,907.56 Start 2°/100'DLS,0°TF,for 30.36' 9,631.78 3,575.19 4,786.04 -4,937.91 Hold for 227.51' 9,859.30 3,568.63 4,786.66 -5,165.33 Start 2°/100'DLS,0°TF,for 67.32' 9,926.61 3,565.90 4,786.85 -5,232.59 Adjust TF to-180°,for 71.36' 9,997.98 3,563.05 4,787.04 -5,303.89 Hold for 120.46' 10,118.44 3,559.75 4,787.37 -5,424.31 Start 2°/100'DLS,0°TF,for 71.36' 10,189.80 3,556.90 4,787.56 -5,495.61 Adjust TF to-180°,for 79.26' 10,269.06 3,553.85 4,787.78 -5,574.81 Hold for 159.87' 10,428.94 3,549.90 4,788.21 -5,734.64 Start 2°/100'DLS,0°TF,for 26.63' 10,455.56 3,549.12 4,788.29 -5,761.25 Hold for 193.18' 2/6/2017 11:33:00AM Page 11 COMPASS 5000.1 Build 74 S S Errors Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Site: Kuparuk 3R Pad MD Reference: Plan:39+9.9©48.90usft(Doyon142) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp09 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") ('') 12,700.00 3,500.36 41/2"x6-3/4" 4-1/2 6-3/4 8,868.02 3,563.90 7-5/8"x 9-7/8" 7-5/8 9-7/8 2,336.79 2,198.90 10 3/4"x 13-1/2 10-3/4 13-1/2 117.90 117.90 20"x 42" 20 42 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (1 (°) 2,038.81 1,956.90 K15 0.00 1,790.75 1,738.40 Base Pfrost 0.00 6,305.05 3,246.00 Top Ugnu A 0.00 3,561.98 2,772.50 Top Ugnu C 0.00 12,691.00 3,500.67 Fault 0.00 4,963.36 3,014.40 Top Ugnu B 0.00 8,580.00 3,547.82 Top West Sak D 0.00 15,426.00 3,328.38 Top West Sak D 0.00 1,735.91 1,689.30 T3 0.00 15,507.80 3,316.91 TD 0.00 7,157.70 3,387.80 Top N Sands 0.00 13,588.00 3,446.58 Base West Sak D 0.00 10,648.74 3,542.55 4,788.81 -5,954.32 Start 2°/100'DLS,180°TF,for 97.37' 10,746.11 3,540.90 4,789.08 -6,051.67 Adjust TF to 0°,for 0' 11,037.14 3,540.90 4,789.87 -6,342.70 Hold for 291.03' 11,085.83 3,540.49 4,790.00 -6,391.38 Start 2°/100'DLS,0°TF,for 0' 11,272.51 3,537.31 4,790.51 -6,578.04 Adjust TF to 0.04°,for 48.69' 11,321.20 3,536.90 4,790.64 -6,626.72 Hold for 186.68' 11,330.80 3,536.92 4,790.67 -6,636.32 Start 2°/100'DLS,-179.6°TF,for 48.69' 11,496.37 3,537.46 4,791.02 -6,801.89 Adjust TF to-171.73°,for 9.6' 11,601.24 3,535.90 4,791.41 -6,906.75 Hold for 165.57' 11,688.40 3,531.70 4,792.03 -6,993.80 Start 2°/100'DLS,4.86°TF,for 104.88' 11,785.44 3,525.55 4,792.90 -7,090.64 Adjust TF to 7.17°,for 87.15' 11,883.69 3,520.90 4,793.18 -7,188.77 Hold for 97.05' 11,973.69 3,519.38 4,792.33 -7,278.75 Start 2°/100'DLS,-158.58°TF,for 98.25' 12,175.94 3,518.91 4,789.22 -7,480.98 Adjust TF to-157.82°,for 90' 12,256.82 3,517.90 4,787.19 -7,561.83 Hold for 202.26' 12,335.84 3,515.36 4,783.64 -7,640.72 Start 2°/100'DLS,-43.83°TF,for 80.88' 12,658.12 3,501.94 4,765.96 -7,962.23 Adjust TF to-46.56°,for 79.01' 12,713.98 3,499.90 4,762.43 -8,017.94 Hold for 322.28' 12,798.19 3,497.87 4,755.34 -8,101.83 Start 2°/100'DLS,-121.63°TF,for 55.86' 12,956.39 3,495.20 4,740.01 -8,259.26 Adjust TF to-119.69°,for 84.21' 13,172.27 3,484.90 4,706.66 -8,472.14 Hold for 158.2' 13,228.07 3,480.17 4,694.00 -8,526.28 TD:12956.39'MD,3495.2'TVD 13,331.80 3,470.73 4,668.89 -8,626.48 Start DLS 3.00 TFO-85.01 13,362.72 3,467.90 4,661.16 -8,656.28 Adjust TF to-68.29°,for 55.8' 13,635.50 3,441.98 4,572.35 -8,912.65 Hold for 103.73' 14,062.09 3,400.43 4,404.99 -9,302.84 Start 3°/100'DLS,-85.01°TF,for 30.92' 14,251.49 3,387.90 4,332.36 -9,477.27 Adjust TF to-87.59°,for 272.78' 14,348.09 3,386.14 4,296.43 -9,566.91 Hold for 426.59' 14,862.79 3,385.29 4,106.24 -10,045.18 Start 2°/100'DLS,161.28°TF,for 189.4' 14,939.04 3,383.90 4,078.08 -10,116.02 Adjust TF to 170.63°,for 96.6' 15,181.35 3,362.67 3,988.94 -10,340.22 Hold for 514.7' 15,507.88 3,316.90 3,869.48 -10,640.65 Start 2.5°/100'DLS,0.16°TF,for 76.25' 2/6/2017 11:33:00AM Page 12 COMPASS 5000.1 Build 74 • • Errors Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Site: Kuparuk 3R Pad MD Reference: Plan:39+9.9 @ 48.90usft(Doyon142) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp09 Database: OAKEDMP2 Checked By: Approved By: Date: 2./6/2017 11:33:00AM Page 13 COMPASS 5000.1 Build 74 Pool Report • • 3R-102 Surface Location ti CPA::c .-c.mateCone h w From: . To: I Datum: [NAD83 Region: lalaska J Datum: (NAD27 J Region: Ialaska .1 C" Latitude/Longitude 'Decimal Degrees J r Latitude/Longitude 'Decimal Degrees 2J C UTM Zone:1 r South r UTM Zone:ITrue r South C: State Plane Zone: q j Units: IL-5"—:3 C% State Plane Zone:p Units: us ft r Legal Description(NAD27 only) r Legal Description(NAD27 only) -Starting Coordinates: -Ending Coordinates: X: 11660667.09 X: I 520635.69038799 Y: 16031455.90 Y: 16031703.84583149 Transform Quit r Help L el CPA(Coordinate D X From: — -- — -To: — — Datum: INAQ83 J Region: Ialaska J Datum: INAD27 J Region: Ialaska j r Latitude/Longitude IDecimal Degrees J C Latitude/Longitude (Decimal Degrees J C UTM Zone:I r South C UTM Zone:'True r South t� State Plane Zone: q Units: (us ft -1 C State Plane Zone:14 J Units: I�{t J C' Legal Description(NAD27 only) a Legal Description(NAD27 only) Starting Coordinates: — -Legal Description X: 11660667.09 Township:P 013 N . Range: 1009 1E w 1 Y: x6031455.90 Meridian lu J Section:lg IFNL J 1165a8271 FEL . 12949.6856 Transform Quit I Help I • • 3R-102 Surface Casing f CPCoo-c; j L I X .. �- urate Converter From: — — — To: Datum: INAD83 J Region: lalaska J Datum: INAD27 Region: ralaska C Latitude/Longitude 'Decimal Degrees .i C Latitude/Longitude Decimal Degrees .j C UTM Zone:1 r South C UTM Zone:'True f South f. i t: State Plane Zone:IT— Units:Fir.D, (% State Plane Zone:14 . Units: us-ft I C Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: Ending Coordinates: — —) X: 11660121.24 X: 1 520089.822708436 Y: 16031727.63 Y: 1 6031975.5885517 Transform I Quit J Help 1 r t3. CPAI Coordinate ., i From: —T. To:— — Datum: INAD83 J Region: lalaska J Datum: INAD27 .1 Region: lalaska J tC Latitude/Longitude !Decimal Degrees J C Latitude/Longitude !Decimal Degrees J C UTM Zone:1 r South C UTM Zone:IT rue E South ts` State Plane Zone:14 J Units: us-ft . C State Plane Zone:14 .- Units: us-ft C Legal Description(NAD27 only) (+` Legal Description(NAD27 only) Starting Coordinates: —Legal Description X: 11660121.24 Township: 1013 I _l E N . Range: Y: 16031727.63 Meridian jU j Section:19— FNL . 11385.5686 1FEL -1 13494.1572 Transform 1 Quit 1 Help 1 0 ill 3R-102 Intermediate Casing & Production Horizon �E, CPA:wc-anate Ccn erer ;� � From: . To: Datum: INAD83 _.1 Region: 'alaska _I Datum: INAD27 J Region: alaska J C Latitude/Longitude 'Decimal Degrees J C Latitude/Longitude 'Decimal Degrees _1 C UTM Zone:1- r South C UTM Zone:(True r South 4' State Plane Zone: 4 ; Units: lus-ft j G State Plane Zone:1 4 J Units:jus-ft :. r Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: --Ending Coordinates: X: 11656480.00 X: 1 516448.570781608 Y: 16036228.00 Y: 16036476.01601078 Transform I Quit 1 Help 1 � CPA:�oo�.; � :rat� _cn.�rter-° X r From: To: Datum: 1NADS3 zal Region: 'alaska J Datum: INADz7 , Region: 'alaska .l r LatitudelLongitude 'Decimal Degrees 2.1 r Latitude/Longitude (Decimal Degrees C UTM Zone:1 r South C UTM Zone: True r South ( State Plane Zone: 4 Units:li-ft j C State Plane Zone: 4 Units: us-ft C Legal Description(NAD27 only] t' Legal Description(NAD27 only) Starting Coordinates: Legal Description X: 11656480.00 Township: 1013 N Range: 1009 'E Y: 16036228.00 Meridian: IU J Section:15 (FNL .) 12155.3262 'FEL j 11831.8625 Transform I Quit 1 Help 1 • il ti 3R-102 TD En. CPAt Coo-dinate Come'` LJ I ._ 1, From: — — To: Datum: NAD83 Region: Jalaska J Datum: 1NAD27 H Region: lalaska +j C Latitude/Longitude [Decimal Degrees .J r Latitude/Longitude !Decimal Degrees C UTM Zone: I _ E South C` UTM Zone:'True E South a State Plane Zone:Ft . Units: lus-ft +j a State Plane Zone: 1 4 I Units: 'us-ft +j Y` Legal Description(NAD27 only) r Legal Description(NAD27 only) Starting Coordinates: Ending Coordinates: X: h 650017.00 X: 1 509985.699020293 Y: 16035296.00 Y: 1 6035544.13003378 Transform 1 Quit 1 Help 1 In CPA?Coo-dinate'' L –From: -To: Datum: NAD83 J Region: lalaska +I Datum: NAD27 J Region: Jalaska +1 C Latitude/Longitude Decimal Degrees . C Latitude/Longitude Decimal Degrees + C UTM Zone:[ 7 South C UTM Zone:1True E South ( .� 4 C State Plane Zone:!4 1 Units: us ft C State Plane Zone: Units: ]us ft C Legal Description(NAD27 or;!_ a Legal Description(NAD27 only) 1 Starting Coordinates: Legal Description X: 11650017.00 Township: 1013 N Range: 1009 1E id Y: 16035296.00 Meridian: lU J Section:16 jFNL •1 '3075.7943 FEL . 13020 2582 Transform 11 Quit I Help I • 4111 11:50,February 06 2017 WELLBORE TARGET DETAILS(MAP COORDINATES) 39--102wp09 Name TVD Shape 39-10219.001Mile 3316.90 Circle(Radius'1320.00) 3 10219.70100 3118 MW 3316.90 Circle(Raius 100.00) Quarter Mile View MW 3R-10218.T17 103118 M 3383.90 Circle(Aadius:100,00) 39-1021].718103116 MW 3387.90 Circle 07zdius:100.00) 39-10216.115 103116 MW 3467.90 Circe�R dius:10000) 314102 15.T14 103118 MN 348490 Gude(Radius:10000) 39-102 14.113 103116 MW 349990 Circle(Radius:100.00) 3R-102 13.T12 103116 MW 3517.90 Circle(Radius:100.00) 36-102 12.111 103116 MW 3520.90 0159(Radius,100.00) QQO 39-10211.791103118 MN 3535 90 GrUe(Radius,19000) ... ..._. ..... _ ..... _.... ......... ___-.- ...._ .....39- 3 e(Radius,100 10210 79103116 MN 536 90 GrU (R 00) *1029 T7033116MW 350.90....._I Gude(Radius, 119-'001...... .....1 3,1029.78103118 MW OI06-05 354090 Grsle(Ratl 10000) a 36-102 7 Top 0010818 MW 3541.90 Gree(Radius,100.00) 3R-102 7 16 103116 MW 0106-05P 90 Circle(Rad 100.00) 1 4 0 0 0— n 3 102 0 15 103116 MW 5558 90 Circle(Radius,100.00) e'F .... ..__ 1 ........_._.... ._.. ...... ._ ..._ ....3=1022 Heel""1%d HF1e ... ._._ .. .3583 90....... _-CirfA6(R46uE T32�W).... ,Q' 3 102 Heel 103116 MW 35111.90 Circle(Rad .100.00) a 3 1025.04103118MW 3565.90 Grde(Radius:10000) 3 102 3.02 103116 MN 3575.90 Gree(Racfius,6100.00) 0Q1fpa �Q� 3 1024.T3103116MW 3575.90 Circle(Radius:100.00) 10500 ._.... _. a Q o` 0 3 Qe 4cE L O eq. Op?7.. In o 2 Oliktk 27000 m Pa, sre'_..._ CO I`��AIIP0141 9 g. 03500 0 Z 39-.10 1 .^, '° • • _C I '- 3R-26PB1• -3500 • I 39--26 I I I I 1 I I I I -21000 -17500 -14000 -10500 -7000 -3500 0 3500 7000 West(-)/East(+) (3500 usft/in) • 0 3R-1 .2wp09 3-D View OP16-03,OP16-O3L1PB7,OP16-03L1P8 OP19T7 N,OP79-T1 N,OP79-T1N ................. • • ..'11,..1: . . „I Plan:314.101,Plan 3R 101 3R-101wpi ��"•-�...., ........-� • • : Plan:313-101,Plan:3R-101L1.3R-101 L1wp1 .OP19-T1 N,OP19-T1 NPB1,0819-T1 NP81 -•-.-. • Plan:3R-102,Plan:3R-102,3R-1. —/f---------- *I ...' � t / ,\ I'. • 0 P22 WW03.OP22 WW03, - . OP22 W W03 OPZI-WWo1,OP.-WWOI,0921 ei-WW1' -�� 3R-12D 3R-120 30-12• • • 3R-102wp09 3-D View r� . ,. i., r:.i r•.41 r:• \,,,,,,...„. d 0 ow r i. li, ,,,,,_,,„„.... _.......i ....'...'.'.'.....'...''....:.',N.,... ,„.. „. ,,,,,-...,..,:„. ' ----......-.I.T.:..i.T.1...T...-..-.1.r'.7.7...1.:„......,......i._,.....,.... 0 0 3R-102wp09 3-D View • Plan:3R-101,Plan:3R-101,3R-101wp1 .,,, .10 PIan:3R-101,Plan:3R-101 L1,3R 101 Liwpt ,..rte . t / . . .............._ .... OP22-W W03,OP22-W W03,OP22- CO Plan:3R-102,Pian 3R-102,3R-102wp0 • • Tollerable Collision Risk Worksheet As - built REV DATE BY CK APP • DESCRIPTION REV DATE BY • APP DESCRIPTION 1 12/29/09 AJR NRB PER K090043ACS 2 12/18/16 JAH JFC PER K160005ACS NOTES: 1. BASIS OF LOCATION AND ELEVATION IS DS3R STP 4 MONUMENTATION PER LOUNSBURY & ASSOC. 6 5 pppl*`,+ PROJECT 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, LOCATION ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES L( ARE N.A.D. 27. s4 t > . 3. ELEVATIONS ARE B.P.M.S.L. 7 '�' 4: g ►`s� 31 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED DEW LINE SECTION 9, TOWNSHIP 13 NORTH, RANGE 9 EAST, SITE +1 UMIAT MERIDIAN, ALASKA 1 1 a 5. DATES OF SURVEY: 12/18/16 FB# L16-40-5 , �':.`- 13Q NO t ` . 1 0CC 18 i ,, r 16 6. ALL DISTANCES SHOWN ARE GROUND i1s. ii 111 iNdlet 17 n 54 y 89 VICINITY MAP N E 1" = 1 MILE 1 Fh- a • g 10 . 11 )5?,0\ ,\,2_ • AA • -\5 LEGEND 2b • 1-1 • EXISTING CONDUCTOR LOCATION '0 '0 ® AS--BUILT CONDUCTOR LOCATION 2Ci 'LA 22 • DS3R GRAPHIC SCALE 0 100 200 400 I I �E 1 inch = 200 ft. �,\ LOUNSBURY & ASSOCIATES, mc. SEE SHEET 2 FOR LOCATION INFORMATION SURVEYORS ENGINEERS PLANNERS 11.7 AREA:3R MODULE: XXXX UNIT: D3 ConocoPhllli s DS3R r WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6318d18 12/29/09CEA—D3RX-6318D18 1 OF 2 2 REV DATE BY CK APP • DESCRIPTION REV DATE BY 1110 APP DESCRIPTION 1 12/29/09 AJR NRB PER K090043ACS 2 12/18/16 JAH JFC PER K160005ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 9, T. 13 N., R. 9 E., UMIAT MERDIAN Well NAD 27 NAD 27 Section No. ASP Coordinates Geographic Coordinates Offset. Elev. Y X Lat. Long. F.N.L F.W.L O.G. PAD 5 6031765.10' 520614.54' 70' 29' 52.596" 149' 49' 53.109" . 1598' 2309' 4.7' 16.9' 6 6031741.56' 520622.68' 70' 29' 52.364" 149' 49' 52.871" 1622' 2317' 4.7' 10.9' 7 6031717.82' 520630,86' 70' 29' 52.131" 149' 49' 52.632" 1645' 2326' 4.8' 11.0' 8 6031694.24' 520639.12' 70' 29' 51.898" 149' 49' 52.391" 1669' 2334' 4.8' 10.8' 9 6031670.68' 520647.18' 70' 29' 51.666" 149' 49' 52.156" 1693' 2342' 4.8' 10.8' 10 6031646.96' 520655.38' 70' 29' 51.433" 149' 49' 51.916" 1716' 2350' 4.9' 10.8' 11 6031623.40' 520663.55' 70' 29' 51.201" 149' 49' 51.678" 1740' 2358' 5.0' 10.8' 12 6031599.81' 520671.67' 70' 29' 50.969" 149' 49' 51.441" 1763' 2366' 5.1' 10.8' 14 6031491.19' 520709.37' 70' 29' 49.899" 149' 49' 50.340" 1872' 2403' 5.5' 10.9' 15 6031467.51' 520717.59' 70' 29' 49.666" 149' 49' 50.100" 1896' 2411' 5.6' 10.9' 17 6031420.30' 520733.83' 70' 29' 49.201" 149' 49' 49.625" 1943' 2427' 5,7' 10.8' 18 6031396.65' 520741.97' 70' 29' 48.969" 149' 49' 49.388" 1967' 2435' 5.8' 10.6' 19 6031373.03' 520750.36' 70' 29' 48.736" 149' 49' 49.143" 1991' 2443' 5.9' 10.6' 20 6031349.41' 520758.32' 70' 29' 48.503" 149' 49' 48.910" 2014' 2451' 6.1' 10.9' 21 6031325.80' 520766.51' 70' 29' 48.271" 149' 49' 48.671" 2038' 2459' 6.3' 11.7' 22 6031302.22' 520774.67' 70' 29' 48.039" 149' 49' 48.433" 2061' 2467' 6.5' 11.4' 25 6031443.85' 520725.61' 70' 29' 49.433" 149' 49' 49.865" 1920' 2419' 5.6' 10.9' 26 6031514.74' 520701.13' 70' 29' 50.131" 149' 49' 50.580" 1849' 2395' 5.5' 11.0' *101 6031732.16' 520625.98' 70' 29' 52.272" 149' 49' 52.775" 1631' 2321' 4.8' 9.9' *102 6031703,85' 520635.69' 70' 29' 51.993" 149' 49' 52.491" 1659' 2330' 4.8' 9.9' !' * CONDUCTOR ASBUILT THIS SURVEY • ,�4%,\„2"'„ ...... . �� "'�+ +11� SURVEYOR'S CERTIFICATE 'r a �•' N,� - ♦�` i HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND +� � �9th /\ LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF l.. -''T % ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND �O 9?JI REMIAH F. CORNELL:�� ait THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION OA C' '+ LS-12663 0 +. 0 +••''.,•�4 ARE CORRECT AS OF DECEMBER 18, 2016. LOUNSBURY ' O & ASSOCIATES, INC. �� iii.'r SSIONA-.,„. SURVEYORS ENGINEERS P1ANNERS ��11ri1r��♦ I AREA:3R MODULE: XXXX UNIT: 93 ConocoPhiJIi s DS3R WELL CONDUCTOR Alaska, Inc. _ ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6318d18 12/29/09 CEA-D3RX-6318D18 2 OF 2 2 3R-102librilling Hazards 4mmary 13-1/2" Open Hole / 10-3/4" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin Running Sands and Gravels Low Maintain planned mud parameters, increase mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out Washouts/Hole Sloughing Low Cool mud temperatures, minimize circulating times when possible 9-7/8" Open Hole / 7-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Stuck Pipe Low Good hole cleaning,pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Pressure Low BOP training and drills, increased mud weight. Lost circulation Moderate Reduced pump rates, mud rheology, LCM Anti-Collision Moderate Follow real time surveys very closely. Hole swabbing on trips Moderate Trip speeds,proper hole filling(use of trip sheets), pumping out 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud weight. Pressure Stuck Pipe Low Good hole cleaning, PWD tools monitoring and analysis, decreased mud weight Lost Circulation Moderate Reduced pump rates, mud rheology, LCM program, additional fluid stored on location during completion run. Differential Sticking Moderate Follow mud program,keep pipe moving when able Hole Swabbing on Trips Moderate Trip speeds, proper hole filling(use of trip sheets),pumping out or back reaming Fault Crossings and Moderate Use developed best practices for concretion drilling. Concretions Getting Liner to Bottom Moderate Maintain solids free water based mud properties and lubricity while running liner lower completion, monitor torque and drag. 3R-102 Drilling Hazards Summary.doc 2/6/20179:49:42 AM • 0 0--0 W m _� - °' . m� ri T °'co- up 6 � ba � obb ,.)0.) o b (:) vcV 7 V _ 00 O M O r a QN_l V U mi a N 4t co /"1 ,-0 3 PO I A CD b N 7 M © a .-0-1) aH x O W Mkt' 00 (NI ^ a tj O °' i p on `n v tea.Q ,a, 000 o i 1--- a b N 3 M .a _ °c�o`°o v 'e C7 WAS t 1 -�I Oal Gam • �Q ' a 'a v , r �C 1cn M 0b o vi -S``' ''' 1 � Q p W C7g #<-• rUe .0.8 .60 aau Q en';',9, r O O ,0 00 0P A O a0 N M al t--� Q�+ 7 N b�A O O Fy ,- �. 00 00 al k x 3k 06 d i t N r • 0 > -" o oe Mk ro ,,,,_kr ,,,,v---------1 c,2 u _N „ x Ch o � O Q 00 CV 00 0 ° c'? �A N o 0 o o 00 U OqM + M N k -"N - U23 M � ConocoPhillips Well Schematic 3R-102(Injector) 3R-102 Completion Schemahc WP09 1/30/2017 Ala-,SA K Hanford • • k..., CONTAINMENT DIKE y 1 ---:\.) { l Ci, r = '4% %JII 1.1 U "D Z M4►dld 0 o ❑; rile =II- W°II53 v Z — 0 -i •N1.11'Vvd CA ,0wMIMI ° 'P1 N 1. I IIID ::: Nr ---.:: ,/, I mN NO❑m r IoOO :,- ..:A'D 11111111. a 01 ❑ Cl)OO W1 C4=1- o L1y �N MI N N m J 4111) a rin o z 0 n D= y if I p (fl • o S ,>'O'J w Enr n o 0 c o E N 0 • TRANSMITTAL LETTER CHECKLIST WELL NAME: /KAU.. 3R - /O Z / l/IS PTD: 02 Development 1 Service Exploratory Stratigraphic Test Non-Conventional FIELD: ��/�� POOL: kyara< 9 41/ 1fJ1 A-K 0 IL l 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 II 0 7 a) N N v a) 0 0 O Tu E . ca . . .,Q . . a �. U I Y. N 0, c c c, �' a o. $ E O H, , a o -o ° 3 0 0o m 0) . N. . Z, C , C. W �' , 0, a) �' N CT N' 2 . . rn d, . w. . , > c c o. U. �. O. 3. . a 0. o' . yo 33@, n aa O. . c. U ,-a. of , S , 9 , . . of . . .5 3 �, N O .0 u), N, , =, 0 Y, 0, W CA j, o d _ p. 4 o cn o '' O rn v g' a Oa j) Y' W. a), ; H. o c 2 . c . z� �, o � co, to 2 . p) 0. r-- CO H r .a - o' . H. ';, , O' E oS �' co. 4 o �' E' v' a �' o) o' �' D �' 0 k. a CO c' a a a . 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'�, a .E a) CU 0 0 o m' o U c �' a) m a) i a`i an c y 3 y c. . �- H. �- . w a ? a; a; a o' a cLi E. @ � m c co , z°; a -J; D; � 5 � in, �' ooaa_,0, a OCOOO' 00' <<0m' m' C.i3 �' 2' 0 0' CI)i0, 1 W a n 0 - N Co v t° CO CO 0 O N CO v to CO Ps CO 0) O N C.) v to CO ti CO O) _' N Co e t° CO CO O - N N N N N N N N N N Co CO CO Co Co Co Co Co Co Co U 0 l'"' N c a) Gf O O @ N m O O o �ILI O «. 0 co o) 0 N- 0 co o H O.r' _O ..0 N [ N N O .E a 0 a) -I: CN • 0 CO O J ik •C a co .0� a J ° a m 0W= 0 E Q0 >H 'C Qa) Q d Cl- Q w (.9 • PTD 211., - �Z Loepp, Victoria T (DOA) From: Hallford, Kelsey <Kelsey.Hallford@conocophillips.com> Sent: Thursday,January 19, 2017 11:47 AM To: Loepp,Victoria T(DOA) Cc: Bearden,J Daniel Subject: RE: PTD:216-157 Rig Change Follow Up Flag: Follow up Flag Status: Flagged Good morning Victoria, There is still some uncertainty in what rig will be drilling 3R-102 (PTD#216-157). I will notify you once we have a final decision. Kelsey Hallford From: Hallford, Kelsey Sent:Wednesday,January 11,2017 3:17 PM To: 'Loepp,Victoria T(DOA)'<victoria.loepp@alaska.gov> Cc: Bearden,J Daniel<J.Daniel.Bearden@conocophillips.com> Subject: PTD: 216-157 Rig Change Victoria, RIG CHANGE: We are approaching spud of 3R-102(216-157)and I wanted to inform you of a rig change. Doyon 142 will be drilling 3R- 102 instead of the planned Doyon141.As such,the directional program is slightly different to reflect an 11' MD difference in RKB of the rigs and as built surveys of conductor placement. I've attached the new directional program for reference. As confirmed over the phone, I will submit a hard copy to you with revisions to the PTD of a different rig being used and subsequent well coordinates this week. BOP Stack Configuration: I wanted to be clear about the fixed ram placement BOP stack configuration to be used on this well,this is what was done for the 1D and 1C West Sak wells drilled in 2015; highlighting that it is different than what we did this past year in the higher pressurized Kuparuk reservoir wells. As 3R-102 has a MASP of-1200psi (Class 2 in ConocoPhillips standards) and following the AOGCC regulations(0-3000psi requiring 3 preventers)we plan on running a fixed preventer placement pictured below. The ram placement is no different than current operations while running casing.The deviation from a Kuparuk reservoir well is that rather than switching the upper cavity of casing rams back to VBRs(after casing has been run and cemented), which is the second set of VBRs in the stack and 4th preventer,we will utilize the annular, blind rams and existing VBRs in the lower cavity. We will have 3 preventers in use at all times for both drilling operations and casing operations: • Casing operations:an annular,casing rams,and blind rams('fixed' in the diagram referencing those casing rams will remain in that cavity for the duration of the well). 1 • i • Drilling operations: an annular, blind rams, and lower VBRs. Class 2 BOP Optiontsl I r�..ra. i♦ Ann n fixtd NM- Blind Ail -7-1 II KO II i x■■�.r VBR ,. T-13 Thank you for taking the time to discuss this with me today and please let me know if the BOP configuration needs further explanation, Kelsey Hallford GKA Drilling Engineer ConocoPhillips,Alaska 907-265-1577 work 907-440-0004 cell 2 VOF T„ • �� THE STATE Alaska Oil and Gas �� ► of/\ TAS}(j.\ Conservation Commission �_ -_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 "° Main: 907.279.1433 O4'ALAS1 Fax: 907.276.7542 www.aogcc.alaska.gov G. Alvord Alaska Drilling Manager er ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU 3R-102 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-157 Surface Location: 1658.7' FNL, 2949.57' FEL, T13N, R9E, S9, UM Bottomhole Location: 3075.79' FNL, 3020.26' FEL, T13N, R9E, S6, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. Per Statute AS 31.05.030(d)(2)(B)and Regulation 20 AAC 25.071,composite curves for well logs run must be submitted to the AOGCC within 90 days after completion,suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition,the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20,Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05,Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, PIIV"-,___ Cathy P. Foerster Chair A DATED this Z3 day of December, 2016. STATE OF ALASKA I A�A OIL AND GAS CONSERVATION COM ON PERMIT TO DRILL NOV 17 2016 20 AAC 25.005 1AQ la.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj Single Zone E1c.S sed for: Drill ❑, - Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas II] Reentry Exploratory Cl Gas Hydrates El ❑ p ry ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q - Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc ♦ Bond No. 59-52-180 ' KRU 3R-102 ' 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 15,500 • TVD: • 3306 Kuparuk River Field , 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1658.7'FNL,2949.57'FEL, T 13N, R 9E,S 9,U ADL 355023,ADL 373301,ADL 355024 West Sak Oil Pool , Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2156.75'FNL,1399.98'FEL, T 13N,R 9E,S 5,U 931695 12/15/2016 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 3075.79'FNL,3020.26'FEL, T 13N,R 9E,S 6,U 3255,677,1800 2156 ft 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 37.9 - feet 15.Distance to Nearest Well Open Surface: x- 520636 y- 6031704 Zone-4 • GL Elevation above MSL: 9.9 - feet to Same Pool: 2860'MD(ENI well) 16.Deviated wells: Kickoff depth: 400 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 98.1 degrees, Downhole: 1590 psi , Surface: 1235 psi, 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" 94# H40 Welded 80 10 10 90 90 200 cf of ArcticCRETE 13.5" 10.75" 45.5# L-80 Hydril 563 2314 10 10 2324 2188 1454 sx DeepCRETE Lead, 193 sx DeepCRETE Tail 9.875" 7.625" 29.7# L-80 H563/TXP 8850 10 10 8860 3553 1008 sx Class'G' 6.75" 4.5" 11.6# L-80 IBTM 4040 8660 3540 12700 3489 Slotted Liner Completion(no cement) 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 Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat BOP Sketch Drilling Program Time v.Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 1/15/2016 22. I hereby certify that the foregoing is true and correct. Contact Kelsey Hallford @ 265-1577 Email kelsey.hallford(cr�cop.com Printed Name G.Alvord Title Alaska Drilling Manager Signature A 6-ak. Phone 265-6120 Date 4110-0/4 Commission Use Only Permit to Dr'l API Number: Permit Approval See cover letter for other Number: ' IC- 15?- 50-Oa9- ._3?i _00 ()Q Date: ) 2--23-/Ce 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: lir Other: 36./0S_f-" Samples req'd: Yes❑ Nog Mud log req'd:Yes[1] No[' c H S measures: Yes g. No Li Directional svy req'd:Yes 2c No❑ ,t KMV/ar PTrV�w fr-r f�� to 25-cf)I e� d 5 'r atr�j czr0 p Ii ca fi�rn (/LJ"4 63) Spacing exception req'd: Yes❑ Nod Inclination-only svy req'd:Yes❑ No ✓✓ po .t in,f rig 1 in/c h ay, I-9'ti rcc! 172r. /ivs Cavive�S1ah aid i-n v571 in clvac Mar rrct'd ,i(-5 iallg pt 00 of krri`Hrvi ur oti-,c)cq/r r fa i iVI Qlc iyr f-rc1 16->i k-sC a-L -z_q 16 p r .0446-25, 4.07 (c)( .` APPROVED BY 3 / Approved by: 9P(14----. COMMISSIONER THE COMMISSION Date: I Z- 2 ^[c Form 10-401`�'At '�fi 2�rr1�2) /2;j'Fiiis+ppPmit's valid fop 4 RTGiVaterpproval AAC hubs in DupUForm ane ((At lit')4)IY ., <</iV1iUIVL (2025.005(g)) Attachments in Duplicate i I Application for Permit to Drill,Well 3R-102 Saved: 15-Nov-16 November 18,2016 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill Well 3R-102,A Kuparuk West Sak D Sand Pre-Produced Injector Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a permit to drill an onshore grassroots pre-produced injector well from the 3R pad. The expected spud date for this well is December 15,2016. It is planned to use rig Doyon 141. ✓' 3R-102 is planned to be a horizontal well in the West Sak D sand.jThe surface section will be drilled with 13-1/2"bit and run 10-3/4"casing to+/-2,324'MD/2,188'TVD. The intermediate section will be drilled with 9-7/8"bit and run 7-5/8" casing to 8,860'MD/3,553'TVD.The production hole will be drilled with 6-3/4"bit to 15,500' MD/3,306' TVD for logging purposes and 4-1/2"slotted liner run to+/- 12,700'MD/3,489'TVD.The upper completion will be run with 4- 1/2"tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Kelsey Hallford at 265-1577 (kelsey.hallford@conocophillips.com)or Chip Alvord at 265-6120. Sincerely, 4o Chip Alvord Drilling Manager • • Application for Permit to Drill Document Kuparuk Well 3R-102 Well Name Requirements of 20 AAC 25.005(0 The well for which this application is submitted will be designated as 3R-102 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must he accompanied by each of the following items.except for an iters already on file with the commission and identified in the application: (2)a plat idem fy°ing the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation.and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration: (C)the proposed depth of the well at the top of each objective formation and at total depth: Location at Surface 1658.7'FNL, 2949.6'FEL, Sec 9, T 13N,R009E,UM NGS Coordinates RKB Elevation 37.9' AMSL Northings: 6,031,703.98' Eastings: 520,635.80' Pad Elevation 9.9'AMSL Location at Top of 2156.8'FNL, 1399.98'FEL,Sec 5,T13N,R009E,UM Productive Interval(West Sak D Sand) NGS Coordinates Measured Depth, RKB: 8,427' Northings: 6,036,475.55' Eastings: 516,880.42' Total Vertical Depth, RKB: 3,528' Total Vertical Depth, SS: 3,490' Location at Total Depth 3075.8'FNL, 3020.3'FEL, Sec 6,T13N,R009E,UM NGS Coordinates Measured Depth,RKB: 15,500' Northings: 6,035,544.13' Eastings:509,985.7 Total Vertical Depth, RKB: 3,306' Total Vertical Depth, SS: 3,268' and (D)other information required by 20 AAC 25.0500): Requirements of 20 AAC 25.050(b) If a well is to he intentionally deviated,the application far a Permit to Drill(Form I0-401)must (I)include a plat.drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment: Directional Plan And (2)fbr all wells within 200 feet(lithe proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records.and show that each named operator has been furnished a copy of the application by certified mail:or- (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application fa-a Permit to Drill must he accompanied by each of the following items.except for an item alreaclr on)*with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPS)as required by 20 AAC 25.035.20 A..4C 25.1136,or 20.4.,1C 25.037,as applicable: Please reference BOP schematics on file for Doyon 141. • Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application fire a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (a)it formation on drilling hazards,including (-t)the nnaximunn downhole pressure that may be encountered,criteria used to determine it,and maximum potential.surface pressure based on a methane gradient: The maximum potential surface pressure (MPSP)while drilling 3R-102 is calculated using an estimated maximum reservoir pressure of 1,590 psi(based on Kigun 1 MDT pressure of 1660 psi and corrected to planned depth), a gas gradient of 0.10 psi/ft, and the estimated depth of the West Sak D sand at 3,550' TVD (WP07): A Sand Estimated. BHP = 1,590 psi / (- 7 /' FP, A Sand estimated depth (WP04) =3,550' TVD 315 Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 355 psi (3,550' TVD * 0.10 psi/ft) MPSP=BHP—gas column = 1235 psi (1,590 psi—355 psi) (B)data on potential gas zones: The well bore is not expected to penetrate any shallow gas zones. And (C)data concerning potential causes of hole problems such as abnormally gen-pressured strata,lost circulation cones.and zones that have a propensity for differential sticking: See attached 3R-102 Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already()Ole with the corurrtission and identified in the application: (5)a description of'the procedure for conducting formation integrity tests,as required under 20 A.-1 C 25.0300: A procedure is on file with the commission for performing LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items.except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner.pre-perforated liner.or screen to be installed Casing and Cement Program Casing and Cementing Program Csg/Tbg Hole Weigh Length Top MD/TVD Btm MD/TVD OD(in) Size t(lb/ft) Grade Conn. () (ff) (ff) Cement Program 20 42 94 H-40 Welded 80 Surf 90/90 Existing Hydril Cement to Surface with 10-3/4 13-1/2 45.5 L-80 563 2,314 Surf 2,324/2,188 1,454 sx ALC Lead 11.0 ppg, 193 sx DeepCRETE Tail Slurry 12.0 ppg Hydril 7-5/8 9-7/8 29.7 L-80 563/ 8,850 Surf 8,860/3,553 1,008 sx Class G at 15.8 ppg TXP w/TOC at 5,044'MD 4 1/2 6-3/4 11.6 L-80 IBTM 4,040 8,660/3,540 12,700/3,489 Slotted liner • • 10.75"Surface Casing run to 2,324'MD/2,188'TVD Cement from 2324'MD to 1824'(500'of tail)with DeepCrete @ 12 ppg,and from 1824'to surface with 11 ppg DeepCrete.Assume 250%excess annular volume in permafrost and 50%excess below the permafrost(1778'MD),zero excess in 20"conductor. Lead slurry from 1,824'MD to surface with Arctic Lite Crete @ 11 ppg Conductor to Surface 80'X 1.9 ft3/ft X 1 (0%excess)= 152 ft3 Permafrost to Conductor (1,778—80') X 0.3637 ft3/ft X 3.5(250%excess)=2,161 ft3 Top of Tail to Permafrost (2,305—1,454')X 0.3637 ft3/ft X 1.5(50%excess) =464 ft3 Total Volume= 152+2,161 +464=2777 ft3=>1,454 sx of 11 ppg DeepCrete @ 1.91 ft3/sk Tail slurry from 2,324' MD to 1,824'MD with 12 ppg DeepCrete Shoe to Top of Tail (2,324—1,824')X 0.3637 ft3/ft X 1.50(50%excess) =273 ft3 Shoe Joint (80')X 0.5399 ft3/ft X 1.0(0%excess) =43 ft3 Total Volume=273+43=316 ft3=>193 sx of 12 ppg DeepCrete @ 1.64 ft3/sk 7.625"Intermediate Casing run to 8,860'MD/3,553 TVD Single stage slurry is designed to be at 5,044'MD,which is 500' above the Ugnu B;40%excess annular volume. Tail slurry from 8,860'MD to 5,044'MD with 15.8ppg Class G+additives Shoe to Top of Cement (8,860'—5,044)X 0.2148 ft3/ft X 1.40(40%excess) = 1148 ft3 Shoe Joint (80')X 0.2577 ft3/ft X 1.0(0%excess) =21 ft3 Total Volume= 1148+21 = 1169 ft3=>1008 sx of 15.8 ppg Class G+additives @ 1.16 ft3/sk Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must he accompanied hi'each of the following items,except for an item already()Ole with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematic on file for Doyon 141. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must he accompanied by each of the following items,except for an item already on file with the commission and identified in the application: s (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Mud Program Summary Surface Intermediate Production 13-1/2" Hole 9-7/8" Hole 6-3/4" Hole 10-3/4"Casing 7-5/8"Casing 4-1/2" Liner FLO-PRO NT Mud System Spud Mud LSND(WBM) (WBM) Density 8.8-9.5 9.0-10.0 9.0-9.5 PV ALAP ALAP ALAP YP 30-80 20-30 15-20 250—300 to Permafrost Base Funnel Viscosity 100—150 to TD N/A N/A Initial Gel 30-50 9-11 7-10 10 minute Gel 30-50 <20 8-16 API Filtrate NC <6 <6 HTHP Fluid Loss at 160 F N/A <10 < 10 pH 10.8-11.2 9.5- 10.0 9.5- 10.0 Diagram of Doyon 141 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A -Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A-Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A-Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska,Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to attachment for proposed well schematic. S 1. Move in/rig up Doyon Rig 141. Install 21-1/4"Annular with 16"diverter line and function test. 2. Spud and directionally drill 13.5"hole to casing point at+2324'MD/2188'TVD as per directional plan. Run MWD tools as required for directional monitoring(gamma ray,resistivity,GWD). 3. Run and cement 10.75",45.5#,L80,Hydril 563 casing to surface. Displace cement with mud and check floats upon bumping plug. Perform top job if required. 4. Remove diverter system,install and test 13-5/8"x 5,000 psi BOP's to 3500 psi(annular preventer to 3500 psi). Notify AOGCC 24 hrs before test. 5. PU 9.875"bit and 6.75"drilling assembly,with MWD(gamma ray,resistivity,density,porosity). RIH,clean out cement to top of float equipment and test casing to 3000 psi for 30min. 6. Drill out cement and,between 20' and 50'of new hole. Perform formation integrity test to 13.0ppg EMW, recording results. 7. Displace to LSND water based drilling fluid. 8. Directionally drill to 7-5/8"casing point at 8860'MD/3553' TVD.Backream out of hole to the surface casing shoe. 9. Run 7.625",29.7#L80,Hydril 563/TXP casing to surface. (top of cement to be 5044'MD/3010' TVD which corresponds to 500' above the Ugnu B formation). 10. Install wellhead x 7.625"packoff and test to 3500 psi. 11. Flush 10.75"x 7.625"annulus with water,followed by isotherm. 12. PU 6.75"PDC Bit and 4.5"drilling assembly,with MWD and LWD logging tools(gamma ray,resistivity, density,porosity,periscope,sonic). RIH,performing MAD pass with sonic tool in memory mode to ensure cement quality. at— 13. Clean out cement to top of float equipment. Test casing to 3500 psi for 30 minutes. 14. Drill out cement and 20'—50'of new hole. Displace hole to lateral drilling Flo-Pro WBM system. Perform formation integrity test to 13.5ppg EMW,recording results. 15. Directionally drill 6.75"hole to West Sak D Sand to TD at+ 15,500'MD/3306' TVD as per directional plan. 16. Back ream out of hole to 7.625"shoe. Circulate to clean up casing and POOH on elevators. 17. If pay is across fault block to west,PU MDT wireline tool and RIH on DP to the intermediate casing shoe. s 18. Pump down TLC-H wireline,ensure MDT tool is communicating before going into open hole with wireline through a side entry sub on the DP. 19. TIH to zones of interest @ 13,670—14,100'MD and 14,930—15,370'MD and take MDT samples. 20. POOH on elevators. 21. PU and run 4-1/2"slotted liner. 22. Make up liner hanger running tool. 23. Finish running liner to 12,700'MD to land liner. 24. Set liner hanger @ f 8660'MD/3540' TVD,set liner top packer and test. POOH. 25. PU 4.5"tubing as required and RIH to depth. Land tubing.Set BPV 26. Nipple down BOPE,nipple up tree and test.Pull BPV. 27. Freeze protect well with diesel by pumping into 4.5"x 7.625"annulus,taking returns from tubing and allowing to equalize. (If the schedule and equipment availability allows,the Wells Group will freeze protect the well post rig). 28. Set BPV and move rig off. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill music be accompanied by each of the folowing items.except for an item already on file with the commission and identifIed in the application: (I 4)a general description of hose'the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20:IA('25.080 fbr an annular disposal operation in the well.: Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (DS 1B CRI)or Prudhoe DS-4.IA11 cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well,or stored,tested for hazardous substances,and(if free of hazardous substances)used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Diverter Layout Diagram E Lf1 U1 � � ) & Ga) E 2 aif - § E > E• 2 3uai ■ -0 -0 u ® ' u CO $ i 2 B / c c Q \ c 7 & � -J 01 it a) 00 0 . E t c 0 2 IAe � 0. _o m ■ 4.4 g 2 [ 7 vt Ct. E R .a -o 0) u g § 3 _o q cuL)§ q ® 0 2 CD o a o 2 a c R c ° ° o a) © m \ E / 4:3• S t g o u > O to R - _ 2 % 2 / ° co r # LA c r "0 \ E o 0• = E u m k 0 � k ° U ' - .! kc) 2 / 3 S. kz 15 kE � kk � § Ca / ° ' ° 2 k ■ t o t o 2 a .� & 2 - 7 r) > 0 2 C k a © E � 2 « • U LA - a / 2 o U g c FS 7.0 In CV 00 u m U cc o ± Q k G 2 m in o o - ! q q Ln o.2 2 m m o 4.0 iii � k k el in VI � 2 ° 2 2 » o o co 0_ c R e r-I MI 7 % z / 2 CNI 3 m 0 0 • 0 Dpi , . . , . , , /../x/ ..., , 3R-102wp07 � , 177 Plan Summary Base Perr .f93M"Csgpt_13+525 Or�� \ '�. OOH 5 / To '01e6fSak C _5 Aill ru = l I� r1 r �f _ 0 O� O T3S n - , of N1 1 1 r rti r o J • L....Top Jgnu CTop U9n.• B ( f ^ ,' 0 I 1! ill ti �r0 I I r i i I ti I f v'341 0 ` '0 110 3/4"x 134200 7000 17-5/8"x 9-7/r#500 14000 r 20'x 42' Measured Deoth ®\\� o, 20"x 42' _-0° Depth Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) • : � Rig: Doyon141 - \ ®b0 10 3/4"x 13-142 0 20° 0 . o ,0 0 17-5/8"x 9-7/81" 14 1/2"x 6-3/4f' o O 00.12.0 O p O 0 1 O ! e. ah 0 1500 3000 4500 6000 750e 9000 '10560 1 X100 '13500 o 28 -- 349 Horizontal Departure2iiimi. 349 - 530 'V�a.'T ° .. . 30 530 - 710 AI/it ii- ��' 0 - 1070 w 710 a r 111'',41101...1661°....', ♦��'��Q��•,; 090 - 1240 • .e ! 60 • 300 �B `JL�q: so zao - 1420 m 3"-10 ♦ 0 _ 0.•;/-P'S' ' a//! ; *t ... 1420 - 1600 u) , ..- > > --\ •-40A ` ...... d►/ �\ 1600 - 2180 m • ... `..`.3R 1 1wp09 -44i 2180 2750 U 30 r t- .1... \ ..r _ _ .. ..... ....... • .�`;I,+Nonxrox�a,m s 2750 - 3330 o 3fin 10 L1wp07 - 270 I I . I _y-a� 11," 90 3330 3900 _ .. ��, �►�4 3900 - 4480 ?R]0] 1wp01 >.d' ,"� 4r 4480 - 5050 v Otlk�dk Polrtt S,_te 't--'•;. °.;t,, i.-IrtOeibkffir.-4-4111tIlk a 5830 -5050 - 6200 5630 0 2500 5000 7500 10000 12500 15000 6 -- -=' 6200 - 7360 24g 120 7360 - 98520 690 _ 8520 -- 9890 SURVEY PROGRAM Surface Location ? • I 12:38,November 11 2016 Easting(6000 usftfin) _11111 ll III Ji , iiii — , ,03 , 1 " , do1 owitakt , 11 111111111111111111111111111111111111111111111111HI °P8ONA011_1 \ I `, OP09-SO1L1PB1 V 0115-S4 - — - p10-.. 1 ''‘, CP65-06L1 OPO4-07 00106-05 „ 010744 01 08-0.11WpotpB2 — .•.01..r,h(141131 , , , ki ••0,-6?,I. 'our 1 _ S i N!'. 0 o oin. „ i 1 _ - z OP16-0 - o ,.... eL,,,„ ,t•,.t,1 05PB2 _ A. °E,b1-8_1 • p: I _7 _ 5 Oh • •• I-''':, o - \ \ to - o - 01 - S op. ii•il.:Lg5 rmint ware 1 cn— • c - - \, g _..1 .3, k'', '.' c“, p02 - re t - - :-.1._ ,011P OP05-0. bi z_ 3R-101wp0• - ,r.,-..vp.- ' 3: I3R- _— 1 3R 10 :- 51141051 3Q-03, Q01 _ .0.0..08 \ r 3Q-04 3R-2> "-2 3F Kuparuk 3R Pad z3Q- %,,40itteAu3 —Kuparuk 3Q Pa 1 ' 23-0101 0-1 30-03 ‘, - Z1Z/Y1C62,4- 'zii'''08, $3 '74 ,30-02AL ;„,f);: ,•7„!::L 04 0-0' '111 t. •-1-30_16-3_02. Q-05 Kuparuk 30 Pad - 3M-26 3Q-21 a,„:.... 3M- 7 3M-18 30-02 1,)9-1Y- PSQ-14 '.- firwirril"- 30-09 — — - 3M-25 30 e it, . ., _ 154_14A vaill ... t0.41-1AAjci 1 3 30_ U0,,,,G4;',A`\ 1 DHH-01wp01 ,A 25A.. - 1 NV? -,, , „ , , , „ , H---,,, , ,14- ,- 3 ipiy-644,11Aul , '.,,t.11:...1..• %-..-.: IIIIIIIIIIIIIIIIIIIIIII 1111 Easting(6000 usftfin) 41 • 3R-102wp07 Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 3R-102 17.116 103116 MW 3R-102 13.T12 103116 MW ' 3R-102 9.T8 103116 MW 6000- 3R-102 16.115 103116 MW 3R-102 8. T7 103116 MW 4 1/2"x 6-3/4" ' 3R-W02 1. Top D 010816 MW 3R-102 7. T6 103116 IiW ' 7-5/8"x 9-7/8" _-- 3R-102 3.T2 103116 MW zo, 4500— t c "' • :5 w X102 2. Heel 103116 W o rn 3R- 102 5.T4 103116 MW 000- 3R 102 4. T3 103116 MW + 3R-102 6. 15 103116 MW 3p00 _C.- 3R-102 10.T9 103116 MW z 3500- 3R-102 15.T14 103116 MW 3R-102 11.T10 103116 MW z 3 in 3R-102 18.T17 103116 MW 3R-102 12. T11 103116 MW `000 3R-102 19.TD 103116 MW 3R-102 14.T13 103116 MW10 3/4"x 13-1/2-'•�'•� 0- 20"x42" -1500— - I I I I I I I I 1 -12000 -10500 -9000 -7500 -6000 -4500 -3000 -1500 0 1500 West(-)/East(+) (1500 usft/in) • • 3R-102wp07 Section View -1500— T 3 Sand Base Permafrost K-15 Top Ugnu C S 0— . , ' Top Ugnu B 20"x 42" 0° Top Ugnu nu A 1040/ Top D inverted 1500— •� fop N Sands 13 p 00 0 ,'o Top West Sak D To ,( ° o U 10 3/4"x 13 1/2 d o a 0 >3000— _. ,/. �► N co'a> rn 2 - 7-5/ r T 1- -- 1 -7t a oP' N,3 �' 8 o o 0 8"x 9-7/8" 0 0 0 0 0 0 s. 4500— Base D inverted Fault-enter West Sak C TD 4 1/2"x 6-3/4" . 6000— I I I I I i I i 1 0 1500 3000 4500 6000 7500 9000 10500 12000 Vertical Section at 290.00° (1500 usft/in) • • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3R Pad Plan: 3R-102 Plan: 3R-102 Plan: 3R-102wp07 Report 11 November, 2016 • • ConocoPhillips Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Site: Kuparuk 3R Pad MD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp07 Database: EDM Alaska ANC Prod Project Kuparuk River Unit,North Slope Alaska,United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 3R Pad Site Position: Northing: usft Latitude: From: Map Easting: usft Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.16 ° Well Plan:3R-102 Well Position +N/-S usft Northing: usft Latitude: +EI-W usft Easting: usft Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 9.90 usft Wellbore Plan:3R-102 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2016 12/5/2016 17.91 81.04 57,555 Design 3R-102wp07 Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 28.00 0.00 0.00 290.00 Survey Tool Program Date 11/11/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 28.00 600.00 3R-102wp07(Plan:3R-102) GYD-GC-SS Gyrodata gyro single shots 600.00 1,600.00 3R-102wp07(Plan:3R-102) MWD MWD-Standard 600.00 2,324.22 3R-102wp07(Plan.3R-102) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,324.22 3,824.22 3R-102wp07(Plan:3R-102) MWD MWD-Standard 2,324.22 8,859.62 3R-102wp07(Plan.3R-102) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,859.62 10,359.62 3R-102wp07(Plan:3R-102) MWD MWD-Standard 8,859.62 15,499.48 3R-102wp07(Plan:3R-102) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 28.00 0.00 0.00 28.00 -9.90 0.00 0.00 0.00 100.00 0.00 0.00 100.00 62.10 0.00 0.00 0.05 106.90 0.00 0.00 106.90 69.00 0.00 0.00 0.20 20"x 42" 200.00 0.00 0.00 200.00 162.10 0.00 0.00 0.20 300.00 0.00 0.00 300.00 262.10 0.00 0.00 0.34 11/11/2016 11:34:43AM Page 2 COMPASS 5000.1 Build 74 • • ConocoPhillips Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Site: Kuparuk 3R Pad MD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp07 Database: EDM Alaska ANC Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°I100usft) (°) (usft) 348.90 0.00 0.00 348.90 311.00 0.00 0.00 0.41 KOP:Start 1.50/100'DLS,2900 TF,for 250.18' 400.00 0.77 290.00 400.00 362.10 1.50 290.00 0.48 500.00 2.27 290.00 499.96 462.06 1.50 0.00 0.59 599.08 3.75 290.00 598.90 561.00 1.50 0.00 0.71 Start 2°/100'DLS,0°TF,for 1135.4' 600.00 3.77 290.00 599.82 561.92 2.00 0.00 0.71 700.00 5.77 290.00 699.47 661.57 2.00 0.00 0.79 800.00 7.77 290.00 798.77 760.87 2.00 0.00 0.84 900.00 9.77 290.00 897.59 859.69 2.00 0.00 0.96 1,000.00 11.77 290.00 995.82 957.92 2.00 0.00 1.16 1,100.00 13.77 290.00 1,093.34 1,055.44 2.00 0.00 1.44 1,200.00 15.77 290.00 1,190.04 1,152.14 2.00 0.00 1.80 1,300.00 17.77 290.00 1,285.78 1,247.88 2.00 0.00 2.22 1,400.00 19.77 290.00 1,380.45 1,342.55 2.00 0.00 2.71 1,500.00 21.77 290.00 1,473.95 1,436.05 2.00 0.00 3.25 1,600.00 23.77 290.00 1,566.15 1,528.25 2.00 0.00 3.87 1,700.00 25.77 290.00 1,656.94 1,619.04 2.00 0.00 2.22 1,723.32 26.24 290.00 1,677.90 1,640.00 2.00 0.00 2.32 T 3 Sand 1,734.48 26.46 290.00 1,687.90 1,650.00 2.00 0.00 2.32 Hold for 111.7' 1,778.04 26.46 290.00 1,726.90 1,689.00 0.00 0.00 2.51 Base Permafrost 1,800.00 26.46 290.00 1,746.56 1,708.66 0.00 0.00 2.51 1,846.18 26.46 290.00 1,787.90 1,750.00 0.00 0.00 2.65 Start 4°1100'DLS,55.27°TF,for 1584.4' 1,900.00 27.74 293.80 1,835.82 1,797.92 4.00 55.27 2.77 2,000.00 30.36 300.04 1,923.25 1,885.35 4.00 51.88 2.98 2,026.35 31.09 301.52 1,945.90 1,908.00 4.00 46.43 3.20 K-15 2,100.00 33.23 305.33 2,008.25 1,970.35 4.00 45.16 3.20 2,200.00 36.29 309.85 2,090.41 2,052.51 4.00 41.93 3.45 2,300.00 39.50 313.74 2,169.32 2,131.42 4.00 38.22 3.73 2,324.22 40.30 314.60 2,187.90 2,150.00 4.00 35.15 4.08 10 3/4"x 13-1/2 2,341.34 40.86 315.19 2,200.90 2,163.00 4.00 34.49 4.08 10 3/4"Csgpt_t3+525 2,400.00 42.82 317.12 2,244.60 2,206.70 4.00 34.04 4.08 2,500.00 46.24 320.11 2,315.89 2,277.99 4.00 32.60 4.69 2,600.00 49.71 322.76 2,382.83 2,344.93 4.00 30.47 5.53 2,700.00 53.25 325.16 2,445.10 2,407.20 4.00 28.69 6.55 2,800.00 56.83 327.34 2,502.40 2,464.50 4.00 27.20 7.70 2,900.00 60.44 329.35 2,554.45 2,516.55 4.00 25.94 8.94 3,000.00 64.08 331.22 2,600.99 2,563.09 4.00 24.90 10.27 11/11/2016 11:34:43AM Page 3 COMPASS 5000.1 Build 74 • ConocoPhillips • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Site: Kuparuk 3R Pad MD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp07 Database: EDM Alaska ANC Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (°) (usft) (usft) (*PI00usft) (0) (usft) 3,100.00 67.75 332.98 2,641.79 2,603.89 4.00 24.03 11.64 3,200.00 71.43 334.65 2,676.67 2,638.77 4.00 23.31 13.06 3,300.00 75.12 336.25 2,705.44 2,667.54 4.00 22.73 14.51 3,400.00 78.83 337.79 2,727.98 2,690.08 4.00 22.27 15.97 3,430.58 79.96 338.26 2,733.60 2,695.70 4.00 21.92 16.42 Hold for 2779.83' 3,500.00 79.96 338.26 2,745.70 2,707.80 0.00 0.00 17.50 3,592.96 79.96 338.26 2,761.90 2,724.00 0.00 0.00 19.03 Top Ugnu C 3,600.00 79.96 338.26 2,763.13 2,725.23 0.00 0.00 19.03 3,700.00 79.96 338.26 2,780.55 2,742.65 0.00 0.00 20.57 3,800.00 79.96 338.26 2,797.98 2,760.08 0.00 0.00 22.11 3,900.00 79.96 338.26 2,815.40 2,777.50 0.00 0.00 9.87 4,000.00 79.96 338.26 2,832.83 2,794.93 0.00 0.00 10.42 4,100.00 79.96 338.26 2,850.25 2,812.35 0.00 0.00 10.97 4,200.00 79.96 338.26 2,867.68 2,829.78 0.00 0.00 11.53 4,300.00 79.96 338.26 2,885.10 2,847.20 0.00 0.00 12.10 4,400.00 79.96 338.26 2,902.53 2,864.63 0.00 0.00 12.66 4,500.00 79.96 338.26 2,919.95 2,882.05 0.00 0.00 13.23 4,600.00 79.96 338.26 2,937.38 2,899.48 0.00 0.00 13.80 4,700.00 79.96 338.26 2,954.81 2,916.91 0.00 0.00 14.37 4,800.00 79.96 338.26 2,972.23 2,934.33 0.00 0.00 14.94 4,900.00 79.96 338.26 2,989.66 2,951.76 0.00 0.00 15.51 5,000.00 79.96 338.26 3,007.08 2,969.18 0.00 0.00 16.09 5,100.00 79.96 338.26 3,024.51 2,986.61 0.00 0.00 16.67 5,200.00 79.96 338.26 3,041.93 3,004.03 0.00 0.00 17.24 5,300.00 79.96 338.26 3,059.36 3,021.46 0.00 0.00 17.82 5,400.00 79.96 338.26 3,076.78 3,038.88 0.00 0.00 18.40 5,500.00 79.96 338.26 3,094.21 3,056.31 0.00 0.00 18.98 5,544.14 79.96 338.26 3,101.90 3,064.00 0.00 0.00 19.56 Top Ugnu B 5,600.00 79.96 338.26 3,111.63 3,073.73 0.00 0.00 19.56 5,700.00 79.96 338.26 3,129.06 3,091.16 0.00 0.00 20.14 5,800.00 79.96 338.26 3,146.48 3,108.58 0.00 0.00 20.72 5,900.00 79.96 338.26 3,163.91 3,126.01 0.00 0.00 21.30 6,000.00 79.96 338.26 3,181.34 3,143.44 0.00 0.00 21.88 6,100.00 79.96 338.26 3,198.76 3,160.86 0.00 0.00 22.47 6,200.00 79.96 338.26 3,216.19 3,178.29 0.00 0.00 23.05 6,210.41 79.96 338.26 3,218.00 3,180.10 0.00 0.00 23.11 Start 3°1100'DLS,-90.24°TF,for 2258.56' 6,300.00 79.96 335.53 3,233.61 3,195.71 3.00 -90.24 23.62 6,307.38 79.97 335.30 3,234.90 3,197.00 3.00 -89.76 