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Home My WebLink About216-011MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1H-07A KUPARUK RIV UNIT 1H-07A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/22/2025 1H-07A 50-029-20755-01-00 216-011-0 W SPT 6425 2160110 3000 2400 2410 2410 2410 127 303 304 304 REQVAR P Sully Sullivan 8/18/2025 MIT-IA to MAIP 3000psi per AIO 2C.060 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 1H-07A Inspection Date: Tubing OA Packer Depth 520 3300 3230 3220IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS251021134249 BBL Pumped:2.3 BBL Returned:2 Wednesday, October 22, 2025 Page 1 of 1             MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, October 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1H-07A KUPARUK RIV UNIT 1H-07A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/17/2023 1H-07A 50-029-20755-01-00 216-011-0 W SPT 6425 2160110 3000 2180 2190 2190 2190 171 338 341 340 REQVAR P Brian Bixby 8/30/2023 MITIA as per AIO 2C.060 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 1H-07A Inspection Date: Tubing OA Packer Depth 680 3300 3240 3210IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230830154153 BBL Pumped:2 BBL Returned:1.9 Tuesday, October 17, 2023 Page 1 of 1            MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Regg DATE: Wednesday, August 4, 2021 J P.I. Supervisor ��9 C �+ SUBJECT: Mechanical Integrity Tests ( ConocoPhillips Alaska, Inc. IH -07A FROM: Bob Noble KUPARUK RIV UNIT 1H -07A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IH -07A Insp Num: mitRCN210802091525 Rel Insp Num: API Well Number 50-029-20755-01-00 Inspector Name: Bob Noble Permit Number: 216-011-0 Inspection Date: 8/1/2021 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Type J p 6425 Tubing 2145 _ 2145 2145 2145 I� — Well IH o7A - T e-In� -1 - -- - --- �y' TVD 2160110 'Type Test s]'r Test sl 3000 j� 1319 - 3290 3219 3200 ' PTD � ---- BBL Pumped: i 1.a IBBL Returned: 1.3 OA 153 - 230-7 230 230 - - - Interval REQVAR [1/F P Notes: MITIA to max anticipated injection pressure of 3000 psi as per AIO 2C.060 ✓ Wednesday, August 4, 2021 Page 1 of 1 Wallace, Chris D (CED) From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Tuesday, March 16, 2021 9:23 AM To: Wallace, Chris D (CED) Cc: Earhart, Will C Subject: RE: KRU 1H -07A (PTD 216-011) Update 3/16/21 Attachments: 1 H-07 90 day TIO trend 3.16.21.pdf, MIT KRU 1 H -07A diagnostic MITIA 03-16-21.xlsx Chris, KRU 1H -07A (PTD 216-011) is at the end of the 60 day monitor period and is not exhibiting signs of IAx0A communication. DHD performed a passing MITIA and re -energized the inner and outer casing pack offs after which the well was placed on the monitor period. The previously observed IA pressure decrease and OA pressure increase did not repeat and annular pressures appear stable. CPAI plans to return the well to it's 'normal' status at this time. A 90 day TIO trend and 10-426 for the MITIA are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 From: Well Integrity Specialist CPF1 & CPF3 Sent: Friday, January 15, 20219:17 AM To: Wallace, Chris D (CED) <chris.waIlace @alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: KRU 1H -07A (PTD 216-011) Report of suspect annular communication Chris, KRU 1H -07A (PTD 216-011) is exhibiting suspect behavior that is observable on a longer TIO trend. The IA pressure was charged on 11/9/2020 and since then the IA pressure has slowly decreased while the OA pressure has slowly increased. The plan is for DHD to perform initial diagnostics including an MITIA and pack off tests after which the well will be placed on a 60 day monitor period due to the slow nature of the phenomenon. A wellbore schematic and 90 day TIO trend are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Wallace, Chris D (CED) From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Friday, January 15, 2021 9:17 AM To: Wallace, Chris D (CED) Cc: Senden, R. Tyler Subject: KRU 1 H -07A (PTD 216-011) Report of suspect annular communication Attachments: 1 H-07 90 day TIO trend 1.15. 1.pdf, 1 H-07A.pdf Chris, KRU 1H -07A (PTD 216-011) is exhibiting suspect behavior that is observable on a longer TIO trend. The IA pressure was charged on 11/9/2020 and since then the IA pressure has slowly decreased while the OA pressure has slowly increased. The plan is for DHD to perform initial diagnostics including an MITIA and pack off tests after which the well will be placed on a 60 day monitor period due to the slow nature of the phenomenon. A wellbore schematic and 90 day TIO trend are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 MEMORANDUM State of Alaska Initial Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday, August 6, 2019 P.I. Supervisor �p - SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. I H -07A FROM: Adam Earl KUPARUK RIV UNIT IH -07A Petroleum Inspector 3220 - 3200 Src: Inspector Reviewed By: 165 - P.I. Supry ZTZ NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IH -07A API Well Number 50-029-20755-01-00 Inspector Name: Adam Earl Insp Num: mitAGPI908051I Ia1g Permit Number: 216-011-0 Inspection Date: 8/3/2019 ' Rel Insp Num: Packer Depth Well IH -07A Type Inj w- TVD 6425 —PTD--!- 2160110 --Type Testi SPT Test psi 3000 - — ----.- — ---- - - BBL Pumped: j 2 IBBL Returned: 2 Interval --,�REQVAR -.— IP/F J P ✓ Notes: MIT/L4 tested as per AIO 2C.060 to max ant. Inj. Press. Tuesday, August 6, 2019 Page 1 of I Pretest Initial 15 Min 30 Min 45 Min 60 Min Tubing 2125 .. 2125 11 2125 ' 2125 IA 500 3300 3220 - 3200 OA 165 - 200 200 200 Tuesday, August 6, 2019 Page 1 of I Yell Name: 1H -OT SUrt Om: 4-NOu-2018 Oats: 135 Eno Date: %-Mar-2019 tiaRuO Antwim CanumfKGauWt Snrwillante 25W lm im4 ?50 � 114 soo4 9Q so4 —MV —IAP —OAP —WIR Annular Communication SunwUlance 3s4 zs4 mA ssa to° m 0 —OGI —MGI —PMA SWI —OIPO • s Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Monday, May 21, 2018 7:03 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU 1H-07A (PTD 216-011) Report of failed MITOA Attachments: 1H-07.pdf; MIT KRU 1H-07A diagnostic MITIA 5-18-18.xlsx; 1H-07 90 day TIO trend 5-21-18.JPG Chris, KRU 1H-07A water injector(PTD 216-011)failed and MITOA on 5-19-18. The well passed an MITIA the previous day 5 18-18. Diagnostics are currently ongoing with a Surface Casing Leak Detect. Once the SCLD has been completed the well will be placed on a 30 day monitor period. The proper paperwork for continued injection or corrective action will be submitted at completion of the monitor period. A 90 day TIO trend,wellbore schematic,and 10-426 for the passin: diagnostic MITIA are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. MAY 21 1$ Office phone: (907)659-7224 SCIA WELLS TEAM coma:144am 1 . • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Wednesday, February 21, 2018 7:26 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU 1H-07A(PTD 216-011) Update Attachments: 1H-07 90 day TIO trend 2-1-18.JPG Chris, KRU water injector 1H-07A(PTD 216-011)was reported on December 23,2017 for exhibiting an unexplained decrease in IA pressure. The IA was pressurized on December 24, 2017 and has demonstrated stable trends throughout the entire monitor period. The well is being returned to normal status at this time. If at anytime in the future the well exhibits suspect annular communication it will be reported at that time. A 90 day TIO trend is attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 4RIZELLS TEAM conocamps SCANNED - 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Saturday, December 23, 2017 4:05 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of IA pressure decrease on KRU 1H-07A (PTD 216-011) 12-23-17 Attachments: 1H-07A 6 month TIO plot 12-23-17.JPG Chris, KRU water injector 1H-07A(PTD 216-011) has been experiencing a partially-unexplained repeated very slow decrease in IA pressure. The pressure drop off appears to at least be partially tied to injection rate and thus is at least partially a thermal phenomenon. However there have been a few brief periods(over the last several weeks and also in mid- October)where the fall off continued even with a relatively steady injection rate. But there is still a possibility that this is only a hysteresis effect and the pressure drop off could be fully a thermal phenomenon. A passing witnessed MITIA was obtained in August of this year during the pad's 4 yr testing. The well has been online since August 5, 2017. DHD will initially be dispatched to investigate to ensure that there is not a slow external gas leak through the surface valve/jewelry. The IA will then be pressurized and put on a 60 day monitor(60 days because of the very slow nature of the pressure fall off)to confirm that this is not a communication issue. If,during the course of the monitor, communication does become more strongly suspected, MIT and packoff testing will be pursued. An update will be provided at the conclusion of the diagnostic monitor period. Please let us know if you disagree with the path forward. Attached is the 6 month TIO plot for reference. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 SCANNEDfE ; 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday,August 21,2017 P.I.Supervisor ��? Z,12(10 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1H-07A FROM: Brian Bixby KUPARUK RIV UNIT 1H-07A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry ;J 3V • NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1H-07A API Well Number 50-029-20755-01-00 Inspector Name: Brian Bixby Permit Number: 216-011-0 Inspection Date: 8/17/2017 Insp Num: mitBDB170817165347 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1H-07A - Type Inj 1 W- TVD 6425 Tubing 2185 - 2185 . 2180 • 1 2180 PTD 2160110 - Type Test' SPT Test psi 1606 - IA 240 i 3000 - 2925 - 2910 - BBL Pumped: I 2 - ;BBL Returned: 2 - OA 97 250 - 250 250 Interval L 4YRTST P/F P Notes: SCM FEB Monday,August 21,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg DATE: Monday,November 28,2016 P.I.Supervisor "\ q1 fiizq`aor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1H-07A FROM: Guy Cook KUPARUK RIV UNIT 1H-07A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry -I NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1H-07A API Well Number 50-029-20755-01-00 Inspector Name: Guy Cook Permit Number: 216-011-0 Inspection Date: 11/20/2016 Insp Num: mitGDC161120182921 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1H 07A Type Inj 1 W TVD 6425 ' Tubing 23102310 . ; 2310 23Io - , PTD est psi'2160110 'SPT 1606 IA 480 3000 2950 • 2945 1 Interval P/F - OA 50 75 - 75 - 75 IAIITAL P ✓ _L ,_ Notes: All went well with test. 1.4 bbls pumped to achieve initial test pressure. After testing was completed 1.7 bbls was bled back. A triplex pump and bleed tank was used for this test. SCANNED APR 2 7 2017 Monday,November 28,2016 Page 1 of 1 DATA SUBMITTAL COMPLIANCE REPORT 2/17/2017 Permit to Drill 2160110 Well Name/No. KUPARUK RIV UNIT 1H -07A '?F -I * Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-20755-01-00 Pp$ 2' MD 9263 TVD 6712 Completion Date 10/21/2016 Comp%tion Status 1WINJ Current Status 1WINJ UIC Yes REQUIRED INFORMATION / Mud Log No Samples No 1z Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/RES/Open Hole Caliper Log (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments Log C 27710 Log Header Scans 0 0 2160110 KUPARUK RIV UNIT 11-1-07A LOG HEADERS ED C 27710 Digital Data 11/9/2016 Electronic File: 1H -07A EOW - NAD27.pdf . ED C 27710 Digital Data 11/9/2016 Electronic File: 1H -07A EOW - NAD27.txt ED C 27711 Digital Data 11/9/2016 Electronic File: 1 H-07APB1 EOW - NAD27.pdf ED C 27711 Digital Data 11/9/2016 Electronic File: 1H-07APB1 EOW - NAD27.txt - Log C 27711 Log Header Scans 0 0 2160110 KUPARUK RIV UNIT 1 H -07A PB1 LOG HEADERS Log C 27712 Log Header Scans 0 0 2160110 KUPARUK RIV UNIT 11-1-07A P62 LOG HEADERS ED C 27712 Digital Data 11/9/2016 Electronic File: 1H-07APB2 EOW - NAD27.pdf' ED C 27712 Digital Data 11/9/2016 Electronic File: 1H-07APB2 EOW - NAD27.txt ED C 27713 Digital Data 11/9/2016 Electronic File: 1H-07AP63 EOW - NAD27.pdf ED C 27713 Digital Data 11/9/2016 Electronic File: 1H-07APB3 EOW - NAD27.txt - Log C 27713 Log Header Scans 0 0 2160110 KUPARUK RIV UNIT 1 H -07A PB3 LOG HEADERS ED C 27739 Digital Data 7475 9263 12/7/2016 Electronic Data Set, Filename: 1H -07A GAMMA RES.las ED C 27739 Digital Data 12/7/2016 Electronic File: 1 H -07A 2MD Final Log.cgm ED C 27739 Digital Data 12/7/2016 Electronic File: 1 H -07A 5MD Final Log.cgm _ ED C 27739 Digital Data 12/7/2016 Electronic File: 1 H -07A 5TVDSS Final Log.cgm , ED C 27739 Digital Data b Y 12/7/2016 Electronic File: 1H -07A 21VID Final.pdf ED C 27739 Digital Data 12/7/2016 Electronic File: 11-1-07A 5MD Final.pdf AOGCC Page 1 of' 6 Friday, February 17, 2017 DATA SUBMITTAL COMPLIANCE REPORT 2/17/2017 Permit to Drill 2160110 Well Name/No. KUPARUK RIV UNIT 1H -07A Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-20755-01-00 MD 9263 TVD 6712 Completion Date 10/21/2016 Completion Status 1WINJ Current Status 1WINJ UIC Yes ED C 27739 Digital Data 12/7/2016 Electronic File: 1H -07A 5TVDSS Final.pdf ED C 27739 Digital Data 12/7/2016 Electronic File: 1H -07A EOW - NAD27.pdf. ED C 27739 Digital Data 12/7/2016 Electronic File: 1H -07A EOW - NAD27.txt - ED C 27739 Digital Data 12/7/2016 Electronic File: 1 H -07A Final Surveys 9263 . TD.csv ED C 27739 Digital Data 12/7/2016 Electronic File: 1H -07A Survey Listing.txt ED C 27739 Digital Data 12/7/2016 Electronic File: 11-1-07A Surveys.txt ED C 27739 Digital Data 12/7/2016 Electronic File: 1H- 07A_25_tapescan_B H I_CTK.txt ED C 27739 Digital Data 12/7/2016 Electronic File: 1H -07A_5_ tapescan_BHI_CTK.txt ' ED C 27739 Digital Data 12/7/2016 Electronic File: 1H-07A_output.tap - ED C 27739 Digital Data 12/7/2016 Electronic File: 11-1-07A 21VID Final Log.tif - ED C 27739 Digital Data 12/7/2016 Electronic File: 1H -07A 51VID Final Log.tif , ED C 27739 Digital Data 12/7/2016 Electronic File: 1 H -07A 5TVDSS Final Log.tif - Log C 27739 Log Header Scans 0 0 2160110 KUPARUK RIV UNIT 11-1-07A LOG HEADERS ED C 27740 Digital Data 12/7/2016 Electronic File: 1H-07APB1 2MD Final.cgm - ED C 27740 Digital Data 12/7/2016 Electronic File: 1H-07APB1 51VID Final.cgm. ED C 27740 Digital Data 12/7/2016 Electronic File: 1H-07APS1 5TVDSS Final.cgm . ED C 27740 Digital Data P 12/7/2016 Electronic File: 1H-07APB1 2MD Flnal.PDWS ED C 27740 Digital Data if 12/7/2016 Electronic File: 1 H-07APB1 51VID Flnal.PDF' -� ED C 27740 Digital Data 12/7/2016 Electronic File: 1 H-07APB1 5TVDSS Flnal.PDF , ED C 27740 Digital Data 12/7/2016 Electronic File: 1H-07APB1 EOW - NAD27.pdf. ED C 27740 Digital Data 12/7/2016 Electronic File: 1H-07APB1 EOW - NAD27.txt ED C 27740 Digital Data 12/7/2016 Electronic File: 1H-07APB1 Final Surveys (Unconfirmed).csv ED C 27740 Digital Data 12/7/2016 Electronic File: 1H-07APB1 Survey Listing.txt - ED C 27740 Digital Data 12/7/2016 Electronic File: 1H-07APB1 Surveys.txt . ED C 27740 Digital Data 12/7/2016 Electronic File: 1 H- 07APB1_25_tapescan_BHI_CTK.txt - AOGCC Page 2 of 6 Friday, February 17, 2017 DATA SUBMITTAL COMPLIANCE REPORT 2/17/2017 Permit to Drill 2160110 Well Name/No. KUPARUK RIV UNIT 111-1-07A Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-20755-01-00 MD 9263 TVD 6712 Completion Date 10/21/2016 Completion Status 1WINJ Current Status 1WINJ UIC Yes ED C 27740 Digital Data 12/7/2016 Electronic File: 1H- 07APB 1_5_tapescan_B H I_CTK.txt ED C 27740 Digital Data 12/7/2016 Electronic File: 1H-07APB1_output.tap , ED C 27740 Digital Data 12/7/2016 Electronic File: 1H-07APB1 21VID Final Color.tif ED C 27740 Digital Data 12/7/2016 Electronic File: 1 H-07APB1 51VID Final Color.tif ' ED C 27740 Digital Data 12/7/2016 Electronic File: 1H-07APB1 5TVDSS Final Color.tif Log C 27740 Log Header Scans 0 0 2160110 KUPARUK RIV UNIT 11-1-07A P61 LOG HEADERS Log C 27741 Log Header Scans 0 0 2160110 KUPARUK RIV UNIT 11-1-07A P62 LOG HEADERS ED C 27741 Digital Data 7475 9013 12/7/2016 Electronic Data Set, Filename: 1H-07APB2 GAMMA RES.Ias ED C 27741 Digital Data 12/7/2016 Electronic File: 1 H-07APB2 21VID Final.cgm . ED C 27741 Digital Data 12/7/2016 Electronic File: 1 H-07APB2 51VID Final.cgm, ED C 27741 Digital Data 12/7/2016 Electronic File: 1 H-07APB2 5TVDSS Final.cgm' ED C 27741 Digital Data P 12/7/2016 Electronic File: 1H-07APB2 21VID Flnal.PDF, ED C 27741 Digital Data 912/7/2016 Electronic File: 1H-07APB2 51VID Final.PDF. ED C 27741 Digital Data \ 12/7/2016 Electronic File: 1H-07AP62 5TVDSS Flnal.PDF, ED C 27741 Digital Data 12/7/2016 Electronic File: 1H-07APB2 EOW - NAD27.pdf ED C 27741 Digital Data 12/7/2016 Electronic File: 1 H-07AP62 EOW - NAD27.txt ' ED C 27741 Digital Data 12/7/2016 Electronic File: 1H-07APB2 Final Surveys TD 9013.csv ED C 27741 Digital Data 12/7/2016 Electronic File: 1 H-07APB2 Survey Listing.txt ED C 27741 Digital Data 12/7/2016 Electronic File: 1H-07APB2 Surveys.txt ED C 27741 Digital Data 12/7/2016 Electronic File: 1H- 07AP132_25_tapescan_BHI_CTK.txt ED C 27741 Digital Data 12/7/2016 Electronic File: 11-1- 07APB2_5_tapescan_B H I_CTK.txt ED C 27741 Digital Data 12/7/2016 Electronic File: 1 H-07APB2_output.tap. ED C 27741 Digital Data 12/7/2016 Electronic File: 1H-07APB2 21VID Final.tif. ED C 27741 Digital Data 12/7/2016 Electronic File: 1H-07APB2 51VID Final.tif` AOGCC Page 3 of 6 Friday, February 17, 2017 DATA SUBMITTAL COMPLIANCE REPORT 2/17/2017 Permit to Drill 2160110 Well Name/No. KUPARUK RIV UNIT 11-11-07A Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-20755-01-00 MD 9263 TVD 6712 Completion Date 10/21/2016 Completion Status 1WINJ Current Status 1WINJ UIC Yes ED C 27741 Digital Data 12/7/2016 Electronic File: 1H-07APB2 5TVDSS Final.tif ' ED C 27742 Digital Data 7475 8790 12/7/2016 Electronic Data Set, Filename: 1H-07AP133 GAMMA RES.Ias ED C 27742 Digital Data 12/7/2016 Electronic File: 1 H-07APB3 2MD Final Log.cgm ED C 27742 Digital Data 12/7/2016 Electronic File: 1 H-07AP63 51VID Final Log.cgm ' ED C 27742 Digital Data 12/7/2016 Electronic File: 1H-07APB3 5TVDSS FlnaJ Log.cgm ED C 27742 Digital Data 12/7/2016 Electronic File: 1 H-07AP63 2MD Final.PDF' ED C 27742 Digital Data P 12/7/2016 Electronic File: 1 H-07APB3 51VID Final.PDF ED C 27742 Digital Data 12/7/2016 Electronic File: 1 H-07APB3 5TVDSS Final.pdf ED C 27742 Digital Data 12/7/2016 Electronic File: 1 H-07APB3 EOW - NAD27.pdf ED C 27742 Digital Data 12/7/2016 Electronic File: 1 H-07AP63 EOW - NAD27.txt ' ED C 27742 Digital Data 12/7/2016 Electronic File: 1 H-07APB3 Final SurveysTD , 8790.csv ED C 27742 Digital Data 12/7/2016 Electronic File: 1H-07APB3 Survey Listing.txt ED C 27742 Digital Data 12/7/2016 Electronic File: 1H-07APB3 Surveys.txt ED C 27742 Digital Data 12/7/2016 Electronic File: 1H- 07AP63_25_tapescan_BHI CTK.txt ED C 27742 Digital Data 12/7/2016 Electronic File: 11-1- 07APB3_5_tapescan_B H I_CTK.txt ,' ED C 27742 Digital Data 12/7/2016 Electronic File: 1H-07APB3_output.tap ED C 27742 Digital Data 12/7/2016 Electronic File: 1H-07APB3 21VID Final Log.tif ED C 27742 Digital Data 12/7/2016 Electronic File: 1H-07APB3 5MD Final Log.tif ED C 27742 Digital Data 12/7/2016 Electronic File: 1H-07APB3 5TVDSS Final Log.tif . Log C 27742 Log Header Scans 0 0 2160110 KUPARUK RIV UNIT 1 H -07A P63 LOG HEADERS ED C 27748 Digital Data 7972 7450 11/15/2016 Electronic Data Set, Filename: 1H- 07A_MFC24_13OCT16.1as ED C 27748 Digital Data P 11/15/2016 Electronic File: 1H-07A_MFC24_13OCT16.pdf ED C 27748 Digital Data 11/15/2016 Electronic File: 1H- 07A_MFC24_13OCT16_Report.pdf AOGCC Page of Friday, February 17, 2017 DATA SUBMITTAL COMPLIANCE REPORT 2/17/2017 Permit to Drill 2160110 Well Name/No. KUPARUK RIV UNIT 11-1-07A Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-20755-01-00 MD 9263 TVD 6712 Completion Date 10/21/2016 Completion Status 1WINJ Current Status 1WINJ UIC Yes ED C 27748 Digital Data 11/15/2016 Electronic File: 1H- 07A_MFC24_13OCT 16_i mg.tif ED C 27748 Digital Data 11/15/2016 Electronic File: WIVArun.zip - ED C 27748 Digital Data 11/15/2016 Electronic File: 11-1- 07A MFC24 13OCT16 CENTERED.cmi ' ED C 27748 Digital Data 11/15/2016 Electronic File: 1H - 07A MFC24 13OCT16 CENTERED.wvd ED C 27748 Digital Data 11/15/2016 Electronic File: 11-1- 07A_MFC24_13OCT16_CENTERED.wvp ED C 27748 Digital Data 11/15/2016 Electronic File: 1H - 07A MFC24 13OCT16 UNCENTERED.cmi ' ED C 27748 Digital Data 11/15/2016 Electronic File: 1H - 07A MFC24 13OCT16 UNCENTERED.wvd ED C 27748 Digital Data 11/15/2016 Electronic File: 11-1- 07A_MFC24_13OCT16_UNCENTERED.wvp Log C 27748 Log Header Scans 0 0 2160110 KUPARUK RIV UNIT 1H -07A LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report Y� Production Test Information Y NA Geologic Markers/Tops O COMPLIANCE HISTORY Completion Date: 10/21/2016 Release Date: 1/22/2016 Description Directional / Inclination Data ® Mud Logs, Image Files, Digital Data Y/rnq Core Chips Y Mechanical Integrity Test Information Y Composite Logs, Image, Data Files E) Core Photographs Y /lll/// Daily Operations Summary OY Cuttings Samples Y / l� Laboratory Analyses Y Date Comments AOGCC Page 5 of 6 Friday, February 17, 2017 DATA SUBMITTAL COMPLIANCE REPORT 2/17/2017 Permit to Drill 2160110 Well Name/No. KUPARUK RIV UNIT 111-11-07A Operator CONOCOPHILLIPS ALASKA INC MD 9263 TVD 6712 Completion Date 10/21/2016 Completion Status 1WINJ Current Status 1WINJ Comments: Compliance Review ed By: Date: API No. 50-029-20755-01-00 UIC Yes AOGCC Page 6 of 6 Friday, February 17, 2017 Fr&11 Y E BAKERDEI, 0 201E PRINT HUGHES COMPANY 6cdThikips Alaska, inc. WELL NAME IH -07A FIELD Prudhoe Bay Unit COUNTY North Slope Borough Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. RiderCcDbakerhughes.com DISTRIBUTION LIST 27 7 3 9 Please sign and return one copy of this transmittal form to ConocoPhillips Alaska, Inc. Tom Osterkamp DATA LOGGED 700 G Street. `Z,/9 /201(0 M. K. BENDER Anchorage, Alaska 99510 to acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE October 17, 2016 TODAYS DATE December 5, 2016 Revision STATUS Final Replacement: No Details: Requested by: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BO.$ PERSON ATTENTION Ca] FIELD FINAL CD CD LOGS LOGS (digital/image) I Surveys (Final Surveys) # OF PRINTS # OF PRIN I S # OF COPIES # OF COPIES # OF CORE 1 BP North Slope 0 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids Agatha Rutka & Barbara Glassmaker 1900 E. Benson Blvd. 'Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgaricio ATO 3-344 700 G Street Anchorage, AK 99510 3 F.xx Mno Mno obil, Alaska 0 0 0 Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4FtateofAlaska -AOGCC 1 1 1 Attn: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 57DNRivision of Oil & Gassource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential' on all material deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotecbnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: TOTALS FOR ALL PAGES: 0 2 3 3 0 0 0 2 3 3 0 0 11bU11 27 73 9 ConocoPhilli s DEC 07 2016 AOGCC ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad 1 H -07A 50-029-20755-01 Baker Hughes INTEQ //a I Definitive Survey Report NU6NES 24 October, 2016 ConocoPhillips � Ras ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Coordinate Reference: Well 11-1-07 Project: Kuparuk River Unit TVD Reference: 1 H-07 @ 85.00usft (1 H-07) Site: Kuparuk 1 H Pad MD Reference: 1 H-07 @ 85.00usft (1 H-07) Well: 1 H-07 North Reference: True Wellbore: 1 H -07A Survey Calculation Method: Minimum Curvature Design: 1 H -07A Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1 H-07 Well Position +N/ -S 0.00 usft Northing: 5,979,935.13 usft Latitude: 70° 21'21.476 N +E/ -W 0.00 usft Easting: 549,560.55usft Longitude: 149° 35'51.058 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1 H -07A Magnetics Model Name Sample Date Declination Dip Angle Field Strength C) (') (nT) BGG M2016 9/1/2016 18.07 80.98 57,554 Design 1 H -07A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,600.77 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (I 85.00 0.00 0.00 200.00 Survey Program Date 10/19/2016 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 100.00 7,800.00 1H-07 (1H-07) BOSS -GYRO Sperry -Sun BOSS gyro multishot 1/8/2001 7,840.50 7,930.52 1H-07APB1 (11-1-07AP131) MWD MWD - Standard 10/1/2016 10/6/2016 7,936.00 8,600.77 1 H-07APB3 (1 H-07APB3) MWD MWD - Standard 10/13/2016 10/16/2016 8,607.00 9,225.47 1H -07A (1H -07A) MWD MWD - Standard 10/16/2016 10/19/2016 Page 2 COMPASS 5000.1 Build 74 10/24/2016 5.24:31PM Survey ConocoPhillips WE as ConocoPhillips Definitive Survey Report BHUGHES Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Coordinate Reference: Well 1 H-07 Project: Kuparuk River Unit TVD Reference: 1 H-07 @ 85.00usft (1 H-07) TVD Site: Kuparuk 1 H Pad MD Reference: 1 H-07 @ 85.00usft (1 H-07) Northing Well: 1H-07 North Reference: True Annotation Wellbore: 1H -07A Survey Calculation Method: Minimum Curvature (usft) Design: 1H -07A Database: EDM Alaska NSK Sandbox (ft) Survey Map Map Vertical MD Inc Ao i TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section Survey Tool Name Annotation (usft) (°) () (usft) (usft) (usft) (usft) (ft) (ft) (°/700') (ft) 8,600.77 85.60 202.88 6,689.07 6,604.07 3,313.03 1,646.91 5,983,258.66 551,185.35 35.57 -3,676.50 MWD (3) TIP 8,607.00 85.62 201.74 6,689.55 6,604.55 3,307.28 1,644.55 5,983,252.90 551,183.03 18.31 -3,670.30 MWD (4) KOP 8,630.49 85.42 199.61 6,691.38 6,606.38 3,285.37 1,636.28 5,983,230.94 551,174.91 9.08 -3,646.88 MWD (4) 8,660.55 85.11 197.02 6,693.87 6,608.87 3,256.94 1,626.87 5,983,202.44 551,165.68 8.65 -3,616.94 MWD (4) 8,685.97 85.82 196.14 6,695.88 6,610.88 3,232.65 1,619.64 5,983,178.11 551,158.61 4.44 -3,591.65 MWD (4) 8,715.72 86.68 196.02 6,697.82 6,612.82 3,204.12 1,611.42 5,983,149.53 551,150.58 2.92 -3,562.03 MWD (4) 8,745.97 87.20 198.03 6,699.44 6,614.44 3,175.24 1,602.57 5,983,120.60 551,141,93 6.85 -3,531.86 MWD (4) 8,775.37 87.79 200.41 6,700.72 6,615.72 3,147.51 1,592.90 5,983,092.80 551,132.44 8.33 -3,502.50 MWD (4) 8,805.09 87.79 201.75 6,701.87 6,616.87 3,119.80 1,582.22 5,983,065.03 551,121.95 4.51 -3,472.81 MWD (4) 8,835.41 87.85 203.10 6,703.02 6,618.02 3,091.79 1,570.67 5,983,036.95 551,110.58 4.45 -3,442.54 MWD (4) 8,865.76 89.29 207.16 6,703.78 6,6.18.78 3,064.33 1,557.78 5,983,009.40 551,097.88 14.19 -3,412.32 MWD (4) 8,895.40 88.89 209.42 6,704.25 6,619.25 3,038.24 1,543.74 5,982,983.22 551,084.01 7.74 -3,383.00 MWD (4) 8,925.36 88.62 210.99 6,704.90 6,619.90 3,012.35 1,528.67 5,982,957.24 551,069.11 5.32 -3,353.52 MWD (4) 8,955.85 88.99 212.69 6,705.54 6,620.54 2,986.46 1,512.59 5,982,931.24 551,053.20 5.70 -3,323.69 MWD (4) 8,985.67 90.43 215.88 6,705.69 6,620.69 2,961.82 1,495.79 5,982,906.49 551,036.57 11.74 -3,294.79 MWD (4) 9,018.15 90.00 219.39 6,705.57 6,620.57 2,936.11 1,475.96 5,982,880.65 551,016.92 10.89 -3,263.85 MWD (4) 9,046.13 88.96 222.60 6,705.82 6,620.82 2,914.99 1,457.61 5,982,859.42 550,998.71 12.06 -3,237.73 MWD (4) 9,076.01 87.67 225.40 6,706.70 6,621.70 2,893.51 1,436.87 5,982,837.80 550,978.11 10.31 -3,210.45 MWD (4) 9,105.95 87.36 228.70 6,708.00 6,623.00 2,873.13 1,414.98 5,982,817.28 550,956.35 11.06 -3,183.81 MWD (4) 9,135.75 87.58 230.06 6,709.31 6,624.31 2,853.75 1,392.38 5,982,797.75 550,933.89 4.62 -3,157.87 MWD (4) 9,166.20 88.74 231.94 6,710.29 6,625.29 2,834.60 1,368.73 5,982,778.44 550,910.37 7.25 -3,131.78 MWD (4) 9,195.45 90.12 234.51 6,710.58 6,625.58 2,817.09 1,345.31 5,982,760.78 550,887.06 9.97 -3,107.32 MWD (4) 9,225.47 88.71 231.46 6,710.89 6,625.89 2,799.02 1,321.34 5,982,742.56 550,863.22 11.19 -3,082.14 MWD (4) 9,263.00 88.71 231.46 6,711.73 6,626.73 2,775.64 1,291.99 5,982,718.99 550,834.03 0.00 -3,050.14 PROJECTED to TD 10/24/2016 5:24:31PM Page 3 COMPASS 5000.1 Build 74 /�DEC 0 7 201E BAKER HUGHES r PRINT DISTRIBUTION LIST COMPANY ConocoPhillips Alaska, Inc. WELL NAME 1 H-07APB1 FIELD Prudhoe Bay Unit COUNTY North Slope Borough BHI DISTRICT Alaska 216011 27 740 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp DATA LOGGED 700 G Street. \Z/9 12016 M K. BENDER Anchorage, Alaska 99510 Ito acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE October 17, 2016 AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider(a-)bakerhughes.corn TODAYS DATE December 5, 2016 Revision STATUS Final Replacement: No Details: Requested by: --- COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BO* PERSON ATTENTION FIELD FINAL 4 4 4 4 CD 0 LOGS LOGS ICD (digital/image) Surveys (Final Surveys) # OF PRINTS # OF F'RIN 1 S # OF COPIES # OF COPIES # OF COPIE 4 4 4 4 4 4 1 !BP North Slope 0 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids Agatha Rutka & Barbara Glassmaker 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 0 Attn: Ricky Elgaricio ATO 3-344 700 G Street Anchorage, AK 99510 3 ExxonMobil, Alaska Attn: L nda M Yaskell and/or I eonardo Elias 0 0 0 3201 C Street, Suite 505 ,Anchorage, AK 99503 0tate of Alaska - AOGCC Attn: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR -Division of Oil & Gas *** Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential' on all material deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. ,Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: TOTALS FOR ALL PAGES: 1 1 1 0 2 3 3 0 0 0 2 3 3 0 0 21 6011 27 740 ConocoPhilli s �mfe I I.�� J 0\0CAC "C ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1 H Pad 1 H-07APB1 50-029-20755-70 Baker Hughes INTEQ WE a I Definitive Survey Report �UGNES 24 October, 2016 ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 1 H-07 Wellbore: 1 H-07APB1 Design: 1 H-07APB 1 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well 1 H-07 ConocoPhillips Definitive Survey Report Local Coordinate Reference: Well 1 H-07 TVD Reference: 1 H-07 @ 85.00usft (1 H-07) MD Reference: 1 H-07 @ 85.00usft (1 H-07) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM Alaska NSK Sandbox Well Position +N/ -S 0.00 usft Northing: Tie On Depth: 7,800.00 +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 1H-07APB1 (usft) Magnetics Model Name Sample Date 0.00 BGGM2016 9/1/2016 Design 1H-07APB1 From Audit Notes: Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,979,935.13 usft 549, 560.55 usft usft Declination V) '18.07 Version: 1.0 Phase: ACTUAL Tie On Depth: 7,800.00 Vertical Section: Depth From (TVD) +N/ -S (usft) (usft) Description Start Date 85.00 0.00 Survey Program Date 10/6/2016 10/1/2016 From To (usft) (usft) Survey (Wellbore) Tool Name 100.00 7,800.00 1H -07(1H-07) BOSS -GYRO 7,840.50 9,338.22 1H-07APB1 (11-1-07AP61) MWD Latitude: Longitude: Ground Level: rias BAKER HUGHES 70° 21'21.476 N 1490 35' 51.058 W 0.00 usft Dip Angle Field Strength (`) (nT) 80.98 57,554 +E/ -W Direction (usft) V) 0.00 200.00 Survey Survey Description Start Date End Date Sperry -Sun BOSS gyro multishot 1/8/2001 MWD - Standard 10/1/2016 10/6/2016 10/24/2016 5:25:36PM Page 2 COMPASS 5000 1 Build 74 Survey MD ConocoPhillips Azi FeA&I ConocoPhillips +N/ -S +E1 -W BAKER Map Definitive Survey Report Vertical HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1 H-07 (uaft) Project: Kuparuk River Unit TVD Reference: 1 H-07 @ 85.00usft (1 H-07) Northing Site: Kuparuk 1 H Pad MD Reference: 1 H-07 @ 85.00usft (1 H-07) Annotation Well: 1H-07 North Reference: True Wellbore: 1 H-07APB1 Survey Calculation Method: Minimum Curvature (ft) Design: 1H-07APB1 Database: EDM Alaska NSK Sandbox Survey MD Inc Azi TVD TVDSS +N/ -S +E1 -W Map Map DLS Vertical luaft) ° () (°) (uaft) (usft) (uaft) (usft) Northing Easting (°1100') Section Survey Tool Name Annotation (ft) (ft) (ft) 7,800.00 31.97 55.69 6,529.91 6,444.91 2,999.74 1,862.27 5,982,946.83 551,402.75 0.37 -3,455.77 MWD (2) TIP 7,840.50 31.77 55.94 6,564.31 6,479.31 3,011.76 1,879.96 5,982,958.96 551,420.36 0.59 -3,473.11 MWD (2) KOP 7,871.39 43.90 40.32 6,588.71 6,503.71 3,024.55 1,893.70 5,982,971.85 551,434.02 49.78 -3,489.84 MWD (2) 7,900.08 53.42 30.09 6,607.67 6,522.67 3,042.17 1,905.96 5,982,989.55 551,446.16 42.56 -3,510.58 MWD (2) 7,930.52 62.75 21.96 6,623.76 6,538.76 3,065.37 1,917.19 5,983,012.82 551,457.23 38.09 -3,536.23 MWD (2) 7,960.31 67.69 15.58 6,636.26 6,551.26 3,090.97 1,925.85 5,983,038.47 551,465.73 25.55 -3,563.24 MWD (2) 7,989.53 72.23 5.17 6,646.29 6,561.29 3,117.92 1,930.75 5,983,065.45 551,470.45 36.88 -3,590.24 MWD (2) 8,019.45 72.38 352.95 6,655.42 6,570.42 3,146.36 1,930.28 5,983,093.88 551,469.79 38.91 -3,616.81 MWD (2) 8,049.41 70.40 341.46 6,665.01 6,580.01 3,173.99 1,924.03 5,983,121.47 551,463.35 36.93 -3,640.63 MWD (2) 8,080.19 68.31 328.89 6,675.90 6,590.90 3,200.08 1,911.98 5,983,147.47 551,451.14 38.80 -3,661.03 MWD (2) 8,104.59 67.74 319.72 6,685.04 6,600.04 3,218.43 1,898.80 5,983,165.74 551,437.84 34.92 -3,673.76 MWD (2) 8,135.61 69.43 308.05 6,696.40 6,611.40 3,238.39 1,878.02 5,983,185.56 551,416.93 35.43 -3,685.42 MWD (2) 8,165.59 71.94 297.35 6,706.34 6,621.34 3,253.63 1,854.25 5,983,200.64 551,393.05 34.70 -3,691.60 MWD (2) 8,195.54 75.29 287.52 6,714.81 6,629.81 3,264.56 1,827.72 5,983,211.39 551,366.46 33.41 -3,692.80 MWD (2) 8,226.35 75.86 276.56 6,722.51 6,637.51 3,270.77 1,798.59 5,983,217.41 551,337.29 34.50 -3,688.67 MWD (2) 8,255.61 76.88 264.25 6,729.43 6,644.43 3,270.97 1,770.22 5,983,217.42 551,308.92 41.03 -3,679.15 MWD (2) -- 8,286.45 79.01 253.66 6,735.89 6,650.89 3,265.19 1,740.66 5,983,211.44 551,279.41 34.28 -3,663.61 MWD (2) 8,316.02 81.84 240.80 6,740.82 6,655.82 3,253.91 1,713.85 5,983,199.99 551,252.67 43.93 -3,643.85 MWD (2) 8,360.84 88.13 224.01 6,744.77 6,659.77 3,226.76 1,678.63 5,983,172.61 551,217.64 39.85 3,606.29 MWD (2) 8,392.67 90.37 220.63 6,745.19 6,660.19 3,203.23 1,657.21 5,983,148.95 551,196.37 12.74 -3,576.85 MWD (2) 8,420.50 90.18 219.24 6,745.05 6,660.05 3,181.90 1,639.35 5,983,127.49 551,178.65 5.04 -3,550.69 MWD (2) 8,451.01 90.15 216.52 6,744.96 6,659.96 3,157.82 1,620.61 5,983,103.29 551,160.08 8.92 -3,521.66 MWD (2) 8,480.36 90.21 214.41 6,744.87 6,659.87 3,133.91 1,603.59 5,983,079.28 551,143.21 7.19 -3,493.37 MWD (2) 8,512.46 89.42 211.83 6,744.98 6,659.98 3,107.03 1,586.05 5,983,052.28 551,125.86 8.41 -3,462.12 MWD (2) 8,540.92 88.71 208.95 6,745.44 6,660.44 3,082.49 1,571.66 5,983,027.65 551,111.63 10.42 -3,434.13 MWD (2) 8,569.88 90.03 206.85 6,745.76 6,660.76 3,056.90 1,558.11 5,983,001.97 551,098.25 8.56 3,405.45 MWD (2) 8,600.11 90.71 208.59 6,745.56 6,660.56 3,030.14 1,544.05 5,982,975.12 551,084.37 6.18 -3,375.49 MWD (2) 8,629.63 91.81 211.27 6,744.91 6,659.91 3,004.56 1,529.32 5,982,949.45 551,069.81 9.81 -3,346.43 MWD (2) 8,659.66 91.38 213.03 6,744.08 6,659.08 2,979.15 1,513.35 5,982,923.94 551,054.01 6.03 -3,317.08 MWD (2) 8,687.39 92.67 214.80 6,743.10 6,658.10 2,956.15 1,497.89 5,982,900.84 551,038.70 7.89 -3,290.18 MWD (2) 10/24/2016 5:25:36PM Page 3 COMPASS 5000.1 Build 74 y'ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Co-ordinate Reference: Well 1 H-07 Project: Kuparuk River Unit TVD Reference: 1H-07 @ 85.00usft (1H-07) Site: Kuparuk 1 H Pad MD Reference: 1 H-07 @ 85.00usft (1 H-07) Well: 1 H-07 North Reference: True Wellbore: 1 H-07APB1 Survey Calculation Method: Minimum Curvature Design: 1 H-07APB1 Database: EDM Alaska NSK Sandbox Survey Annotation MAP itI BAKER HUGHES 10/24/2016 5: 25 36P Page 4 COMPASS 5000 1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing g Eag DLS Section Section Survey Tool Name (usft) (I V) (usft) (usft) (usft) (usft) Ith (ft) [ft) (°/100') 8,720.21 92.52 216.10 6,741.61 6,656.61 2,929.45 1,478.87 5,982,874.01 551,019.87 3.98 -3,258.58 MWD (2) 8,744.58 92.49 219.42 6,740.55 6,655.55 2,910.20 1,463.96 5,982,854.67 551,005.09 13.61 -3,235.40 MWD (2) 8,774.58 94.33 221.98 6,738.76 6,653.76 2,887.50 1,444.44 5,982,831.84 550,985.72 10.50 -3,207.39 MWD (2) 8,804.44 94.24 224.65 6,736.53 6,651.53 2,865.84 1,424.01 5,982.810.04 550,965.44 8.92 -3,180.05 MWD (2) 8,834.70 94.39 227.01 6,734.25 6,649.25 2,844.81 1,402.37 5,982,788.88 550,943.94 7.79 -3,152.89 MWD (2) 8,866.07 94.39 229.76 6,731.85 6,646.85 2,824.04 1,378.99 5.982.767.96 550,920.69 8.74 -3,125.37 MWD (2) 8,896.18 94.92 230.67 6,729.41 6,644.41 2,804.84 1,355.93 5,982,748.60 550,897.76 3.49 -3,099.44 MWD (2) 8,926.13 95.63 233.32 6,726.65 6,641.65 2,786.48 1,332.43 5,982,730.09 550,874.39 9.12 -3,074.15 MWD (2) 8,956.06 96.03 236.01 6,723.61 6,638.61 2,769.26 1,308.14 5,982,712.71 550,850.22 9.04 -3,049.66 MWD (2) 8,986.05 96.25 238.19 6,720.41 6,635.41 2,753.06 1,283.11 5,982,696.35 550.825.30 7.26 -3,025.88 MWD (2) 9,016.57 96.43 240.32 6,717.03 6,632.03 2,737.56 1,257.04 5,982,680.68 550,799.33 6.96 -3,002.39 MWD (2) 9,046.26 95.69 237.67 6,713.90 6,628.90 2,722.35 1,231.74 5,982.665.30 550,774.13 9.22 -2,979.45 MWD (2) 9,076.10 94.74 236.06 6,711.19 6,626.19 2,706.11 1,206.86 5,982,648.90 550,749.36 6.25 -2,955.68 MWD (2) 9,107.87 90.95 234.27 6,709.61 6,624.61 2,687.98 1,180.82 5,982,630.60 550,723.45 13.19 -2,929.74 MWD (2) 9,138.78 89.63 233.96 6,709.45 6,624.45 2,669.87 1,155.78 5,982,612.32 550,698.53 4.39 -2,904.15 MWD (2) 9,170.29 90.86 231.84 6,709.32 6,624.32 2,650.86 1,130.65 5,982,593.15 550,673.53 7.78 -2,877.70 MWD (2) 9,200.50 92.09 231.37 6,708.54 6,623.54 2,632.10 1,106.98 5,982,574.24 550,649.98 4.36 -2,851.98 MWD (2) 91230.58 93.68 230.13 6,707.03 6,622.03 2,613.10 1,083.71 5,982,555.09 550,626.85 6.70 -2,826.16 MWD (2) 9,260.58 95.01 229.62 6,704.76 6,619.76 2,593.82 1,060.84 5,982.535.66 550,604.11 4.75 -2,800.22 MWD (2) 9,290.40 96.18 229.42 6,701.85 6,616.85 2,574.55 1,038.27 5,982,516.25 550,581.66 3.98 -2,774.40 MWD (2) 9,320.29 96.40 228.85 6,698.57 6,613.57 2,555.12 1,015.80 5,982.496.66 550,559.33 2.03 -2,748.45 MWD (2) 9,338.22 95.04 227.79 6,696.79 6,611.79 2,543.25 1,002.48 5,982.484.71 550,546.08 9.60 -2,732.74 MWD (2) 9,378.00 95.04 227.79 6,693.29 6,608.29 2,516.63 973.12 5,982,457.90 550,516.91 0.00 -2,697.69 PROJECTED to TD Annotation MAP itI BAKER HUGHES 10/24/2016 5: 25 36P Page 4 COMPASS 5000 1 Build 74 BAKER DEC0'� 2il a PRINT DISTRIBUTION LIST HUGHES AorArlc COMPANY ConocoPhillips Alaska, Inc. WELL NAME 1H-07APB2 FIELD Prudhoe Bay Unit COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider@bakerhughes.com STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BO)J PERSON ATTENTION 2 1 60 1 1 27741 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp DATA LOGGED \.1i q/zolm 700 G Street. ,.l K. BENDER Anchorage, Alaska 99510 to acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE October 17, 2016 TODAYS DATE December 5, 2016 Revision No Details: Requested by: FIELD FINAL CD CD BP North Slope LOGS LOGS igital/image) [OF Surveys 1# (Final Surveys) 1# # OF PRINTS # OF F'RIN 16 COPIES OF COPIES OF COPIEF-1 ATO 3-344 700 G Street Anchorage, AK 99510 3 �ExxonMobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 (Anchorage, AK 99503 4 State of Alaska - AOGCC Attn: Makana Bender 333 W. 7th Ave, Suite 100 (Anchorage, Alaska 99501 5 DNR -Division of Oil & Gas *** 0 1 1 Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential' on all material deliver to DNR 6 BP Exploration (Alaska) Inc. 1 1 1 Petrotechnical Data Center, LR24 900 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 0 TOTALS FOR ALL PAGES: 0 2 3 3 0 0 1 BP North Slope 0 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids Agatha Rutka & Barbara Glassmaker 900 E. Benson Blvd. lAnchorage, Alaska 99508 J 2 ConocoPhillips Alaska Inc. 0 0 0 Attn: Ricky Elgaricio ATO 3-344 700 G Street Anchorage, AK 99510 3 �ExxonMobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 (Anchorage, AK 99503 4 State of Alaska - AOGCC Attn: Makana Bender 333 W. 7th Ave, Suite 100 (Anchorage, Alaska 99501 5 DNR -Division of Oil & Gas *** 0 1 1 Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential' on all material deliver to DNR 6 BP Exploration (Alaska) Inc. 1 1 1 Petrotechnical Data Center, LR24 900 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 0 TOTALS FOR ALL PAGES: 0 2 3 3 0 0 ConocoPhilli s p ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1H Pad 1 H-07APB2 50-029-20755-71 Baker Hughes INTEQ Definitive Survey Report 24 October, 2016 CLEC 0 ? 