24.04 Top Ugnu A 6,400.00 79.99 332.48 3,251.02 3,213.12 3.00 -89.72 24.04 6,500.00 80.05 329.43 3,268.36 3,230.46 3.00 -89.23 24.40 11/11/2016 11:34:43AM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Site: Kuparuk 3R Pad MD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp07 Database: EDM Alaska ANC Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°1100usft) (°) (usft) 6,600.00 80.13 326.39 3,285.58 3,247.68 3.00 -88.70 24.72 6,700.00 80.24 323.35 3,302.64 3,264.74 3.00 -88.18 24.98 6,719.26 80.26 322.76 3,305.90 3,268.00 3.00 -87.66 25.18 TD 6,800.00 80.37 320.31 3,319.48 3,281.58 3.00 -87.56 25.18 6,820.45 80.40 319.69 3,322.90 3,285.00 3.00 -87.15 25.32 Top D inverted 6,900.00 80.53 317.27 3,336.07 3,298.17 3.00 -87.05 25.32 7,000.00 80.72 314.23 3,352.36 3,314.46 3.00 -86.65 25.40 7,100.00 80.94 311.20 3,368.30 3,330.40 3.00 -86.15 25.43 7,154.95 81.06 309.54 3,376.90 3,339.00 3.00 -85.67 25.39 Top N Sands 7,200.00 81.18 308.18 3,383.85 3,345.95 3.00 -85.41 25.39 7,300.00 81.44 305.15 3,398.97 3,361.07 3.00 -85.20 25.29 7,400.00 81.73 302.13 3,413.62 3,375.72 3.00 -84.74 25.12 7,500.00 82.03 299.12 3,427.74 3,389.84 3.00 -84.30 24.90 7,600.00 82.37 296.11 3,441.32 3,403.42 3.00 -83.87 24.61 7,681.14 82.65 293.67 3,451.90 3,414.00 3.00 -83.46 24.26 Base D inverted 7,700.00 82.72 293.11 3,454.30 3,416.40 3.00 -83.15 24.26 7,800.00 83.09 290.11 3,466.66 3,428.76 3.00 -83.07 23.85 7,900.00 83.48 287.11 3,478.36 3,440.46 3.00 -82.70 23.39 7,995.65 83.87 284.25 3,488.90 3,451.00 3.00 -82.35 22.86 Fault-enter West Sak C 8,000.00 83.89 284.12 3,489.36 3,451.46 3.00 -82.04 22.86 8,100.00 84.31 281.14 3,499.65 3,461.75 3.00 -82.02 22.28 8,200.00 84.75 278.15 3,509.18 3,471.28 3.00 -81.72 21.65 8,300.00 85.20 275.18 3,517.94 3,480.04 3.00 -81.43 20.96 8,400.00 85.67 272.20 3,525.89 3,487.99 3.00 -81.17 20.23 8,427.01 85.80 271.40 3,527.90 3,490.00 3.00 -80.93 19.70 Top West Sak D 8,468.96 86.00 270.16 3,530.90 3,493.00 3.00 -80.87 19.70 Adjust TF to 0°,for 26.58' 8,495.54 86.80 270.16 3,532.57 3,494.67 3.00 0.00 19.83 Hold for 360.66' 8,500.00 86.80 270.16 3,532.82 3,494.92 0.00 0.00 19.85 8,600.00 86.80 270.16 3,538.40 3,500.50 0.00 0.00 20.35 8,700.00 86.80 270.16 3,543.99 3,506.09 0.00 0.00 20.84 8,800.00 86.80 270.16 3,549.57 3,511.67 0.00 0.00 21.35 8,856.20 86.80 270.16 3,552.71 3,514.81 0.00 0.00 21.63 Start 3°/100'DLS,0°TF,for 3.42' 8,859.62 86.90 270.16 3,552.90 3,515.00 2.97 0.00 21.65 Hold for 20'-7-5/8"x 9-7/8" 8,879.62 86.90 270.16 3,553.98 3,516.08 0.00 0.00 21.81 Start 2°/100'DLS,0°TF,for 73.64' 8,900.00 87.31 270.16 3,555.01 3,517.11 2.00 0.00 21.97 11/11/2016 11:34:43AM Page 5 COMPASS 5000.1 Build 74 • • ConocoPhillips Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Site: Kuparuk 3R Pad MD Reference: 3R-102:28+9.9©37.90usft(Doyon141) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp07 Database: EDM Alaska ANC Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 8,953.26 88.37 270.16 3,557.02 3,519.12 2.00 0.00 22.41 Hold for 179.98' 9,000.00 88.37 270.16 3,558.35 3,520.45 0.00 0.00 22.82 9,100.00 88.37 270.16 3,561.19 3,523.29 0.00 0.00 23.77 9,133.24 88.37 270.16 3,562.13 3,524.23 0.00 0.00 24.10 Start 2°/100'DLS,180°TF,for 68.64' 9,200.00 87.04 270.16 3,564.80 3,526.90 2.00 180.00 24.79 9,201.88 87.00 270.16 3,564.90 3,527.00 2.00 180.00 24.81 Adjust TF to 0°,for 202.32' 9,300.00 88.96 270.16 3,568.36 3,530.46 2.00 0.00 25.88 9,400.00 90.96 270.16 3,568.42 3,530.52 2.00 0.00 27.04 9,404.20 91.05 270.16 3,568.35 3,530.45 2.00 0.00 27.09 Hold for 188.82' 9,500.00 91.05 270.16 3,566.60 3,528.70 0.00 0.00 28.26 9,593.02 91.05 270.16 3,564.90 3,527.00 0.00 0.00 29.43 Start 2°/100'DLS,0°TF,for 30.36' 9,600.00 91.19 270.16 3,564.76 3,526.86 2.00 0.00 29.52 9,623.38 91.65 270.16 3,564.19 3,526.29 1.99 0.00 29.82 Hold for 227.51' 9,700.00 91.65 270.16 3,561.98 3,524.08 0.00 0.00 30.83 9,800.00 91.65 270.16 3,559.10 3,521.20 0.00 0.00 32.17 9,850.90 91.65 270.16 3,557.63 3,519.73 0.00 0.00 32.87 Start 2°/100'DLS,0°TF,for 67.32' 9,900.00 92.63 270.16 3,555.80 3,517.90 2.00 0.00 33.55 9,918.21 93.00 270.16 3,554.90 3,517.00 2.02 0.00 33.80 Adjust TF to-180°,for 71.36' 9,989.58 91.57 270.16 3,552.05 3,514.15 2.00 -180.00 34.79 Hold for 120.46' 10,000.00 91.57 270.16 3,551.77 3,513 87 0.00 0.00 34.94 10,100.00 91.57 270.16 3,549.02 3,511.12 0.00 0.00 36.37 10,110.04 91.57 270.16 3,548.75 3,510.85 0.00 0.00 36.52 Start 2°/100'DLS,0°TF,for 71.36' 10,181.40 93.00 270.16 3,545.90 3,508.00 2.00 0.00 37.55 Adjust TF to-180°,for 79.26' 10,200.00 92.63 270.16 3,544.99 3,507.09 2.00 -180.00 37.82 10,260.66 91.41 270.16 3,542.85 3,504.95 2.00 -180.00 38.69 Hold for 159.87' 10,300.00 91.41 270.16 3,541.88 3,503.98 0.00 0.00 39.27 10,400.00 91.41 270.16 3,539.41 3,501.51 0.00 0.00 26.42 10,420.54 91.41 270.16 3,538.90 3,501.00 0.00 0.00 26.50 Start 2°/100'DLS,0°TF,for 26.63' 10,447.16 91.95 270.16 3,538.12 3,500.22 2.00 0.00 26.60 Hold for 193.18' 10,500.00 91.95 270.16 3,536.32 3,498.42 0.00 0.00 26.80 10,600.00 91.95 270.16 3,532.93 3,495.03 0.00 0.00 27.20 11/11/2016 11:34:43AM Page 6 COMPASS 5000.1 Build 74 • ConocoPhillips Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Site: Kuparuk 3R Pad MD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp07 Database: EDM Alaska ANC Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (°) (usft) 10,640.34 91.95 270.16 3,531.55 3,493.65 0.00 0.00 27.36 Start 2°/100'DLS,180°TF,for 97.37' 10,700.00 90.75 270.16 3,530.15 3,492.25 2.00 180.00 27.59 10,737.71 90.00 270.16 3,529.90 3,492.00 2.00 180.00 27.74 Adjust TF to 0°,for 0' 10,800.00 90.00 270.16 3,529.90 3,492.00 0.00 -91.93 27.99 10,900.00 90.00 270.16 3,529.90 3,492.00 0.00 0.00 28.41 11,000.00 90.00 270.16 3,529.90 3,492.00 0.00 0.00 28.82 11,028.74 90.00 270.16 3,529.90 3,492.00 0.00 0.00 28.95 Hold for 291.03' 11,077.43 90.97 270.16 3,529.49 3,491.59 2.00 0.04 29.15 Start 2°/100'DLS,0°TF,for 0' 11,100.00 90.97 270.16 3,529.10 3,491.20 0.00 0.00 29.25 11,200.00 90.97 270.16 3,527.40 3,489.50 0.00 0.00 29.68 11,264.11 90.97 270.16 3,526.31 3,488.41 0.00 0.00 29.96 Adjust TF to 0.04°,for 48.69' 11,300.00 90.26 270.15 3,525.93 3,488.03 2.00 -179.60 30.11 11,312.80 90.00 270.15 3,525.90 3,488.00 2.00 -179.60 30.16 Hold for 186.68' 11,322.40 89.81 270.12 3,525.92 3,488.02 2.00 -171.73 30.19 Start 2°/100'DLS,-179.6°TF,for 48.69' 11,400.00 89.81 270.12 3,526.17 3,488.27 0.00 0.00 30.53 11,487.97 89.81 270.12 3,526.46 3,488.56 0.00 0.00 30.92 Adjust TF to-171.73°,for 9.6' 11,500.00 90.05 270.14 3,526.48 3,488.58 2.00 4.86 30.98 11,592.84 91.90 270.30 3,524.90 3,487.00 2.00 4.86 31.46 Hold for 165.57' 11,600.00 92.04 270.32 3,524.65 3,486.75 2.00 7.17 31.50 11,680.00 93.63 270.52 3,520.70 3,482.80 2.00 7.17 31.93 Start 2°/100'DLS,4.86°TF,for 104.88' 11,700.00 93.63 270.52 3,519.43 3,481.53 0.00 0.00 32.03 11,777.04 93.63 270.52 3,514.55 3,476.65 0.00 0.00 32.38 Adjust TF to 7.17°,for 87.15' 11,800.00 93.20 270.35 3,513.19 3,475.29 2.00 -158.58 32.42 11,875.29 91.80 269.80 3,509.90 3,472.00 2.00 -158.59 32.54 Hold for 97.05' 11,900.00 91.34 269.61 3,509.22 3,471.32 2.00 -157.82 32.58 11,965.29 90.13 269.12 3,508.38 3,470.48 2.00 -157.82 32.68 Start 2°/100'DLS,-158.58°TF,for 98.25' 12,000.00 90.13 269.12 3,508.30 3,470.40 0.00 0.00 32.84 12,100.00 90.13 269.12 3,508.07 3,470.17 0.00 0.00 33.31 12,167.54 90.13 269.12 3,507.91 3,470.01 0.00 0.00 33.63 Adjust TF to-157.82°,for 90' 12,200.00 90.60 268.67 3,507.70 3,469.80 2.00 -43.83 33.62 12,248.42 91.30 268.00 3,506.90 3,469.00 2.00 -43.84 33.59 Hold for 202.26' 11/11/2016 11:34:43AM Page 7 COMPASS 5000.1 Build 74 • • ConocoPhillips Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit ND Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Site: Kuparuk 3R Pad MD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp07 Database: EDM Alaska ANC Prod Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 12,300.00 92.01 267.25 3,505.41 3,467.51 2.00 -46.56 33.55 12,327.44 92.39 266.85 3,504.36 3,466.46 2.00 -46.58 33.53 Start 2°/100'DLS,-43.83°TF,for 80.88' 12,400.00 92.39 266.85 3,501.34 3,463.44 0.00 0.00 33.88 12,500.00 92.39 266.85 3,497.17 3,459.27 0.00 0.00 34.37 12,600.00 92.39 266.85 3,493.01 3,455.11 0.00 0.00 34.86 12,649.72 92.39 266.85 3,490.94 3,453.04 0.00 0.00 35.11 Adjust TF to-46.56°,for 79.01' 12,700.00 91.86 265.99 3,489.08 3,451.18 2.00 -121.63 35.02 4 1/2"x 6-3/4" 12,705.58 91.80 265.90 3,488.90 3,451.00 2.00 -121.67 35.01 Hold for 322.28' 12,789.79 90.97 264.44 3,486.87 3,448.97 2.00 -119.69 34.83 Start 2°/100'DLS,-121.63°TF,for 55.86' 12,800.00 90.97 264.44 3,486.70 3,448.80 0.00 0.00 34.88 12,900.00 90.97 264.44 3,485.01 3,447.11 0.00 0.00 35.39 12,947.99 90.97 264.44 3,484.20 3,446.30 0.00 0.00 35.63 Adjust TF to-119.69°,for 84.21' 13,000.00 91.82 262.83 3,482.94 3,445.04 3.50 -61.98 35.25 13,100.00 93.46 259.73 3,478.33 3,440.43 3.50 -62.02 34.46 13,163.87 94.50 257.75 3,473.90 3,436.00 3.50 -62.16 33.92 Hold for 158.2' 13,200.00 94.97 256.57 3,470.92 3,433.02 3.50 -68.29 33.57 13,219.67 95.22 255.93 3,469.17 3,431.27 3.50 -68.39 33.38 Hold for 103.73' 13,300.00 95.22 255.93 3,461.86 3,423.96 0.00 0.00 33.80 13,323.40 95.22 255.93 3,459.73 3,421.83 0.00 0.00 33.92 Start 3°/100'DLS,-85.01°TF,for 30.92' 13,354.32 95.30 255.00 3,456.90 3,419.00 3.00 -85.01 33.65 Adjust TF to-87.59°,for 272.78' 13,400.00 95.36 253.62 3,452.66 3,414.76 3.00 -87.59 33.25 13,500.00 95.47 250.61 3,443.22 3,405.32 3.00 -87.72 32.33 13,600.00 95.56 247.60 3,433.61 3,395.71 3.00 -88.00 31.37 13,627.10 95.59 246.78 3,430.98 3,393.08 3.00 -88.29 31.10 Hold for 426.59' 13,700.00 95.59 246.78 3,423.88 3,385.98 0.00 0.00 31.47 13,800.00 95.59 246.78 3,414.14 3,376.24 0.00 0.00 31.99 13,900.00 95.59 246.78 3,404.40 3,366.50 0.00 0.00 32.52 14,000.00 95.59 246.78 3,394.66 3,356.76 0.00 0.00 33.04 14,053.69 95.59 246.78 3,389.43 3,351.53 0.00 0.00 33.33 Start 2°/100'DLS,161.28°TF,for 189.4' 14,100.00 94.71 247.08 3,385.27 3,347.37 2.00 161.28 33.69 14,200.00 92.82 247.72 3,378.71 3,340.81 2.00 161.31 34.44 14,243.09 92.00 248.00 3,376.90 3,339.00 2.00 161.35 34.76 Adjust TF to 170.63°,for 96.6' 14,300.00 90.88 248.19 3,375.47 3,337.57 2.00 170.63 35.10 11/11/2016 11:34:43AM Page 8 COMPASS 5000.1 Build 74 ConocoPhillips Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Site: Kuparuk 3R Pad MD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp07 Database: EDM Alaska ANC Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (°) (usft) (usft) (°/100usft) (0) (usft) 14,339.69 90.09 248.31 3,375.14 3,337.24 2.00 170.63 35.33 Hold for 514.7' 14,400.00 90.09 248.31 3,375.04 3,337.14 0.00 0.00 35.63 14,500.00 90.09 248.31 3,374.87 3,336.97 0.00 0.00 36.15 14,600.00 90.09 248.31 3,374.71 3,336.81 0.00 0.00 36.68 14,700.00 90.09 248.31 3,374.55 3,336.65 0.00 0.00 37.21 14,800.00 90.09 248.31 3,374.38 3,336.48 0.00 0.00 37.74 14,854.39 90.09 248.31 3,374.29 3,336.39 0.00 0.00 38.03 Start 2.50/100'DLS,0.160 TF,for 76.25' 14,900.00 91.23 248.32 3,373.76 3,335.86 2.50 0.16 38.27 14,930.64 92.00 248.32 3,372.90 3,335.00 2.50 0.16 38.44 Adjust TF to-0.040,for 242.31' 15,000.00 93.73 248.32 3,369.43 3,331.53 2.50 -0.04 38.81 15,100.00 96.23 248.32 3,360.74 3,322.84 2.50 -0.04 39.35 15,172.95 98.06 248.32 3,351.67 3,313.77 2.50 -0.04 39.74 Hold for 326.53' 15,200.00 98.06 248.32 3,347.88 3,309.98 0.00 0.00 39.88 15,300.00 98.06 248.32 3,333.86 3,295.96 0.00 0.00 40.42 15,400.00 98.06 248.32 3,319.84 3,281.94 0.00 0.00 40.97 15,499.48 98.06 248.32 3,305.90 3,268.00 0.00 0.00 41.51 TD:15499.48'MD,3305.9'TVD 11/11/2016 11:34:43AM Page 9 COMPASS 5000.1 Build 74 • ConocoPhillips • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Site: Kuparuk 3R Pad MD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp07 Database: EDM Alaska ANC Prod Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (..) (,.) 106.90 106.90 20"x 42" 20 42 2,324.22 2,187.90 10 3/4"x 13-1/2 10-3/4 13-1/2 8,859.62 3,552.90 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,700.00 3,489.08 4 1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (0) (0) 1,778 04 1,726.90 Base Permafrost 0.00 1,723.32 1,677.90 T 3 Sand 0.00 3,592.96 2,761.90 Top Ugnu C 7,681.14 3,451.90 Base D inverted 7,995.65 3,488.90 Fault-enter West Sak C 8,427.01 3,527.90 Top West Sak D 7,154.95 3,376.90 Top N Sands 6,719.26 3,305.90 TD 2,026.35 1,945.90 K-15 0.00 6,820.45 3,322.90 Top D inverted 6,307.38 3,234.90 Top Ugnu A 5,544.14 3,101.90 Top Ugnu B 2,341.34 2,200.90 10 3/4"Csgpt_t3+525 11/11/2016 11:34:43AM Page 10 COMPASS 5000.1 Build 74 ConocoPhillips Report I Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:28+9.9©37.90usft(Doyon141) Site: Kuparuk 3R Pad MD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp07 Database: EDM Alaska ANC Prod Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 106.90 106.90 20"x 42" 20 42 2,324.22 2,187.90 10 3/4"x 13-1/2 10-3/4 13-1/2 8,859.62 3,552.90 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,700.00 3,489.08 4 1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (0) (0) 1,778.04 1,726.90 Base Permafrost 0.00 1,723.32 1,677.90 T 3 Sand 0.00 3,592.96 2,761.90 Top Ugnu C 7,681.14 3,451.90 Base D inverted 7,995.65 3,488.90 Fault-enter West Sak C 8,427.01 3,527.90 Top West Sak D 7,154.95 3,376.90 Top N Sands 6,719.26 3,305.90 TD 2,026.35 1,945.90 K-15 0.00 6,820.45 3,322.90 Top D inverted 6,307.38 3,234.90 Top UgnuA 5,544.14 3,101.90 Top Ugnu B 2,341.34 2,200.90 10 3/4"Csgpt_t3+525 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 348.90 348.90 0.00 0.00 KOP:Start 1.50/100'DLS,290°TF,for 250.18' 599.08 598.90 2.80 -7.70 Start 20/100'DLS,0°TF,for 1135.4' 1,734.48 1,687.90 103.34 -283.94 Hold for 111.7' 1,846.18 1,787.90 120.37 -330.71 Start 4°/100'DLS,55.27°TF,for 1584.4' 3,430.58 2,733.60 1,063.90 -1,023.52 Hold for 2779.83' 6,210.41 3,218.00 3,606.44 -2,037.59 Start 30/100'DLS,-90.24°TF,for 2258.55' 8,468.96 3,530.90 4,782.78 -3,784.56 Adjust TF to 0°,for 26.58' 8,495.54 3,532.57 4,782.85 -3,811.09 Hold for 360.66' 8,856.20 3,552.71 4,783.83 -4,171.18 Start 3°/100'DLS,0°TF,for 3.42' 8,859.62 3,552.90 4,783.84 -4,174.60 Hold for 20' 8,879.62 3,553.98 4,783.89 -4,194.57 Start 2°/100'DLS,0°TF,for 73.64' 8,953.26 3,557.02 4,784.09 -4,268.14 Hold for 179.98' 9,133.24 3,562.13 4,784.58 -4,448.05 Start 2°/100'DLS,180°TF,for 68.64' 9,201.88 3,564.90 4,784.77 -4,516.63 Adjust TF to 0°,for 202.32' 9,404.20 3,568.35 4,785.32 -4,718.88 Hold for 188.82' 9,593.02 3,564.90 4,785.84 -4,907.67 Start 20/100'DLS,0°TF,for 30.36' 9,623.38 3,564.19 4,785.92 -4,938.02 Hold for 227.51' 9,850.90 3,557.63 4,786.54 -5,165.44 Start 20/100'DLS,0°TF,for 67.32' 9,918.21 3,554.90 4,786.72 -5,232.70 Adjust TF to-180°,for 71.36' 9,989.58 3,552.05 4,786.92 -5,304.00 Hold for 120.46' 10,110.04 3,548.75 4,787.25 -5,424.42 Start 20/100'DLS,0°TF,for 71.36' 10,181.40 3,545.90 4,787.44 -5,495.72 Adjust TF to-180°,for 79.26' 10,260.66 3,542.85 4,787.66 -5,574.92 Hold for 159.87' 10,420.54 3,538.90 4,788.09 -5,734.75 Start 20/100'DLS,0°TF,for 26.63' 10,447.16 3,538.12 4,788.16 -5,761.36 Hold for 193.18' 11/11/2016 11:34:43AM Page 11 COMPASS 5000.1 Build 74 ConocoPhillips Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) I Site: Kuparuk 3R Pad MD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp07 Database: EDM Alaska ANC Prod Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name f') C') 106.90 106.90 20"x 42" 20 42 2,324.22 2,187.90 10 3/4"x 13-1/2 10-3/4 13-1/2 8,859.62 3,552.90 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,700.00 3,489.08 4 1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (% 1,778.04 1,726.90 Base Permafrost 0.00 1,723.32 1,677.90 T 3 Sand 0.00 3,592.96 2,761.90 Top Ugnu C 7,681.14 3,451.90 Base D inverted 7,995.65 3,488.90 Fault-enter West Sak C 8,427.01 3,527.90 Top West Sak D 7,154.95 3,376.90 Top N Sands 6,719.26 3,305.90 TD 2,026.35 1,945.90 K-15 0.00 6,820.45 3,322.90 Top D inverted 6,307.38 3,234.90 Top UgnuA 5,544.14 3,101.90 Top Ugnu B 2,341.34 2,200.90 10 3/4"Csgpt_t3+525 10,640.34 3,531.55 4,788.69 -5,954.43 Start 2°/100'DLS,180°TF,for 97.37' 10,737.71 3,529.90 4,788.95 -6,051.78 Adjust TF to 0°,for 0' 11,028.74 3,529.90 4,789.75 -6,342.81 Hold for 291.03' 11,077.43 3,529.49 4,789.88 -6,391.49 Start 2°/100'DLS,0°TF,for 0' 11,264.11 3,526.31 4,790.39 -6,578.15 Adjust TF to 0.04°,for 48.69' 11,312.80 3,525.90 4,790.52 -6,626.83 Hold for 186.68' 11,322.40 3,525.92 4,790.54 -6,636.43 Start 2°/100'DLS,-179.6°TF,for 48.69' 11,487.97 3,526.46 4,790.90 -6,802.00 Adjust TF to-171.73°,for 9.6' 11,592.84 3,524.90 4,791.28 -6,906.86 Hold for 165.57' 11,680.00 3,520.70 4,791.91 -6,993.91 Start 2°/100'DLS,4.86°TF,for 104.88' 11,777.04 3,514.55 4,792.78 -7,090.75 Adjust TF to 7.17°,for 87.15' 11,875.29 3,509.90 4,793.05 -7,188.88 Hold for 97.05' 11,965.29 3,508.38 4,792.21 -7,278.86 Start 2°/100'DLS,-158.58°TF,for 98.25' 12,167.54 3,507.91 4,789.10 -7,481.09 Adjust TF to-157.82°,for 90' 12,248.42 3,506.90 4,787.07 -7,561.94 Hold for 202.26' 12,327.44 3,504.36 4,783.52 -7,640.83 Start 2°/100'DLS,-43.83°TF,for 80.88' 12,649.72 3,490.94 4,765.84 -7,962.34 Adjust TF to-46.56°,for 79.01' 12,705.58 3,488.90 4,762.31 -8,018.05 Hold for 322.28' 12,789.79 3,486.87 4,755.22 -8,101.94 Start 2°/100'DLS,-121.63°TF,for 55.86' 12,947.99 3,484.20 4,739.88 -8,259.37 Adjust TF to-119.69°,for 84.21' 13,163.87 3,473.90 4,706.54 -8,472.25 Hold for 158.2' 13,219.67 3,469.17 4,693.88 -8,526.39 Hold for 103.73' 13,323.40 3,459.73 4,668.77 -8,626.59 Start 3°/100'DLS,-85.01°TF,for 30.92' 13,354.32 3,456.90 4,661.04 -8,656.40 Adjust TF to-87.59°,for 272.78' 13,627.10 3,430.98 4,572.23 -8,912.76 Hold for 426.59' 14,053.69 3,389.43 4,404.87 -9,302.95 Start 2°/100'DLS,161.28°TF,for 189.4' 14,243.09 3,376.90 4,332.24 -9,477.38 Adjust TF to 170.63°,for 96.6' 14,339.69 3,375.14 4,296.31 -9,567.02 Hold for 514.7' 14,854.39 3,374.29 4,106.12 -10,045.29 Start 2.5°/100'DLS,0.16°TF,for 76.25' 14,930.64 3,372.90 4,077.95 -10,116.13 Adjust TF to-0.04°,for 242.31' 15,172.95 3,351.67 3,988.82 -10,340.33 Hold for 326.53' 15,499.48 3,305.90 3,869.36 -10,640.76 TD:15499.48'MD,3305.9'TVD 11/11/2016 11:34:43AM Page 12 COMPASS 5000.1 Build 74 • Conoco • Phillips Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:28+9.9©37.90usft(Doyon141) Site: Kuparuk 3R Pad MD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp07 Database: EDM Alaska ANC Prod Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (0) (0) 106.90 106.90 20"x 42" 20 42 2,324.22 2,187.90 10 3/4"x 13-1/2 10-3/4 13-1/2 8,859.62 3,552.90 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,700.00 3,489.08 4 1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (0) (0) 1,778.04 1,726.90 Base Permafrost 0.00 1,723.32 1,677.90 T 3 Sand 0.00 3,592.96 2,761.90 Top Ugnu C 7,681.14 3,451.90 Base D inverted 7,995.65 3,488.90 Fault-enter West Sak C 8,427.01 3,527.90 Top West Sak D 7,154.95 3,376.90 Top N Sands 6,719.26 3,305.90 TD 2,026.35 1,945.90 K-15 0.00 6,820.45 3,322.90 Top D inverted 6,307.38 3,234.90 Top UgnuA 5,544.14 3,101.90 Top Ugnu B 2,341.34 2,200.90 10 3/4"Csgpt_t3+525 I Checked By: Approved By: Date: 11/11/2016 11:34:43AM Page 13 COMPASS 5000.1 Build 74 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3R Pad Plan: 3R-102 Plan: 3R-102 50103xxxxx00 3R-102wp07 Clearance Summary Anticollision Report 11 November,2016 Tray.Cylinder North Proximity Sean on Current Survey Data(North Reference) Reference Design: Kuparuk 3R Pad-Plan:3R-102-Plan:3R-102-3R-102wp07 Well Coordinates: Datum Height: 3R-102:28+9.9 37.90usft(Doyon141) Scan Range: 0.00 to 15,499.48 usft.Measured Depth. Scan Radius is 1,747.15 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version:5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 0 0 ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 3R-102-3R-102wp07 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 3R Pad-Plan:3R-102-Plan:3R-102-3R-102wp07 Scan Range:0.00 to 15,499.48 usft.Measured Depth. Scan Radius Is 1,747.15 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Kuparuk 3R Pad 3R-10-3R-10-3R-10 360.73 59.95 360.73 51.05 375.00 6.735 Centre Distance Pass-Major Risk 3R-10-3R-10-3R-10 459.38 60.93 459.38 49.59 475.00 5.372 Clearance Factor Pass-Major Risk 3R-10-3R-10A-3R-10A 360.73 59.95 360.73 51.05 375.00 6.735 Centre Distance Pass-Major Risk 3R-10-3R-10A-3R-10A 459.38 60.93 459.38 49.59 475.00 5.372 Clearance Factor Pass-Major Risk 3R-11D-3R-11D-3R-11D 385.39 84.19 385.39 77.56 400.00 12.712 Centre Distance Pass-Major Risk 3R-11D-3R-11D-3R-11D 410.05 84.36 410.05 77.35 425.00 12.033 Clearance Factor Pass-Major Risk 3R-12D-3R-12A-3R-12A 385.25 108.55 385.25 99.03 400.00 11.404 Centre Distance Pass-Major Risk 3R-12D-3R-12A-3R-12A 532.49 110.53 532.49 97.36 550.00 8.393 Clearance Factor Pass-Major Risk 3R-12D-3R-12D-3R-12D 385.25 108.55 385.25 99.03 400.00 11.404 Centre Distance Pass-Major Risk 3R-12D-3R-12D-3R-12D 532.49 110.53 532.49 97.36 550.00 8.393 Clearance Factor Pass-Major Risk 3R-14-3R-14-3R-14 35.90 225.17 35.90 222.60 50.00 87.880 Centre Distance Pass-Major Risk 3R-14-3R-14-3R-14 456.82 227.29 456.82 215.75 475.00 19.704 Clearance Factor Pass-Major Risk 3R-15-3R-15-3R-15 235.90 250.16 235.90 244.40 250.00 43.453 Centre Distance Pass-Major Risk 3R-15-3R-15-3R-15 480.34 251.95 480.34 240.05 500.00 21.159 Clearance Factor Pass-Major Risk 3R-26-3R-26-3R-26 360.06 19823 360.06 191.99 375.00 31.784 Centre Distance Pass-Major Risk 3R-26-3R-26-3R-26 408.15 198.88 408.15 191.70 425.00 27.713 Clearance Factor Pass-Major Risk 3R-26-3R-26P81-3R-26PB1 360.06 198.23 360.06 191.90 375.00 31.294 Centre Distance Pass-Major Risk 3R-26-3R-26PB1-3R-26PB1 408.15 198.88 408.15 191.61 425.00 27.356 Clearance Factor Pass-Major Risk Plan:3R-101-Plan:3R-101-3R-101wp09 474.48 29.19 474.48 20.62 475.00 3.408 Centre Distance Pass-Major Risk Plan:3R-101-Plan:3R-101-3R-101wp09 574.84 29.95 574.84 19.69 575.00 2.921 Clearance Factor Pass-Major Risk Plan:3R-101-Plan:3R-101L1-3R-101 L1wp07 474.48 29.19 474.48 20.62 475.00 3.408 Centre Distance Pass-Major Risk Plan:3R-101-Plan:3R-1011_1-3R-101 L1wp07 574.84 29.95 574.84 19.69 575.00 2.921 Clearance Factor Pass-Major Risk Plan:3R-101-Plan:3R-101 PB1-3R-101 PB1wp01 474.48 29.19 47448 20.62 475.00 3.408 Centre Distance Pass-Major Risk Plan:3R-101-Plan:3R-101 PB1-3R-101 PB1wp01 574.84 29.95 574.84 19.69 575.00 2.921 Clearance Factor Pass-Major Risk Kuparuk Oliktok Oliktok Point State 1-Oliktok Point State 1-Oliktok P 423.36 33.40 423.36 26.25 425.00 4.670 Centre Distance Pass-Major Risk Oliktok Point State 1-Oliktok Point State 1-Oliktok P 472.69 33.91 472.69 25.93 474.96 4250 Clearance Factor Pass-Major Risk 11 November,2016-11:27 Page 2 of 6 COMPASS . • ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 3R-102-3R-102wp07 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 3R Pad-Plan:3R-102-Plan:3R-102-3R-102wp07 Scan Range:0.00 to 15,499.48 usft.Measured Depth. Scan Radius Is 1,747.15 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation Is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site:Name. Depth Distance Depth Separation Depth .Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Oliktok Point 0106-05-0106-05-0106-05 6,882.19 723.29 6,882.19 625.58 3,475.00 7.402 Centre Distance Pass-Major Risk 0106-05-0106-05-0106-05 6,869.04 724.83 6,869.04 623.17 3,525.00 7.130 Clearance Factor Pass-Major Risk 0106-05-0106-05P61-0106-05P61 6,882.19 723.29 6,882.19 625.58 3,475.00 7.402 Centre Distance Pass-Major Risk 0106-05-0106-05P61-0106-05PB1 6,869.04 724.83 6,869.04 623.17 3,525.00 7.130 Clearance Factor Pass-Major Risk 0124-08-0124-08-0124-08 11,882.19 746.80 11,882.19 608.97 4,825.00 5.418 Centre Distance Pass-Major Risk 0124-08-0124-08-0124-08 11,919.39 747.99 11,919.39 608.14 4,875.00 5.348 Clearance Factor Pass-Major Risk OP16-13-OP16-03-OP16-03 10,832.00 949.59 10,832.00 835.89 3,925.00 8.352 Centre Distance Pass-Major Risk OP16-13-OP16-03-OP16-03 11,800.00 968.01 11,800.00 821.17 4,875.00 6.592 Clearance Factor Pass-Major Risk OP16-13-OP16-03L1-OP16-03L1 10,831.26 949.59 10,831.26 835.85 3,925.00 8.349 Centre Distance Pass-Major Risk OP16-13-OP16-03L1-OP16-03L1 11,800.00 967.99 11,800.00 821.05 4,875.00 6.588 Clearance Factor Pass-Major Risk OP16-13-OP16-03L1 PB1-OP16-03L1 P61 10,831.26 949.59 10,831.26 836.07 3,925.00 8.365 Centre Distance Pass-Major Risk OP16-13-OP16-03L1 PB1-OP16-03L1 PB1 11,800.00 967.99 11,800.00 821.26 4,875.00 6.597 Clearance Factor Pass-Major Risk OP17-02-OP17-02-OP17-02 10,030.84 844.99 10,030.84 728.04 3,450.00 7.225 Centre Distance Pass-Major Risk OP17-02-OP17-02-OP17-02 10,281.65 852.13 10,281.65 718.32 3,725.00 6.368 Clearance Factor Pass-Major Risk OP17-02-OP17-02PB1-OP17-02PB1 10,030.84 844.99 10,030.84 727.91 3,450.00 7.217 Centre Distance Pass-Major Risk OP17-02-OP17-02PB1-OP17-02PB1 10,281.65 852.13 10,281.65 718.19 3,725.00 6.362 Clearance Factor Pass-Major Risk OP19-T1 N-OP19-T1 N-OP19-TIN 9,057.17 895.17 9,057.17 790.58 3,100.00 8.559 Centre Distance Pass-Major Risk OP19-TIN-OP19-T1 N-OP19-T1 N 9,080.83 896.38 9,080.83 789.51 3,150.00 8.387 Clearance Factor Pass-Major Risk OP19-T1N-OP19-T1NPB1-OP19-T1NPB1 9,057.17 895.17 9,057.17 790.58 3,100.00 8.559 Centre Distance Pass-Major Risk OP19-T1N-OP19-T1NPB1-OP19-T1NPB1 9,080.83 896.38 9,080.83 789.51 3,150.00 8.387 Clearance Factor Pass-Major Risk OP21-WW01-OP21-VWV01-OP21-WWO1 8,230.40 454.37 8,230.40 348.20 3,475.00 4.280 Centre Distance Pass-Major Risk OP21-WVV01-OP21-VVW01-OP21-VWV01 8,226.58 455.73 8,226.58 347.93 3,500.00 4.228 Clearance Factor Pass-Major Risk OP22-WVV03-OP22-WW03-OP22-WW03 8,980.97 519.87 8,980.97 409.46 3,400.00 4.709 Centre Distance Pass-Major Risk OP22-W W03-OP22-VWV03-OP22-VWV03 8,997.15 521.07 8,997.15 407.97 3,450.00 4.607 Clearance Factor Pass-Major Risk • 11 November,2016- 11:27 Page 3 of 6 COMPASS 1111 ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 3R-102-3R-102wpO7 Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 28.00 600.00 3R-102wp07 GYD-GC-SS 600.00 1,600.00 3R-102wp07 MWD 600.00 2,324.22 3R-102wp07 MWD+IFR-AK-CAZ-SC 2,324.22 3,824.22 3R-102wp07 MWD 2,324.22 8,859.62 3R-102wp07 - MWD+IFR-AK-CAZ-SC 8,859.62 10,359.62 3R-102wp07 MWD 8,859.62 15,499.48 3R-102wp07 MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 11 November,2016-11:27 Page 4 of.6 COMPASS ! 0 Ladder View tt: November 11 2`16 3R-102wp07 The Reference Well is along the X-axis. rror Ellipses are the Sum of the Reference and Offset Well Errors H Y m a 1 m rye a m t vmg n n ,I� 1 300 .... A ...... .._ t I 0 1iI11111V�111��II' I VIII' CO 2 ill' Iso—... Ili 9 '� I IIS'i� ��I ,,', Il .•...440111111 U ,.,IIFII1H1111l11,I IP 0 Equivelant Magnetic Distancle I I I I I I I I I I I I I I I I I I 1 I I I I I I 1 0 2500 5000 7500 10000 12500 15000 Displayed interval could be less than entire well1easured DeptR8.00 To 15499.48 SURVEY PROGRAM CASING DETAILS Depth FromDepth To Survey/Plan Tool TVD MD Name 28.00 600.00 3R-102wp07 (Plan: 3R-102) GYD-GC-SS 106.90106.90 20"x 42" 600.00 1600.00 3R-102wp07 (Plan: 3R-102) MWD 2187.E24.2210 3/4"x 13-1/2 600.00 2324.22 3R-102wp07 (Plan: 3R-102) MWD+IFR-AK-CAZ-SC 35524'049.62 7-5/8"x 9-7/8" 2324.22 3824.22 3R-102wp07 (Plan: 3R-102) MWD 34892Jb00.00 4 1/2"x 6-3/4" 2324.22 8859.62 3R-102wp07 (Plan: 3R-102) MWD+IFR-AK-CAZ-SC 8859.6210359.62 3R-102wp07 (Plan: 3R-102) MWD 8859.6215499.48 3R-102wp07 (Plan: 3R-102) MWD+IFR-AK-CAZ-SC w o 3 n c 3 3 1 J l m n a 1 � w� O \1, n • in i / { •y • N 30 U MPI o /11/ 2 aa) • U ••• 0 I ‘I I I I I I I 1 I I I I I I I I I I I I I I I I I I I I I 1 500 1000 1500 2000 2500 3000 3500 Equlvelant Magnetic Distance Partial Measured Depth 1110 3R-102wp07 MD Inc Azi 2 TVD Dleg TFace Target 28 349 28.00 0.00 0.00 8.00 0.00 0.00 349 ---_ 530 28.00 To 15499.48 599.08 0.00 0.00 348.90 290.00 598.90 0.00. 290.00 530 710 1734.48 26.46 290.00 1687.90 2.00 0.00 11:44, November 11 2016 1846.18 26.46 290.00 1787.90 0.00 0.00 710 895 3430.58 79.96 338.26 2733.60 4.00 55.27 890 1070 CASING DETAILS6210.41 79.96 338.26 3218.00 0.00 0.00 8468.96 86.00 270.16 3530.90 3.00 -90.24 3R-W02 1. Top D 010816 MW 1070 1240 TVD MD Name 8495.54 86.80 270.16 3532.57 3.00 0.00 1240 1420 106.90 106.90 20" x 42" 8856.20 86.80 270.16 3552.71 0.00 0.00 2187.90 2324.22 10 3/4" x 13-1/2 8859.62 86.90 270.16 3552.90 3.00 0.00 3R-102 2. Heel 103116 MW 1420 1600 3552.90 8859.62 7-5/8" x 9-7/8" 8879.62 86.90 270.16 3553.98 0.00 0.00 3489.08 12700.00 4 1/2" x 6-3/4" 8953.26 88.37 270.16 3557.02 2.00 0.00 1600 2180 9133.24 88.37 270.16 3562.13 0.00 0.00 PURVEY PROGRAM 9201.88 87.00 270.16 3564.90 2.00 180.00 3R-102 3. T2 103116 MW 2180 2750 (A.nmrrcreneo%'P Survey/Plan/Plan 9404.20 91.05 270.16 3568.35 2.00 0.00 28.00 2750 3330 600.00 1600.00 n-182P,07 (Plan) is-102) .o -PP 9593.02 91.05 270.16 3564.90 0.00 0.00 3R-102 4. T3 103116 MW 600 00 2324.22 2324.22 3824.22 '"-102,07 (Pia is-102) . -_"-`mm 9623.38 91.65 270.16 3564.19 2.00 0.002324.22 6859.62 3330 3900 P-oP2'P.0; (Plan is_lgfl '.`-�-" 9850.90 91.65 270.16 3557.63 0.00 0.00 easP.,P=s,PP.,P oP-=oP.PP, le=an: =a=o=, �.=P.-,•-�_Sc 9918.21 93.00 270.16 3554.90 2.00 0.00 3R-102 5. T4 103116 MW 3900 """"" 4480 9989.58 91.57 270.16 3552.05 2.00 -180.00 10110.04 91.57 270.16 3548.75 0.00 0.00 4480 5050 10181.40 93.00 270.16 3545.90 2.00 0.00 3R-102 6. T5 103116 MW 15260.66 91.41 2/0.16 .3142.01 . 2.UU -185.00 5050mm "' 5630 10420.54 91.41 270.16 3538.90 0.00 0.00 3R-102 7. T6 103116 MW 5630 6200 10447.16 91.95 270.16 3538.12 2.00 0.00 10640.34 91.95 270.16 3531.55 0.00 0.00 6200 7360 10737.71 90.00 270.16 3529.90 2.00 180.00 3R-102 8. T7 103116 MW 10737.71 90.00 270.16 302/9380 2.00 0.00 7360 8520 11028.74 90.00 270.16 3529.90 0.00 0.00 8520 9690 11028.74 90.00 270.16 3529.90 2.I,,- 0.00 3R-102 9. T8 103116 MW 11077.43 90.97 2 0. . 3529 •s~rifin'. . 4 9690 10850 11264.11 90.' - 270.16 3526. ,29 +0 301/1 Q.eo •'.00 2 •.�-► .1 3M o Olo. T9 103116 Mw 10850 12010 11322. : 89.: -270 �, �, 1148 .97 e1 m ,� , , 12010 13170 1 92 A , , ,� „ Velii,-;� '1wp09 MW1682 �;`- inir•�� 13170 14340 r t� 6 2 7 2' i ► c�' �� art 31 14340 15499 J•..0 -/ .t , ti 158\• : 3116.,MW ,` 4^ 90/,'i`. i- 2 jq � � ,.� 8. O e� T . - t,mil ► *, ♦ _�1400 14-74.110 2248' 4•?1:1�, 30 ' 26� .� O.i0., i alr�4;��'' +�$F3.16 ` 2 .4, s�� ..9., <,. ;tl c.. � + ..- ,.�� 3R-101L1wp07 60/300 , 61: 2 \ �� 6 6,8!5, •ilk 444-0,:e 60 `,.2"�0 .5A •!3 e. r.# 4: '�` : ?.4. T1 10 i6 .W 27 , 41�' 4: i r'' .6 "�'t•o`' ''�� Oliktok Point State 1 ',c 9 •a � .� u.. ,. 1:::\ 1�4 0'''. 'r.e (AIM-NV I.j,.MS/ -10: T1 10111 MW 3R-101 PB1wp01 A ' 16lik •k 4`�...i...!1Ni. 4• �C � ' 1-• 3. 0 '-i--,,- � ,%59 j4 ��`�`,/7"° 1.-.359�2. /3�y :"• 3456 1 �:ytr�r� ,:.0 • , 1: 5 1,37•. � 111 i ' \ 4/.1,, ...„,,._.i.�- .78,: 30F .� i) 't 8•.59 I ® X855 1 i �S • dr. 338 �`��'1.yM�' 0.00 41610011 � y� � 1 , ' • .92. 0 24 .00. G-;•'- L t:0� ..:8 R-. "...1,1,,- �ill..,�� .... , �. s .69 90.09 2 .:3 til '.00 1 0.6: 4 1v 4 / _ - `54 39 9 .09 48.- S. 0 :.0 ' 1•i a �� -.„/ T-,- el 14930.64 9'.0 "48 3 1 • •0 ��7'443106110011P / - 1'172.95 9•.0. z.48 3. , `�, } . -90/270,- _ -.1. ,!�C.i . AM, ' 4 �1�k ., ear --grw,.Prk,w ► ► 3R-10A 4. r Atipt 75 90 j`* tiz 10 s;4 ..9a1• ♦st'•►!♦ t 702iO'.v4 444. -120/240 12� / � L,�:,l:Lid, e444�i';i'A�ANTA� 3R-12D 4.1100! ':1r•� 150 4. :!;444.#,•, 165 /4"%iw-NIVO•f4',. •► ll 180 ��® 195 ' 3R-11D 150/210 Iffiller _+.C.19:0701:•%1-74. � . 150 �r`i,• y ie a�►�' e`' 3R-14 -1-80/180 3R-26 3R-26PB1 • • 11:51,November 11 2016 Easting(3000 usft/in) I 11111111111111111 111111111111111111111111111111111111I111 I 11 111111111111111111111J 11111111 - r 0106-05 0106-05PB1 _ oz"ot - - ......0P17-02 - - 012 - - OP19-T1 N OP16-03 - - OP16-03L11 _ OP16-03L1PB1 - OP21-VVVV01 OP19-T1NPB1 - 0P22-VUW03 Oliktok Point State 1 _ Z C. _ o la 3R-101wp09 3R-14 ii CO_ 3R-102wpOZ___ 3R— - c o_ 3R-10A —S Z 3R-15 3R-101PB1wp01 _ \ 3R-12A - \ D Kuparuk 3R Pad R-11D _ 3R-26PB1 - Kuparuk 30 Pad - -3R-26 - I- , , , 11111 ] 1111111111111111111111111 „ III 11 11111111111111111111 11111 111111111III ] I1 Easting(3000 usft/in) AC Flipbook • • survey rrogam Casing Details Depth From Depth To Survey/Plan Tool _..............._.. 3R-102wp0� TVD MD Name 800 600.00 3R-loxwpo](Plan 3Rtox) CDT LC-SS 20 349 n V` 06.90 06.90 042° 600.00 0600.00 30-toxwpo7(Plan:3R-102) MWD 2187.90 2324.22 103/4"0x13-1/2 600.00 2324.22R-102w o Plan:R-102 3 P 7( 3 ) MWD.IFR- AK.CAZ-SC - 2 8.0 0 To 10 0 0.0 0 348990 8859.60 X5/8"x 3/4" 2324.x2 3829 02 3R-102wp07(Plan;Ron) MWD 530 349 `}(l 348908 [x700.00 4th"xa-314" 232122 885962 3R-1oxwPo](Plan:3R-tux) MWDaIFRAKUZ-SC 8859 6x to359 62 3R-102wpu7(Flan:3R-toz) MWD / AAco6> 10220 R 30-ln2wyn>(plan a0.-.n>1 MWD,IFR.AKtA7.5( 530 710 MD Azi 0 / 360 3R-1o1PB1wpo1 710 8 0 9 28.00 0.00 348.90 0.00 90 ' 890 1070 -30133• 599 08 290.00 y__ _____ + 3R-1o1wpo9 1070 ,zoo 1734.48290.00 \ -7)\ 1 i.sil�� 1240 1420 1846.18290.00 ,; ;��-�� 4 1420 1600 3430.58 338.26 Irl /6210.41338.26 -6o / 300 a r/ )1/ 3R-1o1L1wpo7 1600 2180 8468.96 270.16 ► , 2180 2750 8495.54 270.16 �� I- // q'krzir• 75 8856.20 270.16 z o 3330 8859.62 270.16 r \ \ 1p 3330 3900 8879.62 270.16 legal 1, 3900 4480 8953.26 270.1690 / 270 Oliktok Point State 1 46--Now. 90 9133.24 270.16 .if .`�� -�� 4480 5050 9201.88 270.16 ,/ ` � i 5050 5630 9404.20 270.16 01q A 30 d �o �� s;� 5630 E 959302 270.161110111• ' . .. _;;��962338 270.16f ��•� I 3R-10 6zoo 985090 270.16 -120 / 240 J 01 4* `1 ��1 . 7360 9918.21 270.16 , . 6o 4 . ��4�/��4�• 8520 9690 9989.58 270.16 _ „�.a �!!��►�•i 10110.04 270.16 9690 10850 ___ 3R-10A 108 0 ,z , 10181.40 270.16 -150 / 210 tee.-` 50 5 0 0 10260.66 270,16 g0 l '~ 12010 13170 10420.54 270.16 10aa-7 16 '70 16 -180 / 180 3R-11D 13170 14340 14340 15499 11:53,November ii 2016 • • Casing Detail:. Survey Progra 3R-102Wp07 ND MD la 6.90 106.90oName Depth From DeptM1TO Survey/Plan GYDLC 55 28 349 xp2 2800 600.00 3R-to2wpo](Plan 3R to2) 218790 2324.22 103/4'x131/2 60000 1600 Oo 3R tozwp0](Plan:jR 102) MWD 3552.908859.62 7-51e" 600.00 2384.22 3R',ozwpo](PIan;3R tox) MWD.IFR-AK-CAZ-SC /� x9-]/g° 900.00 '('0 5000100 348908 1x]00.00 41h"x6.3/4" 232422 3824.22 3R102wpo](PIan:3R-,o2) MWD 349 530 V 232422 885962 3R-to2wpo](Plan:3R-toz) MWD.IFR-AK-CAZ.SC 885962 1035962 3Rt02wp0](Plan:jRtoi) MWD --_--""-- RR o6, ,2002/ ,R,n>w n,1Ph.3R,n„ MWD.,FRAK-0/0•50 530 710 M D Azi 0 / 360 710 890 28.00 0.00 s _ �� 890 1070 348.90 0.00 -30 / 33' 11111r---1-*---1---__ , 3R-1o1P-B1wpo1 il 599.08 2 0.00 ��' 1070 1240 1734.48290.00 *".‘16-4101240 1420 111 �� AO 1846.18 290.00 � . �� .��,�, 1420 ,600 3430.58 338.26 -60 00 , ��. �� \ , 3 l`` ` ••,, 60 1600 2180 6210.41 338.26 *it 1011 ``� ;, 8468.96 270.16 �.�`� 2180 2750 8495.54 270.1631t-1o1wpo9 0 30 2 75 3330 8856.2o 270.16YtMa 8859.62 270.16 3330 3900 8879.62 270.16 ,MI 3R-101L1Wp07 3900 4480 8953.26 270.1690 270 Ili J 448o 5050 9133.24 270.16 / 9201.88 270.16 __ 5050 563o / 9404.20 270.16 1041430 5630 6200 9593.02 270.16 ,\ 6zoo 7360 9623.38 270.16 9850.90 270.16 -120 / 240 X -- - 120 7360 8520 9918.21 270.16 . 60 8520 9690 9989.58 270.16 . 141111 14 9690 10850 10110.0 270.16 4 •. 10850 12010 10181.40 2 0.16 4 7 -150210 --- � 150 10260.66 270.16 go I 12010 13170 10420.54 270.16 -180 1 180 13170 14340 in/la-71h »n 1h 14340 15499 11:55,November 11 2016 • • casing Detan: survey Program 3R+�o2Wpo7 ND MD Name Depth From Depth To Survey/Plan Tool 28 349 K / 106.90 0MD o"x42" From pthTo 3R ey/PlaJ(PIan:3R-toi) GYDLC 55 T7 2187.90 2324.22 103(4"x13-02 600.00 1600.00 3R foxwpo7(%an:3R-tox) MWD 355x.90 8859.62 ]-5/8"x4]18" 600.00 x3z4�zz 3R lozwpoJ(PIan:3R-f Oz) MWDAFR-AK CAZ.SC 347(] �-' 530 4900.00 To X5499 00 348908 fi]ooao 9th"xb-34" 2324.22 382422 3R10zwpo](Plan:R fox) MWD • • 23x4.22 885962 3R'lozwpoJ(Plan:3R102) MWD.IFR-AKCAZ.SC 885962 m3596x 3R4an,nnn(PIan:3R1oz) MWD 530 - 710 RAso A� ,cnooeA aR-1n7wnn7(PUn aR-1n�1 MWD,PAK-067-RC M D Azi 0 / 360 710 890 28.00 0.00 go 890 1070 348.90 0.00 -30 / 33• In o 599.08 290.00 1070 1240 1734.48 290.00 `N 1240 1420 1846.18 290.00 A6° 142o 1600 1P.3430.58 338.26 , 6210.41 338.26 -60 / 30060 1600 2180 8468.96 270.16 , 2180 2750 8495.54 270.16 0 \ 275o 3330 8856.20 270.16 lit- 1401 8859.62 270.16 ~-1-- itil 3330 3900 8879.62 270.16 � , 3900 448o 9 0 8953.26 270.1690 / 270 � ; 9133.24 270.16 --\ lipl 4480 5050 9201.88 270.16 5050 5630 9404.20 270.16 *Ili, 30 ,./4„ 5630 6zoo 9593.02 270.16 6200 7360 9623.38 270.16 . 9850.90 270.16 -120 / 240 120 736o 852o 9918.21 270.16 *a60 8520 9690 9989.58 270.16 \ 9690 10850 10110.04 270.16 .V__ - -"`� 10181.40 270.1610850 12010 -150 / 210 --r----- ------ 150 10260.66 270.16 go ' 12010 13170 10420.54 270.16 -180 / 180 13170 14340 10.1117 16 »(1 1F) 14340 15499 11:56,November 11 2016 • • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3R Pad Plan: 3R-102 Plan: 3R-102 Plan: 3R-102wp07 Report - Errors 11 November, 2016 • ConocoPhillips • Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Site: Kuparuk 3R Pad MD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp07 Database: EDM Alaska ANC Prod Project Kuparuk River Unit,North Slope Alaska,United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 3R Pad Site Position: Northing: usft Latitude: From: Map Easting: usft Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.16° Well Plan:3R-102 Well Position +N/-S usft Northing: usft Latitude: +E/-W usft Easting: usft Longitude: Position Uncertainty usft Wellhead Elevation: 0.00 usft Ground Level: 9.90 usft Wellbore Plan:3R-102 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BG G M 2016 12/5/2016 17.91 81.04 57,555 I Design 3R-102wp07 Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 28.00 0.00 0.00 290.00 i Survey Tool Program Date 11/11/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 28.00 600.00 3R-102wp07(Plan:3R-102) GYD-GC-SS Gyrodata gyro single shots 600.00 1,600.00 3R-102wp07(Plan:3R-102) MWD MWD-Standard 600.00 2,324.22 3R-102wp07(Plan:3R-102) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,324.22 3,824.22 3R-102wp07(Plan:3R-102) MWD MWD-Standard 2,324.22 8,859.62 3R-102wp07(Plan:3R-102) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,859.62 10,359.62 3R-102wp07(Plan:3R-102) MWD MWD-Standard 8,859.62 15,499.48 3R-102wp07(Plan:3R-102) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (0) (usft) (usft) (usft) (usft) 28.00 0.00 0.00 0.00 -9.90 0.00 0.00 0.00 100.00 1.15 0.00 0.00 62.10 1.15 0.05 0.05 106.90 1.15 0.00 0.00 69.00 1.15 0.20 0.20 20"x 42" 200.00 1.15 0.00 0.00 162.10 1.15 0.20 0.20 300.00 1.15 0.00 0.00 262.10 1.15 0.34 0.34 11/11/2016 11:38:53AM Page 2 COMPASS 5000.1 Build 74 • ConocoPhillips • Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:28+9.9©37.90usft(Doyon141) Site: Kuparuk 3R Pad MD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp07 Database: EDM Alaska ANC Prod Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 348.90 1.15 0.00 0.00 311.00 1.15 0.41 0.41 KOP:Start 1.5°/100'DLS,2900 TF,for 250.18' 400.00 1.15 0.77 45.00 362.10 1.15 0.48 0.48 500.00 1.15 2.27 45.00 462.06 1.15 0.59 0.59 599.08 1.16 3.75 18.91 561.00 1.15 0.71 0.71 Start 2°/100'DLS,0°TE,for 1135.4' 600.00 1.16 3.77 18.91 561.92 1.15 0.71 0.71 700.00 1.16 5.77 24.57 661.57 1.16 0.79 0.78 800.00 1.17 7.77 106.35 760.87 1.15 0.84 0.80 900.00 1.17 9.77 107.35 859.69 1.15 0.96 0.83 1,000.00 1.18 11.77 107.79 957.92 1.15 1.16 0.88 1,100.00 1.19 13.77 108.07 1,055.44 1.15 1.44 0.95 1,200.00 1.20 15.77 108.28 1,152.14 1.15 1.80 1.04 1,300.00 1.21 17.77 108.44 1,247.88 1.15 2.22 1.14 1,400.00 1.22 19.77 108.57 1,342.55 1.16 2.71 1.25 1,500.00 1.24 21.77 108.68 1,436.05 1.16 3.25 1.38 1,600.00 1.26 23.77 108.78 1,528.25 1.17 3.87 1.52 1,700.00 1.27 25.77 102.58 1,619.04 1.16 2.22 1.42 1,723.32 1.28 26.24 102.75 1,640.00 1.16 2.32 1.46 T 3 Sand 1,734.48 1.28 26.46 102.75 1,650.00 1.16 2.32 1.46 Hold for 111.7' 1,778.04 1.29 26.46 103.12 1,689.00 1.17 2.51 1.53 Base Permafrost 1,800.00 1.29 26.46 103.12 1,708.66 1.17 2.51 1.53 1,846.18 1.29 26.46 103.34 1,750.00 1.19 2.65 1.58 Start 4°/100'DLS,55.27°TF,for 1584.4' 1,900.00 1.31 27.74 103.54 1,797.92 1.20 2.77 1.66 2,000.00 1.36 30.36 104.36 1,885.35 1.21 2.98 1.81 2,026.35 1.44 31.09 105.76 1,908.00 1.23 3.20 1.97 K-15 2,100.00 1.44 33.23 105.76 1,970.35 1.23 3.20 1.97 2,200.00 1.55 36.29 107.69 2,052.51 1.25 3.45 2.12 2,300.00 1.68 39.50 109.97 2,131.42 1.28 3.73 2.26 2,324.22 1.86 40.30 112.99 2,150.00 1.25 4.08 2.33 10 3/4"x 13-1/2 2,341.34 1.86 40.86 112.99 2,163.00 1.25 4.08 2.33 10 3/4"Csgpt_t3+525 2,400.00 1.86 42.82 112.99 2,206.70 1.25 4.08 2.33 2,500.00 2.04 46.24 118.47 2,277.99 1.26 4.69 2.35 2,600.00 2.24 49.71 123.99 2,344.93 1.30 5.53 2.39 2,700.00 2.46 53.25 128.65 2,407.20 1.38 6.55 2.45 2,800.00 2.69 56.83 132.38 2,464.50 1.50 7.70 2.53 2,900.00 2.96 60.44 135.37 2,516.55 1.68 8.94 2.64 3,000.00 3.25 64.08 137.84 2,563.09 1.89 10.27 2.77 11/11/2016 11:38:53AM Page 3 COMPASS 5000.1 Build 74 • ConocoPhillips • Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit ND Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Site: Kuparuk 3R Pad MD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp07 Database: EDM Alaska ANC Prod Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 3,100.00 3.57 67.75 139.93 2,603.89 2.13 11.64 2.92 3,200.00 3.91 71.43 141.74 2,638.77 2.41 13.06 3.08 3,300.00 4.29 75.12 143.35 2,667.54 2.71 14.51 3.25 3,400.00 4.70 78.83 144.79 2,690.08 3.03 15.97 3.44 3,430.58 4.83 79.96 145.21 2,695.70 3.13 16.42 3.50 Hold for 2779.83' 3,500.00 4.83 79.96 146.07 2,707.80 3.36 17.50 3.73 3,592.96 4.83 79.96 147.12 2,724.00 3.70 19.03 4.06 Top Ugnu C 3,600.00 4.83 79.96 147.12 2,725.23 3.70 19.03 4.06 3,700.00 4.84 79.96 148.01 2,742.65 4.04 20.57 4.40 3,800.00 4.84 79.96 148.77 2,760.08 4.39 22.11 4.74 3,900.00 3.84 79.96 143.97 2,777.50 2.54 9.87 2.81 4,000.00 3.84 79.96 144.93 2,794.93 2.70 10.42 2.96 4,100.00 3.84 79.96 145.78 2,812.35 2.86 10.97 3.12 4,200.00 3.85 79.96 146.54 2,829.78 3.03 11.53 3.28 4,300.00 3.86 79.96 147.21 2,847.20 3.19 12.10 3.44 4,400.00 3.86 79.96 147.82 2,864.63 3.36 12.66 3.61 4,500.00 3.87 79.96 148.36 2,882.05 3.52 13.23 3.77 4,600.00 3.87 79.96 148.86 2,899.48 3.69 13.80 3.94 4,700.00 3.88 79.96 149.30 2,916.91 3.86 14.37 4.10 4,800.00 3.88 79.96 149.71 2,934.33 4.03 14.94 4.27 4,900.00 3.89 79.96 150.09 2,951.76 4.20 15.51 4.44 5,000.00 3.90 79.96 150.43 2,969.18 4.37 16.09 4.61 5,100.00 3.90 79.96 150.75 2,986.61 4.54 16.67 4.78 5,200.00 3.91 79.96 151.04 3,004.03 4.71 17.24 4.95 5,300.00 3.92 79.96 151.31 3,021.46 4.88 17.82 5.12 5,400.00 3.92 79.96 151.56 3,038.88 5.05 18.40 5.29 5,500.00 3.93 79.96 151.79 3,056.31 5.22 18.98 5.47 5,544.14 3.94 79.96 152.01 3,064.00 5.40 19.56 5.64 Top Ugnu B 5,600.00 3.94 79.96 152.01 3,073.73 5.40 19.56 5.64 5,700.00 3.94 79.96 152.21 3,091.16 5.57 20.14 5.81 5,800.00 3.95 79.96 152.41 3,108.58 5.74 20.72 5.98 5,900.00 3.96 79.96 152.58 3,126.01 5.91 21.30 6.16 6,000.00 3.97 79.96 152.75 3,143.44 6.09 21.88 6.33 6,100.00 3.97 79.96 152.91 3,160.86 6.26 22.47 6.51 6,200.00 3.98 79.96 153.06 3,178.29 6.43 23.05 6.68 6,210.41 3.98 79.96 153.08 3,180.10 6.45 23.11 6.70 Start 3°/100'DLS,-90.24°TF,for 2258.55' 6,300.00 3.58 79.96 153.15 3,195.71 6.60 23.62 6.83 6,307.38 3.50 79.97 153.16 3,197.00 6.78 24.04 6.99 Top Ugnu A 6,400.00 3.50 79.99 153.16 3,213.12 6.78 24.04 6.99 6,500.00 3.85 80.05 153.11 3,230.46 6.95 24.40 7.15 11/1112016 11:38:53AM Page 4 COMPASS 5000.1 Build 74 41111 ConocoPhillips • Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Site: Kuparuk 3R Pad MD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp07 Database: EDM Alaska ANC Prod Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 6,600.00 4.54 80.13 153.01 3,247.68 7.12 24.72 7.32 6,700.00 5.46 80.24 152.86 3,264.74 7.29 24.98 7.50 6,719.26 6.51 80.26 152.65 3,268.00 7.47 25.18 7.67 TD 6,800.00 6.51 80.37 152.65 3,281.58 7.47 25.18 7.67 6,820.45 7.65 80.40 152.40 3,285.00 7.64 25.32 7.85 Top D inverted 6,900.00 7.65 80.53 152.40 3,298.17 7.64 25.32 7.85 7,000.00 8.84 80.72 152.09 3,314.46 7.81 25.40 8.04 7,100.00 10.06 80.94 151.73 3,330.40 7.99 25.43 8.22 7,154.95 11.30 81.06 151.33 3,339.00 8.16 25.39 8.40 Top N Sands 7,200.00 11.30 81.18 151.33 3,345.95 8.16 25.39 8.40 7,300.00 12.56 81.44 150.89 3,361.07 8.34 25.29 8.58 7,400.00 13.81 81.73 150.40 3,375.72 8.51 25.12 8.76 7,500.00 15.07 82.03 149.89 3,389.84 8.68 24.90 8.94 7,600.00 16.31 82.37 149.34 3,403.42 8.86 24.61 9.11 7,681.14 17.54 82.65 148.76 3,414.00 9.03 24.26 9.28 Base D inverted 7,700.00 17.54 82.72 148.76 3,416.40 9.03 24.26 9.28 7,800.00 18.76 83.09 148.15 3,428.76 9.21 23.85 9.45 7,900.00 19.95 83.48 147.53 3,440.46 9.38 23.39 9.61 7,995.65 21.12 83.87 146.88 3,451.00 9.56 22.86 9.76 Fault-enter West Sak C 8,000.00 21.12 83.89 146.88 3,451.46 9.56 22.86 9.76 8,100.00 22.26 84.31 146.21 3,461.75 9.73 22.28 9.92 8,200.00 23.36 84.75 145.53 3,471.28 9.91 21.65 10.07 8,300.00 24.43 85.20 144.84 3,480.04 10.09 20.96 10.21 8,400.00 25.46 85.67 144.13 3,487.99 10.26 20.23 10.36 8,427.01 26.14 85.80 143.64 3,490.00 10.38 19.70 10.46 Top West Sak D 8,468.96 26.14 86.00 143.64 3,493.00 10.38 19.70 10.46 Adjust TF to 0°,for 26.58' 8,495.54 26.16 86.80 143.45 3,494.67 10.43 19.83 10.47 Hold for 360.66' 8,500.00 26.16 86.80 143.42 3,494.92 10.44 19.85 10.48 8,600.00 26.16 86.80 142.73 3,500.50 10.62 20.35 10.66 8,700.00 26.16 86.80 142.04 3,506.09 10.79 20.84 10.83 8,800.00 26.16 86.80 141.35 3,511.67 10.97 21.35 11.01 8,856.20 26.16 86.80 140.96 3,514.81 11.07 21.63 11.11 Start 3°l100'DLS,0°TF,for 3.42' 8,859.62 26.24 86.90 141.01 3,515.00 11.06 21.65 11.10 Hold for 20'-7-5/8"x 9-7/8" 8,879.62 26.24 86.90 140.80 3,516.08 11.07 21.81 11.10 Start 2°/100'DLS,0°TF,for 73.64' 8,900.00 26.25 87.31 140.58 3,517.11 11.07 21.97 11.09 11/11/2016 11:38:53AM Page 5 COMPASS 5000.1 Build 74 • • ConocoPhillips Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Site: Kuparuk 3R Pad MD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp07 Database: EDM Alaska ANC Prod Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (0) (usft) (usft) (usft) (usft) 8,953.26 26.26 88.37 139.99 3,519.12 11.07 22.41 11.07 Hold for 179.98' 9,000.00 26.26 88.37 139.45 3,520.45 11.08 22.82 11.08 9,100.00 26.26 88.37 138.24 3,523.29 11.10 23.77 11.10 9,133.24 26.26 88.37 137.82 3,524.23 11.11 24.10 11.11 Start 2°/100'DLS,1800 TF,for 68.64' 9,200.00 26.25 87.04 136.96 3,526.90 11.14 24.79 11.17 9,201.88 26.25 87.00 136.94 3,527.00 11.14 24.81 11.17 Adjust TF to 0°,for 202.32' 9,300.00 26.27 88.96 135.62 3,530.46 11.18 25.88 11.18 9,400.00 26.26 90.96 134.22 3,530.52 11.24 27.04 11.26 9,404.20 26.26 91.05 134.17 3,530.45 11.24 27.09 11.26 Hold for 188.82' 9,500.00 26.26 91.05 132.78 3,528.70 11.31 28.26 11.33 9,593.02 26.26 91.05 131.42 3,527.00 11.39 29.43 11.41 Start 2°/100'DLS,0°TF,for 30.36' 9,600.00 26.26 91.19 131.31 3,526.86 11.39 29.52 11.42 9,623.38 26.26 91.65 130.96 3,526.29 11.41 29.82 11.45 Hold for 227.51' 9,700.00 26.26 91.65 129.82 3,524.08 11.49 30.83 11.52 9,800.00 26.26 91.65 128.33 3,521.20 11.59 32.17 11.63 9,850.90 26.26 91.65 127.57 3,519.73 11.65 32.87 11.68 Start 2°/100'DLS,0°TF,for 67.32' 9,900.00 26.24 92.63 126.84 3,517.90 11.71 33.55 11.78 9,918.21 26.23 93.00 126.57 3,517.00 11.73 33.80 11.82 Adjust TF to-180°,for 71.36' 9,989.58 26.26 91.57 125.53 3,514.15 11.82 34.79 11.85 Hold for 120.46' 10,000.00 26.26 91.57 125.38 3,513.87 11.83 34.94 11.86 10,100.00 26.27 91.57 123.93 3,511.12 11.96 36.37 12.00 10,110.04 26.27 91.57 123.79 3,510.85 11.98 36.52 12.01 Start 20/100'DLS,0°TF,for 71.36' 10,181.40 26.24 93.00 122.78 3,508.00 12.08 37.55 12.17 Adjust TF to-180°,for 79.26' 10,200.00 26.25 92.63 122.53 3,507.09 12.11 37.82 12.18 10,260.66 26.27 91.41 121.72 3,504.95 12.20 38.69 12.23 Hold for 159.87' 10,300.00 26.27 91.41 121.19 3,503.98 12.26 39.27 12.29 10,400.00 26.28 91.41 135.00 3,501.51 11.40 26.42 11.43 10,420.54 26.28 91.41 134.90 3,501.00 11.41 26.50 11.44 Start 2°1100'DLS,00 TF,for 26.63' 10,447.16 26.27 91.95 134.78 3,500.22 11.42 26.60 11.47 Hold for 193.18' 10,500.00 26.27 91.95 134.53 3,498.42 11.45 26.80 11.50 10,600.00 26.27 91.95 134.05 3,495.03 11.50 27.20 11.55 11/11/2016 11:38:53AM Page 6 COMPASS 5000.1 Build 74 ConocoPhillips Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Site: Kuparuk 3R Pad MD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp07 Database: EDM Alaska ANC Prod Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (0) (0) (usft) (usft) (usft) (usft) 10,640.34 26.27 91.95 133.86 3,493.65 11.52 27.36 11.57 Start 2°/100'DLS,180°TF,for 97.37' 10,700.00 26.29 90.75 133.58 3,492.25 11.55 27.59 11.56 10,737.71 26.30 90.00 133.40 3,492.00 11.57 27.74 11.57 Adjust TF to 0°,for 0' 10,800.00 26.30 90.00 133.10 3,492.00 11.60 27.99 11.60 10,900.00 26.30 90.00 132.60 3,492.00 11.65 28.41 11.65 11,000.00 26.30 90.00 132.10 3,492.00 11.71 28.82 11.71 11,028.74 26.30 90.00 131.96 3,492.00 11.73 28.95 11.73 Hold for 291.03' 11,077.43 26.30 90.97 131.71 3,491.59 11.76 29.15 11.77 Start 2°/100'DLS,0°TF,for 0' 11,100.00 26.30 90.97 131.60 3,491.20 11.77 29.25 11.79 11,200.00 26.30 90.97 131.09 3,489.50 11.83 29.68 11.85 11,264.11 26.30 90.97 130.76 3,488.41 11.87 29.96 11.89 Adjust TF to 0.04°,for 48.69' 11,300.00 26.31 90.26 130.59 3,488.03 11.90 30.11 11.90 11,312.80 26.31 90.00 130.52 3,488.00 11.91 30.16 11.91 Hold for 186.68' 11,322.40 26.33 89.81 130.48 3,488.02 11.91 30.19 11.91 Start 2°/100'DLS,-179.6°TF,for 48.69' 11,400.00 26.33 89.81 130.09 3,488.27 11.97 30.53 11.96 11,487.97 26.33 89.81 129.63 3,488.56 12.03 30.92 12.02 Adjust TF to-171.73°,for 9.6' 11,500.00 26.32 90.05 129.57 3,488.58 12.03 30.98 12.03 11,592.84 26.23 91.90 129.09 3,487.00 12.10 31.46 12.15 Hold for 165.57' 11,600.00 26.22 92.04 129.05 3,486.75 12.11 31.50 12.16 11,680.00 26.10 93.63 128.64 3,482.80 12.16 31.93 12.29 Start 2°/100'DLS,4.86°TF,for 104.88' 11,700.00 26.10 93.63 128.54 3,481.53 12.18 32.03 12.30 11,777.04 26.10 93.63 128.14 3,476.65 12.24 32.38 12.36 Adjust TF to 7.17°,for 87.15' 11,800.00 26.19 93.20 128.02 3,475.29 12.26 32.42 12.36 11,875.29 26.47 91.80 127.65 3,472.00 12.31 32.54 12.36 Hold for 97.05' 11,900.00 26.57 91.34 127.53 3,471.32 12.33 32.58 12.36 11,965.29 26.81 90.13 127.21 3,470.48 12.39 32.68 12.39 Start 2°/100'DLS,-158.58°TF,for 98.25' 12,000.00 26.81 90.13 127.03 3,470.40 12.41 32.84 12.42 12,100.00 26.81 90.13 126.51 3,470.17 12.50 33.31 12.50 12,167.54 26.81 90.13 126.15 3,470.01 12.55 33.63 12.55 Adjust TF to-157.82°,for 90' 12,200.00 27.02 90.60 125.98 3,469.80 12.58 33.62 12.59 12,248.42 27.33 91.30 125.73 3,469.00 12.62 33.59 12.65 Hold for 202.26' 11/11/2016 11:38:53AM Page 7 COMPASS 5000.1 Build 74 ConocoPhillips Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit ND Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Site: Kuparuk 3R Pad MD Reference: 3R-102:28+9.9 @ 37.9ousft(Doyon141) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp07 Database: EDM Alaska ANC Prod Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 12,300.00 27.67 92.01 125.46 3,467.51 12.67 33.55 12.72 12,327.44 27.85 92.39 125.32 3,466.46 12.69 33.53 12.77 Start 2°/100'DLS,-43.83°TF,for 80.88' 12,400.00 27.85 92.39 124.93 3,463.44 12.75 33.88 12.83 12,500.00 27.85 92.39 124.40 3,459.27 12.84 34.37 12.92 12,600.00 27.85 92.39 123.87 3,455.11 12.94 34.86 13.01 12,649.72 27.85 92.39 123.60 3,453.04 12.98 35.11 13.06 Adjust TF to-46.56°,for 79.01' 12,700.00 28.28 91.86 123.34 3,451.18 13.03 35.02 13.08 4 1/2"x 6-3/4" 12,705.58 28.32 91.80 123.32 3,451.00 13.04 35.01 13.09 Hold for 322.28' 12,789.79 29.04 90.97 122.89 3,448.97 13.12 34.83 13.14 Start 2°/100'DLS,-121.63°TF,for 55.86' 12,800.00 29.04 90.97 122.84 3,448.80 13.13 34.88 13.15 12,900.00 29.04 90.97 122.30 3,447.11 13.22 35.39 13.25 12,947.99 29.04 90.97 122.04 3,446.30 13.27 35.63 13.29 Adjust TF to-119.69°,for 84.21' 13,000.00 29.80 91.82 121.77 3,445.04 13.32 35.25 13.38 13,100.00 31.22 93.46 121.23 3,440.43 13.42 34.46 13.61 13,163.87 32.10 94.50 120.89 3,436.00 13.49 33.92 13.80 Hold for 158.2' 13,200.00 32.62 94.97 120.69 3,433.02 13.52 33.57 13.90 13,219.67 32.90 95.22 120.58 3,431.27 13.54 33.38 13.96 Hold for 103.73' 13,300.00 32.90 95.22 120.13 3,423.96 13.63 33.80 14.05 13,323.40 32.90 95.22 120.00 3,421.83 13.65 33.92 14.07 Start 3°/100'DLS,-85.01°TF,for 30.92' 13,354.32 33.32 95.30 119.83 3,419.00 13.68 33.65 14.13 Adjust TF to-87.59°,for 272.78' 13,400.00 33.93 95.36 119.58 3,414.76 13.73 33.25 14.20 13,500.00 35.25 95.47 119.04 3,405.32 13.84 32.33 14.37 13,600.00 36.52 95.56 118.48 3,395.71 13.95 31.37 14.54 13,627.10 36.85 95.59 118.33 3,393.08 13.97 31.10 14.59 Hold for 426.59' 13,700.00 36.85 95.59 117.91 3,385.98 14.05 31.47 14.66 13,800.00 36.85 95.59 117.33 3,376.24 14.16 31.99 14.77 13,900.00 36.86 95.59 116.74 3,366.50 14.28 32.52 14.88 14,000.00 36.86 95.59 116.16 3,356.76 14.39 33.04 14.99 14,053.69 36.86 95.59 115.85 3,351.53 14.45 33.33 15.05 Start 2°/100'DLS,161.28°TF,for 189.4' 14,100.00 36.79 94.71 115.60 3,347.37 14.50 33.69 14.96 14,200.00 36.60 92.82 115.13 3,340.81 14.62 34.44 14.82 14,243.09 36.51 92.00 114.93 3,339.00 14.67 34.76 14.79 Adjust TF to 170.63°,for 96.6' 14,300.00 36.46 90.88 114.66 3,337.57 14.74 35.10 14.78 11/11/2016 11:38:53AM Page 8 COMPASS 5000.1 Build 74 ConocoPhillips Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:28+9.9©37.90usft(Doyon141) Site: Kuparuk 3R Pad MD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp07 Database: EDM Alaska ANC Prod Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (0) (0) (usft) (usft) (usft) (usft) 14,339.69 36.42 90.09 114.47 3,337.24 14.78 35.33 14.79 Hold for 514.7' 14,400.00 36.42 90.09 114.16 3,337.14 14.86 35.63 14.86 14,500.00 36.42 90.09 113.60 3,336.97 14.98 36.15 14.98 14,600.00 36.42 90.09 113.05 3,336.81 15.10 36.68 15.10 14,700.00 36.42 90.09 112.50 3,336.65 15.22 37.21 15.22 14,800.00 36.43 90.09 111.95 3,336.48 15.34 37.74 15.35 14,854.39 36.43 90.09 111.66 3,336.39 15.41 38.03 15.41 Start 2.5°l100'DLS,0.16°TF,for 76.25' 14,900.00 36.40 91.23 111.41 3,335.86 15.47 38.27 15.53 14,930.64 36.38 92.00 111.24 3,335.00 15.51 38.44 15.63 Adjust TF to-0.04°,for 242.31' 15,000.00 36.30 93.73 110.87 3,331.53 15.59 38.81 15.88 15,100.00 36.15 96.23 110.33 3,322.84 15.72 39.35 16.35 15,172.95 36.01 98.06 109.95 3,313.77 15.81 39.74 16.76 Hold for 326.53' 15,200.00 36.01 98.06 109.80 3,309.98 15.85 39.88 16.80 15,300.00 36.01 98.06 109.28 3,295.96 15.97 40.42 16.92 15,400.00 36.01 98.06 108.76 3,281.94 16.10 40.97 17.04 15,499.48 36.02 98.06 108.25 3,268.00 16.23 41.51 17.16 TD:15499.48'MD,3305.9'TVD 11/11/2016 11:38:53AM Page 9 COMPASS 5000.1 Build 74 all ConocoPhillips Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Site: Kuparuk 3R Pad MD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp07 Database: EDM Alaska ANC Prod Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 106.90 106.90 20"x 42" 20 42 2,324.22 2,187.90 10 3/4"x 13-1/2 10-3/4 13-1/2 8,859.62 3,552.90 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,700.00 3,489.08 4 1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (0) (0) 1,778.04 1,726.90 Base Permafrost 0.00 1,723.32 1,677.90 T 3 Sand 0.00 3,592.96 2,761.90 Top Ugnu C 7,681.14 3,451.90 Base D inverted 7,995.65 3,488.90 Fault-enter West Sak C 8,427.01 3,527.90 Top West Sak D 7,154.95 3,376.90 Top N Sands 6,719.26 3,305.90 TD 2,026.35 1,945.90 K-15 0.00 6,820.45 3,322.90 Top D inverted 6,307.38 3,234.90 Top Ugnu A 5,544.14 3,101.90 Top Ugnu B 2,341.34 2,200.90 10 3/4"Csgpt_t3+525 11/11/2016 11:38:53AM Page 10 COMPASS 5000.1 Build 74 ConocoPhillips p Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Site: Kuparuk 3R Pad MD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp07 Database: EDM Alaska ANC Prod Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (') (") 106.90 106.90 20"x 42" 20 42 2,324.22 2,187.90 10 3/4"x 13-1/2 10-3/4 13-1/2 8,859.62 3,552.90 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,700.00 3,489.08 4 1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (1 (") 1,778.04 1,726.90 Base Permafrost 0.00 1,723.32 1,677.90 T 3 Sand 0.00 3,592.96 2,761.90 Top Ugnu C 7,681.14 3,451.90 Base D inverted 7,995.65 3,488.90 Fault-enter West Sak C 8,427.01 3,527.90 Top West Sak D 7,154.95 3,376.90 Top N Sands 6,719.26 3,305.90 TD 2,026.35 1,945.90 K-15 0.00 6,820.45 3,322.90 Top D inverted 6,307.38 3,234.90 Top Ugnu A 5,544.14 3,101.90 Top Ugnu B 2,341.34 2,200.90 10 3/4"Csgpt_t3+525 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 348.90 348.90 0.00 0.00 KOP:Start 1.5°/100'DLS,290°TF,for 250.18' 599.08 598.90 2.80 -7.70 Start 2°/100'DLS,0°TF,for 1135.4' 1,734.48 1,687.90 103.34 -283.94 . Hold for 111.7' 1,846.18 1,787.90 120.37 -330.71 Start 4°/100'DLS,55.27°TF,for 1584.4' 3,430.58 2,733.60 1,063.90 -1,023.52 Hold for 2779.83' 6,210.41 3,218.00 3,606.44 -2,037.59 Start 3°/100'DLS,-90.24°TF,for 2258.55' 8,468.96 3,530.90 4,782.78 -3,784.56 Adjust TF to 0°,for 26.58' 8,495.54 3,532.57 4,782.85 -3,811.09 Hold for 360.66' 8,856.20 3,552.71 4,783.83 -4,171.18 Start 3°/100'DLS,0°TF,for 3.42' 8,859.62 3,552.90 4,783.84 -4,174.60 Hold for 20' 8,879.62 3,553.98 4,783.89 -4,194.57 Start 2°/100'DLS,0°TF,for 73.64' 8,953.26 3,557.02 4,784.09 -4,268.14 Hold for 179.98' 9,133.24 3,562.13 4,784.58 -4,448.05 Start 2°/100'DLS,180°TF,for 68.64' 9,201.88 3,564.90 4,784.77 -4,516.63 Adjust TF to 0°,for 202.32' 9,404.20 3,568.35 4,785.32 -4,718.88 Hold for 188.82' 9,593.02 3,564.90 4,785.84 -4,907.67 Start 2°/100'DLS,0°TF,for 30.36' 9,623.38 3,564.19 4,785.92 -4,938.02 Hold for 227.51' 9,850.90 3,557.63 4,786.54 -5,165.44 Start 2°/100'DLS,0°TF,for 67.32' 9,918.21 3,554.90 4,786.72 -5,232.70 Adjust TF to-180°,for 71.36' 9,989.58 3,552.05 4,786.92 -5,304.00 Hold for 120.46' 10,110.04 3,548.75 4,787.25 -5,424.42 Start 2°/100'DLS,0°TF,for 71.36' 10,181.40 3,545.90 4,787.44 -5,495.72 Adjust TF to-180°,for 79.26' 10,260.66 3,542.85 4,787.66 -5,574.92 Hold for 159.87' 10,420.54 3,538.90 4,788.09 -5,734.75 Start 2°/100'DLS,0°TF,for 26.63' 10,447.16 3,538.12 4,788.16 -5,761.36 Hold for 193.18' 11/11/2016 11:38:53AM Page 11 COMPASS 5000.1 Build 74 • ConocoPhillips Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Site: Kuparuk 3R Pad MD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp07 Database: EDM Alaska ANC Prod Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 106.90 106.90 20"x 42" 20 42 2,324.22 2,187.90 10 3/4"x 13-1/2 10-3/4 13-1/2 8,859.62 3,552.90 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,700.00 3,489.08 4 1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (0) (0) 1,778.04 1,726.90 Base Permafrost 0.00 1,723.32 1,677.90 T 3 Sand 0.00 3,592.96 2,761.90 Top Ugnu C 7,681.14 3,451.90 Base D inverted 7,995.65 3,488.90 Fault-enter West Sak C 8,427.01 3,527.90 Top West Sak D 7,154.95 3,376.90 Top N Sands 6,719.26 3,305.90 TD 2,026.35 1,945.90 K-15 0.00 6,820.45 3,322.90 Top D inverted 6,307.38 3,234.90 Top Ugnu A 5,544.14 3,101.90 Top Ugnu B 2,341.34 2,200.90 10 3/4"Csgpt_t3+525 10,640.34 3,531.55 4,788.69 -5,954.43 Start 2°/100'DLS,180°TF,for 97.37' 10,737.71 3,529.90 4,788.95 -6,051.78 Adjust TF to 0°,for 0' 11,028.74 3,529.90 4,789.75 -6,342.81 Hold for 291.03' 11,077.43 3,529.49 4,789.88 -6,391.49 Start 2°/100'DLS,0°TF,for 0' 11,264.11 3,526.31 4,790.39 -6,578.15 Adjust TF to 0.04°,for 48.69' 11,312.80 3,525.90 4,790.52 -6,626.83 Hold for 186.68' 11,322.40 3,525.92 4,790.54 -6,636.43 Start 2°1100'DLS,-179.6°TF,for 48.69' 11,487.97 3,526.46 4,790.90 -6,802.00 Adjust TF to-171.73°,for 9.6' 11,592.84 3,524.90 4,791.28 -6,906.86 Hold for 165.57' 11,680.00 3,520.70 4,791.91 -6,993.91 Start 2°/100'DLS,4.86°TF,for 104.88' 11,777.04 3,514.55 4,792.78 -7,090.75 Adjust TF to 7.17°,for 87.15' 11,875.29 3,509.90 4,793.05 -7,188.88 Hold for 97.05' 11,965.29 3,508.38 4,792.21 -7,278.86 Start 20/100'DLS,-158.58°TF,for 98.25' 12,167.54 3,507.91 4,789.10 -7,481.09 Adjust TF to-157.82°,for 90' 12,248.42 3,506.90 4,787.07 -7,561.94 Hold for 202.26' 12,327.44 3,504.36 4,783.52 -7,640.83 Start 20/100'DLS,-43.83°TF,for 80.88' 12,649.72 3,490.94 4,765.84 -7,962.34 Adjust TF to-46.56°,for 79.01' 12,705.58 3,488.90 4,762.31 -8,018.05 Hold for 322.28' 12,789.79 3,486.87 4,755.22 -8,101.94 Start 20/100'DLS,-121.63°TF,for 55.86' 12,947.99 3,484.20 4,739.88 -8,259.37 Adjust TF to-119.69°,for 84.21' 13,163.87 3,473.90 4,706.54 -8,472.25 Hold for 158.2' 13,219.67 3,469.17 4,693.88 -8,526.39 Hold for 103.73' 13,323.40 3,459.73 4,668.77 -8,626.59 Start 3°/100'DLS,-85.01°TF,for 30.92' 13,354.32 3,456.90 4,661.04 -8,656.40 Adjust TF to-87.59°,for 272.78' 13,627.10 3,430.98 4,572.23 -8,912.76 Hold for 426.59' 14,053.69 3,389.43 4,404.87 -9,302.95 Start 20/100'DLS,161.28°TF,for 189.4' 14,243.09 3,376.90 4,332.24 -9,477.38 Adjust TF to 170.63°,for 96.6' 14,339.69 3,375.14 4,296.31 -9,567.02 Hold for 514.7' 14,854.39 3,374.29 4,106.12 -10,045.29 Start 2.5°/100'DLS,0.16°TF,for 76.25' 14,930.64 3,372.90 4,077.95 -10,116.13 Adjust TF to-0.04°,for 242.31' 15,172.95 3,351.67 3,988.82 -10,340.33 . Hold for 326.53' 15,499.48 3,305.90 3,869.36 -10,640.76 TD:15499.48'MD,3305.9'TVD 11111/2016 11:38:53AM Page 12 COMPASS 5000.1 Build 74 111/1 111 ConocoPhillips Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3R-102 Project: Kuparuk River Unit TVD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Site: Kuparuk 3R Pad MD Reference: 3R-102:28+9.9 @ 37.90usft(Doyon141) Well: Plan:3R-102 North Reference: True Wellbore: Plan:3R-102 Survey Calculation Method: Minimum Curvature Design: 3R-102wp07 Database: EDM Alaska ANC Prod Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name _ ('•) (") 106.90 106.90 20"x 42' 20 42 2,324.22 2,187.90 10 3/4"x 13-1/2 10-3/4 13-1/2 8,859.62 3,552.90 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,700.00 3,489.08 4 1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 1,778.04 1,726.90 Base Permafrost 0.00 1,723.32 1,677.90 T 3 Sand 0.00 3,592.96 2,761.90 Top Ugnu C 7,681.14 3,451.90 Base D inverted 7,995.65 3,488.90 Fault-enter West Sak C 8,427.01 3,527.90 Top West Sak D 7,154.95 3,376.90 Top N Sands 6,719.26 3,305.90 TD 2,026.35 1,945.90 K-15 0.00 6,820.45 3,322.90 Top D inverted 6,307.38 3,234.90 Top Ugnu A 5,544.14 3,101.90 Top Ugnu B 2,341.34 2,200.90 10 3/4"Csgpt_t3+525 Checked By: Approved By: Date: 11/11/2016 11:38:53AM Page 13 COMPASS 5000.1 Build 74 Pool Report I • 12:02,November 11 2016 //� 7 WELLBORE TARGE)DE1A)LS(MAP CO-ORDINATES) — 3R-102wp0/ 3R-W021Top103966AM 5290 Circle 100 3R-1022.Heel 103116 MW 3552.90 Circle(Radius:100.00) 36-1023.12 103116 MW 3564.90 Circle(Radius:100.00) Quarter Mile View 3R-102 4.11103116 MW 356490 Circle(Radius:100.00) 3R-1025.74103116 SAW 3564.90 Cade(Radius:100.00) 3R-1026.75 103116 MW 3545.90 Circle(Radius:100.00) 36-1027.Te 103116 MW 353890 Circle(Radius:10090) 36-102 B.77 103116 MW 3529.90 Circle(Radius.100.00) 30402918 103116 MW 3529.90 Circle(Radius:100.00) 36-10210.T9 103116 MW 3525.90 Circle(Radius.100.00) 36-10211.T10 103116 MW 352490 Circle(Radius 100.00) 17/73' 3R-10212.711 103116 MW 350990 Circle(Radius:100.00) 36-10213.T12 103116 MW 3506.90 Circle(Radius:100.00) Q 3R-10214.713103116 MW 345890 CScle(Radius 103 00) MI 3 35-3112 1 5.1141W115/31V"i 3773 ,Zirrde' 81538811 -- O R ffiDO) i- S • 9 3 10216.75703118 MW Cade Radius DO) A A i-t 17.T1 1 11 33'690 Ra 3 72 B 03 6MW Circle Ows:10D.00 �7pp0 • 36.10216.717103116 MW a RadWs 100.00 TO MW 00) —.........___.._..___............................................'F......Q............_.........___............................._...................._.._.. ..r31�..__....................._ ..._.._.............................. ....................................._._.................. 14000 • \ 49; 3R1022Heel 9 108))0 W C R.55 5 (Radius: 2090) oQe �Q •� i Not,rd o • 0. ; 10500 • • 0 ^�Q :tte CI''"'"'"'"''. 9' e0. Q y1 Op 1 • fA \ • ° 07 p —........_.._._ I°rook 0 700 tej... • • • R 14 • - 1 0 3500— \\ /ei Ab t o L •• t. 9 O 4 �® 0 • — 73, I-J 3R-26PB1 -3500- ....... .....__.._....................._.i. i • -3R-26 1 I 1 I 1 I 1 -21000 -17500 -14000 -10500 -7000 -3500 0 3500 7000 West(-1/East(+1 (3500 usftlinl • S WELLBORE TARGET DETAILS(MAP CO-OROINAEES) 12:03,November 11 2016 3R-102wp07 Name TVD Shatz 3R-W02 1 Top D 010816 MW 353080 Circle(Radius.100.00) 36.1022.Neel 103116 MW 355290 Circle(Radius,100.00) 36-1023.12 103116 MW 356490 Circle(Radius:100.00) Quarter Mile View 36-102 4 73103118 MW 36-1024.73103116 MW 3564.90 Circle(Radius:100.00) 3554.90 Circle(Radius:100.00) • 3R-1026.T5103116 MW 354590 Circle(Radius.100.00) 36-102 7.T6 103116 MW 353890 Circle(Radius:100.00) 36-1028.T7 103116 MW 3529.90 COOS(Radius:100.00) 3R-102 H.78103116 MW 3529.90 Circle(Radius-100.00) y 3R-10210.19103115MW 352590 Cod (Rad 10000) 1VaG'p` .t�� 36-10211.T10103116MIN 352490 Cd (Radius 10000) 3R-10212.T11 103116 MW 350990 Circle(Radius:100.03) 36-10213.112103116 MW 350890 Circle(Radius:10000) 10500 , 3 ;6 e` P.. o00) ... _...3R 02..T ..... P • 3R-10217.116 103116 MW 3376.90 Circle(Radius:120. :, �P 3R-10218.T17103116 MW 337390 Cirda(Radius:100 Iii Ory • • \ 3R-10219_TD 103118 MJJ 330890 Cede(Rad 100 36-10219.TD 103116 MW Circle 3309.90 Click(Radius 1320. \ ? 3R-f022i Nee1103116 MJJ_Ceck 355290 Circle(Ratlius:132000 • • A i Q5' 9000 .;¢ \ • ,? op2 – • • PA dill"C 'as •� - 7500 j •• 0 • o 6000 - t \i � • ' ymibieviiiir • 00 .K-w a 4500 •-` • • • °� a • 3000 ........... I • -N N::\N N N NH i j • • 1500— i• T I -12000 -10500 -9000 -7500 -6000 -4500 -3000 -1500 0 West(-1/East(+l (1500 usft/inl • S 3R-10wp07 3-D View OP19-T1 NPB'_ ',,,7,. y .°111.1.1.11111111111.11111111.1 -- �� J '., �'•, - Olikt nt State I . ..z,.„ iI f r____ .. ter. - ' `s.... �',, I ak Poi . .... ' A �r;.. ....:.-... D 3R-10 v OR--1• • 410 3R-102wp07 3-D View ro,,,,, fd ::///:////// 4, K),, ,,, --441111111111111111.1111 frdild ‘ _______ I® ice- AVIV" • • 3R-102wp07 3-D View ::_:' .--- . ii -,. /.OP21-W W F r� • E..............././• • • 3r2-�02wp. 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FEL � .:3020.2582 Transform Quitj Help • • Tollerable Collision Risk Worksheet As - staked REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 11/10/16 LGM JAH Update Drawing STP 4 OPP f — + PROJECT LOCAl1O / \ I +:::1.4 R \ 9 \ \ NOC 1 • \ • ri 15 • ACA 3Q j® 1" = 100' 1 • X02 3 ®—0-: . \ 20 • 1 • 12 VICINITY MAP ,---0 J.. p53R \ „<-0 - N sot- ,, \ ,\4 \\ ,, °-,t, ii *It' :11.-% lon-01„0 • ke • . .-: -A---'-:27\ )a , ___ . '\9 \ • / * --- -. • • 22 CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 9, T. 13 N., R. 9 E., UMIAT MERIDIAN, ALASKA Well NAD 27 NAD 27 Section Elev. No. ASP Coordinates Geographic Coordinates Offset. Y X Lat. Long. F.N.L F.W.L. O.G. PAD 101 6,031,732.32 520,625.99 N 70° 29' 52.27" W 149° 49' 52.77" 1631' 2321' 4.8' 9.9' 102 6,031,703.97 520,635.80 N 70° 29' 51.99" W 149° 49' 52.49" 1659' 2330' 4.8' 9.9' LEGEND LOUNSBURY • EXISTING CONDUCTOR & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS o AS STAKED CONDUCTOR AREA: MODULE: XXXX UNIT: ConocoPhillips DS3R WELL CONDUCTOR Alaska, Inc. AS STAKED LOCATIONS CADD FILE NO. I DRAWING NO. PART: REV: LK6318d22 11/04/16 NSK 6.318 — d22 I 1 OF 1 I 1 • 411 3R-102 Drilling Hazards Summary Description Comments Mitigation of risk includes Key Risk: Ability to • Torque and Drag simulation and monitoring trends during the get the liner on run bottom • Ability to rotate the slotted liner with liner hanger and top packer • Centralization • High dog legs in the intermediate section cause issues when Key Risk: High dog running the upper completion. Set the max DLS at 8° and if legs and concretions exceeded in the extreme case, plug back with cement and in West Sak section redrill. • Managing drilling parameters to minimize DLS due to concretion or fault crossing. • Hole cleaning in long laterals leading to high ECD's. Keep Key Risk: Hole RPM over 120 RPM and monitor closely. If increasing ECD Cleaning is a trend, slow ROP to clean hole and back off pump rate, as needed. Key Risk: Obtaining • MDT sampling will occur via wireline tool which will be drill Representative pipe conveyed. If we are uncertain as to the quality of this MDT Fluid Samples fluid sample,this AFE is carrying a separate drill pipe in the West Sak D conveyed percussion sidewall coring operation. in the toe pilot Key Risk: Differential Sticking • Maintain low MW and explore the application of open hole while taking MDT stand off devices on DP. sample Key Risk: • Due to reservoir production across the lease line,there is Low reservoir potential for lower pressures that could result in fluid losses pressure leading to while drilling. LCM will be available and used to heal losses. loses • • Wellhead/Tab,ng Head psi Tree, 3R-102 Injector(WP07) 10-3/4"x 4-1/2",5,000 psi Insulated Conductor Slotted Liner Casing,20",94#, Tubing String: 4-1/2",12.6#,L-80 H563 - K55 x 34",0.312' WT@+/-80'MDA5 Gas Lift Mandrel, CAMCO 10-3/4",45.54,L-80,Hyd563 Model KMBG w/Dummy @ 2325'MD/2189 TVD @ XXXXMD/XXXX'TVD(XX deb) @ 40 degrees n TD 13.5"hole lit- cc 1 s A 3 'i Gas Lift Mandrel, CAMCO 'C, - Model KMBG w/DCK-2 Shear Valve 0 4 @ XXXX'MD/XXXX TVD(XX deg) 1 2.812"DB nipple w/pre-installed RHC plug body @)00(.X'MD/XXXX'TVD(XX deg) I_ - - 4-A"Slotted Liner ID @ 12,700'MD/3,489'TVD_ @ 89 degrees 6-3.4"OH TD - Slotted Liner, 4-1/2",11.64 3840'Lined Lateral @ 15,000'MD/ n - -__1 L80 IBTM 3,306'ND 1 ZXP Liner Top packer&Liner Hanger - _. 6640'Lateral — @ 8,660 MD(-200 ft above 7-5/8"shoe) ----*i r i 7-5/8",29.7#,L-80,Hyd563/TXP,Casing h-.,i @8.86(YMD/3,553'TVD____,„/3V - ° @ 87 degrees L 6-3/4"Swellable Packer 4-1/2"Solid Shoe TD 9-7/8"hole (Water Expanded) aa,.. • • E r. CONTAINMENT DIKE 1 , N N Io 117_, , _— 4M4d _.�� O J \ 0 ❑= I\- 0 'i- � N v�1,3- I NJ N . v it. r11r1'� I• W o �-4 owox 09— Z1 ®\ ol.InPon'Pu+dp j '6 A@\ 0" _ D O I W JO❑ O A_ IN W P ,(�,�y,(��,, r U v�IN _ , O 9 m UO❑� NII n y o LTJ I I/ J �° UO I ^ Ne❑O _. I — 1 WoOO❑f �1 N N N I N linJ O 7 O n Rif( D S m0790 6 i 6,0"'0 n 0 P c .. ti O o D 1 2 O 4 • • Well: KRU 3R-102 <==Data Input Name: CPAI <==Data Input o I Mud Weight(ppg) 10.00 <==Data Input JIMit Weak point or LOT-Measured depth(ft) 2,324' <==Data Input Weak point or LOT True vertical depth(ft) 2,188' <==Data Input , Weak point or LOT-Hole angle(deg) 40.3° <==Data Input Weak point or LOT-Hole size(in) 16.000" <==Data Input Weak point pressure or LOT-EMW(ppg) 13.00 <==Data Input Zone of interest-Measured depth(ft) 8,660' <==Data Input Zone of interest-True vertical depth (ft) 3,540' <==Data Input Zone of interest-Hole angle(deg) 87.0° <==Data Input Zone of interest-Hole size(in) 13.500" <==Data Input ,. Zone of interest-Pore pressure EMW(ppg) 8.60 <==Data Input Gas gradient(psi/ft) 0.10 <==Data Input Bottom hole assembly OD(in) 8.0" <==Data Input Bottom hole assembly length(ft) 151' <==Data Input Drill pipe OD(in) 5.000" <==Data Input 4. BHA annular vol.@ zone of interest(bbl/ft) 0.1149 DP annular vol.@ zone of interest (bbl/ft) 0.1528 DP annular vol. .' weak .oint bbl/ft 0.2244 Additional safety margin(psi) 0.00 <==Data Input Weak point pressure(psi): Plo 1,479 psi Weak point pressure-Safety margin: Pmax 1,479 psi Pmax EMW 13.00 ppg Max anticipated formation pressure(psi): Pf ,,583 psi Weak Pt to Zone of Interest distance(TVD ft): OH {TVD} 1,352' Weak Pt to Zone of Interest distance(MD ft): OH {MD} 6,336' Maximum influx height at the bit (TVD ft): H {TVD} 1,426' Maximum influx height at the bit (MD ft): H {MD} 27,253' Calc.volume of(H}around BHA: Vlbha N/A Calc.volume of(H)around drill pipe: Vldp N/A Calc.volume that H equals @ initial shut in: V1 N/A Calc.vol.that H equals @ weak point(MD ft): Vwp N/A Calc.volume of Vwp @ initial shut in: V2 N/A 1111111111111111 IF • Kick Tolerance: N/A Infinite NOTE: Maximum influx hei•ht(H)extend V Loe• • 12/23/16 • • Loepp. Victoria T (DOA) From: Hallford, Kelsey <Kelsey.Hallford@conocophillips.com> Sent: Thursday, December 08, 2016 1:05 PM To: Loepp,Victoria T(DOA) Subject: RE:3R-102 injector new drill (PTD 216-157)AOR Attachments: 3R-102wp07 PlanSummary- Permit Pack.pdf The X mile plat is in the submitted PTD,directional plan attached here for easier access.The planned spud at the date of 10-401 submittal was December 15t",there have been some rig schedule changes and we are now planning for spud between Last week of December and the first week of January. Kelsey From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday, December 08,2016 12:59 PM To: Hallford, Kelsey<Kelsey.Hallford@conocophillips.com> Subject: [EXTERNAL]RE:3R-102 injector new drill (PTD 216-157)AOR Kelsey, We can't permit a well as an injector without a review. Approving a PTD for a well as an injector implies injection is approved.The AOR is always required for a injector PTD(10-401).The other option is to permit the well as a producer and submit a 10-403 for conversion to a WI at such time an AOR would be required. The table below looks complete. I will review. Do you have a map that indicates all wells in the X mile radius?That should be included. What is the planned spud date? Thanx, Victoria From: Hallford, Kelsey [mailto:Kelsey.Hallford@conocophillips.com] Sent:Thursday, December 08,2016 11:47 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: RE: 3R-102 injector new drill (PTD 216-157)AOR Victoria, Is the below spreadsheet sufficient for the AOR?Guy mentioned this wasn't required until we applied for a permit to inject via the 10-403 form as we will need a sundry to switch from pre-production to injection,and I didn't find any guidance under the drilling regulations on the AOGCC site. Let me know if there is further information you're requesting. Top of West Sak TOC Determined Well Name Status D Sand(MD/ TOC(MD/ND) to Reservoir Status Zonal Isolal By ND) 1 • • Proposed Column of cem( 3R-102 Injector 8,427'/3,528' 5,044'/3,020' Sonic LWD Not Yet Drilled 500'above Ug 5,044' MD/3,C Calculated with Perfs open for Column of cem OP21ww01 Water Producer 3,883'/3,516' 2,960'/2,865' 40%washout, no production in 3,826' MD to losses during job Ivishak 2,960' MD,is. West Sa Perfs open for Surface csg set k Returns to D Sand @ 4,02 OP22ww03 Water Producer 3,815'/3,523' Surface surface production in 3,728'ND, Ivishak cemented to Thanks, Kelsey From: Loepp,Victoria T(DOA) [mailto:victoria.Ioepp@alaska.gov] Sent:Thursday, December 08, 2016 7:25 AM To: Hallford, Kelsey<Kelsey.Hallford@conocophillips.com> Subject: [EXTERNAL]RE:3R-102 injector new drill (PTD 216-157)AOR Kelsey, To be approved and permitted as an injector,an AOR is necessary as a part of the 10-401 permit. Please provide this data for review. I understand Guy forwarded his AOR information paper for your reference. 