2016 21 6011 27 74 1 FM as BAKER 11!l6NES ConocoPhillips /elks �. ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1 H-07 Project: Kuparuk River Unit TVD Reference: 1 H-07 @ 85.00usft (1 H-07) Site: Kuparuk 1 H Pad MD Reference: 1 H-07 @ 85.00usft (1 H-07) Well: 1 H-07 North Reference: True Wellbore: 1 H-07APB2 Survey Calculation Method: Minimum Curvature Design: 1 H-07APB2 Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well IH-07 Well Position +N/-S 0.00 usft Northing: 5,979,935.13usft Latitude: 70° 21' 21.476 N +E/-W 0.00 usft Easting: 549,560.55usft Longitude: 149° 35'51.058 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1 H-07APB2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I (I (nT) BGG M2016 9/l/2016 18.07 80.98 57,554 Design 1 H-07APB2 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,989.53 Vertical Section: Depth From (TVD) +NIS +E/-W Direction (usft) (usft) (usft) (I 85.00 0.00 0.00 200.00 Survey Program Date 10/12/2016 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 100.00 7,800.00 1H-07 (1H-07) BOSS-GYRO Sperry-Sun BOSS gyro multishot 1/8/2001 7,840.50 7,989.53 1H-07APB1 (11-1-07AP81) MWD MWD- Standard 10/1/2016 10/6/2016 7,999.00 8,965.89 1 H-07APB2 (1 H-07APB2) MWD MWD - Standard 10/7/2016 10/12/2016 10/24/2016 5:26:32PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips Azi IGkI TVDSS Definitive Survey Report +E/ -W BAKER U NES Map Vertical Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1 H-07 (usft) Project: Kuparuk River Unit TVD Reference: 1 H-07 @ 85.00usft (1 H-07) Northing Site: Kuparuk 1 H Pad MD Reference 1 H-07 @ 85.00usft (1 H-07) Annotation Well: 1 H-07 North Reference: True 6,646.29 Wellbore: 1 H-07APB2 Survey Calculation Method: Minimum Curvature 5,983,065.45 Design: 1 H-07APB2 Database: EDM Alaska NSK Sandbox Survey MD Inc Azi TVD TVDSS +N/ -S +E/ -W Map Map Vertical usft ( ) (°) (°) (usft) (usft) (usft) (usft) Northing Easting DLS (°/100•) Section Survey Tool Name Annotation 7,989.53 72.23 5.17 6,646.29 6,561.29 3,117.92 1,930.75 5,983,065.45 551,470.45 36.88 (ft) -3,590.24 MWD (2) 7,999.00 72.19 1.30 6,649.19 6,564.19 3,126.92 1,931.26 5,983,074.46 551,470.90 38.90 -3,598.88 MWD (3) TIP 8,030.90 84.09 357.37 6,655.73 6,570.73 3,158.08 1,930.88 5,983,105.60 551,470.31 39.18 -3,628.02 MWD (3) KOP 8,060.84 87.39 344.81 6,657.96 6,572.96 3,187.51 1,926.26 5,983,135.00 551,465.49 43.26 -3,654.10 MWD (3) 8,091.05 86.34 331.59 6,659.62 6,574.62 3,215.45 1,915.06 5,983,162.87 551,454.13 43.83 -3,676.54 MWD (3) 8,120.83 86.31 318.80 6,661.54 6,576.54 3,239.81 1,898.15 5,983,187.11 551,437.04 42.86 -3,693.63 MWD (3) 8,150.64 87.08 305.12 6,663.27 6,578.27 3,259.66 1,876.07 5,983,206.81 551,414.84 45.89 -3,704.73 MWD (3) 8,180.72 87.85 292.68 6,664.60 6,579.60 3,274.15 1,849.82 5,983,221.13 551,388.49 41.39 -3,709.37 MWD (3) 8,210.61 83.29 280.36 6,666.92 6,581.92 3,282.61 1,821.31 5,983,229.40 551,359.93 43.82 -3,707.57 MWD (3) 8,240.74 80.87 267.24 6,671.09 6,586.09 3,284.60 1,791.61 5,983,231.19 551,330.21 43.87 -3,699.28 MWD (3) 8,270.62 79.94 254.16 6,676.09 6,591.09 3,279.85 1,762.60 5,983,226.25 551,301.24 43.27 -3,684.90 MWD (3) 8,300.88 80.60 239.87 6,681.23 6,596.23 3,268.23 1,735.22 5,983,214.45 551,273.94 46.59 -3,664.61 MWD (3) 8,330.13 80.72 226.15 6,686.00 6,601.00 3,250.91 1,712.22 5,983,196.98 551,251.06 46.28 -3,640.47 MWD (3) 8,360.77 80.76 222.94 6,690.93 6,605.93 3,229.36 1,691.01 5,983,175.29 551,230.00 10.34 -3,612.97 MWD (3) 8,390.28 81.44 220.14 6,695.50 6,610.50 3,207.54 1,671.68 5,983,153.35 551,210.81 9.65 -3,585.85 MWD (3) 8,420.09 83.61 220.14 6,699.37 6,614.37 3,184.95 1,652.63 5,983,130.63 551,191.91 7.28 -3,558.10 MWD (3) 8,449.99 86.04 220.27 6,702.07 6,617.07 3,162.21 1,633.41 5,983,107.76 551,172.84 8.14 -3,530.16 MWD (3) - 8,480.30 88.59 220.71 6,703.49 6,618.49 3,139.18 1,613.75 5,983,084.61 551,153.34 8.54 -3,501.80 MWD (3) 8,510.61 88.65 223.34 6,704.22 6,619.22 3,116.67 1,593.47 5,983,061.97 551,133.21 8.68 -3,473.71 MWD (3) 8,541.39 89.29 226.17 6,704.77 6,619.77 3,094.82 1,571.80 5,983,039.98 551,111.69 9.42 -3,445.77 MWD (3) 8,570.99 90.12 225.24 6,704.93 6,619.93 3,074.15 1,550.62 5,983,019.17 551,090,64 4.21 -3,419.10 MWD (3) 8,600.58 89.26 223.80 6,705.09 6,620.09 3,053.06 1,529.87 5,982,997.94 551,070.04 5.67 -3,392.18 MWD (3) 8,630.79 88.68 220.73 6,705.63 6,620.63 3,030.71 1,509.56 5,982,975.46 551,049.88 10.34 -3,364.23 MWD (3) 8,660.51 88.83 217.82 6,706.28 6,621.28 3,007.71 1,490.75 5,982,952.34 551,031.22 9.80 -3,336.19 MWD (3) 8,691.11 88.28 215.22 6,707.05 6,622.05 2,983.12 1,472.55 5,982,927.64 551,013.19 8.68 -3,306.86 MWD (3) 8,721.19 89.08 214.15 6,707.74 6,622.74 2,958.40 1,455.43 5,982,902.80 550,996.24 4.44 -3,277.77 MWD (3) 8,751.35 91.10 216.53 6,707.69 6,622.69 2,933.80 1,437.99 5,982,878.09 550,978.96 10.35 -3,248.69 MWD (3) 8,781.19 90.12 218.66 6,707.38 6,622.38 2,910.16 1,419.79 5,982,854.33 550,960.92 7.86 -3,220.25 MWD (3) 8,811.19 89.72 221.18 6,707.42 6,622.42 2,887.15 1,400.54 5,982,831.20 550,941.82 8.51 -3,192.05 MWD (3) 8,841.19 89.20 222.47 6,707.70 6,622.70 2,864.80 1,380.53 5,982,808.72 550,921.97 4.64 -3,164.20 MWD (3) 10/24/2016 5:26:32PM Page 3 COMPASS 5000. 1 Build 74 Annotation FfAbI BAKER HUGHES 10/24/2016 5: 26 32P Page 4 COMPASS 5000 1 Build 74 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1 H-07 Project: Kuparuk River Unit TVD Reference: 1 H-07 @ 85.00usft (1 H-07) Site: Kuparuk 1 H Pad MD Reference: 1 H-07 @ 85.00usft (1 H-07) Well: 1 H-07 North Reference: True Wellbore: 1 H-07APB2 Survey Calculation Method: Minimum Curvature Design: 1 H-07AP62 Database: EDM Alaska NSK Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +EI -W Northing DLS Easting Section (usft) (°) (°) (usft) (usft) (usft) (usft) (°1100') Survey Tool Name (ft) (ft) (ft) 8,870.49 88.43 224.73 6,708.31 6,623.31 2,843.58 1,360.33 5,982,787.38 550,901.91 8.15 -3,137.36 MWD (3) 8,905.03 87.97 228.19 6,709.39 6,624.39 2,819.81 1,335.31 5,982,763.43 550,877.05 10.10 -3,106.46 MWD (3) 8,935.25 89.26 232.33 6,710.12 6,625.12 2,800.50 1,312.09 5,982.743.97 550,853.95 14.35 -3,080.37 MWD (3) 8,965.89 88.80 235.71 6,710.64 6,625.64 2,782.50 1,287.30 5,982,725.82 550,829.29 11.13 -3,054.98 MWD (3) 9,013.00 88.80 235.71 6,711.63 6,626.63 2,755.97 1,248.39 5,982,699.03 550.790.56 0.00 -3.016.73 PROJECTED to TD Annotation FfAbI BAKER HUGHES 10/24/2016 5: 26 32P Page 4 COMPASS 5000 1 Build 74 /rag BAKER HUGHES DECO 7 2016 PRINT DISTRIBUTION LIST COMPANY ConocoPhillips Alaska, Inc. WELL NAME 1H-07APB3 FIELD Prudhoe Bav Unit COUNTY North Slope Borough BHI DISTRICT Alaska 216011 27 74 2 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp DATA LOGGED 700 G Street. A2- /9 /toy C o ;.i K. BENDER Anchorage, Alaska 99510 to acknowledge receipt of this data. LOG TYPE LOG DATE GR - RES October 17, 2016 AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider(a)bakerhughes.com TODAYS DATE December 5, 2016 Revision STATUS Final Replacement: No Details: Requested by: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BO)) PERSON ATTENTION FIELD FINAL CD 4 4 CD 0 LOGS LOGS (digital/image) ]# Surveys (Final Surveys) # OF PRINTS # Ur PRIN 16 # OF COPIES OF COPIES # OF CORE _ JJ LJ 4 4 4 1 BP North Slope 0 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids Agatha Rutka & Barbara Glassmaker 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 0 Attn: Ricky Elgaricio ATO 3-344 700 G Street Anchorage, AK 99510 3 I ExxonMobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 (Anchorage, AK 99503 4State of Alaska - AOGCC Attn: Makana Bender 333 W. 7th Ave, Suite 100 (Anchorage, Alaska 99501 5 DNR - Division of Oil & Gas *** 0 Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential' on all material deliver to DNR 6I BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 0 TOTALS FOR ALL PAGES: 0 2 3 3 0 0 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1 H Pad 1 H-07APB3 50-029-20755-72 Baker Hughes INTEQ Definitive Survey Report 24 October, 2016 2 160 27 74 2 F&A a I BAKER M11GNE5 ✓ ConocoPhillips W/%I BAKER ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Coordinate Reference: Well 1 H-07 Project: Kuparuk River Unit TVD Reference: 1 H-07 @ 85.00usft (1 H-07) Site: Kuparuk 1 H Pad MD Reference: 1 H-07 @ 85.00usft (1 H-07) Well: 1 H-07 North Reference: True Wellbore: 1 H-07APB3 Survey Calculation Method: Minimum Curvature Design: 1 H-07AP63 Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1 H-07 Well Position +N/ -S 0.00 usft Northing: 5,979,935.13usft Latitude: 70° 21' 21.476 N +E/ -W 0.00 usft Easting: 549,560.55usft Longitude: 149° 35'51.058 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1 H-07APB3 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I (I (nT) BGGM2016 9/1/2016 18.07 80.98 57,554 Design 1 H-07APB3 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,930.52 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (') 85.00 0.00 0.00 200.00 Survey Program Date 10/19/2016 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 100.00 7,800.00 1H-07 (1H-07) BOSS -GYRO Sperry -Sun BOSS gyro multishot 1/8/2001 7,840.50 7,930.52 1H-07APB1 (1H-07APB1) MWD MWD - Standard 10/1/2016 10/6/2016 7,936.00 8,750.61 1H-07APB3 (1H-07APB3) MWD MWD - Standard 10/13/2016 10/16/2016 10/24/2016 5:27.27PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips , eA.I Definitive Survey Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Coordinate Reference: Well 1 H-07 Project: Kuparuk River Unit TVD Reference: 1 H-07 @ 85.00usft (1 H-07) Site: Kuparuk 1 H Pad MD Reference: 1 H-07 @ 85.00usft (1 H-07) Well: 1 H-07 North Reference: True Wellbore: 1 H-07APB3 Survey Calculation Method: Minimum Curvature Design: 11-1-07AP63 Database: EDM Alaska NSK Sandbox Survey MD Inc Azi TVD TVDSS +N/ -S +E/.W Map Map Vertical (usft) (I (I (usft) (usft) (usft (usft) Northing Easting DLS (%100') Section Survey Tool Name Annotation 7,930.52 62.75 21.96 6,623.76 6,538.76 3,065.37 1,917.19 (ft) 5,983,012.82 5511,,457.23 38.09 7,936.00 63.64 20.75 6,626.23 6,541.24 3,069.93 1,918.97 5,983,017.39 -3,,5536.23 MWD (2) TIP 7,965.76 75.21 27.00 6,636.68 6,551.69 3,095.32 551,458.98 25.54 -3,541.12 MWD (3) KOP 1,930.27 5,983,042.86 551,470.12 43.54 -3,568.85 MWD (3) 7,990.15 84.01 31.55 6,541.08 6,556.08 3,116.22 1,942.00 5,983,063.82 551,481.70 40.47 -3,592.49 MWD (3) 8,015.33 91.26 31.06 6,642.12 6,557.12 3,137.70 1,955.06 5,983,085.39 551,494.62 28.84 -3,617.14 MWD (3) 8,035.24 91.62 24.37 6,641.62 6,556.62 3,155.31 1,964.32 5,983,103.06 551,503.76 33.63 -3,636.86 MWD (3) 8,060.34 91.35 15.91 6,640.97 6,555.97 3,178.85 1,972.95 5,983,126.65 551,512.23 33.72 -3,661.93 MWD (3) 8,090.30 91.01 7.42 6,640.35 6,555.35 3,208.15 1,979.00 5,983,155.99 551,518.09 28.36 -3,691.54 MWD (3) 8,120.31 88.83 358.78 6,640.39 6,555,39 3,238.09 1,980.62 5,983,185.94 551,519.51 29.69 -3,720.22 MWD (3) 8,150.29 86.41 350.40 6,641.63 6,556.63 3,267.88 1,977.80 5,983,215.71 551,516.49 29.05 -3,747.25 MWD (3) 8,180.75 83.02 342.01 6,644.44 6,559.44 3,297.31 1,970.58 5,983,245.08 551,509.08 29.61 -3,772.43 MWD (3) 8,210.29 80.85 331.75 6,648.60 6,563.60 3,324.17 1,959.11 5,983,271.86 551,497.44 35.17 -3,793.75 MWD (3) 8,240.40 81.22 321.75 6,653.30 6,568.30 3,349.01 1,942.83 5,983,296.59 551,480.99 32.82 8,270.37 81.32 311.77 6,657.86 6,572.86 3,370.56 1,922.56 5,983,318.01 -3,811.52 MWD (3) 8,300.86 81.75 302.21 6,662.36 6,577.36 3,388.68 551,460.58 32.89 -3,824.85 MWD (3) 8,330.29 82.49 292.68 1,898.50 5,983,335.97 551,436.41 31.06 -3,833.65 MWD (3) 6,666.40 6,581.40 3,402.10 1,872.66 5,983,349.21 551,410.48 32.18 -3,837.42 MWD (3) 8,360.41 82.80 283.07 6,670.26 6,585.26 3,411.26 1,844.26 5,983,358.18 551,382.03 31.66 8,390.52 84.38 273.61 6,673.63 6,588.63 3,415.59 1,814.69 5,983,362.32 -3,836.31 MWD (3) 8,420.33 85.21 263.80 6,676.34 6,591.34 551,352.43 31.66 -3,830.26 MWD (3) 8,450.47 85.36 253.88 3,414.91 1,785.05 5,983,361.45 551,322.80 32.88 -3,819.49 MWD (3) 6,678.83 6,593.83 3,409.11 1,755.62 5,983,355.45 551,293.41 32.80 -3,803.97 MWD (3) 8,481.01 85.70 243.81 6,681.21 6,596.21 3,398.13 1,727.26 5,983,344,28 551,265.12 32.91 -3,783.96 MWD (3) 8,510.31 85.92 233.48 6,683.36 6,598.36 3,382.95 1,702.34 5,983,328.93 551,240.31 35.15 -3,761.16 MWD (3) 8,540.33 86.81 223.49 6,685.27 6,600.27 3,363.11 1,679.94 5,983,308.96 551,218.04 33.36 -3,734.87 MWD (3) 8,570.67 86.59 213.57 6,687.02 6,602.02 3,339.45 1,661.09 5,983,285.17 551,199.35 32.64 -3,706.18 MWD (3) 8,600.77 85.60 202.88 6,689.07 6,604.07 3,313.03 1,646.91 5,983,258.66 551,185.35 35.57 -3,676.50 MWD (3) 8,630.82 85.72 197.38 6,691.35 6,606.35 3,284.91 1,636.60 5,983,230.47 551,175.22 18.26 -3,646.55 MWD (3) 8,660.41 86.16 194.41 6,693.44 6,608.44 3,256.52 1,628.52 5,983,202.04 551,167.33 10.13 -3,617.12 MWD (3) 8,690.57 86.89 192.14 6,695.27 6,610.27 3,227.22 1,621.60 5,983,172.70 551,160.61 7.90 -3,587.22 MWD (3) 8,720.59 87.08 193.88 6,696.85 6,611.85 3,198.02 1,614.86 5,983,143.45 551,154.06 5.82 -3,557.47 MWD (3) 8,750.61 87.36 197.01 6,698.31 6,613.31 3,169.12 1,606.87 5,983,114.50 551,146.27 10.46 -3,527.58 MWD (3) 10/24/2016 5:2T 27PM Page 3 COMPASS 5000.1 Build 74 Survey MD Inc Azi (usft) (I C) 8,790.00 87.36 197.01 TVD TVDSS +N/ -S (usft) (usft) (usft) 6,700.12 6,615.12 3,131.49 ConocoPhillips Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map +E/ -W Northing (usft) (ft) 1,595.36 5,983,076.80 Well 1 H-07 1 H-07 @ 85.00usft (1 H-07) 1 H-07 @ 85.00usft (1 H-07) True Minimum Curvature EDM Alaska NSK Sandbox Map Vertical Easting DLS Section Survey Tool Name Annotation (ft) (°/100') (ft) 551,135.01 0.00 -3,488.29 PROJECTED to TD ri.9 BAKER HUGHES 10/24/2016 5 27:27PM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 1 H-07 Wellbore: 1 H-07APB3 Design: 1 H-07AP63 Survey MD Inc Azi (usft) (I C) 8,790.00 87.36 197.01 TVD TVDSS +N/ -S (usft) (usft) (usft) 6,700.12 6,615.12 3,131.49 ConocoPhillips Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map +E/ -W Northing (usft) (ft) 1,595.36 5,983,076.80 Well 1 H-07 1 H-07 @ 85.00usft (1 H-07) 1 H-07 @ 85.00usft (1 H-07) True Minimum Curvature EDM Alaska NSK Sandbox Map Vertical Easting DLS Section Survey Tool Name Annotation (ft) (°/100') (ft) 551,135.01 0.00 -3,488.29 PROJECTED to TD ri.9 BAKER HUGHES 10/24/2016 5 27:27PM Page 4 COMPASS 5000.1 Build 74 STATE OF ALASKA NOV 18 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ 0 ' WAG❑ WDSPL ❑ No. of Completions: 1 b. Well Class: Development ❑ Exploratory ❑ Service R1 . Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., Aband.: 4#4#t2646-� 14. Permit to Drill Number/ Sundry: 216-011 / 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 10/4/2016 15. API Number: 50-029-20755-01-00 4a. Location of Well (Governmental Section): Surface: 768' FNL, 788' FEL, Sec 33, T1 2N, R1 OE, UM Top of Productive Interval: 2916' FNL, 4466' FEL, Sec 27, T1 2N, R1 OE, UM Total Depth: 3272' FNL, 4770' FEL, Sec 27, T1 2N, R1 OE, UM 8. Date TD Reached: 10/18/2016 16. Well Name and Number: KRU 1H-07A/1H-07AP81/1H-07APB2/ 7 9. Ref Elevations: KB:85 GL: 50 BF:56 17. Field / Pool(s): Kupurak River Field/Kuparuk Oil Pool 10. Plug Back Depth MD/TVD: 9079/6707 , 18. Property Designation: ADL 25639 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 549560 y- 5979935 Zone- 4 TPI: x- 551135 y- 5983077 Zone- 4 Total Depth: x- 550834 y- 5982719 Zone- 4 11. Total Depth MD/TVD: 9263/6712 • 19. Land Use Permit: ALK 464 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1597/1599 5. Directional or Inclination Survey: Yes - 0 (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 7841/6564 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/Open Hole Caliper Log 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD HOLE SIZE CEMENTING RECORD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H-40 30 80 30 80 24 315 sx AS 11 103/4 45.5 K-55 29 2365 29 2340 131/2 1000 sx AS III & 250 sx AS 11 7 26 K-55 29 8274 29 6937 83/4 962 sx Class C 23/8 4.7 L-80 7654 9079 6406 6707 13 Slotted Liner 24. Open to production or injection? Yes 2 No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number): Slotted Liner @ 7654-9079 MD and 6406-6707 TVD "OI�,� tTl�3i 10! `IIT to L`- 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3 1/2 7642 7573 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 10/28/2016 Method of Operation (Flowing, gas lift, etc.): INJECTOR Date of Test: Hours Tested: Production for Test Period -11110. Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: 1 Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravitv - API (corr): Form 10-407 Revised 11/201�,, (/`fy Z�`,r COfjITIZ�60N PAGE 2 RBDMS L NCVG J 2016 Submit ORIGINIAL o 28. CORE DATA Conventional Core(s): Yes ❑ No El Sidewall Cores: Yes ❑ No El 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 El If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1597 1599 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 8790 6701 information, including reports, per 20 AAC 25.071. 1H-07APB1 (TD) 9378 6693 1 H-07APB2 (TD) 9013 6712 1 H-07APB3 (TD) 8790 6700 Formation at total depth: Ku aruk A Sand 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematics Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, oaleontolociical reoort. oroduction or well test results, per 20 AAC 25.070. 