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(aalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.00v From: Hallford, Kelsey[mailto:Kelsey.Hallford@conocophillips.com] Sent:Wednesday, December 07, 2016 4:12 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov>;Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov>; Bearden,J Daniel<J.Daniel.Bearden@conocophillips.com> Subject: RE:3R-102 injector new drill (PTD 216-157) Victoria, 2 •, I have had a couple discussions with regarding his request for AOR and notification for the two ENI Oliktok Point Y g g q wells that are within the%mile radius of our wellbore. However,after discussing these items with our compliance team, I believe both of those requests will be addressed when we submit the Permit to Inject(10-403)as this is a pre-produced injector. While the AOR and notification will accompany the 10-403, I have done the due diligence at this stage to ensure zonal isolation for both OP21ww01 (PTD 210-187)and OP22ww03 (PTD 213-054). Both of these water source wells have cement across the West Sak interval in either their surface or intermediate casing strings. Is this data something you require for your review of the 10-401 for 3R-102 injector(PTD 216-157)? Please let me know if you require further information. Regards, Kelsey Hallford GKA Drilling Engineer ConocoPhillips,Alaska 907-265-1577 work 907-440-0004 cell From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Tuesday, November 22, 2016 3:25 PM To: Hallford, Kelsey<Kelsey.Hallford@conocophillips.com> Cc: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject: [EXTERNAL]RE:3R-102 injector new drill (PTD 216-157) Kelsey, Had the wrong email for you .. here you go. Re attached the AOR tips letter. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). From:Schwartz,Guy L(DOA) Sent:Tuesday, November 22, 2016 3:21 PM To:'Kelsey.hallfod@cop.com'<Kelsey.hallfod@cop.com> Cc: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject: RE:3R-102 injector new drill (PTD 216-157) Kelsey, 3 41 Also per 20 AAC 25.402(C)(3)you must notify any operators or surface owners wit hin'/o mile of the injector are notified and provided a copy of the application for injection(ie PTD). This would obviously be ENI. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at (907-793-1226) or(Guy.schwartz@alaska.gov). From:Schwartz,Guy L(DOA) Sent:Tuesday, November 22,2016 3:08 PM To: Kelsey.hallfod@cop.com Cc: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject:3R-102 injector new drill(PTD 216-157) Kelsey, In looking over the Permit to Drill application I didn't see much information regarding a X mile AOR. The ENI Oliktok Point wells should be included if they are within the X mile area. The 3D plots make It appear that they have wellbores that pass thru the West Sak sands within the area limits. Attached is a tips note I put out last year. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). 4 F • = E • 0. d b Nit IA E E t E E . 0 .0 S ai 3 a -8m 00214 ° c CO t 4. o - c \ Q -0 7 k k � § � ka. A / a § c - & 2 g24, C 2 [ q 7 2 § R _o -o $ 6. R § 3 / 0 NC) c 2 2 t � ,. Q to S u i a / § 2 o ° 2 - / 46 cq 7C K -0 o E q o t E u \ ) 0 - ~ 3In o ° o S ± v) c E � u g Q a e _ R 2 8 2 / £ J = k 15 c k kf .c § in f o ff : 0 � : ■ o t o - Z 0_ 0. 0- & 2 � ' _ W > k W -0 C k © m 2 $ ° 3 L- 0 » / 2 � 2 d c 0 0 ).000 m U + u b 15 o ® 2 \ a - iq- VI % o mq c q t oac r cri ri 0 , C m 3 CL w 2 # 7 a. c R a R CL © 0 m ea §$ z 0 _ N - k k k • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, November 22,2016 3:21 PM To: 'Kelsey.hallfod@cop.com' Cc: Bettis, Patricia K(DOA) Subject RE:3R-102 injector new drill (PTD 216-157) Kelsey, Also per 20 MC 25.402(C)(3)you must notify any operators or surface owners within%mile of the injector are notified and provided a copy of the application for injection(ie PTD). This would obviously be ENI. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226)or(Guv.schwartz@alaska.gov). From:Schwartz,Guy L(DOA) Sent:Tuesday, November 22, 2016 3:08 PM To: Kelsey.hallfod@cop.com Cc: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject:3R-102 injector new drill (PTD 216-157) Kelsey, In looking over the Permit to Drill application I didn't see much information regarding a X mile AOR. The ENI Oliktok Point wells should be included if they are within the'X mile area. The 3D plots make It appear that they have wellbores that pass thru the West Sak sands within the area limits. Attached is a tips note I put out last year. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). 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: K Au,. 3 A - J02 PTD: O(,l4 Development 4ervice Exploratory Stratigraphic Test Non-Conventional FIELD: 4iatia4. , ,l We— POOL: 4f.i VLC1 t t I Saik 01 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 0 o. a) Q ; a, N Y -o N O (n O 0 O 0 . 1 E 6 L C �, a N c co : Q a V, O, L M o' Lu (i) •o, t, a, it0, O, N O ci, Oc 7 C o a O O H, �, s 3 �, u? V CD m o �; O, ; o �� o, C U, _ CO v, o,,- o, 1, o, (I> E' a o 3 , a, cO ,- as 3 o d O, '3, o O To •V c o a oQE 2, _ , 4 d y, 0, L V d O, y, w, N, CL 0 • H o i, y, . H, �, 0 E, aoi 05 �, co a p) 0, 0 a Z M, Q. 0) o, d i, 0 C. w, o p E �: 0. -a o, Q, , b O 2 6 0, E 0 '-, w, ' a. lr , J, , (/) c. Q l0, Crj, • CO D: Q. , N f0, y, co, O. 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CO •O, V O; 0; .0 O' d o' a€)' .,_,co" a) a)'. o; 0 @Z a _ D �' �' 5cnOOaaU5, Q; a oco, U, U', U, U, ¢ _, ¢, �; o, co, m, U, s, N, 2, a, 0, (0, co 0,, IJ.1 a N COO cor () a O CO 0) O) 0 N CO v c1) co r CO 0) O N CO') V (C) CO F- co 0) I E coo O) 0 N N N N N N N N N N CO CO CO CO CO CO CO CO M M O C-) co __ co (O .. ,.- p 0 G O C 0 N N U o '.O-+ 0 N O O N O N O y W ` c - p•E�I J N N N OT 0 EO ^ c m c a Q m U J 1.- a s a s C a > 0 a a Li, U • • Well History File APPENDIX Infoinnation of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplrfy finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically • organize this category of information. Technical Report Title Date Client: ConocoPhillips Alaska, Inc Field: Kuparuk River Unit Rig: Doyon 142 Date: March 19, 2017 Surface Data Logging End of Well Report 3R-102 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Show Reports 6. Mud Record 7. Bit Record 8. Morning Reports 9. Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: ConocoPhillips Alaska Inc. Rig: Doyon 142 Well: 3R-102 Field: Kuparuk River Unit Borough: North Slope Borough State: Alaska Country: United States API Number: 50-029-23572-00-00 Sperry Job Number: AK-XX-0903754613 Job Start Date: 04 March 2017 Spud Date: 28 February 2017 Total Depth: 14950’ MD’ MD, 3386’ TVD North Reference: True Declination: 17.781° Dip Angle: 81.041° Total Field Strength: 57552.205 nT Date Of Magnetic Data: 25 February 2017 Wellhead Coordinates N: North 70° 29’ 50.952” Wellhead Coordinates W: West 149° 50’ 3.816“ Drill Floor Elevation 49.0’ Ground Elevation: 9.9’ Permanent Datum: Mean Sea Level SDL Engineers: Leigh Ann Rasher, Ryan Lenberg Company Geologist: Mike Werner Company Representatives: David Coates, Randy Dolcater, Granville Rizek, Rock Rauchstein, Nick Lehman SSDS Unit Number: 118 DAILY SUMMARY 03/04/2017 SDL arrived on location and received power to unit. SDL crew began rig up operations and installed constant volume extraction system onto the rig flow line. 03/05/2017 SDL crew continued rig up operations and completed rigging up the constant volume extraction system and gas equipment. The constant volume extraction system was function tested and the gas equipment was calibrated. The 9000 THA was calibrated with 10.017%, 20.055% and 98.985% C1 and the 8900 gas chromatograph was calibrated with a low calibration cocktail gas mixture. Rig crew continued retrieving fish and made up intermediate BHA #2. The rig began tripping in hole and pressure test casing to 3000 psi for 30 minutes. Shallow hole test MWD tools and begin to drill out cement and shoe from 2210’ MD to 2298’. Drill 20 feet of new hole from 2298’ MD to 2321’ MD. Perform formation integrity test to 12.8 ppg, run in hole and begin to drill intermediate hole to 2473’ MD while displacing the well to 9.2 ppg LSND mud. Gas: The max gas was 21 units at 2418’ MD and the average gas was 8 units. Fluids: No gains or losses. Geology: Samples have consisted of predominately Sandstone with 40% to 50% Claystone. Sandstone was transparent-translucent-clear-white in color, very hard grains, medium to occasional coarse size grains, sub elongated, sub rounded, moderately sorted, unconsolidated with trace black lithics and rare mica. Claystone was medium grey to dark grey, soft, with common sandstone and siltstone interbedded, sub platy with rare black lithics. 03/06/2017 Continue to drill ahead through intermediate section from 2473’ MD to 5423’ MD. Gas: The max gas was 53 units at 3154’ MD and the average gas was 22 units. Fluids: No gains or losses. Geology: Samples have consisted of predominately Sandstone with interbedded Siltstone and Claystone. Near the top of the Ugnu C formation samples became siltier with 30% to 60% Siltstone from 3500’ MD to 4100’ MD. From 4300’ MD to 4700’ MD 30% to 60% Claystone was observed. 03/07/2017 Perform rig maintenance on drag chain in the pits. Resume drilling at 04:15 hours from 5423’ MD to 7421’ MD. Gas: The max gas was 307 units at 6042’ MD and the average gas was 33 units. Fluids: 20 barrels of LSND lost downhole. Geology: Samples continued to consist of predominately Sandstone with occasional interbedded Siltstone and Claystone through the Ugnu A, Ugnu B and Ugnu C formations. Samples from 5700’ MD and 5900’ MD to 6100’ MD consisted of 90% to 100% Sandstone contained a brown to black oil stain, 20% to 40% dull orange fluorescence, streaming bright to dull yellow streaming cut fluorescence, light amber to brown residue and dull orange residue fluorescence. 03/08/2017 Continue to drill ahead to intermediate TD of 8602’ MD. Rotate and circulate, flow check well (static) and begin to back ream out of hole to 6745’ MD at midnight. Gas: The max gas was 521 units at 7730’ MD and the average gas was 187 units. The max gas observed while back reaming out of the hole was 124 units. Fluids: No gains or losses. Geology: Samples continued to consist of predominately Sandstone with occasional interbedded Siltstone and Claystone through the N Sands to the intermediate landing point in the upper West Sak D formation. Oil shows were seen throughout this section 7421’ MD – 8602’ MD. In the upper D Sands 7500’-8000’ MD, show quality was moderate and decreased to poor quality in lower clay rich portion of this formation. Upon entering the West Sak D, the good quality oil shows with abundant light brown oil staining and 50% fluorescence seen in the 8600’ MD sample. 03/09/2017 Continued back reaming out of hole from 6752' MD until shoe at 2286' MD, circulate bottoms up, pull out of hole on elevators to surface, lay down BHA, rig up and run 7 5/8" casing at a depth of 496' MD at midnight. Gas: The max gas of 68 units was seen while back reaming out of hole and the average gas was 23 units. Fluids: No gains or losses. 03/10/2017 Continued running intermediate casing, landed at 15:00, rig up cementers, pump cement job, successfully tested casing to3500 psi for 30 minutes and are currently rigging down the casing running tool at midnight. Gas: The max gas of 97 units occurred while circulating bottoms up after setting casing and the average gas was 14 units. Fluids: A total of 24 barrels were lost down hole; 18 barrels were lost while running casing and 6 barrels were lost while cementing. 03/11/2017 Set and test packoff, lay down 5" drill pipe, leak off test annulus to 13.1 EMW, continue lay down 5" drill pipe, pump isotherm in annulus, and pick up heavy weight 4" drill pipe. Perform preventative maintenance on constant volume extractor pump, 4 point calibration on total hydrocarbon gas detector, calibrate gas chromatograph, and prepare for upcoming production section. Gas: No gas data due to cemented hole and no flow out. Fluids: No gains or losses. 03/12/2017 Make up 84 stands of 4" drill pipe, rig up to test BOPE, successfully test BOPE, and make up production BHA at report time. Function test and calibrate constant volume extractor pump and prepare sample supplies for upcoming production section. Gas: No gas data due to cemented hole and no flow out. Fluids: No gains or losses. 03/13/2017 Continue picking up BHA, run in hole, log while running in, drill out cement, plug, float collar, and 20' of new formation. Circulate and condition mud for formation integrity test. Gas: Max gas of 244 units when circulating up new formation at 8618' MD and average gas of 9 units. Fluids: No gains or losses. Geology: Only cement seen in bottoms up sample. 03/14/2017 Continue to circulate and condition mud for formation integrity test. Perform formation integrity test to 14.2 ppg equivalent mud weight and displace well to 9.2 ppg Flo-Pro mud while beginning to drill ahead. Drill from 8622’ MD to 10125’ MD at midnight. Gas: Max gas of 2017 units at 9440' MD and average gas of 618 units. Fluids: 40 barrels of Flo-Pro mud lost to formation. Geology: Lithology has been fine to very fine grain of mostly unconsolidated quartz Sandstone with 0-30% Siltstone present. The Sandstone has been heavily oil stained with bright yellow fluorescence and with very fast streaming yellow cut fluorescence. 03/15/2017 Continue drill ahead in production section from 10,125' MD to 11,926' MD. Gas: The max formation gas of 1412 units at 10,742' MD with an average of 591 units. Fluids: 195 barrels of Flo-Pro mud lost to formation. Geology: Lithology has been fine to very fine grain mostly unconsolidated quartz Sandstone with 0-60% Siltstone present. Samples with increased Siltstone occurred at 10,100’ MD to 10,400' MD and at 11,500' MD to 11,700' MD. The Sandstone has been moderately oil stained with bright yellow fluorescence and with fast streaming yellow cut fluorescence. 03/16/2017 Continue to drill ahead in production section from 11,926' MD to 13,286’ MD. Gas: Max formation gas of 742 units was seen at 11,997' MD with an average of 268 units. Fluids: 135 barrels of Flo-Pro mud lost to formation. Geology: Lithology has been very fine to coarse grain unconsolidated to consolidated quartz Sandstone with 0% to 50% Siltstone present. Samples with increased Siltstone occurred at 12,000' MD to 12,300' MD and at 12,700' MD to 13,200' MD. Oil shows have generally been trace to weak today; with trace oil staining present and 30% to 70% dull yellow fluorescence with slow streaming white fluorescence cut. 03/17/2017 Continue to drill ahead in production section from 13,286' MD to production section TD of 14,950’ MD. Circulate bottoms up, flow check the well and observe well breathing. Begin to back ream out of the hole to 14,331’ MD. Gas: Max formation gas of 647 units was seen at 14.535' MD with an average of 139 units. Fluids: 135 barrels of Flo-Pro mud lost to formation. Geology: Lithology has been very fine to fine grain unconsolidated quartz Sandstone with 0% to 60% Siltstone present. Samples with increased Siltstone occurred from 13,500’ MD to 13,600’ MD and 13,900’ MD to 14300’ MD. Oil shows have generally been trace to weak but improved to moderate grade at 14,700’ MD to TD. Moderate oil shows had abundant oil staining present and 90% bright yellow fluorescence with a very fast streaming white to yellow fluorescence cut. 03/18/2017 Continue to back ream out of the hole. SDL crew released and rigged down. 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 0 5 10 15 20Measured Depth Rig Days Prognosed Actual WELL NAME: 3R-102 OPERATOR: ConocoPhillips Alaska Inc. MUD CO: MI Swaco RIG: Doyon 142 SPERRY JOB: AK-XX-903754613 Days vs. Depth 04 March 2017 Sperry SDL Arrived on Location LOCATION: Kuparuk River Unit AREA: North Slope Borough STATE: Alaska SPUD: 28-Feb-2017 TD: 17-Mar-2017 Commenced 9-7/8" Intermediate Hole Section On Bot: 22:09 05 Mar 2017 TD Intermediate Hole Section 8602' MD, 3564' TVD Off Bot: 16:05 08 Mar 2017 Landed 7-5/8" Casing 8595' MD, 3562' TVD 10 Mar 2017 Commenced 6-3/4" Production Hole Section On Bot: 21:55 13 Mar 2017 TD Production Hole Section 14950' MD, 3386' TVD Off Bot: 20:09 17 Mar 2017 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: A vital CVE fitting was left on rig from a previous job and was luckily found again. We will confirm all parts are together when rig down and will bring more spare parts on rig ups. Recommendations: Document rig specific Insite settings for future jobs. Confirm all parts of CVE are together when we rig down and bring more spare parts on rig ups. Innovations and/or cost savings: N/A Doyon 142 Intermediate Ryan Lenberg 9-Mar-2017 What went as, or better than, planned: Rig up went well, considering having it shortened a day due to flight cancellations, no major issues encountered. Depth tracked very well. 3R-102 Kuparuk River Unit ConocoPhillips Alaska Inc.North Slope Borough AK-XX-0903754613 Alaska Surface Data Logging After Action Review WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Doyon 142 Production Recommendations: In the future put a tag on air supply to gas equipment so the rig air won't get shut off during operations. Innovations and/or cost savings: N/A Leigh Ann Rasher 18-Mar-2017 What went as, or better than, planned: No major issues were encountered. Mudloggers kept up with wet samples and isotubes throughout this section. Difficulties experienced: One wet sample interval was missed due to the lag jumping ahead during a lag adjustment. Also the 8900 GC was changed out causing a 50' gap in chromatograph data. Another 30' gap in gas data was encountered at 9370' MD due to a member of the rig crew turning off the rig air supply to the mudlogging equipment without permission. There was a high level of background methane, either due to not degassing the mud or methane leaking into the wellbore from higher in the well. The elevated background methane caused the Pixler ratios to be artifially high giving the appearance of gas when you have oil. AK-XX-0903754613 Alaska 3R-102 Kuparuk River Unit ConocoPhillips Alaska Inc.North Slope Borough Surface Data Logging After Action Review Surface Data Logging Well Name:Depth (MD)#to ft Location:(TVD)#to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: trace amounts Depth ft C1 C1 C1 C1 .C2 C3 C4 C5 Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis X Gas Oil Water Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis X Gas Oil Water Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 .C2 C3 C4 C5 Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis X Gas Oil Water Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis X Gas Oil Water Non-Producible Hydrocarbons Show Report Report # 1 3R-102 7540 8602 Kuparuk River Unit 3426 3564 ConocoPhillips Alaska, Inc. Leigh Ann Rasher N Sand & West Sak D Mike Werner 9-Mar-2017 Interpretation: The samples throughout these intervals consisted of mostly Quartz Sandstone with interbedded Siltstone and Claystone. Generally the Sandstone was very fine to fine grained, sub elongated to sub spherical, sub angular to sub rounded, well sorted, unconsolidated with trace amounts of mica. Elevated methane background gas (either from not degassing the mud or methane leaking into the wellbore from above wellbore) causes the Pixler ratios to read artificially high giving the appearance of gas when there is oil. Cuttings Analysis: Odor slight odor Fluorescence Cut Fluorescence Residual Cut lt amber-amber Color lt brown-brown Intensity dull Color orange-yellow Residual Flourescence thin-medium Amount trace-abundant Distribution patchy Intensity dull-bright Color Stain Amount 40% to 50%Type streaming Amount orange Oil Show Rating weak-moderate Free Oil in Mud faint-dull Color lt brown-brown Color Cut Color orange Intensity 18336 4018 14318 38 1 Hydrocarbon Ratios 7539 Gas Units 376 Mud Chlorides (mg/L) =1400 613 94 519 48 436 63 373 40 411 55 356 28 2 366 66 300 29722 4018 25704 52 554 63 491 51 7724 Gas Units 521 Mud Chlorides (mg/L) =1400 Hydrocarbon Ratios 563 55 508 35 823 94 729 65 1400 22264 9010 13254 55 464 66 398 3 344 104 240 46 429 138 291 29 7873 Gas Units 366 Mud Chlorides (mg/L) = 4 8561 Gas Units 472 Mud Chlorides (mg/L) = 741 289 452 30 491 52 439 1400 34865 22101 12764 68 356 168 188 50 658 409 249 507 250 257 31 940 534 406 51 Oil Gas NPH NPH NPH Oil Gas NPH Oil Gas NPH NPH NPH Oil Gas NPH Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH Well Name:Depth (MD)#to ft Location:(TVD)#to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Depth ft C1 C1 C1 C1 .C2 C3 C4 C5 Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis X Gas Oil Water Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis X Gas Oil Water Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 .C2 C3 C4 C5 Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis X Gas Oil Water Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas X Oil Water Non-Producible Hydrocarbons 2735 1282 1453 2586 1186 1400 12 3911 1759 2152 18 19000 66099 39345 26754 38 1320 617 703 19 4 10736 Gas Units 1348 Mud Chlorides (mg/L) = 2844 718 2126 34 1899 231 1668 1048 244 804 39 1907 470 1437 27 10024 Gas Units 1353 Mud Chlorides (mg/L) =19000 75296 18718 56578 70 2487 1364 1123 3 Hydrocarbon Ratios 2549 993 1556 15 3808 1726 2082 27 73029 42420 30609 36 1341 484 857 20 9743 Gas Units 1713 Mud Chlorides (mg/L) =19000 2 2810 1364 1446 4400 1726 2674 35 1483 484 999 25 2977 993 1984 19 92593 42420 50173 50 1 Hydrocarbon Ratios 9439 Gas Units 2017 Mud Chlorides (mg/L) =19000 yellow Oil Show Rating moderate Free Oil in Mud bright Color Color Cut Color yellow Intensity yes amber Color lt brown-brown Intensity bright Color yellow Residual Flourescence moderate Amount abundant Distribution even Intensity bright Color Stain Amount 100%Type streaming Amount Cuttings Analysis: Odor moderate Fluorescence Cut Fluorescence Residual Cut Mike Werner 16-Mar-2017 Interpretation: Samples have consisted of predominately quartz Sandstone. The Sandstone was translucent-transparent-clear-light grey, very fine-fine grained, sub spherical, sub rounded-sub angular, well sorted, unconsolidated, with 10%-20% Siltstone. Show Report Report # 2 3R-102 9400 10800 Kuparuk River Unit 3583 3562 ConocoPhillips Alaska, Inc. Leigh Ann Rasher West Sak D Oil Gas NPH NPH NPH Oil Gas NPH Oil Gas NPH