32. 1 hereby certify that th foregoing is true an c rect to the best of my knowledge. Contact: Ron Philli ` 265-6312 Email: ron.l. hilli s co .com Printed Name: G. Eller e' Title: Lead CTD Engineer \ Signature: Phone: 263-4172 Date: INSTRUCTIONS General: This form and the required att chments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: 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 1 H-07 EOW CTD Schematic 16" 65# H-40 at 80' MD 10-3/4" 45.5# K-55 at 2365' MD C3/4 perfs (sqz'd) 7696'-7755' MD C4 straddle cement squeezed unless infectivity low C1 perfs 7805'-7830' MD C1 straddle cement squeezed KOP @ 7840' MD Annulus of C1 straddle assembly cement squeezed A -sand perfs 8015'-8051' MD 7" 29# K-55 at 8274' MD Liner top @ 7,654' MD (released 184' off DS nipple at 503' MD (2.875" min ID) 3%" 9.3# L-80 ELIE 8rd Tubing to surface 3%" Camco KBMG gas lift mandrel at 7572' MD DS landing nipple at 7620' MD (2.812" min ID) Baker 3'/2" PBR at 7662' MD Baker FHL packer at 7675' MD 3Y2' Camco MMM production mandrel at 7689' MD AVA ported nipple at 7781'(2.813" ID) Baker KBG-22 anchor seal assembly at 7788' MD Baker SAB -3 packer at 7789' MD 3'h" Camco MMM production mandrel at 7801' MD AVA ported nipple at 7874'(2.75" ID) x/o to 2%" tubing at 7877' MD Baker D packer at 7880' MD XN landing nipple at 7899' MD (2.25" min ID) Plug set to abandon A -sand perfs, capped with cement 1 H-07APB 1 TD @ 9378' MD Anchored billets @ 8095', 8045'& 7999' MD 1 H-07APB2 TD@9013'MD Anchored billets @ .7970'& 7936' MD TD @ 9,263' MD 1 H-07APB3 Liner 9079'-7654' TD @ 8790' MD Open hole sidetrack @ 8607' Operations Summary (with Timelog Depths) 1 H-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P T -X Operation (ftKB) End Depth (ftKB) 9/30/2016 9/30/2016 6.00 MIRU MOVE RURD P Finish ND and secure BOP. Methanol 0.0 0.0 06:00 12:00 in XMT, function valves. Disconnect PUTZ. Prepare rig for move. 9/30/2016 9/30/2016 9.00 MIRU MOVE MOB P Move pit sub away from drilling sub, 0.0 0.0 12:00 21:00 hook up sow. SI adjacent wells, move drilling sub away from well row. Move off 3F pad @ 14:45. Stopped at Oliktok Y for change out. 9/30/2016 10/1/2016 3.00 MIRU MOVE MOB P Spot drilling sub over well followed by 0.0 0.0 21:00 00:00 pits sub. 10/1/2016 10/1/2016 5.00 MIRU WHDBOP NUND P NU BOP. Connect PUTZ. 0.0 0.0 00:00 05:00 Note: Valve crew greased tree prior to rig arrival. 10/1/2016 10/1/2016 4.50 MIRU WHDBOP RURD P Prepare for initial BOP test. Take on 0.0 0.0 05:00 09:30 SW, fill stack, shell test. **Rig Accept @ 09:30 (after stack filled)** 10/1/2016 10/1/2016 10.00 MIRU WHDBOP BOPE P Initial BOP Test 250/3500 psi (annular 0.0 0.0 09:30 19:30 2500 psi), witnessed by AOGCC Inspector, Johnnie Hill. Leaking Tango 1 valve during Test #8, continue on with BOP test. Leaking Romeo 3 valve during test #10, serviced, pass. While testing lower 2" pipe rams (test #15), swab 1 & 2 started leaking. Carry on with BOP test. Note: Both swab 1 & 2 had passed earlier during tests #1 and 2. 10/1/2016 10/1/2016 2.00 MIRU WHDBOP BOPE P Valve crew came out two separate 0.0 0.0 19:30 21:30 times during BOP test to service Tango 1 and then, swab 1 & 2. Passing test against swabs, continue on with BOP test. 10/1/2016 10/1/2016 1.00 MIRU WHDBOP BOPE T Continue BOP test. During draw down 0.0 0.0 21:30 22:30 test, new high pressure N2 manifold hose ruptured. Repaired and restarted test, pass. Note: Nabors 1 hour NPT 10/1/2016 10/1/2016 1.00 MIRU WHDBOP RURD P Fluid packed reel, lined up to reverse 0.0 0.0 22:30 23:30 circulate and tested Inner reel valve / stripper, pass. 10/1/2016 10/2/2016 0.50 MIRU WHDBOP MPSP P Un Stab injector, PJSM, RU valve 0.0 0.0 23:30 00:00 crew lubricator to pull BPV 10/2/2016 10/2/2016 1.50 MIRU WHDBOP MPSP P Pull BPV, PJSM, RD Valve crew 0.0 0.0 00:00 01:30 lubricator and release crew. 10/2/2016 10/2/2016 2.00 SLOT WELLPR PRTS P PJSM, Pressure test PDL's and TT 0.0 0.0 01:30 03:30 line, blow down same, CO stripper packing. Install floats in UQC. 10/2/2016 10/2/2016 2.00 PROD1 RPEQPT PULD P PJSM, Pick up Baker whipstock on 0.0 81.0 03:30 05:30 10# J hydraulic setting tool, BHA#1. Open EDC. 10/2/2016 10/2/2016 1.50 PROD1 RPEQPT TRIP P RIH with BHA #1. 81.0 7,510.0 05:30 07:00 Page 1/23 Report Printed: 10/25/2016 Operations Summary (with Timelog Depths) h 1 H-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log StartDepth Start Time End Time Dur (h[) Phase Op Code Activity Code Time P -T -X Operation (ftK6) End Depth. (ftKB) 10/2/2016 10/2/2016 1.50 PROD1 RPEQPT DLOG P Tie in to K1, minus 12' correction. 7,510.0 7,834.0 07:00 08:30 PUW=38k. Log CCL @ 16 FPM to bit depth of 7,844' (CCL 62' behind end of BHA; CCL log obtained down to 7,782'; 60' from planned set depth of whipstock due to pre -rig cement mill/reamed depth). Discuss with town engr. Correct depth +1' based on CCL compared to caliper log. 10/2/2016 10/2/2016 0.50 FROM RPEQPT TRIP P RIH to set depth. Close EDC. PU 30k. 7,834.0 7,851.5 08:30 09:00 Set whipstock, set down 3k WOB. PU and line up for swap to mud. 10/2/2016 10/2/2016 0.75 PROM RPEQPT DISP P Swap out SW for used 8.7 ppg FloPro 7,851.5 7,817.0 09:00 09:45 (milling fluid). 1.4 BPM. 10/2/2016 10/2/2016 1.25 PROM RPEQPT TRIP P POOH BHA #1. 7,817.0 67.0 09:45 11:00 10/2/2016 10/2/2016 0.50 PROM RPEQPT OWFF P Flow check / 30 mins. Dead well. 67.0 67.0 11:00 11:30 10/2/2016 10/2/2016 1.00 PROM RPEQPT PULD P PJSM, LD BHA #1. 67.0 0.0 11:30 12:30 SIMOPS: Replace washers/bolts on reel hub. 10/2/2016 10/2/2016 1.00 PROM WHPST PULD P PU BHA #2, Baker diamond mill & 0.0 70.0 12:30 13:30 reamer, Baker Xtreme motor. Window mill 2.80" no go, Sring mill 2.79" no go SIMOPS: Replace washers/bolts on reel hub. 10/2/2016 10/2/2016 0.50 PROD1 RPEQPT RGRP T Replace washers and bolts that attach 70.0 21.0 13:30 14:00 the reel to the hub on driller's side. Secure well - PU BHA with tugger, SI master valve. 10/2/2016 10/2/2016 4.50 PROM RPEQPT RGRP T Replace washers and bolts that attach 21.0 14:00 18:30 the reel to the hub on driller's side. 10/2/2016 10/2/2016 2.20 PROM WHPST PULD P 21.0 74.3 18:30 20:42 PJSM, Change out UQC, surface test, good, pick up 3.5" milling assembly BHA #2, on well, open EDC, test tools. 10/2/2016 10/2/2016 1.80 PROM WHPST TRIP P RIH W BHA #2, K1 Tie in -13' 74.3 7,491.0 20:42 22:30 correction Close EDC. 10/2/2016 10/2/2016 0.70 PROM WHPST TRIP P RIH, wt ck @ 7820, 37.5k lbs, RIH 7,491.0 7,840.7 22:30 23:12 Wt16.5 k lbs, Tag TOW 7841'. PU Wt 40 k Itis bring pumps up to 1.5 bpm, up weight 33k lbs, CT 3343 psi, WH 84 psi, IA 463 psi, OA 254 psi, 10/2/2016 10/3/2016 0.80 PROD1 WHPST WPST P Tag up, 7840.7' CT wt 15k lbs, CT 7,840.7 7,841.1 23:12 00:00 13388 psi, WH 86 psi, WOB .33 K lbs. 10/3/2016 10/3/2016 4.50 PROM WHPST WPST P Milll 2.80" window @ 7841'330 7,841.1 7,847.0 00:00 04:30 ROHS, CT wt 10.6k lbs, CT 3580 psi, WH 85 psi, WOB 3.7k lbs. Stall#1 at 7843.46, PU Wt 42k lbs, #2, @7841.6', PU Wt 40k lbs. Page 2/23 Report Printed: 10/25/2016 Operations Summary (with Timelog Depths) ` 1 H-07 k- Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/3/2016 10/3/2016 1.00 PROD1 WHPST WPST P Attempt to RIH past TOW dry, stacked 7,841.1 7,843.5 04:30 05:30 weight 7841.3' PU, 40k lbs Attempt to RIH past TOW pumping 0.5 bpm -2 fpm stacked weight at 7841.4' Attempt to RIH past TOW pumping 0.3 bpm -5 fpm stacked weight at 7841.9' PU Wt 40.5 K lbs Consult with Baker and town. Go back to milling. 10/3/2016 10/3/2016 2.00 PROD1 WHPST WPST P Milling ahead from 7,841.4' to 7,842.6' 7,843.5 7,842.6 05:30 07:30 increasing WOB to 3.2k. Motor work -1000 psi diff. No head way made with 3.2k WOB after 20 mins. Pumping 1.4 BPM. CTSW 13k. 10/3/2016 10/3/2016 3.25 PROD1 WHPST WPST P PU just passed breakover, still below 7,842.6 7,846.7 07:30 10:45 TOWS. Increased rate from 1.4 to 1.8 BPM. RBIH, milling ahead. WOB 1.6k, 1.8 BPM, CTSW 14.3k, motor work 585 psi. Motor work increased @ 7,846', potential contact with 7" casing. 10/3/2016 10/3/2016 0.50 PROD1 WHPST REAM P Backream up to TOWS 3 times. 7,846.7 7,846.0 10:45 11:15 PUW=37k. 1.8 BPM. PUH, dry drift to 7,846. PU, open EDC. 10/3/2016 10/3/2016 1.50 PROD1 WHPST TRIP P POOH BHA #2. 7,846.0 62.0 11:15 12:45 10/3/2016 10/3/2016 0.50 PROD1 WHPST OWFF P Flow check / 30 mins. 62.0 62.0 12:45 13:15 10/3/2016 10/3/2016 1.00 PROD1 WHPST PULD P LD BHA #2. 62.0 0.0 13:15 14:15 10/3/2016 10/3/2016 1.00 PROD1 WHPST PULD P PU BHA #3. 0.0 76.0 14:15 15:15 10/3/2016 10/3/2016 2.50 PROD1 WHPST TRIP P Test MWD. RIH BHA #3. PUH to 76.0 7,505.0 15:15 17:45 check injector after stop @ 236'. Cont RIH. 10/3/2016 10/3/2016 0.20 PROD1 WHPST DLOG P Tie in to K1, minus 12' correction. 7,505.0 7,532.0 17:45 17:57 10/3/2016 10/3/2016 0.10 PROD1 WHPST TRIP P Cont RIH. Dry tag @ 7,847.7'. 7,532.0 7,847.7 17:57 18:03 10/3/2016 10/4/2016 5.95 PROD1 WHPST MILL P Time milling ahead per schedule @ 7,847.7 7,851.0 18:03 00:00 345 ROHS. PUW=39k, 1.8 BPM @ 4241 psi. BHP 3609 psi. 10/4/2016 10/4/2016 1.50 PROD1 WHPST MILL P Time milling ahead per schedule @ 7,847.7 7,852.0 00:00 01:30 345 ROHS 10/4/2016 10/4/2016 2.00 PROD1 WHPST MILL P Increase WOB to 2k lbs, ROP 5 fph. 7,847.7 7,866.0 01:30 03:30 CT Wt 11.3 k lbs, WB 3.3 k lbs, ROP 9.4 fph, CT 4332 psi, WH 84 psi. Sample from the shaker, 15% sand, 16% metal. 10/4/2016 10/4/2016 1.42 PROD1 WHPST REAM P Make back reaming / reaming passes 7,866.0 7,836.0 03:30 04:55 holding original tool face up and down then +/-30 up. Dry drift clean 10/4/2016 10/4/2016 1.00 PROD1 WHPST TRIP P POOH, Open EDC above window. 7,866.0 72.0 04:55 05:55 10/4/2016 10/4/2016 0.50 PROD1 WHPST OWFF P At surface. Observe well for 72.0 72.0 05:55 06:25 flow........... zero flow observed............ Page 3123 Report Printed: 1 0/2 512 01 6 Operations Summary (with Timelog Depths) 1H-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/4/2016 10/4/2016 1.00 PROD1 WHPST PULD P Lay down BHA #3, Window Milling 72.0 0.5- 06:25 07:25 BHA ""Note: 2.80" Window Mill No- Go'ed at 2.80" 10/4/2016 10/4/2016 1.70 PROD1 DRILL PULD P Pick up BHA #4, Drill Build and Turn 0.0 72.2 07:25 09:07 BHA w/ 2 3/8" X-Treme motor and HCC 2.7" X 3.0" Bi -Center Bit. 10/4/2016 10/4/2016 1.58 PROD1 DRILL TRIP P Trip in hole with the Drill Build and 72.2 7,500.0 09:07 10:42 Turn assembly............ 10/4/2016 10/4/2016 0.14 PROD1 DRILL DLOG P Tie in for K1 Marker at 0.0 7,526.0 10:42 10:50 7,500...............make correction of - 2.5................ 10/4/2016 10/4/2016 0.28 PROD1 DRILL TRIP P Continue RIH................. 7,526.0 7,803.0 10:50 11:07 10/4/2016 10/4/2016 0.17 PROD1 DRILL TRIP P At 7,803'...... stop........ offline with 7,803.0 7,866.0 11:07 11:17 pump...... close EDC......... RBIH... ........ online with pump at 1.62 bpm.......... 10/4/2016 10/4/2016 1.14 PROD1 DRILL DRLG P At 7,866.0 ........... start 7,866.0 7,930.0 11:17 12:25 drilling ............ checking everything out before swapping to new 8.6 fluid................at 7,868.0 ............ start pumping new drilling fluid ............ ROP = 38 fpm, WOB = 1.36 ........... second stall....... at 7,896 ............ PUH and RBIH........... continue drilling ........... pumping at 1.79 bpm, ROP = 83 fpm, WOB = 1.67, BHP = 3,843, WHP = 323 ""Note; New mud at bit at 7,898.0' 10/4/2016 10/4/2016 0.25 PROD1 DRILL WPRT P At 7,930.0 ........... PUH to sweep hole 7,930.0 7,500.0 12:25 12:40 and log K1 Marker and RA........... PUW = 32K..... 10/4/2016 10/4/2016 0.10 PROD1 DRILL DLOG P At 7,500.0 ........... RBIH logging the K1 7,500.0 7,534.0 12:40 12:46 Marker and RA.................Reduce pump rate to .33 bpm while RBIH logging....................make correction of +.5 .............RA shows a depth of 17,860.0 ........... 10/4/2016 10/4/2016 0.33 PROD1 DRILL TRIP P Continue RIH ..............slowdown 7,534.0 7,930.0 12:46 13:06 through newly drilled build section ............ TOWS is at 7,840.5'.......... 10/4/2016 10/4/2016 4.15 PROD1 DRILL DRLG P At 7,930.0 8,120.0 13:06 17:15 7,930.0 ................. BOBD.......... Pump Rate = 1.75, CP = 4,244, BHP = 3,863, WHP = 338, ROP = 101, WOB = 1.82 10/4/2016 10/4/2016 4.50 PROD1 DRILL DRLG P At 8,120.0' and drilling ahead in the 8,120.0 8,360.0 17:15 21:45 turn and build section ............ Pump Rate = 1.75 bpm, CP = 4,492, BHA = 3,953, WHP = 397, ROP = 46 fpm, WOB = 2.22. Call build section TD at 8360'. 10/4/2016 10/5/2016 2.24 PROD1 DRILL TRIP P At 8360', 8 BBL Hi Vis sweep at 8,360.0 72.2 21:45 00:00 nozzel, chase sweep at 50 FPM, trip thru window per plan at 15 FPM, slow pump rate to .4 BPM, no issues. Open EDC above window, POOH per MPD trip schedule, jog at surface from 100' to 420', bump up. Page 4/23 Report. Printed: 10/25/2016 Operations Summary (with Timelog Depths) 1 H-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ttKB) 10/5/2016 10/5/2016 3.75 PROD1 DRILL PULD P Bump up, trap 1025 psi WHP, hold 72.2 0.0 00:00 03:45 PJSM, PUD BHA #4 and lay down Baker X-Treme motor. 10/5/2016 10/5/2016 3.90 PROD1 DRILL PULD P PJSM, PU/MU Weatherford motor with 0.0 74.7 03:45 07:39 0.53° AKO and re -built HYC 2.7 x 3.0" bi-center bit. PD BHA #5, 10/5/2016 10/5/2016 1.14 PROD1 DRILL TRIP P Trip in hole ............ 74.7 7,480.0 07:39 08:47 10/5/2016 10/5/2016 0.37 PROD1 DRILL DLOG P Tie in to K1 Marker ........... make 7,480.0 7,536.0 08:47 09:09 correction of - 7' .................. 10/5/2016 10/5/2016 0.38 PROD1 DRILL TRIP P Continue to RIH......... stop at 7,813' 7,536.0 8,180.0 09:09 09:32 and close EDC ............... 10/5/2016 10/5/2016 0.79 PROD1 DRILL TRIP T At 8,180 ........... tag ............ PUH ........ a 8,180.0 8,218.0 09:32 10:19 little sticky.................Continue RIH................tag again at 8,195......................PUH again and again the weights are erratic and a little heavy.... PUH again to 7,947' ................ RBIH.............. Tag at 8,210'...... PUH 40' and RBIH.......... tag at 8,218' ................. 10/5/2016 10/5/2016 0.19 PROD1 DRILL TRIP T PUH to window ............ 8,218.0 7,900.0 10:19 10:31 10/5/2016 10/5/2016 0.20 PROD1 DRILL TRIP T RBIH at 40 fpm pumping at .34 bpm 7,900.0 8,216.0 10:31 10:43 10/5/2016 10/5/2016 0.23 PROD1 DRILL TRIP T Tag at 8,216.............PUH again and 8,216.0 8,358.3 10:43 10:57 try RIH pumping at .18 bpm and RIH at 50 fpm..................make it past last tag................confer with town again and decision made to stay on bottom and drill instead of coimng back up again ............... 10/5/2016 10/5/2016 0.39 PROD1 DRILL DRLG P BOBD.............Pump Rate = 1.70 bpm, 8,358.3 8,404.0 10:57 11:20 CP = 4,879, BHP = 3,967, Differ = 1,135, ROP = 123, WOB = 1.70 10/5/2016 10/5/2016 0.05 PROD1 DRILL DLOG P PUH to conduct a survey as per 8,404.0 8,390.0 11:20 11:23 DD .............. 10/5/2016 10/5/2016 5.70 PROD1 DRILL DRLG P RBIH.......... BOBD.............Pump Rate 8,390.0 8,860.0 11:23 17:05 = 1.72 bpm, CP = 4,869, BHP = 3,890, Differ = 1,275, ROP = 205, WOB = 2.22 Note; A lot of vibration..... motor, bit, formation? Pump 5/5 Hi/Lo Vis Pill as we get closer to doing a wiper trip......... 10/5/2016 10/5/2016 0.30 PROD1 DRILL WPRT P At 8,860...... begin wiper trip up to 8,860.0 8,240.0 17:05 17:23 8,240.0' with gamma. .............. 10/5/2016 10/5/2016 0.30 PROD1 DRILL TRIP P At 8,240.0 .......... trip back in 8,240.0 8,861.0 17:23 17:41 hole ................ 10/5/2016 10/5/2016 5.82 PROD1 DRILL DRLG P At 8,861'........ BOBD........... Pump Rate 8,861.0 9,143.0 17:41 23:30 = 1.72 bpm, CP = 4,732, BHP = 3,972, Differ = 1,063, ROP = 62, WOB = 1.76. Drill per geo, build to 960, BHA wipers at 8858', PUW = 45K and 9070', PUW = 50K, try different pump rate due to vibration, 1.6 bpm, CP = 4580, BHP = 4093, Differ = 1026. Attempt BHA wiper, work up to 60K, coil not moving. Page 5/23 Report Printed: 10/25/2016 Operations Summary (with Timelog Depths) , 1 H-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (MB) 10/5/2016 10/6/2016 0.49 PROD1 DRILL WPRT T Circulating a BU at 1.5 bpm, CP = 9,143.0 9,143.0 23:30 00:00 4583, attempt to move coil, pull up to 60K, 3X. no movement 10/6/2016 10/6/2016 2.50 PROD1 DRILL WPRT T Finish circulating BU, able to rotate 9,143.0 9,143.0 00:00 02:30 orienter, working stuck pipe at 9143', alternate with pumps on and off, allow BHP to relax to 3350 psi (ECD = 10.1 ppg), progressively work coil WT to 73K, confer with town, prep to pump LVT. 10/6/2016 10/6/2016 0.50 PROM DRILL WPRT T Wait for Vac truck to arrive to offload 9,143.0 9,143.0 02:30 03:00 42 MIS of Lo-Vis from Pill Pit 2. 10/6/2016 10/6/2016 1.50 PROD1 DRILL WPRT T Load Pill Pit 2 and pump 7.5 bbls 9,143.0 9,143.0 03:00 04:30 LVT200, LVT at nozzle at 04:28, all out and pipe came free 10/6/2016 10/6/2016 1.23 PROM DRILL WPRT T Long wiper trip to 9,143.0 8,210.0 04:30 05:43 TBG...............hanging up and pulling heavy.......... 10/6/2016 10/6/2016 0.63 PROD1 DRILL WPRT T At 8,210' and hung up 8,210.0 7,806.0 05:43 06:21 again.............tryning different pump rates and speeds ......... having difficulty getting past 8,205, now...............finally pull free and continue PUH 10/6/2016 10/6/2016 0.04 FROM DRILL WPRT T At 7,806............ Open EDC 7,806.0 7,806.0 06:21 06:24 10/6/2016 10/6/2016 0.54 PROM DRILL TRIP T Circulate with open EDC and 7,806.0 7,822.0 06:24 06:56 RBIH...................tied into RA and made a +10' correction 10/6/2016 10/6/2016 0.05 PROM DRILL TRIP T At 7,822........ Close EDC 7,822.0 7,822.0 06:56 06:59 10/6/2016 10/6/2016 2.29 PROD1 DRILL TRIP T RBIH...............get back into build 7,822.0 9,143.0 06:59 09:16 section... start stacking weight at 8,256' through 8,274........... work through this area after PUH several times .......... confer with town engineer and decision made to start taking bites ( 300' to 400') after leaving build section and circulate a bottoms up after each bite until back on bottom (9,143')............ circulate in new mud with 1 % Lo-Torque, 1% 776, 1 % Drill Zone.......... 10/6/2016 10/6/2016 6.74 PROM DRILL DRLG P At 9,143' with new mud system w/ 1% 9,143.0 9,378.0 09:16 16:01 776, 1 % Lo-Torque and 1 % Drill Zone............... BOBD.......... Pump Rate = 1.42 bpm, Circ Press = 4,377, WHP = 95, BHP = 4,064, ROP = 52 fph, WOB = 1.65 k We expierenced bad vibration for about the first 45' of drilling .......... a couple of times had to PUH to get a survey ............ vibration is gradually getting a little better at least good enough to capture multiple consecutive surveys ........... still some sticky drilling / weight transfer issues occasionally ...... having to PUH for a short ways from time to time ........... after new mud has circulated in the weight transfer is better now ( after 9,200' )....... Page 6/23 Report Printed: 10/25/2016 Operations Summary (with Timelog Depths) g 1 H-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (MB) End Depth (ftKB) 10/6/2016 10/6/2016 0.05 PROD1 DRILL WPRT P At 9,378'........ Receive a call from Ron 9,378.0 9,378.0 16:01 16:04 and Gary to POOH pumping at 75 gpm and to "jog" through build area making note of any difficult areas to be passed on to Ron. Weatherford motor will be released and Inteq motor used on next drilling run. Anchored Billet will be set at 8,450. We have stopped drilling .......... 