NPH NPH Oil Gas NPH Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH Well Name:Depth (MD)#to ft Location:(TVD)#to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Depth ft C1 C1 C1 C1 .C2 C3 C4 C5 Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis X Gas Oil Water Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis X Gas Oil Water Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 .C2 C3 C4 C5 Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas X Oil Water Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas X Oil Water Non-Producible Hydrocarbons 2735 861 1874 2586 451 2135 3 3911 917 2994 6 1800 22666 12318 10348 9 1320 211 1109 5 4 12278 Gas Units 588 Mud Chlorides (mg/L) = 1968 966 1002 13 1520 371 1149 572 216 356 23 1126 460 666 15 12006 Gas Units 626 Mud Chlorides (mg/L) =1800 27221 12122 15099 42 2437 2175 262 3 Hydrocarbon Ratios 1926 1653 273 20 3249 2857 392 30 38476 30528 7948 44 969 788 181 29 11492 Gas Units 1039 Mud Chlorides (mg/L) =1800 2 2514 2213 301 3455 3003 452 36 1132 984 148 35 2191 1887 304 24 45157 34409 10748 73 1 Hydrocarbon Ratios 11125 Gas Units 1186 Mud Chlorides (mg/L) =1800 yellow Oil Show Rating moderate Free Oil in Mud bright Color Color Cut Color yellow Intensity yes amber Color lt brown-brown Intensity bright Color yellow Residual Flourescence moderate Amount abundant Distribution even Intensity bright Color Stain Amount 80%-100%Type streaming Amount Cuttings Analysis: Odor slight Fluorescence Cut Fluorescence Residual Cut Mike Werner 16-Mar-2017 Interpretation: Samples have consisted of predominately quartz Sandstone. The Sandstone was translucent-transparent-clear-light grey, very fine-fine grained, sub spherical, sub rounded-sub angular, well sorted, unconsolidated, with 10%-20% Siltstone. Show Report Report # 3 3R-102 11100 12300 Kuparuk River Unit 3563 3557 ConocoPhillips Alaska, Inc. Leigh Ann Rasher West Sak D Oil Gas NPH NPH NPH Oil Gas NPH Oil Gas NPH NPH NPH Oil Gas NPH Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH Well Name:Depth (MD)#to ft Location:(TVD)#to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Depth ft C1 C1 C1 C1 .C2 C3 C4 C5 Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water X Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis X Gas Oil Water Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 .C2 C3 C4 C5 Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water X Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis X Gas Oil Water Non-Producible Hydrocarbons 191 74 117 103 45 58 262 237 174 63 141 1900 16846 363 16483 201 148 66 82 284 4 14740 Gas Units 137 Mud Chlorides (mg/L) = 469 174 295 23 250 29 221 50 42 8 276 39 21 18 17 14189 Gas Units 159 Mud Chlorides (mg/L) =1900 5557 584 4973 622 272 74 198 3 Hydrocarbon Ratios 91 11 80 33 513 174 339 57 15202 3931 11271 116 121 24 97 141 13760 Gas Units 171 Mud Chlorides (mg/L) =1900 2 134 127 7 95 91 4 518 59 23 36 726 23 18 5 907 3796 168 3628 101 1 Hydrocarbon Ratios 13530 Gas Units 179 Mud Chlorides (mg/L) =1900 orange-yellow Oil Show Rating moderate Free Oil in Mud bright Color white-yellow Color Cut Color yellow Intensity yes amber-brown Color lt brown Intensity bright Color white-yellow Residual Flourescence thin/faint Amount abundant Distribution even Intensity fast Color Stain Amount 90%Type streaming Amount Cuttings Analysis: Odor moderate Fluorescence Cut Fluorescence Residual Cut Mike Werner 17-Mar-2017 Interpretation: Samples have consisted of predominately quartz Sandstone. The Sandstone was translucent-transparent-clear-light grey, very fine-fine grained, sub spherical, rounded, very well sorted, unconsolidated, with 0%-60% Siltstone. Trace oil shows were seen 13,500'- 14,300' MD. Weak oil shows were seen from 14,400'-14,700' MD and improved to a moderate oil show grade at 14,800' to TD at 14,950' MD. Show Report Report # 4 3R-102 13530 14740 Kuparuk River Unit 3469 3397 ConocoPhillips Alaska, Inc. Leigh Ann Rasher West Sak D Oil Gas NPH NPH NPH Oil Gas NPH Oil Gas NPH NPH NPH Oil Gas NPH Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH 3R-102 ConocoPhillips Alaska Inc. MI Swaco Doyon 142 AK-XX-0903754613 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 5-Mar 2321 9.50 50 21 6 4/39/54 11.8 48/27/20/12/4/3 4/-9.5 /90.5 20.00 3.00 11.5 20.0 1.1/2 1200 120 Drill 9.875" Hole 6-Mar 5045 9.20 49 10 27 12/18/21 5.1 47/37/32/29/13/12 1/4.8 4/91.2 0.25 0.60 9.8 7.5 .4/1.4 900 40 Drill 9.875" Hole 7-Mar 7168 9.20 48 12 25 13/22/29 5.3 49/37/32/26/13/12 1/5.3 4/90 0.25 0.20 9.5 9.5 .2/1.2 1000 40 Drill 9.875" Hole 8-Mar 8602 9.35 55 13 30 17/38/50 4.9 56/43/37/30/16/14 1/7.0 4.2/88.8 0.25 0.40 9.3 18.3 0.2/1.2 1400 40 BROOH 9-Mar 8602 9.25 50 14 28 15/27/38 5.5 56/42/36/28/14/13 1/7.0 4/89 0.15 0.40 9.7 15.3 .2/1.3 1100 40 Run 7.625" Casing 10-Mar 8602 9.30 48 14 20 11/17/20 4.7 48/34/29/22/11/10 1/7.0 4/89 0.15 0.10 8.5 18.0 0.1/1 1200 40 L/D CRT 11-Mar 8602 9.30 59 12 21 10/14/17 4.9 45/33/28/23/10/9 1/7.0 4/89 0.20 -8.1 18.3 0/.12 1200 40 PU 4" HWDP 12-Mar 8602 9.30 46 11 20 9/13/16 5.0 42/31/25/19/9/8 1/7.0 0.0 0.15 -8.1 18.8 0/1.2 1200 40 MU BHA 13-Mar 8602 9.30 60 15 26 16/45/63 7.9 56/41/35/17/15/14 1/7.8 4/88.2 0.15 0.40 9.4 18.0 .3/2.3 1500 160 Circulate and Condition 14-Mar 9947 9.20 50 9 22 8/11/12 3.8 40/31/27/21/10/8 .5/1 6.5 1.5/92 -1.50 10.6 1.8 .9/2.3 19000 20 Drill 6 3/4" Prod Hole 15-Mar 117321 9.20 54 11 24 15/15/17 4.0 46/35/31/25/12/10 .5/1 6.5 2/91.5 0.10 0.80 10.1 3.3 .7/3.9 18000 30 Drill 6 3/4" Prod Hole 16-Mar 13058 9.20 54 9 28 11/15/17 4.3 46/37/32/25/12/10 .5/1 6.5 2/91.5 0.10 0.50 9.5 4.8 .3/5 19000 30 Drill 6 3/4" Prod Hole 17-Mar 14950 9.25 51 10 27 11/13/14 5.2 47/37/33/26/12/11 .5/1 6.5 2/91.5 0.20 0.90 9.8 6.5 .5/3.8 18000 40 BROOH Casing Record WELL NAME:LOCATION:Kuparuk River Unit OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG:SPUD:28-Feb-2017 SPERRY JOB:TD:17-Mar-2017 Remarks 20" Conductor @ 116' MD, 116'TVD 10.75" Casing @ 2291' MD, 2170'TVD 7.625" Casing @ 8595' MD, 3562'TVD Water and Oil Based Mud Record BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 4 100 4 MM65 PDC 9.88 2301 8602 6301 42.86 1.035 162.0 12 170 2611 780 1-4-BT-S-X-I-CT-TD Intermediate Section TD 5 200 5 X516 PDC 6.75 8602 14950 6348 -0.464 ------Production Section TD Alaska RIG:Doyon 142 SPUD:28-Feb-2017 WELL NAME:3R-102 LOCATION:Kuparuk River Unit OPERATOR:ConocoPhillips Alaska Inc.AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-0903754613 TD:17-Mar-2017 MI Swaco STATE:Bit Record . . * 24 hr Recap: the fly. out 20'. Perform FIT to 12.8 ppg equivalent. Began drilling ahead at 2321' in intermediate section at 22:09 while displacing mud on the fly. 8 No losses or gains Losses/Gains: Calibrated and tested gas system. Began logging 100' samples at 2400' MD. Mudlogging Activity: Arrived on location Saturday, March 4th and rigged up CVE gas system and logging equipment. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 171 0 114721240 11 (max)(current) 11 Cly 12814 - Set AtSize 45.5 L-80 Grade 10.75'' (907) 670-6042Unit Phone: 5 Ryan Lenberg Maximum Report By:Logging Engineers:Ryan Lenberg\Leigh Ann Rasher - 1845 612 143 Units* Casing Summary Lithology (%) 0 MBT 2473' pH 1.035 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 20.061 C-5n 2418' 99.4 C-2 21 in Depth Time: 2298' 2473' 175' Max @ ft Current 2330'82.1 Date: Avg to2298' Yesterday's Depth: Current Depth: 24 Hour Progress: 99.7 Flow In (gpm) Flow In (spm) - - Gas Summary 0 0 (current) D. Coates, R. Dolcator ShClyst - - TuffGvlCoal cP 21 - Footage - - Ss (ppb Eq) C-1 C-5i AK-AM-0903680227 - - Drilling Interm. PV - 24 hr Max Weight 3 Hours C-3 - CementChtSilt C-4i C-4n YP (lb/100ft2) 11.50 100 - Spud 11.82321'6 Depth in / out Mud Type Lst 60% - Type Average -8Background (max)Trip 9.9210.00 Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Resisitivity, PWD API FL Chromatograph (ppm) -2321' - WOB Surface 100% Gas In Air=10,000 Units-Connection 40% 0 2291' Condition - Bit # 2 9.5 9.875 9.50 PDC 9.50 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.29 Doyon 142 Report For: Morning Report Report # 1 Customer: Well: Area: Location: Rig: 3R-102 ConocoPhillips Alaska Inc. North Slope Borough Kuparuk River Unit - ROP ROP (ft/hr) 3.55 @ Mud Data Depth 5-Mar-2017 23:59:59 PM Current Pump & Flow Data: 832 Max 0 Chlorides ml/l 1200.00 Rig Activity: Completed fishing operation, TOH, pick up intermediate BHA, drill out floats, cement shoe, and drill Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Rig Activity: Density (ppg) out (sec/qt) Viscosity Cor Solids %ml/l 900.00 0 Chlorides 6-Mar-2017 23:59:59 PM Current Pump & Flow Data: 1851 Max - ROP ROP (ft/hr) 3.55 @ Mud Data Depth Morning Report Report # 2 Customer: Well: Area: Location: Rig: 3R-102 ConocoPhillips Alaska Inc. North Slope Borough Kuparuk River Unit Total Charges: MWD Summary 96% Rig Activity: 10.92 Doyon 142 Report For: 2291' Condition - Bit # 2 4.8 9.875 9.20 PDC 9.20 100% Gas In Air=10,000 Units-Connection - 0 Tools Gamma, Resisitivity, PWD API FL Chromatograph (ppm) -2321' - WOB Surface 9.9610.35 Avg Min Comments RPM ECD (ppg) ml/30min 14Background (max)Trip Average - Mud Type Lst 80% - Type LSND 5.15045'27 Depth in / outSize YP (lb/100ft2) 9.80 000 - C-3 - CementChtSilt C-4i C-4n Ss (ppb Eq) C-1 C-5i AK-AM-0903680227 - - Drilling Interm. PV - Footage - Hours - TuffGvlCoal cP 10 - Weight Yesterday's Depth: Current Depth: 24 Hour Progress: 269.0 Flow In (gpm) Flow In (spm) D. Coates, R. Dolcator 24 hr Max Job No.: Daily Charges: Date: Avg to2298' - - Gas Summary 2473' 5423' 2950' 0 in Depth Time: Max @ ft Current 3458'164.0 C-2 53 190.0 (current) Bit Type Depth 7.549 C-5n 3154'0 ShClyst - 1.035 0 Siltst SPP (psi) Gallons/stroke TFA 777 182 Units* Casing Summary Lithology (%) 0 MBT 5423' pH 20% 1200 - 1 (907) 670-6042Unit Phone: 0 Ryan Lenberg Maximum Report By:Logging Engineers:Ryan Lenberg\Leigh Ann Rasher Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) 9 Cly 2394 - Bottoms Up Time 377.05 -3705469.53 92.48 20 Continued collecting and logging 100' samples and monitoring pits. Mudlogging Activity: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Continue drilling ahead from 2473' MD to 5423' MD at midnight with no issue. 22 There were 0 bbls of LSND mud lost or gained. Losses/Gains: . . * 24 hr Recap:Rig Activity: Density (ppg) out (sec/qt) Viscosity Cor Solids %ml/l 1000.00 Condition - Bit # 2 Chlorides - Depth 2291' 7-Mar-2017 23:59:59 PM Current Pump & Flow Data: 2210 Max ROP ROP (ft/hr) 3.55 @ Mud Data API FL 10.4210.65 Morning Report Report # 3 Customer: Well: Area: Location: Rig: 3R-102 ConocoPhillips Alaska Inc. North Slope Borough Kuparuk River Unit Total Charges: MWD Summary 96% Rig Activity: 11.08 Doyon 142 Report For: Tools Gamma, Resisitivity, PWD 2 6.0 9.875 9.20 PDC 9.20 Bit Type 100% Gas In Air=10,000 Units-Connection 10% 29 Avg Min Comments RPM ECD (ppg) ml/30min - 19Background (max)Trip Average - Mud Type Lst 70% - Type LSND 5.37168'25 Depth in / outSize 112 Chromatograph (ppm) Surface C-4i C-4n YP (lb/100ft2) 9.50 - WOBFootage Ss (ppb Eq) C-1 C-5i AK-AM-0903680227 - - Drilling Interm. PV - Hours - TuffGvlCoal - Cement 2321' -- Weight - Yesterday's Depth: Current Depth: 24 Hour Progress: 223.0 Flow In (gpm) Flow In (spm) D. Coates, R. Dolcator 24 hr Max Job No.: Daily Charges: Date: Avg to2298' - - Gas Summary 5423' 7421' 1998' 67 Bottoms Up Time in Depth Time: Max @ ft Current 6513'174.0 C-2 307 166.0 (current) C-5n 6042'38 ShClyst - C-3 Cht Silt SPP (psi) Gallons/stroke TFA 777 Depth 9.548 MBT 7421' pH 53 Siltst 1.035 cP 12 - 9 516.32 182 Units* Casing Summary Lithology (%) 2 (907) 670-6042Unit Phone: 32 Ryan Lenberg Maximum Report By:Logging Engineers:Ryan Lenberg\Leigh Ann Rasher Set AtSize 45.5 L-80 Grade 10.75'' 1036 Cly 34939 - 20% saw a peak of 108 units of gas. The max formation gas of 307 units occurred at 6042' MD. Continued collecting and logging 100' samples and monitoring pits. After circulating bottoms up from drill break from 00:00-04:15 Mudlogging Activity: Volumes (max)(current) 2756 issue to 7421' MD at report time. The drag chain broke in the pits just after midnight and by 4:15 resumed drilling ahead. Continued drilling ahead the rest of the day without 33 -5074643.9 127.6 28 There were 20 bbls of LSND mud lost downhole. Losses/Gains: Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes No LSND mud was gained or lost downhole over the last 24 hours. Losses/Gains: occurred at 17:45. (static) and begin back reaming out of hole by 17:45 and at a bit depth of 6745' MD at report time. Continued drilling ahead until reached intermediate TD 8,602' MD at 16:00 this afternoon. Rotate and circulate, flow check well 187 -4614469.54 115.8 25 encountered in the West Sak D formation and an average gas of 187 units while drilling. Max gas while BROOH of 124 units Continued collecting and logging 100' samples and monitoring pits while BROOH. Max formation gas of 471 units was Mudlogging Activity: Volumes (max)(current) 13970 571 Cly 43134 - - Hole Capacity (bbls) Drillstring Capacity (bbls) Set AtSize 45.5 L-80 Grade 10.75'' (907) 670-6042Unit Phone: 238 Ryan Lenberg Maximum Report By:Logging Engineers:Ryan Lenberg\Leigh Ann Rasher - 169 469.54 181 Units* Casing Summary Lithology (%) 195 MBT 8602' pH 472 Siltst 1.035 cP 13 SPP (psi) Gallons/stroke TFA 774 Depth 18.355 C-5n 7730'571 ShClyst - C-3 Cht Silt - C-2 521 166.0 (current) in Depth Time: Max @ ft Current 8168' 7421' 8602' 1181' 423 Bottoms Up Time Date: Avg to2298' - - Gas Summary Yesterday's Depth: Current Depth: 24 Hour Progress: 200.6 Flow In (gpm) Flow In (spm) G. Rizek, R. Rauchenstein 24 hr Max Job No.: Daily Charges: 6281' Weight - - TuffGvlCoal - CementSs (ppb Eq) C-1 C-5i AK-AM-0903680227 - - Back Reaming OOH PV - C-4i C-4n YP (lb/100ft2) 9.30 - WOBFootage 79212208 Chromatograph (ppm) Surface LSND 4.98602'30 Depth in / outSize Mud Type Lst 100% - Type Average 12460Background (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min - 100% Gas In Air=10,000 Units-Connection - 571 2 7.0 9.875 9.40 PDC 9.35 Bit Type Hours 2321' 8602' Total Charges: MWD Summary 96% Rig Activity: 11.33 Doyon 142 Report For: Tools Gamma, Resisitivity, PWD Morning Report Report # 4 Customer: Well: Area: Location: Rig: 3R-102 ConocoPhillips Alaska Inc. North Slope Borough Kuparuk River Unit ROP ROP (ft/hr) 4.27 @ Mud Data API FL 10.4510.86 8-Mar-2017 23:59:59 PM Current Pump & Flow Data: 2250 Max 218 Chlorides - Depth 2291' ml/l 1400.00 Condition - Bit # Rig Activity: Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Rig Activity: Density (ppg) out (sec/qt) Viscosity Cor Solids %ml/l 1100.00 Condition - Bit # 12 Chlorides - Depth 2291' 9-Mar-2017 23:59:59 PM Current Pump & Flow Data: - Max ROP ROP (ft/hr) 4.27 @ Mud Data API FL -- Morning Report Report # 5 Customer: Well: Area: Location: Rig: 3R-102 ConocoPhillips Alaska Inc. North Slope Borough Kuparuk River Unit Total Charges: MWD Summary 96% Rig Activity: - Doyon 142 Report For: Tools Gamma, Resisitivity, PWD 2 7.0 9.875 9.30 PDC 9.30 Bit Type Hours 2321' 8602' 100% Gas In Air=10,000 Units-Connection - 64 Avg Min Comments RPM ECD (ppg) ml/30min - 6Background (max)Trip Average 68 Mud Type Lst - - Type LSND 5.58602'28 Depth in / outSize 332657 Chromatograph (ppm) Surface C-4i C-4n YP (lb/100ft2) 9.70 - WOBFootage Ss (ppb Eq) C-1 C-5i AK-AM-0903680227 - - RIH 7.625" csg PV - - TuffGvlCoal - Cement Weight - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) G. Rizek, R. Rauchenstein 24 hr Max Job No.: Daily Charges: Date: Avg to2298' - - Gas Summary 8602' 8602' 0' 158 Bottoms Up Time in Time Time: Max @ ft Current -- C-2 68 - (current) C-5n 02:30 140 ShClyst - C-3 Cht Silt SPP (psi) Gallons/stroke TFA - Depth 15.350 8602' pH 92 Siltst 1.035 cP 14 6281' 8 799.84 - Units* Casing Summary Lithology (%) 0 MBT (907) 670-6042Unit Phone: 86 Ryan Lenberg Maximum Report By:Logging Engineers:Ryan Lenberg\Leigh Ann Rasher Set AtSize 45.5 L-80 Grade 10.75'' Cly 5037 - - Hole Capacity (bbls) Drillstring Capacity (bbls) - and an after action review of intermediate section. Currently monitoring fluid during casing run. The max gas was 68 units and the Continued monitoring pits during back ream and trip to surface. Quality check mud logs, prepare show reports, create gas ratio log, Mudlogging Activity: Volumes (max)(current) 468 36 surface, lay down BHA, rig up and run 7 5/8" casing. Intermediate casing at a depth of 496' MD at midnight. Continued back reaming out of hole from 6752' MD until shoe at 2286' MD, circulate bottoms up, pull out of hole on elevators to 23 -822.62 22.78 Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes No LSND mud was gained or lost downhole over the last 24 hours. Losses/Gains: average of 23 units over the last 24 hours. . . * 24 hr Recap: Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes A total of 24 barrels were lost downhole; 18 barrels were lost while running casing and 6 barrels were lost while cementing. Losses/Gains: 3500 psi for 30 minutes and are currently rigging down the casing running tool at midnight. Continued running intermediate casing, landed at 15:00, rig up cementers, pump cement job, successfully tested casing to 15 -394.52 up at 16:30 and had an average gas of 15 units over the last 24 hours. Continued monitoring fluids while running casing and cement job. The max gas of 97 units occurred while circulating bottoms Mudlogging Activity: Volumes (max)(current) 40 24 Cly 467 - - Hole Capacity (bbls) Drillstring Capacity (bbls) - Set AtSize 45.5 L-80 Grade 10.75'' 7.625" (907) 670-6042Unit Phone: 74 Ryan Lenberg Maximum Report By:Logging Engineers:Ryan Lenberg\Leigh Ann Rasher 3 - Units* Casing Summary Lithology (%) 25 L-80 MBT 8602' pH 224 Siltst 1.035 cP 14 6281' SPP (psi) Gallons/stroke TFA - Depth 18.048 C-5n 16:24 38 ShClyst - C-3 Cht Silt - C-2 97 - (current) in Time Time: Max @ ft Current - 8602' 8602' 0' 142 Bottoms Up Time Date: Avg to2298' - - Gas Summary Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) G. Rizek, R. Rauchenstein 24 hr Max Job No.: Daily Charges: 29.7 Weight 42.86 Intermediate - TuffGvlCoal - CementSs (ppb Eq) C-1 C-5i AK-AM-0903680227 - - R/D CRT PV - C-4i C-4n YP (lb/100ft2) 8.50 50-170 WOBFootage 16330 Chromatograph (ppm) Surface LSND 4.78602'20 Depth in / outSize Mud Type Lst - - Type 8573' Average --Background (max)Trip Avg Min Comments - RPM ECD (ppg) ml/30min .6-12 100% Gas In Air=10,000 Units-Connection - 59 2 7.0 9.875 9.30 PDC 9.30 Bit Type Hours 2321' 8602' Total Charges: MWD Summary 96% Rig Activity: - Doyon 142 Report For: Tools Gamma, Resisitivity, PWD Morning Report Report # 6 Customer: Well: Area: Location: Rig: 3R-102 ConocoPhillips Alaska Inc. North Slope Borough Kuparuk River Unit ROP ROP (ft/hr) 4.27 @ Mud Data API FL -- 10-Mar-2017 23:59:59 PM Current Pump & Flow Data: - Max 0 Chlorides - Depth 2291' ml/l 1200.00 Condition 1-4-BT-S-X-IN-CT-TD Bit # Rig Activity: Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes No significant amount of fluids lost over the last 24 hours. Losses/Gains: annulus, and begin picking up heavy weight 4" drill pipe at report time. Set and test packoff, lay down 5" drill pipe, leak off test annulus to 13.1 EMW, continue lay down 5" drill pipe, pump isotherm in -394.52 calibrate gas chromatograph, both loggers attended SLT meeting, and prepare for upcoming production section. Perform preventative maintenance on constant volume extractor pump, 4 point calibration on total hydrocarbon gas detector, Mudlogging Activity: Volumes (max)(current) Cly - - Hole Capacity (bbls) Drillstring Capacity (bbls) - Set AtSize 45.5 L-80 Grade 10.75'' 7.625" (907) 670-6042Unit Phone:Ryan Lenberg Maximum Report By:Logging Engineers:Ryan Lenberg\Leigh Ann Rasher - Units* Casing Summary Lithology (%) L-80 MBT 8602' pH Siltst 1.035 cP 12 6281' SPP (psi) Gallons/stroke TFA - Depth 18.347 C-5n ShClyst - C-3 Cht Silt - C-2 - (current) in Time Time: Max @ ft Current - 8602' 8602' 0' Bottoms Up Time Date: Avg to2298' - - Gas Summary Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) G. Rizek, R. Rauchenstein 24 hr Max Job No.: Daily Charges: 29.7 Weight 42.86 Intermediate - TuffGvlCoal - CementSs (ppb Eq) C-1 C-5i AK-AM-0903680227 - - P/U HWDP PV - C-4i C-4n YP (lb/100ft2) 8.10 50-170 WOBFootage Chromatograph (ppm) Surface LSND 4.98602'21 Depth in / outSize Mud Type Lst - - Type 8573' Average -Background (max)Trip Avg Min Comments - RPM ECD (ppg) ml/30min .6-12 100% Gas In Air=10,000 Units-Connection - 2 7.0 9.875 9.30 PDC 9.30 Bit Type Hours 2321' 8602' Total Charges: MWD Summary 96% Rig Activity: - Doyon 142 Report For: Tools Gamma, Resisitivity, PWD Morning Report Report # 7 Customer: Well: Area: Location: Rig: 3R-102 ConocoPhillips Alaska Inc. North Slope Borough Kuparuk River Unit ROP ROP (ft/hr) 4.27 @ Mud Data API FL -- 11-Mar-2017 23:59:59 PM Current Pump & Flow Data: - Max Chlorides - Depth 2291' ml/l 1200.00 Condition 1-4-BT-S-X-IN-CT-TD Bit # Rig Activity: Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Rig Activity: Density (ppg) out (sec/qt) Viscosity Cor Solids %ml/l 1200.00 Condition 1-4-BT-S-X-IN-CT-TD Bit # Chlorides - Depth 2291' 12-Mar-2017 23:59:59 PM Current Pump & Flow Data: - Max ROP ROP (ft/hr) 4.27 @ Mud Data API FL -- Morning Report Report # 8 Customer: Well: Area: Location: Rig: 3R-102 ConocoPhillips Alaska Inc. North Slope Borough Kuparuk River Unit Total Charges: MWD Summary 96% Rig Activity: - Doyon 142 Report For: Tools Density, Porosity, Gamma, Resisitivity, NMR, SonicScope 2 7.0 9.875 9.30 PDC 9.30 Bit Type Hours 2321' 8602' 100% Gas In Air=10,000 Units-Connection - Avg Min Comments - RPM ECD (ppg) ml/30min .6-12 Background (max)Trip Average - Mud Type Lst - - Type 3 8595' PDC LSND 5.08602'20 Depth in / outSize 6.75 Chromatograph (ppm) Surface C-4i C-4n YP (lb/100ft2) 8.10 50-170 WOBFootage Ss (ppb Eq) C-1 C-5i AK-AM-0903680227 - - M/U BHA PV - - TuffGvlCoal - Cement 29.7 Weight 42.86 Intermediate Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) G. Rizek, R. Rauchenstein 24 hr Max Job No.: Daily Charges: Date: Avg to8602' - - Gas Summary 8602' 8602' 0' Bottoms Up Time in Time Time: Max @ ft Current -- C-2 - (current) C-5n ShClyst - C-3 Cht Silt SPP (psi) Gallons/stroke TFA - Depth 18.846 pH Siltst 1.035 cP 11 6281' - Units* Casing Summary Lithology (%) L-80 MBT (907) 670-6042Unit Phone:Ryan Lenberg Maximum Report By:Logging Engineers:Ryan Lenberg\Leigh Ann Rasher Set AtSize 45.5 L-80 Grade 10.75'' 7.625" Cly - - Hole Capacity (bbls) Drillstring Capacity (bbls) - Function test and calibrate constant volume extractor pump and prepare sample supplies for upcoming production section. Mudlogging Activity: Volumes (max)(current) Make up 84 stands of 4" drill pipe, rig up to test BOPE, successfully test BOPE, and make up production BHA at report time. - Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes No significant amount of fluids lost over the last 24 hours. Losses/Gains: . . * 24 hr Recap: Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes No losses to formation. Losses/Gains: Circulate and condition mud for formation integrity test at midnight. Continue picking up BHA, run in hole, log while running in, drill out cement, plug, float collar, and 20' of new formation. 9 -2651355.63 85.83 56 average gas of 9 units over the last 24 hours. Monitor the run in hole and prepare for production section. Max gas of 244 units when circulating up new formation at 8618' MD and Mudlogging Activity: Volumes (max)(current) 469 191 Cly 26922 - - Hole Capacity (bbls) Drillstring Capacity (bbls) - Set AtSize 45.5 L-80 Grade 10.75'' 7.625" (907) 670-6042Unit Phone: 80 Ryan Lenberg Maximum Report By:Logging Engineers:Ryan Lenberg\Leigh Ann Rasher 5 267.79 47 Units* Casing Summary Lithology (%) 5 L-80 MBT 8622' pH 134 Siltst 1.035 cP 15 6281' SPP (psi) Gallons/stroke TFA 200 Depth 18.060 C-5n 8618'208 ShClyst - C-3 Cht Silt 0.0 C-2 244 146.7 (current) in Depth Time: Max @ ft Current 8617' 8602' 8622' 20' 122 Bottoms Up Time Date: Avg to8602' - 100 Gas Summary Yesterday's Depth: Current Depth: 24 Hour Progress: 200.2 Flow In (gpm) Flow In (spm) G. Rizek, R. Rauchenstein 24 hr Max Job No.: Daily Charges: 29.7 Weight 42.86 Intermediate - TuffGvlCoal - CementSs (ppb Eq) C-1 C-5i AK-AM-0903680227 - - Circulate & Condition PV - C-4i C-4n YP (lb/100ft2) 9.40 50-170 WOBFootage 589 Chromatograph (ppm) Surface PDC LSND 7.9 8602' 8602'26 Depth in / outSize 6.75 Mud Type Lst - - Type 3 8595' Average -13Background (max)Trip Avg Min Comments - RPM ECD (ppg) ml/30min .6-12 100% Gas In Air=10,000 Units-Connection - 269 2 7.8 9.875 9.30 PDC 9.30 Bit Type Hours 2321' 8602' Total Charges: MWD Summary 96% Rig Activity: - Doyon 142 Report For: Tools Density, Porosity, Gamma, Resisitivity, NMR, SonicScope Morning Report Report # 9 Customer: Well: Area: Location: Rig: 3R-102 ConocoPhillips Alaska Inc. North Slope Borough Kuparuk River Unit ROP ROP (ft/hr) 4.27 @ Mud Data API FL -- 13-Mar-2017 23:59:59 PM Current Pump & Flow Data: 1328 Max 6 Chlorides - Depth 2291' ml/l 1500.00 Condition 1-4-BT-S-X-IN-CT-TD Bit # Rig Activity: Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes 40 barrels were lost to formation. Losses/Gains: cut fluorescence. The max formation gas of 2017 units was seen at 9,440' MD with an average of 618 units. present. The sandstone has been heavily oil stained with bright yellow fluorescence and with a very fast streaming yellow and at 10000' MD. Lithology has been fine to very fine grain of mostly unconsolidated quartz sandstone with 0-30% siltstone mud on the fly, and continue drilling ahead to a depth of 10,125' MD at midnight. Continue circulate and condition mud for FIT, perform FIT to 14.2 EMW, drill ahead in production section while displacing to flo-pro 618 -2446350.02 101.16 41 samples as specified by wellsite geologist. A total of 11 isotube samples were collected today at 8890' MD, 9000' - 9800' MD, Collect 100' wet samples and 100' cleaned samples for lithology during the entire production section. Collect 100' isotube gas Mudlogging Activity: Volumes (max)(current) 39440 1563 Cly 144616 - 20% Hole Capacity (bbls) Drillstring Capacity (bbls) - Set AtSize 45.5 L-80 Grade 10.75'' 7.625" (907) 670-6042Unit Phone: 1126 Ryan Lenberg Maximum Report By:Logging Engineers:Ryan Lenberg\Leigh Ann Rasher 411 248.86 60 Units* Casing Summary Lithology (%) 454 L-80 MBT 10125' pH 1562 Siltst 1.035 cP 22 6281' SPP (psi) Gallons/stroke TFA 256 Depth 1.850 C-5n 9440'2841 ShClyst - C-3 Cht Silt 98.0 C-2 2017 160.0 (current) in Depth Time: Max @ ft Current 9512' 8622' 10125' 1503' 1684 Bottoms Up Time Date: Avg to8602' - - Gas Summary Yesterday's Depth: Current Depth: 24 Hour Progress: 300.0 Flow In (gpm) Flow In (spm) G. Rizek, R. Rauchenstein 24 hr Max Job No.: Daily Charges: 29.7 Weight 42.86 Intermediate - TuffGvlCoal - CementSs (ppb Eq) C-1 C-5i AK-AM-0903680227 - - Drill Ahead 6-3/4" PV - C-4i C-4n YP (lb/100ft2) 10.60 50-170 WOBFootage 400860569 Chromatograph (ppm) Surface PDC FloPro 3.8 8602' 9947'22 Depth in / outSize 6.75 Mud Type Lst 80% - Type 3 8595' Average -505Background (max)Trip Avg Min Comments - RPM ECD (ppg) ml/30min .6-12 100% Gas In Air=10,000 Units-Connection - 2977 2 6.5 9.875 9.20 PDC 9.20 Bit Type Hours 2321' 8602' Total Charges: MWD Summary 96% Rig Activity: 11.47 Doyon 142 Report For: Tools Density, Porosity, Gamma, Resisitivity, NMR, SonicScope Morning Report Report # 10 Customer: Well: Area: Location: Rig: 3R-102 ConocoPhillips Alaska Inc. North Slope Borough Kuparuk River Unit ROP ROP (ft/hr) 4.27 @ Mud Data API FL 10.2910.74 14-Mar-2017 23:59:59 PM Current Pump & Flow Data: 2165 Max 800 Chlorides - Depth 2291' ml/l 19000.00 Condition 1-4-BT-S-X-IN-CT-TD Bit # Rig Activity: Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: max formation gas of 1412 units was seen at 10,742' MD with an average of 591 units. Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes 195 barrels of Flo-Pro mud was lost to formation over the last 24 hours. Losses/Gains: sandstone has been heavily oil stained with bright yellow fluorescence and with a very fast streaming yellow cut fluorescence. The with 0-60% siltstone present. Samples with increased siltstone occurred at 10,100'-10,400' MD and at 11,500'-11,700' MD. The 10,350'-10,850' MD; and 11,125'-11,825' MD. Lithology has been fine to very fine grain mostly unconsolidated quartz sandstone Continue drill ahead in production section from 10,125' MD to 11,926' MD. 591 60 3648490.73 119.53 60 samples as specified by wellsite geologist. A total of 16 isotube samples were collected today at 10,100'-10,200' MD; Collect 100' wet samples and 100' cleaned samples for lithology during the entire production section. Collect 100' isotube gas Mudlogging Activity: Volumes (max)(current) 28510 1364 Cly 86451 - 30% Hole Capacity (bbls) Drillstring Capacity (bbls) - Set AtSize 45.5 L-80 Grade 10.75'' 7.625" (907) 670-6042Unit Phone: 1130 Ryan Lenberg Maximum Report By:Logging Engineers:Ryan Lenberg\Leigh Ann Rasher 459 371.2 61 Units* Casing Summary Lithology (%) 571 L-80 MBT 11926' pH 1333 Siltst 1.035 cP 11 6281' SPP (psi) Gallons/stroke TFA 260 Depth 3.354 C-5n 10742'2623 ShClyst - C-3 Cht Silt 97.5 C-2 1412 157.0 (current) in Depth Time: Max @ ft Current 10717' 10125' 11926' 1801' 1606 Bottoms Up Time Date: Avg to8602' - - Gas Summary Yesterday's Depth: Current Depth: 24 Hour Progress: 305.0 Flow In (gpm) Flow In (spm) G. Rizek, N. Lehman 24 hr Max Job No.: Daily Charges: 29.7 Weight 42.86 Intermediate - TuffGvlCoal - CementSs (ppb Eq) C-1 C-5i AK-AM-0903680227 - - Drill Ahead 6-3/4" PV - C-4i C-4n YP (lb/100ft2) 10.10 50-170 WOBFootage 5501063747 Chromatograph (ppm) Surface PDC FloPro 4.0 8602' 11731'24 Depth in / outSize 6.75 Mud Type Lst 70% - Type 3 8595' Average -507Background (max)Trip Avg Min Comments - RPM ECD (ppg) ml/30min .6-12 100% Gas In Air=10,000 Units-Connection - 2591 2 6.5 9.875 9.20 PDC 9.20 Bit Type Hours 2321' 8602' Total Charges: MWD Summary 96% Rig Activity: 11.91 Doyon 142 Report For: Tools Density, Porosity, Gamma, Resisitivity, NMR, SonicScope Morning Report Report # 11 Customer: Well: Area: Location: Rig: 3R-102 ConocoPhillips Alaska Inc. North Slope Borough Kuparuk River Unit ROP ROP (ft/hr) 4.27 @ Mud Data API FL 11.2311.64 15-Mar-2017 23:59:59 PM Current Pump & Flow Data: 2410 Max 936 Chlorides - Depth 2291' ml/l 18000.00 Condition 1-4-BT-S-X-IN-CT-TD Bit # Rig Activity: Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Rig Activity: Density (ppg) out (sec/qt) Viscosity Cor Solids %ml/l 19000.00 Condition 1-4-BT-S-X-IN-CT-TD Bit # 461 Chlorides - Depth 2291' 16-Mar-2017 23:59:59 PM Current Pump & Flow Data: 2726 Max ROP ROP (ft/hr) 4.27 @ Mud Data API FL 11.4911.94 Morning Report Report # 12 Customer: Well: Area: Location: Rig: 3R-102 ConocoPhillips Alaska Inc. North Slope Borough Kuparuk River Unit Total Charges: MWD Summary 96% Rig Activity: 12.70 Doyon 142 Report For: Tools Density, Porosity, Gamma, Resisitivity, NMR, SonicScope 2 6.5 9.875 9.25 PDC 9.20 Bit Type Hours 2321' 8602' 100% Gas In Air=10,000 Units-Connection - 1146 Avg Min Comments - RPM ECD (ppg) ml/30min .6-12 68Background (max)Trip Average - Mud Type Lst 70% - Type 3 8595' PDC FloPro 4.3 8602' 13058'28 Depth in / outSize 6.75 341598480 Chromatograph (ppm) Surface C-4i C-4n YP (lb/100ft2) 9.50 50-170 WOBFootage (ppb Eq) C-1 C-5i AK-AM-0903680227 - - Drill Ahead 6-3/4" PV - - TuffGvlCoal - Cement 29.7 Weight 42.86 Intermediate Yesterday's Depth: Current Depth: 24 Hour Progress: 268.0 Flow In (gpm) Flow In (spm) G. Rizek, N. Lehman 24 hr Max Job No.: Daily Charges: Date: Avg to8602' - - Gas Summary 11926' 13286' 1360' 1097 Bottoms Up Time in Depth Time: Max @ ft Current 12798'197.0 C-2 708 131.0 (current) C-5n 11997'1295 ShClyst - C-3 Cht Silt SPP (psi) Gallons/stroke TFA 256 Depth 4.854 13286' pH 860 Siltst 1.035 cP 9 6281' 228 412.5 60 Units* Casing Summary Lithology (%) 342 L-80 MBT (907) 670-6042Unit Phone: 648 Ryan Lenberg Maximum Report By:Logging Engineers:Ryan Lenberg\Leigh Ann Rasher Set AtSize 45.5 L-80 Grade 10.75'' 7.625" Cly 38808 - 30% Hole Capacity (bbls) Drillstring Capacity (bbls) - Ss samples as specified by wellsite geologist. A total of 6 isotube samples were collected today from 12,000'-12,500' MD. Collect 100' wet samples and 100' cleaned samples for lithology during the entire production section. Collect 100' isotube gas Mudlogging Activity: Volumes (max)(current) 14939 598 Continue drilling ahead in production section from 11,926' MD to 13,286' MD. 268 60 4053545.85 133.4 68 Max formation gas of 742 units was seen at 11,997' MD with an average of 268 units. Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes 135 barrels of Flo-Pro mud was lost to formation over the last 24 hours. Losses/Gains: to weak today; with trace oil staining present and 30-70% dull yellow fluorescence with slow streaming white fluorescence cut. Samples with increased siltstone occurred at 12,000'-12,300' MD and at 12,700'-13,200' MD. Oil shows have generally been trace Lithology has been very fine to coarse grain unconsolidated to consolidated quartz sandstone with 0-50% siltstone present. . . * 24 hr Recap:Rig Activity: Density (ppg) out (sec/qt) Viscosity Cor Solids %ml/l 18000.00 Condition 1-4-BT-S-X-IN-CT-TD Bit # 64 Chlorides - Depth 2291' 17-Mar-2017 23:59:59 PM Current Pump & Flow Data: 2802 Max ROP ROP (ft/hr) 4.27 @ Mud Data API FL 12.3512.85 Morning Report Report # 13 Customer: Well: Area: Location: Rig: 3R-102 ConocoPhillips Alaska Inc. North Slope Borough Kuparuk River Unit Total Charges: MWD Summary 96% Rig Activity: 13.24 Doyon 142 Report For: Tools Density, Porosity, Gamma, Resisitivity, NMR, SonicScope 2 6.5 9.875 9.30 PDC 9.25 Bit Type Hours 2321' 8602' 100% Gas In Air=10,000 Units-Connection - 2531 Avg Min Comments - RPM ECD (ppg) ml/30min .6-12 87Background (max)Trip Average - Mud Type Lst 100% - Type 3 8595' PDC Flo-Pro 5.2 8602' 14950'27 Depth in / outSize 6.75 6510392 Chromatograph (ppm) Surface C-4i C-4n YP (lb/100ft2) 9.80 50-170 WOBFootage - (ppb Eq) C-1 C-5i AK-AM-0903680227 - - BROOH PV - TuffGvlCoal - Cement 29.7 Weight 42.86 Intermediate Yesterday's Depth: Current Depth: 24 Hour Progress: 256.3 Flow In (gpm) Flow In (spm) G. Rizek, N. Lehman 24 hr Max Job No.: Daily Charges: Date: Avg to8602' - - Gas Summary 13286' 14950' 1664' 1702 Bottoms Up Time in Depth Time: Max @ ft Current 13234'- C-2 647 71.3 (current) C-5n 14535'3089 ShClyst - C-3 Cht Silt SPP (psi) Gallons/stroke TFA 257 Depth 6.551 14950' pH 2545 Siltst 1.035 cP 10 6281' 108 458 60 Units* Casing Summary Lithology (%) 71 L-80 MBT (907) 670-6042Unit Phone: 1013 Ryan Lenberg Maximum Report By:Logging Engineers:Ryan Lenberg\Leigh Ann Rasher Set AtSize 45.5 L-80 Grade 10.75'' 7.625" Cly 56636 - - Hole Capacity (bbls) Drillstring Capacity (bbls) - Ss A total of 5 isotube samples were collected today from 13,500'-13,800' MD. Lithology has been very fine to fine grain Collect 100' wet/lithology/isotubes while drilling, prepare sample shipments, and monitor back ream out of hole. Mudlogging Activity: Volumes (max)(current) 8731 6782 Continue drilling ahead from 13,286' MD to 14,950' MD well TD at 20:09 and begin back ream out of hole. 139 60 4501599141 75 white-yellow fluorescence cut. Max formation gas of 647 units was seen at 14,535' MD with an average of 268 units. Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes 135 barrels of Flo-Pro mud was lost to formation over the last 24 hours. Losses/Gains: Moderate oil shows had abundant oil staining present and 90% bright yellow fluorescence with a very fast streaming and at 13,900'-14,300' MD. Oil shows have generally been trace to weak but improved to moderate grade at 14,700' MD to TD. unconsolidated quartz sandstone with 0-60% siltstone present. Samples with increased siltstone occurred at 13,500'-13,600' MD WELL INFORMATION Created On : Mar 22 2017 Customer :ConocoPhillips Alaska Inc. Well Name :3R-102 Job Number :AK-XX-0903754613 Rig Name :Doyon 142 Country :USA State / Province :Alaska Survey Report SURVEY HEADER Survey data provided by Schlumberger. DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 39.10 0.00 0.00 39.10 0.00 N 0.00 E 0.00 0.00 48.00 0.24 109.51 48.00 0.01 S 0.02 E -0.02 2.70 88.00 0.28 92.52 88.00 0.04 S 0.19 E -0.20 0.22 185.00 0.35 103.46 185.00 0.12 S 0.72 E -0.72 0.09 278.00 0.20 171.69 278.00 0.34 S 1.02 E -1.08 0.36 369.00 1.46 267.60 368.99 0.55 S 0.12 W -0.08 1.64 393.00 1.74 268.51 392.98 0.57 S 0.79 W 0.54 1.17 486.00 3.42 271.16 485.88 0.55 S 4.97 W 4.48 1.81 579.00 4.97 277.90 578.63 0.06 N 11.74 W 11.05 1.75 671.00 7.55 284.91 670.07 2.16 N 21.53 W 20.97 2.92 743.00 9.62 287.07 741.26 5.14 N 31.85 W 31.69 2.91 766.58 10.24 288.31 764.49 6.38 N 35.72 W 35.75 2.78 861.59 11.22 289.99 857.84 12.19 N 52.43 W 53.43 1.08 957.11 11.09 291.85 951.55 18.79 N 69.69 W 71.91 0.40 1051.84 12.51 291.92 1,044.28 26.01 N 87.66 W 91.27 1.50 1145.75 17.49 291.29 1,134.96 34.94 N 110.26 W 115.56 5.31 1241.18 18.15 291.47 1,225.81 45.58 N 137.45 W 144.75 0.69 1336.00 17.88 292.20 1,315.98 56.49 N 164.67 W 174.06 0.37 1429.78 17.41 291.84 1,405.35 67.15 N 191.03 W 202.47 0.51 1525.57 16.21 292.49 1,497.05 77.59 N 216.68 W 230.15 1.27 1619.63 18.31 294.96 1,586.87 88.85 N 242.21 W 257.99 2.36 1714.79 18.75 295.27 1,677.09 101.69 N 269.59 W 288.11 0.47 1809.56 23.39 297.30 1,765.50 116.83 N 300.10 W 321.96 4.96 1903.92 26.23 299.98 1,851.15 135.84 N 334.81 W 361.08 3.24 1998.35 31.13 304.42 1,933.98 160.08 N 373.05 W 405.31 5.66 2093.16 34.11 305.46 2,013.83 189.37 N 414.93 W 454.68 3.20 2188.51 37.42 306.80 2,091.18 222.24 N 459.92 W 508.19 3.57 2215.65 39.83 307.03 2,112.39 232.42 N 473.46 W 524.40 8.90 2259.63 40.99 307.51 2,145.87 249.68 N 496.15 W 551.63 2.73 INSITE V8.5.0 Page 1Job No:AK-XX-0903754613 Well Name:3R-102 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2328.59 41.26 308.24 2,197.82 277.53 N 531.95 W 594.79 0.80 2423.80 42.44 312.17 2,268.75 318.53 N 580.43 W 654.37 3.02 2519.56 43.80 317.78 2,338.67 364.79 N 626.66 W 713.64 4.25 2615.24 44.72 323.22 2,407.22 416.29 N 669.09 W 771.11 4.08 2709.20 48.84 326.03 2,471.56 472.13 N 708.66 W 827.40 4.90 2803.34 52.75 328.78 2,531.06 533.59 N 747.91 W 885.30 4.73 2898.93 57.01 330.25 2,586.04 600.97 N 787.54 W 945.59 4.63 2993.29 60.25 330.81 2,635.16 671.10 N 827.16 W 1006.81 3.47 3088.91 65.24 331.43 2,678.93 745.52 N 868.20 W 1070.82 5.25 3182.44 70.24 332.52 2,714.35 821.91 N 908.84 W 1135.14 5.45 3277.72 75.07 334.34 2,742.75 903.23 N 949.49 W 1201.15 5.39 3372.75 78.58 336.64 2,764.41 987.41 N 987.85 W 1265.99 4.38 3467.06 81.98 338.97 2,780.33 1,073.46 N 1,022.95 W 1328.40 4.35 3562.28 81.65 338.70 2,793.89 1,161.35 N 1,056.98 W 1390.44 0.45 3656.27 81.44 337.98 2,807.71 1,247.75 N 1,091.29 W 1452.24 0.79 3751.53 81.48 337.36 2,821.85 1,334.89 N 1,127.09 W 1515.67 0.65 3845.60 81.48 336.69 2,835.79 1,420.54 N 1,163.40 W 1579.09 0.70 3941.30 81.28 337.61 2,850.14 1,507.74 N 1,200.14 W 1643.44 0.97 4036.63 81.21 337.59 2,864.65 1,594.85 N 1,236.05 W 1706.97 0.08 4131.07 81.37 338.38 2,878.95 1,681.39 N 1,271.04 W 1769.45 0.84 4226.09 81.48 338.22 2,893.11 1,768.69 N 1,305.78 W 1831.96 0.20 4320.22 81.57 339.18 2,906.99 1,855.43 N 1,339.60 W 1893.40 1.01 4415.08 81.42 340.00 2,921.02 1,943.36 N 1,372.32 W 1954.22 0.87 4510.35 81.34 340.67 2,935.30 2,032.06 N 1,404.01 W 2014.34 0.70 4604.35 80.84 341.13 2,949.86 2,119.81 N 1,434.40 W 2072.91 0.72 4699.95 80.34 340.51 2,965.49 2,208.89 N 1,465.39 W 2132.49 0.83 4794.44 80.46 340.31 2,981.24 2,296.66 N 1,496.62 W 2191.87 0.24 4889.65 80.83 339.34 2,996.72 2,384.84 N 1,529.02 W 2252.47 1.08 4983.31 80.49 338.90 3,011.92 2,471.19 N 1,561.96 W 2312.96 0.59 5077.70 80.53 337.97 3,027.48 2,557.77 N 1,596.18 W 2374.73 0.97 5172.82 80.23 337.04 3,043.38 2,644.41 N 1,632.06 W 2438.08 1.01 5267.22 80.03 336.06 3,059.56 2,729.74 N 1,669.07 W 2502.04 1.04 5362.10 79.88 335.84 3,076.11 2,815.05 N 1,707.15 W 2566.99 0.28 5457.08 80.16 335.68 3,092.57 2,900.35 N 1,745.55 W 2632.26 0.34 5551.85 79.91 335.39 3,108.97 2,985.31 N 1,784.21 W 2697.64 0.40 5646.54 79.97 335.85 3,125.51 3,070.23 N 1,822.69 W 2762.85 0.48 5741.01 79.94 336.37 3,141.99 3,155.28 N 1,860.36 W 2827.34 0.54 5836.02 80.01 337.12 3,158.53 3,241.23 N 1,897.30 W 2891.45 0.78 5930.60 79.48 337.27 3,175.37 3,327.03 N 1,933.38 W 2954.69 0.58 6024.99 79.20 338.35 3,192.83 3,412.92 N 1,968.41 W 3016.98 1.16 6119.39 79.90 338.90 3,209.95 3,499.37 N 2,002.24 W 3078.35 0.94 6214.91 80.12 338.63 3,226.52 3,587.05 N 2,036.32 W 3140.35 0.36 6309.08 80.58 337.85 3,242.31 3,673.27 N 2,070.73 W 3202.18 0.95 6403.68 81.37 337.21 3,257.15 3,759.61 N 2,106.44 W 3265.27 1.07 6498.44 81.67 334.31 3,271.12 3,845.06 N 2,144.92 W 3330.65 3.04 INSITE V8.5.0 Page 2Job No:AK-XX-0903754613 Well Name:3R-102 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6593.92 81.06 332.28 3,285.46 3,929.38 N 2,187.34 W 3399.35 2.20 6688.48 81.26 328.95 3,300.00 4,010.78 N 2,233.18 W 3470.27 3.49 6783.31 82.22 326.73 3,313.62 4,090.22 N 2,283.13 W 3544.38 2.53 6834.32 83.15 325.68 3,320.12 4,132.27 N 2,311.27 W 3585.20 2.74 6877.51 83.25 324.80 3,325.23 4,167.50 N 2,335.72 W 3620.23 2.04 6972.07 83.41 322.66 3,336.21 4,243.22 N 2,391.28 W 3698.33 2.25 7017.74 82.78 321.84 3,341.70 4,279.07 N 2,419.04 W 3736.68 2.25 7067.39 82.20 320.11 3,348.19 4,317.30 N 2,450.03 W 3778.88 3.65 7104.15 81.81 318.29 3,353.31 4,344.86 N 2,473.81 W 3810.65 5.02 7160.22 81.84 316.89 3,361.28 4,385.84 N 2,511.24 W 3859.84 2.47 7208.88 81.39 314.39 3,368.38 4,420.25 N 2,544.90 W 3903.24 5.17 7256.01 80.40 312.46 3,375.84 4,452.24 N 2,578.69 W 3945.93 4.56 7304.32 79.61 310.09 3,384.22 4,483.62 N 2,614.45 W 3990.26 5.10 7350.36 79.13 307.93 3,392.72 4,512.11 N 2,649.61 W 4033.04 4.73 7399.84 79.41 304.55 3,401.93 4,540.84 N 2,688.81 W 4079.71 6.74 7445.17 79.82 301.49 3,410.10 4,565.13 N 2,726.19 W 4123.15 6.70 7496.96 80.51 299.41 3,418.95 4,590.99 N 2,770.18 W 4173.33 4.18 7539.35 81.33 299.56 3,425.64 4,611.59 N 2,806.62 W 4214.61 1.97 7634.94 81.68 297.10 3,439.76 4,656.45 N 2,889.83 W 4308.15 2.57 7730.93 82.36 294.45 3,453.09 4,697.78 N 2,975.42 W 4402.72 2.82 7824.08 82.41 291.59 3,465.44 4,733.89 N 3,060.39 W 4494.91 3.04 7919.11 82.13 286.29 3,478.23 4,764.44 N 3,149.43 W 4589.02 5.53 8012.75 82.45 282.19 3,490.80 4,787.26 N 3,239.35 W 4681.33 4.35 8065.51 82.91 280.19 3,497.52 4,797.41 N 3,290.68 W 4733.04 3.86 8107.62 83.00 278.75 3,502.69 4,804.29 N 3,331.90 W 4774.12 3.40 8202.76 82.37 274.13 3,514.81 4,814.87 N 3,425.64 W 4865.83 4.86 8297.70 81.86 269.64 3,527.84 4,817.97 N 3,519.61 W 4955.19 4.72 8392.36 82.74 265.38 3,540.53 4,813.89 N 3,613.31 W 5041.84 4.56 8487.18 83.77 265.54 3,551.66 4,806.44 N 3,707.17 W 5127.50 1.10 8541.76 83.79 265.37 3,557.58 4,802.14 N 3,761.26 W 5176.85 0.31 8638.78 83.66 263.50 3,568.18 4,792.79 N 3,857.24 W 5263.85 1.92 8671.52 84.90 262.76 3,571.44 4,788.89 N 3,889.58 W 5292.91 4.40 8703.61 86.14 264.28 3,573.95 4,785.28 N 3,921.37 W 5321.54 6.10 8733.13 87.10 265.71 3,575.69 4,782.71 N 3,950.72 W 5348.25 5.83 8765.80 87.73 266.95 3,577.16 4,780.62 N 3,983.29 W 5378.14 4.25 8797.18 87.82 267.13 3,578.38 4,779.00 N 4,014.61 W 5407.01 0.64 8828.00 88.09 269.81 3,579.48 4,778.18 N 4,045.39 W 5435.66 8.73 8924.07 88.04 270.16 3,582.73 4,778.15 N 4,141.41 W 5525.87 0.37 9018.79 89.82 269.32 3,584.50 4,777.72 N 4,236.11 W 5614.71 2.08 9113.14 90.05 268.69 3,584.60 4,776.08 N 4,330.44 W 5702.80 0.71 9208.72 89.95 267.85 3,584.60 4,773.20 N 4,425.98 W 5791.59 0.89 9303.05 90.12 270.04 3,584.54 4,771.46 N 4,520.29 W 5879.61 2.33 9397.06 91.08 272.78 3,583.56 4,773.77 N 4,614.25 W 5968.70 3.09 9490.90 91.22 275.30 3,581.68 4,780.38 N 4,707.83 W 6058.90 2.69 9584.52 91.24 274.35 3,579.67 4,788.26 N 4,801.10 W 6149.23 1.01 INSITE V8.5.0 Page 3Job No:AK-XX-0903754613 Well Name:3R-102 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 9681.00 92.62 272.67 3,576.42 4,794.16 N 4,897.34 W 6241.69 2.25 9773.86 93.38 267.36 3,571.55 4,794.19 N 4,990.04 W 6328.81 5.77 9869.63 93.48 266.30 3,565.82 4,788.90 N 5,085.49 W 6416.69 1.11 9965.16 93.65 265.40 3,559.88 4,782.00 N 5,180.58 W 6503.69 0.96 10058.11 93.03 266.21 3,554.47 4,775.21 N 5,273.12 W 6588.33 1.10 10154.55 91.08 266.50 3,551.01 4,769.08 N 5,369.30 W 6676.61 2.04 10248.93 88.57 265.92 3,551.30 4,762.85 N 5,463.47 W 6762.97 2.73 10342.27 86.74 265.64 3,555.12 4,755.98 N 5,556.47 W 6848.02 1.98 10437.85 90.02 266.75 3,557.82 4,749.65 N 5,651.79 W 6935.42 3.62 10533.00 89.08 266.56 3,558.57 4,744.09 N 5,746.77 W 7022.77 1.01 10627.38 89.33 269.07 3,559.88 4,740.50 N 5,841.07 W 7110.15 2.67 10720.67 89.47 271.40 3,560.85 4,740.88 N 5,934.34 W 7197.93 2.50 10816.39 89.47 271.47 3,561.74 4,743.28 N 6,030.03 W 7288.67 0.07 10911.11 88.80 271.14 3,563.17 4,745.43 N 6,124.71 W 7378.38 0.79 11006.68 89.79 270.27 3,564.34 4,746.61 N 6,220.27 W 7468.57 1.38 11099.59 92.28 270.83 3,562.67 4,747.50 N 6,313.15 W 7556.16 2.75 11193.48 91.15 272.58 3,559.86 4,750.29 N 6,406.95 W 7645.26 2.22 11289.46 89.40 271.78 3,559.40 4,753.94 N 6,502.86 W 7736.63 2.00 11384.81 88.29 272.77 3,561.32 4,757.73 N 6,598.11 W 7827.43 1.56 11478.98 88.32 272.54 3,564.10 4,762.09 N 6,692.14 W 7917.28 0.25 11573.63 89.57 272.42 3,565.85 4,766.18 N 6,786.68 W 8007.52 1.33 11669.26 90.14 271.75 3,566.09 4,769.66 N 6,882.25 W 8098.51 0.92 11763.98 92.00 269.81 3,564.32 4,770.95 N 6,976.93 W 8187.93 2.84 11857.55 92.52 268.51 3,560.63 4,769.58 N 7,070.42 W 8275.31 1.50 11953.14 93.10 268.11 3,555.94 4,766.76 N 7,165.85 W 8364.02 0.74 12048.52 92.43 268.67 3,551.34 4,764.09 N 7,261.08 W 8452.60 0.92 12142.97 89.65 268.19 3,549.63 4,761.50 N 7,355.47 W 8540.41 2.99 12237.59 89.67 267.91 3,550.19 4,758.28 N 7,450.03 W 8628.17 0.30 12332.05 89.74 268.48 3,550.68 4,755.31 N 7,544.44 W 8715.87 0.61 12426.14 89.62 268.02 3,551.20 4,752.43 N 7,638.49 W 8803.26 0.51 12518.51 91.69 267.95 3,550.15 4,749.18 N 7,730.79 W 8888.88 2.24 12608.99 90.69 268.50 3,548.27 4,746.38 N 7,821.21 W 8972.89 1.26 12701.93 91.20 267.69 3,546.73 4,743.29 N 7,914.08 W 9059.10 1.03 12796.93 93.31 266.71 3,543.00 4,738.66 N 8,008.89 W 9146.61 2.45 12890.26 95.83 264.32 3,535.56 4,731.39 N 8,101.62 W 9231.26 3.72 12982.92 96.10 263.20 3,525.93 4,721.37 N 8,193.23 W 9313.92 1.24 13071.76 96.03 262.96 3,516.54 4,710.73 N 8,280.93 W 9392.69 0.28 13164.19 96.09 261.85 3,506.79 4,698.58 N 8,372.04 W 9474.15 1.20 13257.05 96.10 259.00 3,496.92 4,683.22 N 8,463.08 W 9554.45 3.05 13349.20 96.20 256.03 3,487.05 4,663.42 N 8,552.52 W 9631.72 3.21 13441.20 96.13 254.45 3,477.17 4,640.11 N 8,640.97 W 9706.86 1.71 13533.72 96.13 252.93 3,467.29 4,614.28 N 8,729.25 W 9780.99 1.63 13624.70 96.13 249.41 3,457.57 4,585.09 N 8,814.86 W 9851.45 3.85 13715.41 96.00 247.11 3,447.98 4,551.68 N 8,898.64 W 9918.75 2.53 13808.53 96.27 246.29 3,438.03 4,515.06 N 8,983.67 W 9986.13 0.92 INSITE V8.5.0 Page 4Job No:AK-XX-0903754613 Well Name:3R-102 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 13900.76 96.17 245.73 3,428.04 4,477.78 N 9,067.44 W 10052.10 0.61 13993.20 95.61 247.20 3,418.55 4,441.06 N 9,151.74 W 10118.75 1.69 14085.29 91.50 247.79 3,412.84 4,405.89 N 9,236.63 W 10186.50 4.51 14176.85 89.79 246.05 3,411.81 4,370.00 N 9,320.85 W 10253.37 2.66 14269.99 89.87 244.97 3,412.09 4,331.39 N 9,405.61 W 10319.81 1.16 14361.44 90.84 244.72 3,411.52 4,292.52 N 9,488.39 W 10384.30 1.10 14453.76 92.68 246.48 3,408.69 4,254.41 N 9,572.42 W 10450.22 2.76 14545.65 92.18 248.52 3,404.79 4,219.27 N 9,657.23 W 10517.90 2.28 14635.90 92.38 247.74 3,401.20 4,185.68 N 9,740.92 W 10585.06 0.89 14729.03 93.00 248.92 3,396.83 4,151.33 N 9,827.37 W 10654.54 1.43 14820.59 92.90 249.47 3,392.12 4,118.85 N 9,912.84 W 10723.76 0.61 14890.02 92.86 252.82 3,388.63 4,096.45 N 9,978.46 W 10777.75 4.82 14950.00 92.86 252.82 3,385.64 4,078.75 N 10,035.69 W 10825.48 0.00 DIRECTIONAL SURVEY DATA NOTES - Calculation based on minimum curvature method. - Survey coordinates relative to well system reference point. - TVD values given relative to drilling measurement point. - Vertical section relative to well head. - Vertical section is computed along a direction of 290.00 degrees (True) - A total correction of 17.78 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 14,950.00 feet is 10,832.88 feet along 292.12 degrees (True) WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V8.5.0 Page 5Job No:AK-XX-0903754613 Well Name:3R-102 Survey Report