10/6/2016 10/6/2016 0.43 PROD1 DRILL TRIP T POOH pumping at 1.7 bpm chasing 9,378.0 8,168.0 16:04 16:30 returns to surface 10/6/2016 10/6/2016 1.75 PROD1 DRILL TRIP T Start pulling heavy and packing off at 8,168.0 7,780.0 16:30 18:15 8,180'. Stuck at 8,166', unable to orient, come off pumps, dump CP, relax pipe, came free, PUH thru window at 7840' ................ 10/6/2016 10/6/2016 1.00 PROD1 DRILL TRIP T Open EDC, circulate and PUH while 7,780.0 7,485.0 18:15 19:15 building Lo Vis pill. Pump 5x5 Lo/Hi vis sweep. 10/6/2016 10/6/2016 0.25 PROD1 DRILL DLOG T Tie-in for + 6.5' correction at K1 7,485.0 7,526.0 19:15 19:30 10/6/2016 10/6/2016 0.25 PROD1 DRILL TRIP T RIH to clean at 50 FPM, circulate thru 7,526.0 8,456.0 19:30 19:45 build section at min rate, at EOB bring rates 1.4 bpm, packing off at 8420', sat down -10K at 8456'. Pull up to 66K, to get moving 10/6/2016 10/6/2016 1.75 PROD1 DRILL WPRT T Pulling stickey up to 8110'. First 8,456.0 7,900.0 19:45 21:30 sweep at nozzle at 8086', start second 5x5 Lo/Hi vis sweep, wiper up to 7900', First sweep at surface, plug choke A with large shale sloughings. Confer with town, continue hole cleaning and wipers above 8150'. 10/6/2016 10/6/2016 1.25 PROD1 DRILL TRIP T Pump sweep #3 and run back to 7,900.0 8,150.0 21:30 22:45 8150', cleaner this time, still getting back shale, smaller size particles. Decision made to set KO billet above 8150', pump final 5x5 sweep and clean hole above 8150'. 10/6/2016 10/6/2016 0.75 PROD1 DRILL WPRT T Wiper up to window, open EDC 8,150.0 7,808.0 22:45 23:30 10/6/2016 10/7/2016 0.50 PROD1 DRILL TRIP T Trip out per MPD schedule.... 7,808.0 5,500.0 23:30 00:00 10/7/2016 10/7/2016 1.50 PROD1 DRILL TRIP T Continue to POOH, bump up and 5,500.0 74.7 00:00 01:30 space out, maintain 950 psi WHIP. 10/7/2016 10/7/2016 2.00 PROD1 DRILL PULD T PJSM, Pressure undeploy and 74.7 0.0 01:30 03:30 Iaydown BHA #5 10/7/2016 10/7/2016 4.00 PROD1 STK PULD T MU BHA #6 2.60" Anchored KO billet, 0.0 73.4 03:30 07:30 PD BHA #6 10/7/2016 10/7/2016 1.68 PROD1 STK TRIP T Start RIH with Anchored Billet setting 73.4 7,490.0 07:30 09:10 BHA with open EDC pumping at minmum rate.......... 10/7/2016 10/7/2016 0.25 PROD1 STK DLOG T At 7,490'.start slowing down and log 7,490.0 7,534.0 09:10 09:25 for K1 Marker and make a correction of minus 8.5' 10/7/2016 10/7/2016 0.13 PROD1 STK TRIP T Continue RIH with Anchor Billet Billet 7,534.0 7,821.0 09:25 09:33 setting BHA Page 7/23 Report Printed: 1 0/2 512 01 6 Operations Summary (with Timelog Depths) 1 H-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 10/7/2016 10/7/2016 0.06 PROD1 STK TRIP T At 7,821 .......... offline with 7,821.0 7,821.0 09:33 09:37 pump ........ close EDC ........... perform a WT CK=32.5k 10/7/2016 10/7/2016 0.17 PROD1 STK TRIP T Continue RIH............... 7,821.0 8,106.3 09:37 09:47 10/7/2016 10/7/2016 0.23 PROD1 STK WPST T At 8,106.5 ft ..... PUH to neutral 8,106.3 8,106.3 09:47 10:01 weight ......... bring pump online ........... release off billet.... offline with pump...... anchored billet set with uphole anchor oriented high side, top of Billet at 8096 ft ..... set down 2.5k and billet is holding...... 10/7/2016 10/7/2016 0.09 PROD1 STK TRIP T PUH several feet and open EDC......... 8,106.3 8,106.3 10:01 10:06 10/7/2016 10/7/2016 1.87 PROD1 STK TRIP T POOH pumping at 1 bpm. 8,106.3 61.8 10:06 11:58 10/7/2016 10/7/2016 1.74 PROD1 STK PULD T At surface. Pressure Undeploy BHA 61.8 61.8 11.58 13:43 #6 after PJSM. 10/7/2016 10/7/2016 0.93 PROD1 STK PULD T L/D BHA #6 61.8 0.0 13:43 14:39 10/7/2016 10/7/2016 2.80 PROD1 STK PULD T PJSM, P/U A Lateral KO / Build 0.0 72.2 14:39 17:27 Section BHA #7. Pressure Deploy BHA #7. 10/7/2016 10/7/2016 1.55 PROD1 STK TRIP T Trip in w/ BHA #7 to 7500 ft.......... 72.2 7,500.0 17:27 19:00 10/7/2016 10/7/2016 0.25 PROD1 STK DLOG T 7,500 ft, log K1 Marker and make 7,500.0 7,536.0 19:00 19:15 correction of -11 ft 10/7/2016 10/7/2016 0.25 PROD1 STK TRIP T Continue trip in, dry drift through 7,536.0 8,096.0 19:15 19:30 window, 1 bobble near BOW (2.31 AKO bend motor), dry tag KO billet at 8096 ft, 3K WOB, 38K PU, Bring pump online to 1.7 bpm, 4400 CP, 4000 BHP, 411 dP, 15K RIH CW 10/7/2016 10/7/2016 1.75 PROD1 STK KOST T Auto drill at 1 FPH, 13.4K CW, 0.3K 8,096.0 8,100.0 19:30 21:15 WOB, 1.7 bpm, 4360 CP, 3981 BHP, 420 dP. After 1 hour not seeing WOB or dP change, PU, Off bottom parameters at1.5 bpm, 3900 CP, 3933 AP, 350 dP. Continue to auto drill at 2 FPH„ stall at 8100 ft, appear to be past the the billet. 10/7/2016 10/8/2016 2.75 PROD1 STK DRLG T Drill to 8117 ft at midnight 8,100.0 8,117.0 21:15 00:00 10/8/2016 10/8/2016 1.00 PROD1 STK DRLG T Continue drilling A-Lat build section, 8,117.0 8,132.0 00:00 01:00 trying to get BHA to build, not building, changed TF to high side, try pushing 4K WOB, slow pump rate to 1.5 BPM 10/8/2016 10/8/2016 1.25 PROD1 STK WPRT T Wiper to window, open EDC and 8,132.0 7,800.0 01:00 02:15 circulate. Consult with town engineer to continue drilling ahead, build is already -10' low. Decision to drill ahead, attempt build hole angle. 10/8/2016 10/8/2016 0.25 PROD1 STK TRIP T Close EDC, trip in, bobble at window, 7,800.0 8,131.0 02:15 02:30 dry drift past billet, tag at 8131 ft, 36K PUW, 1.5 bpm, 13K RIH wt, 3956 CP, 4082 BHP, 392 dP, 0 WOB Page 8/23 Report Printed: 10/25/2016 Operations Summary (with Timelog Depths) . 1H-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Der (hr) Phase Op Code Activity Cade Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 10/8/2016 10/8/2016 0.25 PROD1 STK DRLG T Start drilling at 8131 ft to 8138 ft, ROP 8,131.0 8,155.0 02:30 02:45 increased to 200+ FPH appears to have entered PB1. 10/8/2016 10/8/2016 0.42 PROD1 STK WPRT T Wiper back through window, open 8,155.0 7,797.0 02:45 03:10 EDC, PUH slowly 10/8/2016 10/8/2016 1.00 PROD1 STK WAIT T Waiting on work direction from 7,797.0 7,802.0 03:10 04:10 town...... 10/8/2016 10/8/2016 0.07 PROD1 STK TRIP T Close EDC 7,802.0 7,802.0 04:10 04:14 10/8/2016 10/8/2016 0.52 PROD1 STK TRIP T Circulate in 5x5 Lo/Hi-Vis sweep, 7,802.0 8,075.0 04:14 04:45 RIH........... 10/8/2016 10/8/2016 0.40 PROD1 STK TRIP T At 8,075 ............ start POOH 8,075.0 7,818.0 04:45 05:09 10/8/2016 10/8/2016 0.05 PROD1 STK TRIP T Open EDC....... 7,818.0 7,818.0 05:09 05:12 10/8/2016 10/8/2016 1.59 PROD1 STK TRIP T POCH ............ 7,818.0 56.0 05:12 06:48 10/8/2016 10/8/2016 0.29 PROD1 STK DRLG T At surface. Space out. PJSM. 56.0 56.2 06:48 07:05 10/8/2016 10/8/2016 1.10 PROD1 STK PULD T Pressure Undeploy BHA #7 after 56.2 56.2 07:05 08:11 PJSM.......... 10/8/2016 10/8/2016 1.14 PROD1 STK PULD T L/D BHA #7 ........... all scribes and 56.2 0.0 08:11 09:19 motor bend OK 10/8/2016 10/8/2016 0.52 PROD1 STK BOPE P Function Test BOPE... ........ good test. 0.0 0.0 09:19 09:51 10/8/2016 10/8/2016 0.39 PROD1 STK PULD T Prep for BHA #8 for setting the 0.0 0.0 09:51 10:14 second billet............ 10/8/2016 10/8/2016 0.90 PROD1 STK PULD T P/U BHA #8 with PB2 Billet after 0.0 72.9 10:14 11:08 PJSM........... 10/8/2016 10/8/2016 1.40 PROD1 STK PULD T Pressure Deploy BHA #8, Test 72.9 72.9 11:08 12:32 MWD........... 10/8/2016 10/8/2016 1.67 PROD1 STK TRIP T RIH pumping at minimum 72.9 7,500.0 12:32 14:12 rate.......... with EDC open ............. 10/8/2016 10/8/2016 0.34 PROD1 STK DLOG T Log for K1 Marker and make 7,500.0 7,552.0 14:12 14:33 correction of minus 12'............ 10/8/2016 10/8/2016 0.18 PROD1 STK TRIP T Continue RIH. 7,552.0 7,820.0 14:33 14:43 10/8/2016 10/8/2016 0.06 PROD1 STK TRIP T At 7,820'.stop and close 7,820.0 7,820.0 14:43 14:47 EDC........... WT CK = 32K 10/8/2016 10/8/2016 0.18 PROD1 STK TRIP T Continue RIH.... .......... RIW = 16.42 7,820.0 8,056.7 14:47 14:58 10/8/2016 10/8/2016 0.32 PROD1 STK WPST T At 8,056.77 (Top at 8045 8,056.7 0.0 14:58 15:17 ft)...............PUH to neutral weight ............ bring pump online at .63..............anchored billet releases at 4,600 psi circ pressure.... ...... try and set down weight.............billet starts moving with .9 k on it.............the top of billet is at 8,056.3 ........... confer with town engineer. Decision made to pull off and then POOH to set another one higher.......... 10/8/2016 10/8/2016 0.22 PROD1 STK TRIP T POOH pumping at .4 bpm ................. 8,056.3 7,820.0 15:17 15:30 10/8/2016 10/8/2016 0.05 PROD1 STK TRIP T Stop here and open EDC........... EDC 7,820.0 7,820.0 15:30 15:33 open and pump online .......... 10/8/2016 10/8/2016 1.50 PROD1 STK TRIP T POOH pumping MP trip 7,820.0 61.3 15:33 17:03 schedule........... Page 9/23 Report Printed: 10/25/2016 /4 Operations Summary (with Timelog Depths) �.. x 1 H-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (WB) 10/8/2016 10/8/2016 0.45 PROD1 STK TRIP T At surface. Space out. PJSM. 61.3 61.3 17:03 17:30 10/8/2016 10/8/2016 1.75 PROD1 STK PULD T Pressure Undeploy, had trouble 61.3 0.0 17:30 19:15 getting BHA thru tree, L/D BHA #8 10/8/2016 10/8/2016 1.75 PROD1 STK PULD T PU BHA #9, pressure deploy Anchor 0.0 75.9 19:15 21:00 Billet, checked pack offs, MWD surface check, finish pressure deploy 10/8/2016 10/8/2016 1.75 PROD1 STK TRIP T Trip in with EDC is open, maintain 75.9 7,500.0 21:00 22:45 MPD trip schedule 10/8/2016 10/8/2016 0.25 PROD1 STK DLOG T Log for K1 Marker, make correction of 7,500.0 7,547.0 22:45 23:00 -14 ft, (corrected depth from 7547.35 to 7533.35 ft) 10/8/2016 10/8/2016 0.50 PROD1 STK TRIP T Continue RIH, at 7800 take PUW= 7,547.0 8,011.8 23:00 23:30 33.5K, stop and close EDC, pumps off, RIH, 20 FPM 10/8/2016 10/8/2016 0.25 PROD1 STK WPST T At 8011.75, PU to neutral weight 28K, 8,011.8 8,011.8 23:30 23:45 bring rate to 0.45 bpm, sheared at 4500 psi, SO to 4.4K WOB, billet holding, PUW 36K *** top of billet at 8000 ft **** 10/8/2016 10/9/2016 0.24 PROD1 STK TRIP T POOH follow MPD trip schedule. 8,011.8 7,300.0 23:45 00:00 10/9/2016 10/9/2016 1.50 PROM STK TRIP T Continue trip out with BHA #9, Baker 7,300.0 75.9 00:00 01:30 10 setting tool, bump up and space out BHA. 10/9/2016 10/9/2016 1.50 PROD1 STK PULD T PUD and L/D BHA #9 75.9 0.0 01:30 03:00 10/9/2016 10/9/2016 1.00 PROD1 STK PULD T PU BHA #10 with 2.3+ AKO motor, RB 0.0 72.2 03:00 04:00 HCC Bi -Center bit, scribe and check HS correction. 10/9/2016 10/9/2016 2.25 PROD1 STK PULD T PD BHA #10 72.2 72.2 04:00 06:15 10/9/2016 10/9/2016 1.00 PROD1 STK RGRP T PD finished. Wait on motorman to 72.2 72.2 06:15 07:15 take measurements of right angle motors, taking 1 hour for maintenance and to straighten out the String Manager............ 10/9/2016 10/9/2016 1.70 PROD1 STK TRIP T RIH with EDC open and pumping at .3 72.2 7,500.0 07:15 08:57 bpm 10/9/2016 10/9/2016 0.18 PROD1 STK DLOG T At 7,500 ........... start logging for K1 7,500.0 7,532.4 08:57 09:07 Marker and make correction of minus 13' 10/9/2016 10/9/2016 0.32 PROD1 STK TRIP T Continue RIH pumping at minimum 7,532.4 7,822.0 09:07 09:27 rate. 10/9/2016 10/9/2016 0.22 PROD1 STK TRIP T Stop at 7,822' and offline with pump. 7,822.0 7,989.0 09:27 09:40 Close EDC. Online with pump again at minimum rate. Continue RIH 10/9/2016 10/9/2016 0.07 PROD1 STK TRIP T Offline with and dry tag top of 7,989.0 7,999.9 09:40 09:44 I billet ............ tag at 7,999.9' Page 10/23 Report Printed: 10/25/2016 Operations Summary (with Timelog Depths) 1 H-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 10/9/2016 10/9/2016 2.24 PROD1 STK SEQP T PUH a short ways and bring pump 7,999.9 7,826.0 09:44 11:58 online at 1.1 bpm, PUW = 36.5K, Choke B is acting like it's partially plugged, switch to choke A. .........annular pressure stays the same ........... open bypass and annular pressure stays the same ............ decisiion made to go back to Choke B and start milling. Annular pressure rises, go back to an open bypass..... line still plugged .......... offline with pump and troubleshoot problem. After much troubleshooting and much angst, finally determined that the MM6 / MM7 valve line and the hose off the Annular bag is clogged. Able to get line clear. The pit watcher got a slug of shale and shale pieces about a 1/4" in diameter when line came free. Circulate fluid around to ensure all lines are clear before proceeding. 10/9/2016 10/9/2016 0.44 PROD1 STK SEQP T RBIH slowly and once again bring 7,826.0 7,827.0 11:58 12:25 pump online to minimum rate. At 7989' bring pump rate up to 1.6 bpm to check pressures ......... free spin at 4.3k .......... RIH slowly till motor work and WOB observed.... Choke A clogging up again..... annular pressure rising. PUH above window and troubleshoot plugged chokes again..... 10/9/2016 10/9/2016 2.00 PROD1 STK SEQP T At 7,827 ........... troubleshoot clogged 7,827.0 7,827.0 12:25 14:25 chokes.............repeat all steps previously tried. This time clogged area seems to be at both chokes. Isolated both chokes to disassemble and clean. Choke B had very little debris in it, but Choke A had a wire ball of small thin curly Q shavings and flat thin pieces, mostly magnetic looks like coil shavings and some window milling debris. 10/9/2016 10/9/2016 0.24 PROD1 STK TRIP T Close EDC and RIH to try and mill on 7,827.0 7,998.9 14:25 14:39 billet again .............. 10/9/2016 10/9/2016 2.34 PROD1 STK KOST T On top of billet drilling at 1.45 bpm 7,998.9 8,000.4 14:39 17:00 with a ROP of 1.0' p/hr, CP = 4,318, WHP = 202, BHP = 3,920, WOB =.05 10/9/2016 10/9/2016 1.00 PROD1 STK KOST T On top of billet drilling at 1.45 bpm 8,000.4 8,032.0 17:00 18:00 with a ROP of 1.0' p/hr CP = 3,968, WHP = 202, BHP = 3,923, WOB = .05, 6 motor stalls....... KO from billet at 8002', drill ahead to 8032'. 10/9/2016 10/9/2016 0.25 PROD1 STK REAM T Wiper up past billet, RIH to dry drift 8,032.0 8,032.0 18:00 18:15 past billet, increase pump rate to 1.72 bpm, 10/9/2016 10/9/2016 4.50 PROD1 DRILL DRLG T OBD at 1.72 bpm, 45 to 55'/hr ROP, 8,032.0 8,306.0 18:15 22:45 4762 CP, 185 WHP, 3937 BHP, 692 dP. Control drill to limit DLS less than 45°. Pump 5x5 Lo/Hi Vis sweep Page 11/23 Report Printed: 10/25/2016 J }� Operations Summary (with Timelog Depths) 1 H-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 10/9/2016 10/9/2016 0.25 PROD1 DRILL WPRT T Wiper up to 8160', 37K PUW, RBIH, 8,306.0 8,306.0 22:45 23:00 13.5K, off -bottom parameters 1.72 bpm, 4834 CP, 4108 BHP, 559 dP, 0 WOB 10/9/2016 10/9/2016 0.50 PROD1 DRILL DRLG T Drill to EOB at 8330' 8,306.0 8,330.0 23:00 23:30 10/9/2016 10/9/2016 0.25 PROD1 DRILL WPRT T Wiper up to 7800', jog down to 7826', 8,330.0 7,800.0 23:30 23:45 Open EDC 10/9/2016 10/10/2016 0.25 PROD1 DRILL TRIP T Tripping out at a depth of 6800' as of 7,800.0 6,800.0 23:45 00:00 midnight. 10/10/2016 10/10/2016 1.50 PROD1 DRILL TRIP T Finish tripping, at surface, bump up 6,800.0 72.2 00:00 01:30 and space out. 10/10/2016 10/10/2016 1.50 PROD1 DRILL PULD T Hold PJSM, PUD BHA #10, laydown 72.2 0.0 01:30 03:00 2.3° AKO motor, bit has 3 chipped cutters and 1 plugged jet. 10/10/2016 10/10/2016 1.75 PROD1 DRILL PULD T PU/MU A -Lateral 0.53° AKO motor 0.0 72.2 03:00 04:45 and RB HCC 3.0" bi-center bit, PD BHA #11 10/10/2016 10/10/2016 1.56 PROD1 DRILL TRIP T Trip in with EDC open, pumping MP 72.2 7,500.0 04:45 06:18 schedule.... 10/10/2016 10/10/2016 0.20 PROD1 DRILL DLOG T Logging for tie in to K1 Marker and 7,500.0 7,536.0 06:18 06:30 make correction of minus 14' 10/10/2016 10/10/2016 0.53 PROD1 DRILL TRIP T Continue RIH........... 7,536.0 8,330.0 06:30 07:02 10/10/2016 10/10/2016 1.07 PROD1 DRILL DRLG T At bottom....... PUH becuase weights 8,330.0 8,340.0 07:02 08:06 are a little sticky ......... RBIH and start drilling 1.7 bpm, WHP 90 ...... annular pressure starts climbing. Reduce pump rate to 1.5 bpm. WHP falls to 81 and eventually climbs back to 90 with choke wide open. Trouble shoot surface piping and chokes while drilling ahead. It appears we have some blockage downhole. Returns are pretty sticky and clay -like. 10/10/2016 10/10/2016 5.20 PROD1 DRILL DRLG T Something lets loose from downhole 8,340.0 8,530.0 08:06 13:18 and enters piping and slams into choke and works it self through the choke. Pressures are now back to normal..... WHP = 256, BOP = 4,025, Pick pump rate back up to 1.7 bpm........ work WHP back down to 170. ROP = 29, WOB = 2.45 Continue drilling ahead...... 10/10/2016 10/10/2016 1.02 PROD1 DRILL DRLG T At 8,530....... Drilling ahead ........... Rate 8,530.0 8,630.0 13:18 14:19 = 1.7 bpm, CP = 4,927, BHP = 4,014, WHP = 134, ROP = 78 fph, WOB = 1.49 10/10/2016 10/10/2016 0.33 PROD1 DRILL WPRT T At 8,630 ............ PUH for a wiper 8,630.0 7,890.0 14:19 14:39 trip........... 10/10/2016 10/10/2016 0.35 PROD1 DRILL WPRT T RBIH........... 7,890.0 8,630.0 14:39 15:00 10/10/2016 10/10/2016 2.50 PROD1 DRILL DRLG T At 8,630'....... BOB Drilling 8,630.0 8,923.0 15:00 17:30 ahead ........... Rate = 1.7 bpm, CP = 4,927, BHP = 4,014, WHP = 134, ROP = 78 fph, WOB = 1.49 10/10/2016 10/10/2016 0.35 PROD1 DRILL WPRT T At 8,923.0 ......... PUH for a wiper trip to 8,923.0 8,025.0 17:30 17:51 8,025' 10/10/2016 10/10/2016 0.40 PROD1 DRILL WPRT T At 8,025'........ RBIH ............ 8,025.0 8,923.0 17:51 18:15 Page 12/23 Report Printed: 10/25/2016 Operations Summary (with Timelog depths) Rig: NABORS CDR3-AC 1 H-07 Inh. nmi I Mr; RIMTRAr Time Log Start Time End Time Dur (hr} Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 10/10/2016 10/10/2016 0.75 PROD1 DRILL DRLG T At 8,630'....... BOB Drilling 8,923.0 9,011.0 18:15 19:00 ahead ........... Rate = 1.7 bpm, CP = 4,927, BHP = 4,014, WHP = 134, ROP = 78 fph, WOB = 1.49 10/10/2016 10/11/2016 4.99 PROD1 DRILL WPRT T PUH so tool face can be 9,011.0 9,011.0 19:00 00:00 moved.............stuck pipe. Work pipe up to 60K, several times, pump a 5x5 Lo/Hi Vis Pill.............try pulling to 60K again with no luck. Confer with town engineer. Prep to pump LVT. Pump LVT and let soak ..... contune to try pulling........... 10/11/2016 10/11/2016 1.75 PROM DRILL WPRT T LVT mineral oil on BHA. Alternate 9,011.0 9,011.0 00:00 01:45 work pipe and relax. Bleed WHP to 80 psi, SO to -5K and pull up 70K at 60 FPM, repeat and come up at 80FPM to 75K. 10/11/2016 10/11/2016 4.75 PROD1 DRILL WPRT T Resume pumping to move fluid, 9,011.0 9,011.0 01:45 06:30 circulate LVT to surface, LVT strung out no clear interface. Pump another 8 bbl LVT pill, stop pumping, let soak with 56K on coil. Work pipe to 70K. Consult with town engineer, decision to set down weight and allow BHP to falloff 10/11/2016 10/11/2016 1.25 PROM DRILL WPRT T Shut down pumping, bleed off CP to 9,011.0 9,011.0 06:30 07:45 280, SO weight to 5K. Work pipe 3 cycles, last cycle pull up at 100 FPM to 80K. 10/11/2016 10/11/2016 5.00 PROM DRILL WPRT T Allow pipe to relax while waiting for 9,011.0 9,011.0 07:45 12:45 LVT. Start sending mud to TT to make room for mud swap, Circulating at 0.81 bpm, 2705 CP, 3955 BHP, 11.5 ECD. Annular pressure is eratic, builds up 70 to 100 psi then breaks back. 10/11/2016 10/11/2016 0.50 PROM DRILL WPRT T Bring pump rate up slowly to 1.48 9,011.0 9,011.0 12:45 13:15 bpm, 4512 CP, 4672 BHP, start experiencing losses above 12.6 ppg ECD, bring rate down to .83 bpm, 3032 CP, 4270 BHP, 12.4 ECD. Wait on returns truck to start transfering new mud. 10/11/2016 10/11/2016 1.75 PROM DRILL WPRT T Wait on returns truck to start 9,011.0 9,011.0 13:15 15:00 transfering new mud. 10/11/2016 10/11/2016 0.80 PROM DRILL WPRT T Start downhole with new mud system 9,011.0 9,011.0 15:00 15:48 3 10/11/2016 10/11/2016 0.20 PROD1 DRILL WPRT T Trap WHP, Work pipe down 3 times to 9,011.0 9,011.0 15:48 16:00 -5K, Work down and up -5 to 75K. No weight change on DHWOB, Able to orient normally 10/11/2016 10/11/2016 3.00 PROD1 DRILL WPRT T Hold pipe in tension, 70K, Hook up 9,011.0 9,011.0 16:00 19:00 LVT Truck 10/11/2016 10/11/2016 1.60 PROM DRILL WPRT T Pump 20 BBIs LVT, stop and let 9,011.0 9,011.0 19:00 20:36 soakfor 30 min after 8 BBIs out, Pump only to maintain BHP, Work pipe -10K to 76K up. No weight change observed from DHWOB. Still able to orient normally 10/11/2016 10/11/2016 1.50 PROD1 DRILL WPRT T Pump 4 MIS down coil, 8 bbls LVT 9,011.0 9,011.0 20:36 22:06 still in coil, Soak and work pipe Page 13/23 Report Printed: 10/25/2016 ' Operations Summary (with Timelog Depths) 1 H-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/11/2016 10/11/2016 1.20 PROM DRILL WPRT T Pull pipe free 80K during step wise 9,011.0 7,795.0 22:06 23:18 pressure reduction, 500 PSI WHP, 10.2 ECD, Hole problems 9000 to 8800 and 8650 to 8480. Poor conditions to window 10/11/2016 10/11/2016 0.20 PROD1 DRILL WPRT T Open EDC, Continue up hole to tie in 7,795.0 7,495.0 23:18 23:30 10/11/2016 10/11/2016 0.10 PROD1 DRILL DLOG T Log K1 for+10' correction, Shales 7,495.0 7,514.0 23:30 23:36 coming over shaker, Geo call Kuparuk B shales with siltstone and sand 10/11/2016 10/12/2016 0.40 PROM DRILL WPRT T Consult with town for plan forward, 7,514.0 7,514.0 23:36 00:00 Pumping 1.8 BPM in, 1.75 Out. 10/12/2016 10/12/2016 4.00 PROM DRILL WPRT T Continue wiper to swab. Started 7,514.0 72.0 00:00 04:00 unloading additional shales —1100' from surface. Pipe gouged @ 195' from coil connector, —.023" deep 10/12/2016 10/12/2016 0.20 PROM DRILL WPRT T Tag up, Reset counters, Down load 72.0 72.0 04:00 04:12 string data and restart job 10/12/2016 10/12/2016 1.80 PROM DRILL TRIP T Trip in well, EDC open, Pumping 1 72.0 7,500.0 04:12 06:00 BPM 10/12/2016 10/12/2016 0.50 PROM DRILL SFTY T Hold first CDR 3 SLT meeting. 7,500.0 7,800.0 06:00 06:30 10/12/2016 10/12/2016 1.90 PROM DRILL CLEN T Consult with town engineers about 7,800.0 7,830.0 06:30 08:24 plan forward. Transfer new mud to active sytem, viscosify Hi Vis pit 1, prep to clean hole 10/12/2016 10/12/2016 0.45 PROM DRILL TRIP T Close EDC, dry drift window, RIH at 7,830.0 8,330.0 08:24 08:51 0.28 bpm thru build at 25 FPM, to 8330' EOB, saw -5K bobbles at 8056, 8087,8152,8162,8234- 087,8152,8162,8234'10/12/2016 10/12/2016 10/12/2016 0.40 PROM DRILL WPRT T Wiper trip back to window, turn around 8,330.0 7,830.0 08:51 09:15 pulling heavy 60K , and grabing motor from 8282 to ..... Pull back through window and open EDC 10/12/2016 10/12/2016 1.75 PROM DRILL CIRC T PUH slow while circulate for 4 BU, 7,830.0 7,830.0 09:15 11:00 heavy cuttings and shales in the returns. Choke A show signs of plugging, bring rate to 2 bpm, swap to choke B, back flush choke A. RBIH to top of window 10/12/2016 10/12/2016 0.84 PROM DRILL TRIP T Close EDC, RIH at 25 FPM, pumping 7,830.0 8,322.0 11:00 11:50 1 bpm through build, sat down at 8194', PUW 50 to 55K. Sat down at 8075', 8085', 8278. PUW 55K, pull up to 8210', go back down to 8322', PUW 45 to 60K 10/12/2016 10/12/2016 0.25 PROM DRILL WPRT T Work pipe, pull up to 72K, got 8200' 8,322.0 7,811.0 11:50 12:05 weight back to 32K, wiper to window. Open ECD 10/12/2016 10/12/2016 0.75 PROM DRILL CIRC T Circulate hole at 2.4 bpm, heavy 7,811.0 7,500.0 12:05 12:50 cuttings and shale inreturns 10/12/2016 10/12/2016 0.25 PROD1 DRILL DLOG T Log K1, make +5.5' correction 7,500.0 7,523.0 12:50 13:05 10/12/2016 10/12/2016 1.90 PROD1 DRILL TRIP T RIH, close EDC, RIH at 25 FPM, 7,523.0 8,389.0 13:05 14:59 pumping 1 bpm, SD at 8345', PUW 40 to 60K, pull up to 8290, RBIH, SD at 8376' SD got hung up, pulled 62K, pull up at 10 FPM to 8200', RBIH, SD at 8345' pull up to 8283', RBIH, SD at 8389', Page 14/23 Report Printed: 10/25/2016 Operations Summary (with Timelog Depths) 1 H-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (W) End Depth (ftKB) 10/12/2016 10/12/2016 0.75 PROD1 DRILL WPRT T Wiper up to 8279', stuck near BHA, 8,389.0 7,811.0 14:59 15:44 work pipe to 70K, able to orient, circulate at 1.5 BPM to get BU, got free, pull up, packing off near 8030'. Call from town to come out to set a KO billet. Pull up into window, 10/12/2016 10/12/2016 1.30 PROD1 DRILL TRIP T Open EDC, circulate a BU, pump 5 x 5 7,811.0 8,000.0 15:44 17:02 Hi/Lo vis sweep, close EDC, RIH to 8000'. 10/12/2016 10/12/2016 1.50 PROD1 DRILL WPRT T Wiper trip to surface, Open EDC 8,000.0 72.0 17:02 18:32 @7810 10/12/2016 10/12/2016 3.20 PROD1 DRILL PULD T At surface, Tag up and space out. 72.0 72.0 18:32 21:44 PJSM. PUD BHA #11, PD pre loaded BHA #12 Anchored Billet. M/U to coil and surface test 10/12/2016 10/12/2016 1.00 PROD1 STK SVRG T Complete coil fatigue update, tear 72.0 72.0 21:44 22:44 down MP choke A 10/12/2016 10/13/2016 1.26 PROD1 STK TRIP T Trip in hole, EDC open, Pumping .3 72.0 6,300.0 22:44 00:00 BPM 10/13/2016 10/13/2016 0.30 PROD1 STK TRIP T Continue in well with anchor billet 6,300.0 7,500.0 00:00 00:18 10/13/2016 10/13/2016 0.20 PROD1 STK DLOG T Log K1 for -14' correction 7,500.0 7,546.0 00:18 00:30 10/13/2016 10/13/2016 0.40 PROD1 STK TRIP T Continue in well, stop @ 7800' and 7,546.0 7,981.7 00:30 00:54 shut EDC, PUW=33K, Clean trip through window and down to set depth @ 7981.73, Anchor oriented to 30ROHS for HS kick off 10/13/2016 10/13/2016 0.40 PROD1 STK WPST T At set depth and orientation, Pumps 7,981.7 7,997.0 00:54 01:18 on .5 BPM, See tool shift @4200 PSI, set down on billet. At 2000 lbs billet started moving down hole with 300 to 900 Lbs DHWOB. Got up to 1500 Lbs @ 7997. Pulled off billet, PUW=36K, TOB @ 7985' 10/13/2016 10/13/2016 1.50 PROD1 STK TRIP T 7997, Trip out after billet mis set, 7,997.0 61.5 01:18 02:48 Open EDC @ 7795' 10/13/2016 10/13/2016 1.20 PROD1 STK PULD T At surface, Tag up and space out, 61.5 0.0 02:48 04:00 PJSM, PUD BHA #12 Anchor billet running tools 10/13/2016 10/13/2016 1.00 PROD1 STK PULD T Prepping to run memory caliper. 0.0 0.0 04:00 05:00 10/13/2016 10/13/2016 2.00 PROD1 STK WAIT T Wait on Halliburton Memory Caliper 0.0 0.0 05:00 07:00 Service to arrive from Deadhorse 10/13/2016 10/13/2016 2.50 PROD1 STK PULD T Load tools to rig floor, pre job meeting 0.0 0.0 07:00 09:30 to discuss job objectives, off load suction pit and and 50 bbls from shaker pit to vac truck, transfer K - Formate KWF all while PU/MU caliper tools Page 15/23 Report Printed: 10/25/2016 Operations Summary (with Timelog Depths) 1= 1H-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (MB) End Depth (ftKB) 10/13/2016 10/13/2016 1.50 PROD1 STK PULD T BHA #13 pre loaded in DS PDL, MU 0.0 0.0 09:30 11:00 Hallibuton 24 -arm memory caliper tool, perform surface check, fuse on battery section appears to have blown, swap to back-up battery section, perform second surface check, tool started open sequence and stopped partially open, after several minutes, went fully open, then fully closed. Break down caliper to check, reprogram tool, MU caliper and perform a third surface check. Third check was good, *** Batties Installed 11:17 AM, 270 min to open *** 10/13/2016 10/13/2016 1.75 PROD1 STK PULD T PD BHA #13.... 0.0 61.6 11:00 12:45 10/13/2016 10/13/2016 1.50 PROD1 STK TRIP T Trip in with EDC open to K1 marker, 61.6 7,450.0 12:45 14:15 pumping 11.8 K -Formate KWF at minimumm rate 10/13/2016 10/13/2016 0.25 PROD1 STK DLOG T Log K1 marker, -14.5 ft correction 7,525.0 7,525.0 14:15 14:30 10/13/2016 10/13/2016 0.25 PROD1 STK TRIP T Trip in to window, 7,525.0 7,830.0 14:30 14:45 10/13/2016 10/13/2016 1.00 PROD1 STK CIRC T Stop at 7820' and cicrulate hole to 7,830.0 7,830.0 14:45 15:45 KWF, at 0.98 bpm, staring pressures 1642 CP, 483 WHP, 3874 BHP, 11.57 ECD, MiM In reading 11.74 ppg. After xxx bbls MM out showing ending pressures 10/13/2016 10/13/2016 0.50 PROD1 STK TRIP T Trip in and wait for caliper to open at 7,830.0 7,975.0 15:45 16:15 16:12 10/13/2016 10/13/2016 0.75 PROD1 STK DLOG T Log up at 35 FPM, tie in to K1 marker, 7,975.0 7,230.0 16:15 17:00 arms close at 17:00 10/13/2016 10/13/2016 1.00 PROD1 STK TRIP T Trip to surface 7,230.0 48.8 17:00 18:00 10/13/2016 10/13/2016 0.50 PROD1 STK OWFF T 30 min Flow check 48.8 48.0 18:00 18:30 10/13/2016 10/13/2016 0.50 PROD1 STK PULD T Lay down BHA #13 from dead well 48.0 0.0 18:30 19:00 10/13/2016 10/14/2016 5.00 PROD1 STK PULD T Break down caliper, Down load data to 0.0 0.0 19:00 00:00 town, Process and interpet caliper data 10/14/2016 10/14/2016 1.10 PROD1 STK OTHR T continue to analyze caliper data - 0.0 0.0 00:00 01:06 formulate plan forward 10/14/2016 10/14/2016 0.90 PROD1 STK PULD T M/U BHA #14 with non ported bull 0.0 116.0 01:06 02:00 nose, 3 pups, 1 jt 2 3/8 STL Blank, and anchor billet, Make up coiltrack to coil and surface test 10/14/2016 10/14/2016 2.00 PROD1 STK TRIP T Trip in well, EDC open, pumping 116.0 7,570.0 02:00 04:00 minimum rate 10/14/2016 10/14/2016 0.10 PROD1 STK DLOG T Log K1 for -13.5' 7,570.0 7,594.0 04:00 04:06 Page 16/23 Report Printed: 10/25/2016 Operations Summary (with Timelog Depths) 1 H-07 -01 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (MB) 10/14/2016 10/14/2016 0.70 PROM STK WPST T Continue in hole, set down in window 7,594.0 7,988.0 04:06 04:48 with anchor slips at bottom of window. Pull up5K over, RIH and stack out. Pull up to neutral weight on DHWOB and orient anchor, worked through window @ 200°. Continue in hole orient slipback to 30° ROHS. Start taking weight @ 7984 - top offish. Get to 25001-bs DHWOB @ 7988. Slips @ 7943.2. Pumps on tool shifted @ 320OPSI set 2.5K down. Looks good, TOB=7933 10/14/2016 10/14/2016 1.70 PROM STK TRIP T Good Set POOH, PUW=41K 7,988.0 116.0 04:48 06:30 10/14/2016 10/14/2016 2.50 PROM STK PULD T Breakdown BHA #14, make up jet 116.0 0.0 06:30 09:00 nozzel, jet stack. 10/14/2016 10/14/2016 1.00 PROM STK BOPE T Flush Stack and reel 0.0 0.0 09:00 10:00 10/14/2016 10/14/2016 6.00 PROM STK BOPE T BOP Test 250/3500 psi (annular 2500 0.0 0.0 10:00 16:00 psi), witnessed by AOGCC Inspector, Chuck Sheve. Swab 1 & 2 leaked. Carry on with BOP test. 10/14/2016 10/14/2016 1.25 PROM STK RURD T Lay down test joint, re -head ELine 0.0 0.0 16:00 17:15 (BHI), tested continuity was 1.6 M ohm, checked/cleand flow sub and retested, 96 M ohm. Stab on to blow down stack and WC chokes. 10/14/2016 10/14/2016 0.75 FROM STK PULD T PJSM, P/U BHA # 15, with 2.2° motor 0.0 72.2 17:15 18:00 and Hughes bit 10/14/2016 10/14/2016 0.50 PROD1 STK PULD T Crew change out / Valve check list 72.2 72.2 18:00 18:30 10/14/2016 10/14/2016 0.60 PROD1 STK PULD T PJSM, M/U injector to coil track and 72.2 72.2 18:30 19:06 suface test 10/14/2016 10/14/2016 1.40 PROD1 STK TRIP T Trip in well with BHA #15, Test HOT 72.2 7,510.0 19:06 20:30 while tripping in 10/14/2016 10/14/2016 0.10 PROM STK DLOG T Log K1 for -12' correction 7,510.0 7,519.0 20:30 20:36 10/14/2016 10/14/2016 0.10 PROD1 STK TRIP T Continue into well 7,519.0 7,550.0 20:36 20:42 10/14/2016 10/14/2016 1.60 PROM STK CIRC T Stop @ 7550', EDC open, displace 7,550.0 7,550.0 20:42 22:18 well back to 8.6PPG flo pro, Shut EDC, PUW=33K 10/14/2016 10/14/2016 0.30 PROD1 STK TRIP T Trip in hole, Clean pass through 7,550.0 7,936.0 22:18 22:36 window, Tag billet @ 7936, P/U 10/14/2016 10/15/2016 1.40 PROM STK KOST T Bring on pumps, 1.77 BPM @ 4350 7,936.0 7,938.6 22:36 00:00 PSI FS, BHP=3910, Call milling @ 7936.2 10/15/2016 10/15/2016 0.20 PROM STK KOST T Continue milling billet kick off, 1.77 7,938.6 7,939.0 00:00 00:12 BPM @ 4350 PSI FS, BHP=3910 10/15/2016 10/15/2016 0.50 PROD1 STK DRLG T Go to 10-20 FPH, 1.73 BPM @ 4200 7,939.0 7,946.0 00:12 00:42 PSI FS, BHP=3910 10/15/2016 10/15/2016 0.90 PROM DRILL DRLG T 7946', Drill ahead, 1.75 BPM @ 4200 7,946.0 7,975.0 00:42 01:36 PSi FS, BHP=3905 10/15/2016 10/15/2016 0.10 FROM DRILL WPRT T Drift billet area, PUW=36K, Clean 7,975.0 7,975.0 01:36 01:42 pass up and down 10/15/2016 10/15/2016 1.90 PROM DRILL DRLG T 7975', Drill, 1.75 BPM @ 4200 PSI 7,975.0 8,065.0 01:42 03:36 FS, BHP=3930 Page 17123 Report Printed: 10/25/2016 tea -� Operations Summary (with Timelog Depths) 1 H-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/15/2016 10/15/2016 3.00 PROD1 DRILL WPRT T 8065, DD Wiper, getting less then 8,065.0 8,065.0 03:36 06:36 expected DLS. Planned for 45's, Came off billet @ 43°, Last two surveys 28 - 33°. Now need 35's to skirt edge of polygon. Confer with rig Geo / Town engineer 10/15/2016 10/15/2016 5.90 PROD1 DRILL DRLG T 8065' drill ahead to 8104', come off 8,065.0 8,300.0 06:36 12:30 bottom and pull up to 8050', BHI tool glitch. Back to drilling at average ROP 30 to 50 FPH, made BHA wiper at 8250', change pump rate to 1.6 bpm, 4177 CP, 361 WHP, 4043 BHP, 517 off bottom dP 10/15/2016 10/15/2016 0.30 PROD1 DRILL WPRT T Wiper up to 7965' at 50 FPM, 37K 8,300.0 8,300.0 12:30 12:48 PUW. Trip back in at 50 FPM, 16K. 10/15/2016 10/15/2016 1.70 PROD1 DRILL DRLG T Continue drilling ahead to 8360' 8,300.0 8,360.0 12:48 14:30 10/15/2016 10/15/2016 0.50 PROD1 DRILL WPRT T Wiper trip up to 8060' while DD, GEO 8,360.0 8,360.0 14:30 15:00 and Directional Planner discuss WP13 targets. 10/15/2016 10/15/2016 6.30 PROD1 DRILL WPRT T Continue drilling ahead, 1.72 BPM @ 8,360.0 8,615.0 15:00 21:18 4650 CP, 390 WHP, 4153 BHP, 556 dP off bottom, 10/15/2016 10/15/2016 2.20 PROD1 DRILL TRIP T TD Build / Turn section @ 8615, Pump 8,615.0 55.2 21:18 23:30 5 X 5 Sweeps, Trip out, Open EDC @ 7804, AVG DLS 32.9- 10/15/2016 10/16/2016 0.50 PROD1 DRILL PULD T At surface, PJSM. Lay down BHA #15 55.2 55.2 23:30 00:00 10/16/2016 10/16/2016 1.50 PROD1 DRILL PULD T Complete PUD BHA #15 55.0 0.0 00:00 01:30 10/16/2016 10/16/2016 1.50 PROD1 DRILL PULD T PJSM, PD BHA #16 lateral section 0.0 72.2 01:30 03:00 with .5° AKO motor and RB HYC bi- center bit. Make up to coil and surface test. 10/16/2016 10/16/2016 1.40 PROD1 DRILL TRIP T Trip in hole, EDC open, Pumping min 72.2 7,510.0 03:00 04:24 rate 10/16/2016 10/16/2016 0.20 PROD1 DRILL DLOG T Log K1 tie in for -15' correction, Shut 7,510.0 7,520.0 04:24 04:36 EDC, PUW=34K 10/16/2016 10/16/2016 1.80 PROD1 DRILL TRIP T Continue in well to drill, work pipe to 7,520.0 8,609.0 04:36 06:24 bottom, stack out at 8609', 51 K PUW 10/16/2016 10/16/2016 2.60 PROD1 DRILL WPRT T Clean hole, wiper up to billet, RBIH, 8,609.0 8,609.0 06:24 09:00 try drilling to bottom, work tight spot at 8490' to 8510', made multiple attempts to get back to bottom, sit down at 8600' and lose 5' to 10' of ground each time we pick up and turn around. Pick up weights are sticky, 45K to 55K, see -2K to -4K overpull on DHWOB, heavy returns on shaker, very fine grained silty sandstone, fine shale and siltstone. 10/16/2016 10/16/2016 2.00 PROD1 DRILL DRLG T Drill to bottom from 8606' to 8615', drill 8,609.0 8,723.0 09:00 11:00 ahead at 1.62 bpm, 4408 CP, 294 WHP, 4035 BHP, 780 dP on bottom, 2.5K WOB, 1 OK CW. BHA wiper at 8694', 35K PUW, 10/16/2016 10/16/2016 4.00 PROD1 DRILL DRLG T 8723' new mud (sys 4) at bit, 9.8K 8,723.0 8,790.0 11:00 15:00 CW, 1.61 bpm, 4277 CP, 286 WHP, 4072 BHP, 695 dP, 1.4K WOB Page 18/23 Report Printed: 10/25/2016 Operations Summary (with Timelog Depths) 1H-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dar (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 10/16/2016 10/16/2016 2.50 PROD1 DRILL WPRT T Wiper trip, clean PU 36K, pulled thru 8,790.0 7,780.0 15:00 17:30 tight spots 8590' and 8470', 45 to 53K, continued to 8000', RBIH and sat down at 8065, 8170, 8490', 8640', worked tight spots to 8670', got back to 8700' pulled 62K with no change in WOB, wiper back to 8000', try to go back down, not able to pass 8600', wiper back to the tubing. Open EDC and 1.89 bpm, PUH to 7501 for tie in 10/16/2016 10/16/2016 0.20 PROD1 DRILL DLOG T Log K1 for+7', 7,501.0 7,514.0 17:30 17:42 10/16/2016 10/16/2016 1.50 PROD1 DRILL WPRT T RBIH to drill, cloase EDC @ 7798, 7,514.0 8,609.0 17:42 19:12 Multiple tight spots, Unable to get past 8609 with multiple speeds and tool faces. Hard bottom with stalls. Pick ups @ 50K but consistant. Confer with town, drill through tight spot @ 70 to 80° LOHS 10/16/2016 10/16/2016 1.90 PROD1 DRILL DRLG T Attempt to drill past tight spot @ 8609, 8,609.0 8,659.0 19:12 21:06 1.68 BPM @ 4225 PSi FS, BHP=4215, TF 70° LOHS. Never got in old hole, Near bit changing from other hole, Drill ahead 50' 10/16/2016 10/16/2016 0.60 PROD1 DRILL WPRT T Wiper trip from 8659, got past 8609, 8,659.0 8,090.0 21:06 21:42 PUH to 8093, Tight spots with motor work and over pulls 8600 to 8430, Pull up to 8090 10/16/2016 10/16/2016 0.80 PROD1 DRILL WPRT T RBIH to drill, Hole in better shape, still 8,090.0 8,659.0 21:42 22:30 ratty 8430 to 8500, Easy past 8607 10/16/2016 10/17/2016 1.50 PROD1 DRILL DRLG T 8659', Drill, 1.7 BPM @ 4465PSI FS, 8,659.0 8,726.0 22:30 00:00 BHP=4100 PSI 10/17/2016 10/17/2016 1.90 PROD1 DRILL DRLG T 8726', Drill ahead, 1.7 BPM @ 4390 8,726.0 8,826.0 00:00 01:54 PSI FS, BHP=4115, RIW=7.7K DHWOB=2.2K 10/17/2016 10/17/2016 0.50 PROD1 DRILL WPRT T BHA wiper, 100', PUW=43 8,826.0 8,826.0 01:54 02:24 10/17/2016 10/17/2016 3.80 PROD1 DRILL DRLG T 8826', Drill, 1.7 BPM @ 4375 PSI FS, 8,826.0 8,960.0 02:24 06:12 BHP=4170, RIW=7.3 @ 1K DHWOB 10/17/2016 10/17/2016 0.70 PROD1 DRILL WPRT T Wiper to 8400', PUW off bottom was 8,960.0 8,960.0 06:12 06:54 53K, worked tight areas, pulled tight at 8400' to 58K, opted to stay below 8400', worked to get past 8600' 10/17/2016 10/17/2016 2.70 PROD1 DRILL DRLG T 8960', Drill, 1.60 BPM, @ 4190 PSI 8,960.0 9,050.0 06:54 09:36 FS, 4225 BHP, 9.6K, 1.9K WOB. ROP avg 35 FPH. PU off bottom, change rate to try to get higher ROP, 1.75 BPM, 4675 PSI FS, 4280 BHP, 550 dP, not much change in ROP 30 to 50 FPH 10/17/2016 10/17/2016 0.20 PROD1 DRILL WPRT T BHA wiper, 1 00'to 8950', PUW=62K 9,053.0 9,050.0 09:36 09:48 10/17/2016 10/17/2016 4.50 PROD1 DRILL DRLG T 9050', Drill at 1.76 bpm, 4675 PSI FS, 9,050.0 9,262.0 09:48 14:18 4280 BHP, 550 dP. At 9153' pumped 5x5 Lo/Hi Vis sweep, seeing some stick/slip, got back small gravel size pieces of sand/shale. At 9167' pumped a 5x5 Lo/Hi sweep, At 9252' start 5x5 Lo/Hi vis sweep Page 19/23 Report Printed: 10/25/2016 Operations Summary (with Timelog Depths) r 1H-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 10/17/2016 10/17/2016 5.70 PROD1 DRILL WPRT T 9260', PUW= 62K, wiper up hole at 15 9,260.0 7,500.0 14:18 20:00 FPM, 33k CW, 1.8 bpm, 4600 CP, 371 WHIP, 4070 BHP, 578 dP, work though tight areas, pulled 63K at 8560', wiper up to 8000', attempt to RBIH and keep sitting down at 8509', tried to vary running speed, pump rates, tool face, keep sitting down in the same spot. Pump 5 bbl Hi Vis sweep, Consult town engineer, pull up into tubing, open EDC while waiting. 10/17/2016 10/17/2016 1.50 PROD1 DRILL TRIP T Trip out for different BHA 7,500.0 72.2 20:00 21:30 10/17/2016 10/17/2016 1.30 PROD1 DRILL PULD T Hold PJSM, PUD BHA# 16, 72.2 0.0 21:30 22:48 10/17/2016 10/18/2016 1.20 PROD1 DRILL PULD T MU BHA #17 with 1.2° AKO motor, 0.0 72.0 22:48 00:00 2.79" D331 mill with diamond side cut. PD BHA 10/18/2016 10/18/2016 1.30 PROD1 DRILL PULD T Continue PD BHA #17 with D331 and 72.0 72.0 00:00 01:18 1.2° motor, Inspect choke A, All good, M/U to coil and surface test tools 10/18/2016 10/18/2016 1.50 PROD1 DRILL TRIP T Trip in hole BHA #17, Test HOT on 72.0 7,510.0 01:18 02:48 way in 10/18/2016 10/18/2016 0.20 PROD1 DRILL DLOG T Log K1 for -15.5' correction, Close 7,510.0 7,520.0 02:48 03:00 EDC, PUW=34k, 10/18/2016 10/18/2016 3.50 PROD1 DRILL TRIP T Continue in well, Clean pass through 7,520.0 9,263.0 03:00 06:30 window, Initial set down @ 8492. Work pipe down to 8517, Back ream up Continue working to bottom. 8530 hard to get by 10/18/2016 10/18/2016 0.90 PROD1 DRILL WPRT T Made it to TD @ 9263', Pump 5 X 5 9,263.0 7,850.0 06:30 07:24 sweeps and chase to window, PUW=38K 10/18/2016 10/18/2016 0.30 PROD1 DRILL WPRT T Pull up through window, Open EDC 7,850.0 7,510.0 07:24 07:42 and circ 2 BPM, PUH to K1 10/18/2016 10/18/2016 0.20 PROD1 DRILL DLOG T Log K1 for +4' correction 7,510.0 7,517.0 07:42 07:54 10/18/2016 10/18/2016 0.70 PROD1 DRILL WPRT T RBIH, Close EDC @ 7822, Trip in to 7,517.0 9,260.0 07:54 08:36 TD @ 9260, hole in much better shape 10/18/2016 10/18/2016 2.30 PROD1 DRILL WPRT T Tag TD, Pump 10 X 10 sweeps and 9,260.0 62.0 08:36 10:54 chase to swab 10/18/2016 10/18/2016 1.50 PROD1 DRILL WPRT T Tag up, Reset counters, RBIH 62.0 7,510.0 10:54 12:24 10/18/2016 10/18/2016 0.20 PROD1 DRILL DLOG T Log K1 for -16' correction 7,510.0 7,538.0 12:24 12:36 10/18/2016 10/18/2016 2.00 PROD1 DRILL WPRT T Continue in well to confirm TD, Close 7,538.0 9,263.0 12:36 14:36 EDC @ 7801, Slight bobble @ 8600', Pretty clean to TD @ 9263 10/18/2016 10/18/2016 2.40 PROD1 DRILL TRIP T Trip out pumping beaded liner running 9,263.0 52.0 14:36 17:00 pill followed by 11.8 PPG Completion fluid, Paint EOP flag @ 6300', Continue out of well 10/18/2016 10/18/2016 0.50 PROD1 DRILL OWFF T Tag up at surface, Perform 30 Min 52.0 52.0 17:00 17:30 flow check 10/18/2016 10/18/2016 1.50 PROD1 DRILL PULD T PJSM, LD BHA #17 (D331 and 1.2° 52.0 0.0 17:30 19:00 motor). Page 20/23 Report Printed: 10/25/2016 Operations Summary (with Timelog Depths) 1 H-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/18/2016 10/18/2016 1.00 FROM DRILL PULD T PU BHA #18 (HCC RR and 0.5° 0.0 72.2 19:00 20:00 motor). 10/18/2016 10/18/2016 1.65 FROM DRILL TRIP T RIH with BHA #18, EDC open 72.2 7,510.0 20:00 21:39 10/18/2016 10/18/2016 0.20 PROM DRILL DLOG T Log K1 for-15.5' correction. 7,510.0 7,535.0 21:39 21:51 10/18/2016 10/19/2016 2.15 FROM DRILL DISP T Cont RIH to 7,810'. Displace well from 7,535.0 7,820.0 21:51 00:00 11.8 ppg K-formate brine to 8.6 ppg FloPro holding 11.4 ppg managed pressure schedule at the window. 10/19/2016 10/19/2016 0.20 PROD1 DRILL DISP T Finish displacing wellbore above 7,820.0 7,754.0 00:00 00:12 window from 11.8ppg K-formate brine to 8.6ppg FloPro. PUH to close EDC. PUW=31 k. 10/19/2016 10/19/2016 0.30 PROM DRILL TRIP T RIH, stacked out @ 8,051' once. PUH 7,754.0 8,531.0 00:12 00:30 and run through. Stacked out again @ 8,531'. Worked pipe varying speed from 5 to 50 FPM, tried various tool faces, no luck. 10/19/2016 10/19/2016 5.70 FROM DRILL WPRT T PUH, pull heavy @ 8,315'. Work pipe. 8,531.0 8,531.0 00:30 06:12 Cont POOH to above window. Discuss with town. Decision made to swap back to beaded liner pill and completion fluid (k-formate brine) and run liner. RBIH, pump 1 0x1 0 sweeps, PUH above window, wait on liner pill and completion fluid. RBIH to 8,531'. 10/19/2016 10/19/2016 2.90 PROM DRILL DISP T Trip out pumping beaded liner running 8,531.0 66.0 06:12 09:06 pill followed by 11.6 PPG completion fluid, Paint EOP flag 7690, and 6300' 10/19/2016 10/19/2016 0.50 FROM DRILL OWFF T At surface, perform 30 min no flow 66.0 66.0 09:06 09:36 10/19/2016 10/19/2016 0.90 PROD1 DRILL PULD T Good no flow, PJSM, Lay down BHA 66.0 0.0 09:36 10:30 #18 10/19/2016 10/19/2016 4.50 COMPZ1 CASING PUTB P PJSM, R/U floor to run liner, M/U BHA 0.0 1,428.2 10:30 15:00 #19 with non-ported bullnose, 15 AS slotted liner, 32 Jts blank and 6.42' seal bore deployment sleeve 10/19/2016 10/19/2016 1.00 COMPZ1 CASING PULD P M/U coiltrac to completion and surface 1,428.2 1,472.4 15:00 16:00 test 10/19/2016 10/19/2016 2.50 COMPZ1 CASING TRIP P Trip in hole, BHA#19 1,472.4 8,057.0 16:00 18:30 10/19/2016 10/19/2016 2.00 COMPZ1 CASING TRIP T Hard tag @ 8,057'. Worked liner at 8,057.0 1,472.0 18:30 20:30 various speeds (5-100 FPM), various pump rates, to no avail. Decision made with town to POOH with liner. 10/19/2016 10/19/2016 0.50 COMPZ1 CASING OWFF T At surface with coil, perform 30 min 1,472.0 1,472.0 20:30 21:00 flow check. 10/19/2016 10/19/2016 1.75 COMPZ1 CASING PULD T PJSM, LD BHA #19 (liner running 1,472.0 1,422.0 21:00 22:45 assembly). 10/19/2016 10/20/2016 1.25 COMPZ1 CASING PULD T LD 14jnts solid liner averaging 11-12 1,422.0 1,002.0 22:45 00:00 jnts/hr. 10/20/2016 10/20/2016 2.50 COMPZ1 CASING PULD T Cont LD remaining 33 jnts liner (47 1,002.0 0.0 00:00 02:30 total) averaging 13 jnts/hr. 10/20/2016 10/20/2016 1.50 COMPZ1 CASING PULD T PJSM, MU BHA #20 (D-331 mill 2.79" 0.0 62.4 02:30 04:00 NoGo + 1.2° AKO motor). Pull and replace UQC check valves. MU to coil connector and test tools. Page 21/23 Report Printed: 10/25/2016 Operations Summary (with Timelog Depths) 1 H-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (W) End Depth (ftKB) 10/20/2016 10/20/2016 1.40 COMPZ1 CASING TRIP T Trip in EDC closed, pumping min rate 62.4 7,510.0 04:00 05:24 10/20/2016 10/20/2016 0.20 COMPZ1 CASING DLOG T Log K1 for -15.5' correction 7,510.0 7,520.0 05:24 05:36 10/20/2016 10/20/2016 0.10 COMPZ1 CASING TRIP T RIH to just above window. 7,510.0 7,822.0 05:36 05:42 10/20/2016 10/20/2016 2.00 COMPZ1 CASING DISP T Displace 11.6ppg K -formate brine to 7,822.0 7,822.0 05:42 07:42 9.Oppg FloPro (higher weight due to K -formate mixing from previous fluid swaps). Receive EDC error code 4, BHI consult with town. Calibrate EDC in hole. Continue swapping to Flo Pro 10/20/2016 10/20/2016 2.80 COMPZ1 CASING WPRT T Continue in hole, Clean pass through 7,822.0 9,263.0 07:42 10:30 window. Tag up @ 8090 work pipe and back ream up from 8108. Work and get through 8530 tag up and ream up from 8624 to 8460. Set down at 8530 and attempt to get by. Pump sweep and ream up to 8450. RBIH to 8530 try to work past. Try different tool faces and go through @ 130° LOHS. Trip in to bottom 10/20/2016 10/20/2016 3.50 COMPZ1 CASING WPRT T PUH, PUW=33K, 8630 pulling heavy, 9,263.0 8,110.0 10:30 14:00 back ream area. 8544 again pulling heavy and slight packing off. Back ream up 8520 and 8497. recip these areas and work pipe up to 8110. 10/20/2016 10/20/2016 0.60 COMPZ1 CASING WPRT T Trip in hole to bottom, Liner running 8,110.0 9,263.0 14:00 14:36 pill ready to go, Stack out at 8497, Pick up and continue in hole 10/20/2016 10/20/2016 0.40 COMPZ1 CASING WPRT T Tag up at TD 9263, Recip waiting on 9,263.0 9,263.0 14:36 15:00 pill 10/20/2016 10/20/2016 2.00 COMPZ1 CASING TRIP T Trip out of hole laying in beaded liner 9,263.0 62.4 15:00 17:00 running pill 11.5PPG followed by 11.5PPG Completion fluid. Paint YELLOW flag @ 7,700' and WHITE flag @ 6,300'. 10/20/2016 10/20/2016 0.50 COMPZ1 CASING OWFF T Perform 30 min flow check. 62.4 62.4 17:00 17:30 10/20/2016 10/20/2016 1.50 COMPZ1 CASING PULD T LD BHA #20 (D331 mill + 1.2° AKO 62.4 0.0 17:30 19:00 motor). Mill was still 2.79" NoGo. 10/20/2016 10/20/2016 2.75 COMPZ1 CASING PULD T PJSM, MU liner assembly, BHA #21, 0.0 1,423.1 19:00 21:45 with 1.5° bent sub + 1.82' pup jnt + bull nose to simulate same lift as the previous BHA. RD power tongs. RU little jerks. 10/20/2016 10/20/2016 1.50 COMPZI CASING PULD T PJSM, MU liner assembly to running 1,423.1 1,479.7 21:45 23:15 tools, including Torque Through Deployment Sleeve to allow for orienting. CO UQC check valves, check inj PO. 10/20/2016 10/21/2016 0.75 COMPZ1 CASING TRIP T RIH BHA#21. 1,479.7 6,077.0 23:15 00:00 10/21/2016 10/21/2016 0.95 COMPZ1 CASING TRIP T RIH BHA#21 oriented HS. Stacked 6,077.0 8,052.0 00:00 00:57 out @ 8,052'. Worked pipe in 10° increments LOHS, 20-50 FPM. Passed through at 70°LOHS, 22 FPM. Page 22/23 Report Printed: 10/25/2016 Operations Summary (with Timelog Depths) 1H-07 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (fir) Phase Op Code Activity Code Cade Time P -T -x Operation (ftKB) End Depth (ftKB) 10/21/2016 10/21/2016 1.15 COMP21 CASING TRIP T Cont RIH oriented 130°LOHS. 8,052.0 8,538.0 00:57 02:06 Stacked out @ 8,538'. PUH, oriented to 160°ROHS and passed through. 10/21/2016 10/21/2016 2.80 COMPZ1 CASING TRIP P Cont RIH. Worked pipe extensively 8,538.0 9,022.0 02:06 04:54 from 8,900' to 9,022'. Worked pipe in 20° increments, various speeds. Tried to stay above 8,900' while working pipe due to fault. 10/21/2016 10/21/2016 1.00 COMPZ1 CASING TRIP P Closed Choke, pressured up wellbore 9,022.0 9,061.0 04:54 05:54 to BHP @ tool=4200 psi. Worked pipe from 9,022' to 9,061'. PUWs —50-65k. Bled off pressure, cont to work pipe. Pressure up wellbore to BHP @ tool=4400 psi. Cont working pipe. 10/21/2016 10/21/2016 2.50 COMPZ1 CASING TRIP P Continue working pipe, loosing ground 9,061.0 9,079.0 05:54 08:24 at every pick up, Trying multilpe tool faces and running speeds 10/21/2016 10/21/2016 0.30 COMPZ1 CASING TRIP P Unable to get past 9079, consult with 9,079.0 9,045.0 08:24 08:42 town, Release from liner, TOL=7654.4, PUH 10/21/2016 10/21/2016 2.00 COMPZ1 CASING DISP P PUH to 9045, Reset depth for liner left 9,045.0 7,607.0 08:42 10:42 in hole, roll hole to seawater 10/21/2016 10/21/2016 3.80 COMPZ1 CASING DISP P Trip out of well, Pump 25 BBIs freeze 7,607.0 41.0 10:42 14:30 protect well from 2500' 10/21/2016 10/21/2016 2.50 COMPZ1 CASING PULD P At surface, PJSM, PUD BHA #21, 41.0 0.0 14:30 17:00 FVS not holding, Power up and shut EDC. Cont PUD ops. 10/21/2016 10/21/2016 2.50 DEMOB WHDBOP MPSP P PJSM, RU and lubricate in BPV, 550 0.0 0.0 17:00 19:30 psi WHP. BPV set, RD lubricator. 10/21/2016 10/22/2016 4.50 DEMOB WHDBOP RURD P Pull UQC checks, blow down stack, 0.0 0.0 19:30 00:00 reel, other rig lines. Troubleshoot Gen power issue. 10/22/2016 10/22/2016 3.00 DEMOB WHDBOP NUND P Finish blowing down lines, ND BOP, 0.0 0.0 00:00 03:00 install tree cap. **Rig Release @ 0300 after ND BOP** Cont with rig down checklist, trucks arrived 0400. Page 23/23 Report Printed: 10/25/2016 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1 H Pad 1 H -07A 50-029-20755-01 Baker Hughes INTEQ Definitive Survey Report 24 October, 2016 rel BAKER HUGHES - ConocoPhillips 200.00 ConocoPhillips Survey Audit Notes: Start Date Definitive Survey Report 1/8/2001 Company: ConocoPhillips (Alaska) Inc. -Kupt Local Coordinate Reference: Well 1H-07 Project: Kuparuk River Unit TVD Reference: 1 H-07 @ 85.00usft (1 H-07) Site: Kuparuk 1 H Pad MD Reference: 1 H-07 @ 85.00usft (1 H-07) Well: 1H-07 North Reference: True Wellbore: 1H -07A Survey Calculation Method: Minimum Curvature Design: iH-07A Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit, North Slope Alaska, United States 0.00 0.00 Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Date 1011912016 Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1 H-07 (usft) (usft) Well Position -NI-S 0.00 usft Northing: 5,979,935.13usft Latitude: +EI -W 0.00 usft Easting: 549,560.55usft Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: Wellbore 1H -07A 1H-07APB1 (11-1-07AP81) MWD Magnetics Model Name Sample Date Declination 1+) Dip Angle (1) BGGM2016 9/1/2016 18.07 80,98 Design 1H -07A 200.00 Survey Audit Notes: Start Date End Date 1/8/2001 version: 1.0 Phase: ACTUAL Tie On Depth: 8,600.77 10/16/2016 Vertical Section: Depth From (TVD) -NIS +E7 -W (usft) (usft) (usft} 85.00 0.00 0.00 Survey Program Date 1011912016 From To (usft) (usft) Survey (Wellbore) Tool Name Description 100.00 7,800.00 1 H-07 (1 H-07) BOSS -GYRO Sperry -Sun BOSS gyro multishot 7,840.50 7,930.52 1H-07APB1 (11-1-07AP81) MWD MWD - Standard 7,936.00 8,600.77 1H-07APB3(1 H-07APB3) MWD MWD - Standard 8,607.00 9,225.47 1H -07A(1 H -07A) MWD MWD -Standard MANN BAKER HUGHES 70° 21' 21.476 N 149° 35'51.058 W 0 00 usft Field Strength (nT) 57,554 Direction r) 200.00 Survey Survey Start Date End Date 1/8/2001 10/1/2016 10/6/2016 10/13/2016 10/16/2016 10/16/2016 10/19/2016 1024!1016 5.24:31PM Page 2 COMPASS 5000.1 Build 74 Survey MD ConocoPhillips fAzf ConocoPhillips TVDSS +N/ -S +El -W Definitive Survey Report Map Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 11-1-07 Project: Kupamk River Unit TVD Reference: 1 H-07 @ 85.00usg (11-1-07) Site: Kuparuk 1 H Pad MD Reference: 1 H-07 @ 85.00usft (1 H-07) Well: 1H-07 North Reference: True Wellbore: 1H -07A Survey Calculation Method: Minimum Curvature Design: 1H -07A Database: EDM Alaska NSK Sandbox Survey MD Inc fAzf TVD TVDSS +N/ -S +El -W Map Map DLS Vertical (usft) (1) (1) (Usti) fusfl) (usft) (usft) Northing East) (°lt0o') Section SurveyToot Name 8,600.77 85.60 202.88 6,689.07 6,604.07 3,313.03 1,646.91 (n) 5,983,258.66 ift) 551,185.35 35.57 (ft) -3,676.50 MWD (3) 8,607.00 85.62 201.74 6,689.55 6,604.55 3,307.28 1,644.55 5,983,252.90 551,183.03 18.31 -3,670.30 MWD (4) 8,630.49 85.42 199.61 6,691.38 6,606.38 3,285.37 1,636.28 5,983,230.94 551,174.91 9.08 -3,646.88 MWD (4) 8,660.55 85.11 19702 6,693.87 6,608.87 3,256.94 1,626.87 5,983,202.44 551,165.68 8.65 -3,616.94 MWD (4) 8,685.97 85.82 196.14 6,695.88 6,610.88 3,232.65 1,619.64 5,983,178.11 551,158.61 4.44 -3,591.65 MWD (4) 8,715.72 86.68 196.02 6,697.82 6,612.82 3,204.12 1611.42 5,983,149.53 551,150.58 2.92 -3,562.03 MWD (4) 8,745.97 87.20 198.03 6,699.44 6,614.44 3,175.24 1,602.57 5,983,120.60 551,141.93 6.85 -3,531.86 MWD (4) 8,775.37 87.79 200.41 6,700.72 6,615.72 3,147.51 1,592.90 5,983,092.80 551,132.44 8.33 -3,502.50 MWD (4) 8,805.09 87.79 201.75 6,701.87 6,616.87 3,119.80 1,582.22 5,983,065.03 551,121.95 4.51 -3,472.81 MWD (4) 8,835.41 87.85 203.10 6,703.02 6,618.02 3,091.79 1,570.67 5,983,036.95 551,110.58 4.45 -3,442.54 MWD(4) 8,865.76 89.29 207,16 6,703.78 6,618.78 3,064.33 1,557.78 5,983,009.40 551,097,88 14.19 -3,412.32 MWD (4) 8,895.40 88.89 209.42 6,704.25 6,619.25 3,038.24 1,543.74 5,982,983.22 551,084.01 7.74 -3,383.00 MWD (4) 8,925.36 88.62 210.99 6,704.90 6,619.90 3,012.35 1,528.67 5,982,957.24 551,069.11 5.32 -3,353.52 MWD (4) 8,955.65 88.99 212.69 6,705.54 6,620.54 2,986.46 1,512.59 5,982,931.24 551,053.20 5.70 -3,323.69 MWD (4) 8,985.67 90.43 215.88 6,705.69 6,620.69 2,961.82 1,495.79 5,982,906.49 551,036.57 11.74 -3,294.79 MWD (4) 9,018.15 90.00 219.39 6,705.57 6,620.57 2,936.11 1,475.96 5,982,880.65 551,016.92 10.89 -3,263.85 MWD (4) 9,046.13 88.96 222.60 6,705.82 6,620.82 2,914.99 1,45261 5,982,859.42 550,998.71 1206. -3,237.73 MWD (4) 9,076.01 87.67 225.40 6,706.70 6,621.70 2,893.51 1,436.87 5,982,837.80 550,978.11 10.31 -3,210.45 MWD (4) 9,105.95 87.36 228.70 6,708.00 6,623.00 2,873.13 1,414.98 5,982,817.28 550,956.35 11.06 -3,183.81 MWD (4) 9,135.75 87.58 230.06 6,709.31 6,624.31 2,853.75 1,392.38 5,982,797.75 550,933.89 4.62 -3,157.87 MWD (4) 9,166.20 88.74 231.94 6,710.29 6,625.29 2,834.60 1,368.73 5,982,778.44 550,910.37 7.25 -3,131,78 MWD (4) 9,195.45 90.12 234.51 6,710.58 6,625.58 2,817.09 1,345.31 5,982,760.78 550,887.06 9.97 -3,107.32 MWD (4) i. 9,225.47 88.71 231.46 6,710.89 6,625.89 2,79902 1,321.34 5,982,742.56 550,863.22 11.19 -3,082.14 MWD (4) i 9,263.00 88.71 231.46 6,711.73 6,626.73 2,775.64 1,291.99 5,982,718.99 550,834.03 0.00 -3,050.14 PROJECTED to TD Annotation TIP KOP B,AKER`r HUGHES 10242016 5:24:31PM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1 H Pad 1 H-07APB1 50-029-20755-70 Baker Hughes INTEQ Definitive Survey Report 24 October, 2016 FIC FAI BAKER HUGHES w ConocoPhillips //'le ConocoPhillips BAKER Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupt Local Co-ordinate Reference: Well 1 H-07 Project: Kuparuk River Unit TVOReference: 1 H-07 @ 85.00usft (1 H-07) Site: Kuparuk 1 H Pad MD Reference: 1 H-07 @ 85.00usft (1 H-07) Well: 1H-07 North Reference: True Wellbore: iH-07APBl Survey Calculation Method: Minimum Curvature Design: 1 H-07AP81 Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point 'i Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1 H-07 Well Position +NIS 0.00 usft Northing: 5,979,935.13usft Latitude: 70° 21'21.476 N +E/ -W 0.00 Usti Easting: 549,560.55usft Longitude: 149° 35'51 .058 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1H-07APB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1) 111 InT) BGGM2016 9/1/2016 18.07 80.98 57,554 Design 1H-07APB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,800.00 Vertical Section: Depth From (TVD) +N/ -S +EFW Direction (usft) (usft) (usft) (1) - 85.00 0.00 0.00 200.00 Survey Program Date 10/6/2016 From To Survey Survey {usft) !usft) Survey( Wellbore) Tool Name Description Start pate End Date 100.00 7,800.00 1H-07 (1H-07) BOSS -GYRO Sperry -Sun BOSS gyro multishot 1/8/2001 7,840.50 9,338.22 1H-07APB1 (iH-07APBl) MWD MWD - Standard 10/1/2016 10/6/2016 10124!2016 5:25:36PM Page 2 COMPASS 5000.1 Budd 74 ConocoPhillips ConocoPhillips Definitive Survey Report Aid M/ jI ZMER UGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1 H-07 Map Project: Kuparuk River Unit TVD Reference: 1 H-07 @ 85.00usft (1 H-07) Site: Kuparuk 1 H Pad MD Reference: 1 H-07 @ 85.00usft (1 H-07) (usrt) Well: 1H-07 North Reference: True Naming Wellbore: 1 H-07APB1 Survey Calculation Method: Minimum Curvature Annotation Design: 1 H-07APB1 Database: EDM Alaska NSK Sandbox survey MD Inc Aid TVD NDSS rNI-S +E7 -W Map Map DLS Vertical Nam (1) (°I (usrt) (usn) (usft) (u�) Naming Eas#ng Section Surve Toot Name y Annotation (M (1! Plow) 11:1) 7,800.00 31.97 55.69 6,529.91 6,444.91 2,999.74 1,862.27 5,982,946.83 551,402.75 0.37 -3,455.77 MWD (2) TIP 7,840.50 31.77 55.94 6,564.31 6,479.31 3,011.76 1,879.96 5,982,958.96 551,420.36 0.59 -3,473.11 MWD (2) KOP 7,871.39 43.90 40.32 6,588.71 6,503.71 3,024.55 1,893.70 5,982,971.85 551,434.02 49.78 -3,489.84 MWD (2) - 7,900.08 53.42 30.09 6,607.67 6,522.67 3,042.17 1,905.96 5,982,989.55 551,446.16 42.56 -3,510.58 MWD (2) 7,930.52 62.75 21.96 6,623.76 6,538.76 3,065.37 1,917.19 5,983,012.82 551,457.23 38.09 -3,536.23 MWD (2) 7,960.31 67.69 15.58 6,636.26 6,551.26 3,090.97 1,925.85 5,983,038.47 551,465.73 25.55 3,563.24 MWD (2) 7,989.53 72.23 5.17 6,646.29 6,561.29 3,117.92 1,930.75 5,983,065.45 551,470.45 36.88 -3,590.24 MWD (2) 8,019.45 72.38 352.95 6,655.42 6,570.42 3,146.36 1,930.28 5,983,093.88 551,469.79 38.91 3,616.81 MWD (2) 8,04941 70.40 341.46 6,665.01 6,580.01 3,173.99 1,924.03 5,983,121.47 551,463.35 36.93 3,640.63 MWD (2) 8,080.19 68.31 328.89 6,675.90 6,590.90 3,200.08 1,911.98 5,983,147.47 551,451.14 38.80 3,661.03 MWD (2) 8,104.59 67.74 319.72 6,685.04 6,600.04 3,218.43 1,898.80 5,983,165.74 551,437.84 34.92 3,673.76 MWD (2) 8,135.61 69.43 308.05 6,696.40 6,611.40 3,238.39 1,878.02 5,983,185.56 551,416.93 35.43 3,685.42 MWD (2) 8,165.59 71.94 297.35 6,706.34 6,621.34 3,253.63 1,854.25 5,983,200.64 551,393.05 34.70 3,691.60 MWD (2) 8,195.54 75.29 287.52 6,714.81 6,629.81 3,264.56 1,827.72 5,983,211.39 551,366.46 33.41 -3,692.80 MWD (2) 8,226.35 75.86 276.56 6,722.51 6,637.51 3,270.77 1,798.59 5,983,217.41 551,337.29 34.50 3,688.67 MWD (2) y 8,255.61 76.88 264.25 6,729.43 6,64443 3,270.97 1,770.22 5,983,217.42 551,308.92 41.03 -3,679.15 MWD (2) 8,286.45 79.01 25366 6,735.89 6,650.89 3,265.19 1,740.66 5,983,211.44 551,279.41 34.28 -3,663.61 MWO(2) 8,316.02 81.84 240.80 6,740.82 6,65582 3,253.91 1,713.85 5,983,199.99 551,252.67 43.93 -3,643.85 MWD (2) 8,360.84 88.13 224.01 6,744.77 6,659.77 3,226.76 1,678.63 5,983,172.61 551,217.64 39.85 -3,606.29 MWD (2) 8,39267 90.37 220.63 6,745.19 6,660.19 3,203.23 1,657.21 5,983,148.95 551,196.37 12.74 -3,576.85 MWD (2) 8,420.50 90.18 219.24 6,745.05 6,660.05 3,181.90 1,639.35 5,983,127.49 551,178.65 5.04 3,550.69 MWD (2) 8,451.01 90.15 216.52 6,744.96 6,659.96 3,157.82 1,620.61 5,983,103.29 551,160.08 8.92 3,521.66 MWD (2) 8,480.36 90.21 214.41 6,744.87 6,659.87 3,133.91 1,603.59 5,983,079.28 551,143.21 7.19 -3,493.37 MWD (2) 8,512.46 89.42 211.83 6,744.98 6,659.98 3,107.03 1,586.05 5,983,052.28 551,125.86 8.41 -3,462.12 MWD (2) 8,540.92 88.71 208.95 6,745.44 6,660.44 3,082.49 1,571.66 5,983,027.65 551,111.63 10.42 3,434.13 MWD (2) 8,569.88 90.03 206.85 6,745.76 6,660.76 3,056.90 1,558.11 5,983,001.97 551,098.25 8.56 3,405.45 MWD (2) ,. 8,600.11 90.71 208.59 6,745.56 6,660.56 3,030.14 1,544.05 5,982,975.12 551,084.37 6.18 -3,375.49 MWD (2) 8,629.63 91.81 211.27 6,744.91 6,659.91 3,004.56 1,529.32 5,982,949.45 551,069.81 9.81 -3,346.43 MWD (2) 8,659.66 91.38 213.03 6,744.08 6,659.08 2,979.15 1,513.35 5,982,923.94 551,054.01 6.03 -3,317.08 MWD (2) 8,687.39 92.67 214.80 6,743.10 6,658.10 2,956.15 1,497.89 5,982,900.84 551,038.70 7.89 -3,290.18 MWD(!) IW412016 5.25:36PM Page 3 COMPASS 5000.1 Budd 74 ConocoPhillips ConocoPhillips Definitive Survey Report RN BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Coordinate Reference: Well 1H-07 Project: Kuparuk River Unit TVD Reference: 1 H-07 @ 85.00usft (1 H-07) MD Site: Kuparuk 1 H Pad MD. Reference: 1 H-07 @ 85.00usft (1 H-07) TVDSS WeIv 1H-07 North Reference: True E �g Wellbore: 1H-07APB1 Survey Calculation Method: Minimum Curvature (°) Design: 1 H-07APB1 Database: EDM Alaska NSK Sandbox (usft) Survey Map MD Inc Azi TVD TVDSS -NI-S +E/.W Northing E �g OLS Section (usft) (°) (j Oat) (usft) (usft) (usft) (ft) 00 (°M00') Survey Tool Name Annotation (ft) 8,720.21 92.52 216.10 6,741.61 6,656.61 2,92945 1,478.87 5,982,874.01 551,019.87 3.98 -3,258.58 MWD (2) 8,744.58 92.49 219.42 6,740.55 6,655.55 2,910.20 1,463.96 5,982,854.67 551,005.09 13.61 -3,235.40 MWD (2) 8,774.58 94.33 221.98 6,738.76 6,653.76 2,887.50 1,444.44 5,982,831.84 550,985.72 10.50 -3,207.39 MWD (2) 8,804.44 94.24 224.65 6,736.53 6,651.53 2,865.84 1,424.01 5,982,810.04 550,965.44 8.92 -3,180.05 MWD (2) 8,834.70 94.39 227.01 6,734.25 6,649.25 2,844.81 1402.37 5,982,788.88 550,943.94 7.79 -3,152.89 MWD (2) 8,866.07 94.39 229.76 6,731.85 6,646.85 2,824.04 1,378.99 5,982,767.96 550,920.69 8.74 3,125.37 MWD (2) 8,896.18 94.92 230.67 6,729.41 6,644.41 2,804.84 1,355.93 5,982,748.60 550,897.76 3.49 -3,099.44 MWD (2) 8,926.13 95.63 233.32 6,726.65 6,641.65 2,786.48 1,332.43 5,982,730.09 550,874.39 9.12 3,074.15 MWD (2) 8,956.06 96.03 236.01 6,723.61 6,638.61 2,769.26 1,308.14 5,982,712.71 550,850,22 9.04 -3,049.66 MWD (2) 8,986.05 96.25 238.19 6,720.41 6,635.41 2,753.06 1,283.11 5,982,696.35 550,825.30 7.26 -3,025.88 MWD (2) 9,016.57 96.43 240.32 6,717.03 6,632.03 2,737.56 1,257.04 5,982,680.68 550,799.33 6.96 -3,002.39 MWD (2) 9,046.26 95.69 237.67 6,713.90 6,628.90 2,722.35 1,231.74 5,982,665.30 550,774.13 9.22 -2,979.45 MWD (2) 9,076.10 94.74 236.06 6,711.19 6,626.19 2,706.11 1,206.86 5,982,648.90 550,749.36 6.25 -2,955.68 MWD (2) 9,107.87 90.95 234.27 6,709.61 6,624.61 2,687.98 1,180.82 5,982,630.60 550,723.45 13.19 -2,929.74 MWD (2) 9,138.78 89.63 233.96 6,709.45 6,624.45 2,669.87 1,155.78 5,982,612.32 550,698.53 4.39 -2,904.15 MWD (2) 9,170.29 90.86 231.84 6,709.32 6,624.32 2,650.86 1,130.65 5,982,593.15 550,673.53 7.78 -2,877.70 MWD (2) 9,200.50 92.09 231.37 6,708.54 6,623.54 2,632.10 1,106.98 5,982,574.24 550,649.98 4.36 -2,851.98 MWD (2) 9,230.58 93.68 230.13 6,707.03 6,622.03 2,613.10 1,083.71 5,982,555.09 550,626.85 6.70 P -2,826.16 MWD (2) 9,260.58 95.01 229.62 6,704.76 6,619.76 2,593.82 1,060.84 5,982,535.66 550,604.11 4.75 -2,800.22 MWD (2) ' 9,290.40 96.18 229.42 6,701.85 6,61685 2,574.55 1,038.27 5,982,516.25 550,581.66 3.98 -2,774.40 MWD (2) 9,320.29 96.40 228.85 6,698.57 6,613.57 2,555.12 1,015.80 5,982,496.66 550,559.33 2.03 -2,748.45 MWD (2) 9,338.22 95.04 227.79 6,696.79 6,611.79 2,543.25 1,002.48 5,982,484.71 550,546.08 9.60 -2,732.74 MWD(2) 9,37800 95.04 227.79 6,693.29 6,608.29 2,516.63 973.12 5,982,457.90 550,516.91 0.00 -2,697.69 PROJECTEDto TD 10/248016 5.•25.B6PM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1 H Pad 1 H-07APB2 50-029-20755-71 Baker Hughes INTEQ Definitive Survey Report 24 October, 2016 WEaI BAKER HUGHES ConocoPhillips 10112 ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well IH-07 Project: Kuparuk River Unit TVD. Reference: 1 H-07 @ 85.00usft (1 H-07) Site: Kuparuk 1 H Pad MD Reference: 1 H-07 @ 85.00usft (1 H-07) Well: 1H-07 North Reference: True Wellbore: 1H-07APB2 Survey Calculation Method: Minimum Curvature Design: 1 H-07APB2 Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1 H-07 Well Position -NI-S 0.00 usft Northing: 5,979,935.13usft Latitude: 700 21' 21.476 N +E/-W 0.00 usft Easting: 549,560.55usft Longitude: 149° 35'51.058 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1H-07APB2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength l% 11 (nT) BGGM2016 9/1/2016 18.07 80.98 57,554 Design 1H-07APB2 Audit Notes: " Version: 1.0 Phase: ACTUAL Tie On Depth: 7,989.53 Vertical Section: Depth From (TVD) -NI-S +Ef-W Direction (usft) (usft) (usft) ( ) 85.00 0.00 0.00 200.00 Survey Program Date 10/12/2016 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 100.00 7,800.00 1H-07 (1H-07) BOSS-GYRO Sperry-Sun BOSS gyro multishot 1/8/2001 7,840.50 7,989.53 1H-07APB1 (1H-07APB1) MWD MWD- Standard 10/1/2016 10/6/2016 7,999.00 8,965.89 1H-07APB2(1 H-07APB2) MWD MWD- Standard 10/7/2016 10/12/2016 f 0242016 5:26:32PM Page 2 COMPASS 5000 1 Build 74 Survey ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupl Local Coordmate Reference: Well 11-1-07 Project: Kuparuk River Unit ND Reference: 1 H-07 @ 85.00usft (1 H-07) Site: Kuparuk 1H Pad MD Reference 1 H-07 @ 85.00usft (1 H-07) Well. 1H-07 North Reference: True Wellbore: 1 H-07APB2 Survey Calculation Method: Minimum Curvature Design: 1 H-07APB2 Database: EDM Alaska NSK Sandbox Survey Annotation TIP KOP Fails BAKER HUGHES 10124/2016 5:26.32PM Page 3 COMPASS 5000 1 Build 74 Map Map Vertical MD (usft) Inc (°) Axl (') TVD (usft) TVDSS (usft) -N/-S+E1•ilit (usft) (usit) Northing Eastin 0 DLS (11100.) Section Survey Tool Name (n) (ft) (ft) 7,989.53 72.23 5.17 6,646.29 6,561.29 3,117.92 1,930.75 5,983,065.45 551,470.45 36.88 -3,590.24 MWD (2) 7,99900 72.19 1.30 6,649.19 6,564.19 3,126.92 1,931.26 5,983,074.46 551,470.90 38.90 -3,598.88 MWD (3) 8,030.90 84.09 357.37 6,655.73 6,570.73 3,158.08 1,930.88 5,983,105.60 551,470.31 39.18 -3,628.02 MWD (3) 8,060.84 87.39 344.81 6,657.96 6,572.96 3,187.51 1,926.26 5,983,135.00 551,465.49 43.26 -3,654.10 MWD(3) 8,091.05 86.34 331.59 6,659.62 6,574.62 3,21545 1,915.08 5,983,162.87 551,454.13 43.83 -3,676.54 MWD (3) 8,120.83 86.31 318.80 6,661.54 6,576.54 3,239.81 1,898.15 5,983,187.11 551,437.04 42.86 -3,693.63 MIND (3) 8,150.64 87.08 305.12 6,663.27 6,578.27 3,259.66 1,876.07 5,963,206.81 551,414.84 45.89 -3,704.73 MWD(3) 8,180.72 87.85 292.68 6,664.60 6,579.60 3,274.15 1,849.82 5,983,221.13 551,388.49 41.39 -3,709.37 MWD (3) 8,210.61 83.29 280.36 6,666.92 6,581.92 3,282.61 1,821.31 5,983,229.40 551,359.93 43.82 -3,707.57 MWD (3) 8,240.74 80.87 267.24 6,671.09 6,586.09 3,284.60 1,791.61 5,983,231.19 551,330.21 43.87 -3,699.28 MWD(3) 8,270.62 79.94 254.16 6,676.09 6,591.09 3,279.85 1,762.60 5,983,226.25 551,301.24 43.27 -3,684.90 MWD (3) 8,300.88 80.60 239.87 6,681.23 6,596.23 3,268.23 1,735.22 5,983,214.45 551,273.94 46.59 -3,664.61 MWD (3) 8,330.13 80.72 226.15 6,686.00 Q601.00 3,250.91 1,712.22 5,983,196.98 551,251.06 46.28 -3,640.47 MWD (3) 8,360.77 80.76 222.94 6,690.93 6,605.93 3,229.36 1,691.01 5,983,175.29 551,230.00 10.34 -3,612.97 MWD (3) 8,390.28 81.44 220.14 6,695.50 6,610.50 3,207.54 1,671.68 5,983,153.35 551,210.81 9.65 -3,585.&5 MIND (3) 8,420.09 83.61 220.14 6,699.37 6,614.37 3,184.95 1,652.63 5,983,130.63 551,191.91 7.28 -3,558.10 MWD (3) 8,449.99 86.04 220.27 6,702.07 6,617.07 3,162.21 1,633.41 5,983,107.76 551,172.84 8.14 -3,530.16 MWD (3) 8,480.30 88.59 220.71 6,703.49 6,618.49 3,139.18 1,613.75 5,983,084.61 551,153.34 8.54 -3,501.80 MWD (3) 8,510.61 88.65 223.34 6,704.22 6,619.22 3,116.67 1,593.47 5,983,061.97 551,133.21 8.68 -3,473.71 MWD (3) 8,541.39 89.29 226.17 6,704.77 6,619.77 3,094.82 1,571.80 5,983,039.98 551,111.69 9.42 -3,445.77 MWD (3) 8,570.99 90.12 225.24 6,704.93 6,619.93 3,074.15 1,550.62 5,983,019.17 551,090.64 4.21 -3,419.10 MWD (3) 8,600.58 89.26 223.80 6,705.09 6,620.09 3,053.06 1,529.87 5,982,997.94 551,070.04 5.67 -3,392.18 MWD (3) 8,630.79 88.68 220.73 6,705.63 6,620.63 3,030.71 1,509.56 5,982,975.46 551,049.88 10.34 -3,364.23 MIND (3) 8,660.51 88.83 217.82 6,706.28 6,621.28 3,007.71 1490.75 5,982,952.34 551,031.22 9.80 -3,336.19 MWD(3) 8,691.11 88.28 215.22 6,707.05 6,622.05 2,983.12 1,472.55 5,982,927.64 551,013.19 8.68 -3,306.86 MWD (3) 8,721.19 89.08 214.15 6,707.74 6,622.74 2,958.40 1,455.43 5,982,902.80 550,996.24 4.44 3,277.77 MWD (3) 8,751.35 91.10 216.53 6,707.69 6,622.69 2933.80 1,437.99 5,982,878.09 550,978.96 10.35 -3,248.69 MWD (3) 8,781.19 90.12 218.66 6,707.38 6,622.38 2,910.16 1,419.79 5,982,854.33 550,960.92 7.86 -3,220.25 MWD (3) 8,811.19 89.72 221.18 6,707.42 6,622.42 2,887.15 1,400.54 5,982,831.20 550,941.82 8.51 -3,192.05 MWD (3) 8,841.19 89.20 222.47 6,707.70 6,622.70 2,864.80 1,380535 982,8()& 72 550,921.97 4.64 3,164.20 MWD (3) Annotation TIP KOP Fails BAKER HUGHES 10124/2016 5:26.32PM Page 3 COMPASS 5000 1 Build 74 `- ConocoPhillips NN ConocoPhillips Definitive Survey Report BAKER Company: ConocoPhillips (Alaska) Inc. -Kupi Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 1 H-07 Wellbore: 1 H-07APB2 Design: 1 H-07APB2 Survey Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 1 H-07 1 H-07 @ 85,00usft (1 H-07) 1 H-07 @ 85.00usft (1 H-07) True Minimum Curvature EDM Alaska NSK Sandbox Annotation 1"412016 5:26:32PM Page 4 COMPASS 5000.1 Build 74 Mop Map Vertical MD Inc Azi TVD TVDSS +NtS +E1 -W Northing Fasting DLS Section (u 1 (°j 1°l (usft) (usft) (usft) (usft) If (ft)j (°n00. Survey Tool Name (It) 8,870.49 8843 224.73 6,708.31 6,623.31 2,843.58 1,360.33 5,982,787.38 550,901.91 8.15 -3,137.36 MWD (3) 8,905.03 87.97 228.19 6,709.39 6,624.39 2,819.81 1,335.31 5,982,763.43 550,877.05 10.10 -3,106.46 MWD (3) 8,935.25 89.26 232.33 6,710.12 6,625.12 2,800.50 1,312.09 5,982,743.97 550,853.95 14.35 -3,080.37 MWD (3) 8,965.89 88.80 235.71 6,710.64 6,625.64 2,782.50 1,287.30 5,982,725.82 550,829.29 11.13 -3,054.98 MWD (3) 9,013.00 88.80 235.71 6,711.63 6,626.63 2,755.97 1,248.39 5,982,699.03 550,790.56 0.00 -3,016.73 PROJECTEDto TD Annotation 1"412016 5:26:32PM Page 4 COMPASS 5000.1 Build 74 "W' ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1 H Pad 1 H-07APB3 50-029-20755-72 Baker Hughes INTEQ Definitive Survey Report 24 October, 2016 rIC RI BAKER HUGHES V_' ConocoPhillips His ConocoPhillips Definitive Survey Report HKER ILIGHES Company: ConocoPhillips (Alaska) Inc. -Kupi Local Co-ordinate Reference: Well 1 H-07 Project: Kuparuk River Unit TVD Reference: 1 H-07 @ 85.00usft (1 H-07) Site: Kuparuk 1 H Pad MO Reference: 1 H-07 @ 85.00usft (1 H-07) Well: 1 H-07 North Reference: True Wellbore: 1H-07APB3 Survey Calculation Method: Minimum Curvature Design: 1 H-07APB3 Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1 H-07 Well Position -NI-S 0.00 usft Northing: 5,979,935.13usft Latitude: 70" 21' 21.476 N +EI-W 0.00 usft Easting: 549,560.55usft Longitude: 149" 35'51,058 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1H-07APB3 Magnetics Model Name Sample Date Declination Dip Angie Field Strength t°) (1) InT) BGGM2016 9/1/2016 18.07 80.98 57,554 Design 1H-07APB3 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,930.52 Vertical Section: Depth From (TVD) -NIS +Ef-W Direction (use) (use) (use) 11 85.00 0.00 0.00 200.00 Survey Program Data 1011912016 From To Survey survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End. Date 100.00 7,800.00 1H-07 (1H-07) BOSS-GYRO Sperry-Sun BOSS gyro multishot 1/8/2001 7,840.50 7,930.52 iH-07APB1 (iH-07APBI) MWD MWD- Standard 10/1/2016 10/6/2016 ' 7,936.00 8,750.61 1H-07APB3(1 H-07APB3) MWD MWD- Standard 10/13/2016 10/16/2016 IW412016 5.27'27PM Page 2 COMPASS 5000.1 Build 74 Survey Well 11-1-07 1 H-07 @ 85.00usft (1 H-07) 1 H-07 @ 85.00usft (1 H-07) True Minimum Curvature EDM Alaska NSK Sandbox ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 1H Pad MD Reference: Well: 1 H-07 North Reference: Wellbore: 1 H-07APB3 Survey Calculation Method: Design: 1 H-07APB3 Database: Survey Well 11-1-07 1 H-07 @ 85.00usft (1 H-07) 1 H-07 @ 85.00usft (1 H-07) True Minimum Curvature EDM Alaska NSK Sandbox Annotation TIP KOP was MHUl HO 1024/1016 5.2727PM Page 3 COMPASS 5000 1 Build 74 Map Map vertical MID (110,111(1)(°1 Inc Azl TVD Nam TVDSS Will +W -S r� +E/ -W Wall) Norming Easting OLS ' Section Survey 7001 Name Ing (to(^stool) (ft) 7,930.52 62.75 21.96 6,623.76 6,538.76 3,065.37 1,917.19 5,983,012.82 551,457.23 38.09 3,536.23 MWD(2) 7,936.00 63.64 20.75 6,626.23 6,541.24 3,069.93 1,918.97 5,983,017.39 551,458.98 25.54 -3,541.12 MWD (3) 7,965.76 75.21 27.00 6,636.68 6,551.69 3,095.32 1,930.27 5,983,042.86 551,470.12 43.54 -3,568.85 MWD (3) 7,990.15 84.01 31.55 6,641.08 6,556.08 3,116.22 1,942.00 5,983,063.82 551,481.70 40.47 3,592.49 MWD (3) 8,015.33 91.26 31.06 6,642.12 6,557.12 3,137.70 1,955.06 5,983,085.39 551,494.62 28.84 3,617.14 MWD (3) 8,035.24 91.62 24.37 6,641.62 6,556.62 3,155.31 1,964.32 5,983,103.06 551,503.76 33.63 -3,636.86 MWD (3) 8,060.34 91.35 15.91 6,640.97 6,555.97 3,178.85 1,972.95 5,983,126.65 551,512.23 33.72 -3,66193 MWD (3) 8,090.30 91.01 7.42 6,640.35 6,555.35 3,208.15 1,979.00 5,983,155.99 551,518.09 28.36 3,691.54 MWD (3) 8,120.31 88.83 358.78 6,640.39 6,555.39 3,238.09 1,980.62 5,983,185.94 551,519.51 29.69 -3,720.22 MWD (3) 8,150.29 86.41 350.40 6,641.63 6,556.63 3,267.88 1,977.80 5,983,215.71 551,516.49 29.05 -3,747.25 MWD (3) 8,180.75 83.02 342.01 6,644.44 6,559.44 3,297.31 1,970.58 5,983,245.08 551,509.08 29.61 3,772.43 MWD(3) 8,210.29 80.85 331.75 6,648.60 6,563.60 3,324.17 1,959.11 5,983,271.86 551,497.44 35.17 -3,793.75 MWD (3) 8,240.40 81.22 321.75 6,653.30 6,568.30 3,349.01 1,942.83 5,983,296.59 551,480.99 32.82 -3,811.52 MIND (3) 8,270.37 81.32 311.77 6,657.86 6,572.86 3,370.56 1922.56 5,983,318.01 551,460.58 32.89 3,824.85 MWD (3) 8,300.86 81.75 302.21 6,662.36 6,577.36 3,388.68 1,898.50 5,983,335.97 551,436.41 31.06 3,833.65 MWD (3) 8,330.29 82.49 292.68 6,666.40 6,581.40 3,402.10 1,872.66 5,983,349.21 551,410.48 32.18 -3,837.42 MWD (3) 8,360.41 82.80 283.07 6,670.26 6,585.26 3,411.26 1,844.26 5,983,358.18 551,382.03 31.66 3,836.31 MWD (3) 8,390.52 84,38 273.61 6,673.63 6,588.63 3,415.59 1,814.69 5,983,362.32 551,352.43 31.66 3,830.26 MWD (3) 8,420.33 85.21 263.80 6,676.34 6,591.34 3,414.91 1,785.05 5,983,361.45 551,322.80 32.88 -3,819.49 MWD (3) 8,450.47 85.36 253.88 6,678.83 6,593.83 3,409.11 1,755.62 5,983,355.45 551,293.41 32.80 3,803.97 MWD (3) 8,481.01 85.70 243.81 6,681.21 6,596.21 3,398.13 1,727.26 5,983,344.28 551,265.12 32.91 3,783.96 MWD (3) 8,510.31 85.92 233.48 6,683.36 6,598.36 3,382.95 1,702.34 5,983,328.93 551,240.31 35.15 -3,761.16 MWD (3) 8,540.33 86.81 223.49 6,685.27 6,600.27 3,363.11 1,679.94 5,983,308.96 551,218.04 33.36 -3,734.87 MWD (3) 8,570.67 86.59 213.57 6,687.02 6,602.02 3,33945 1,661.09 5,983,285.17 551,199.35 32.64 -3,706.18 MWD (3) 8,600.77 85.60 202.88 6,689,07 6,604.07 3,313.03 1,646.91 5,983,258.66 551,185.35 35.57 3,676.50 MWD (3) 8,630.82 85.72 197.38 6,691.35 6,606.35 3,284.91 1,636.60 5,983,230.47 551,175.22 18.26 3,646.55 MWD (3) 8,660.41 86.16 194.41 6,693.44 6,608.44 3,256.52 1,628.52 5,983,202.04 551,167.33 10.13 -3,617.12 MWD (3) 8,690.57 86.89 192.14 6,695.27 6,610.27 3,227.22 1,621.60 5,983,172.70 551,160.61 7.90 -3,587.22 MWD (3) 8,720.59 87.08 193.88 6,696.85 6,611.85 3,198.02 1,614.86 5,983,143.45 551,154.06 5.82 -3,557.47 MWD (3) 8,750.61 87.36 197.01 6,698.31 6,613.31 3,169.121,606.87 5,983,114.50 551,146.27 10.46 -3,527.58 MWD (3) Annotation TIP KOP was MHUl HO 1024/1016 5.2727PM Page 3 COMPASS 5000 1 Build 74 V. ConocoPhillips W/N ConocoPhillips Definitive Survey Report BAKER Company: ConocoPhillips (Alaska) Inc. -Kupi Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: 1 H-07 Wellbore: 1 H-07APB3 Design: 1H-07APB3 Survey MD Inc Azi TVD TVDSS (usft) (°) V) (usft) (usft) 8,790.00 87.36 197.01 6,70012 6,615.12 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: +N1S +EJ -W Map Northing (usft) (usft) (ft) 3,13149 1,595.36 5,983,076.80 Well 11-1-07 1 H-07 @ 85.00usft (1 H-07) 1 H-07 @ 85.00usft (1 H-07) True Minimum Curvature EDM Alaska NSK Sandbox Map Vertical Fasting MLS Section Survey Tool Name Annotation (ft) (°7900') (ft) 551,135.01 0.00 -3,488.29 PROJECTED to TD 10242016 5.27.27PM Page 4 COMPASS 5000.1 Build 74 RECEIVED NOV 15 2016 WELL LOG TRANSMITTAL #903603707 AOGCC To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multi Finger Caliper: 1H -07A Run Date: 10/13/2016 21 60 11 27 74 8 November 10, 2016 DATA LOGGED %X /25 /2014, m.K BENDER The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com 1H -07A Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-20755-01 Multi Finger Caliper (Field Log) 1 color log 50-029-20755-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS—ANC@halliburton.com Date: Signed: � e FfA &- 2 BAKER HUGHES To ECLIV ) 2 1 E ®1 1 C�� Letter of Transmittal Date: DATA LOGGED November 8, 2016 11KtBENDER Makana Bender AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 From: Yosha Ragbirsingh / Michael Soper Baker Hughes INTEQ 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 1H-07APB1 27 7 1 1 1H-07APB2 27 7 12 1H-07APB3 27 7 13 1H -07A 27 7 10 (4) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael. Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh@BakerHughes.com ConocoPhilli s p ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad 1 H -07A 50-029-20755-01 Baker Hughes INTEQ Definitive Survey Report 24 October, 2016 216011 27710 Few a I BAKER RUCHES ConocoPhillips WGill ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1 H-07 Project: Kuparuk River Unit TVD Reference: 1 H-07 @ 85.00usft (1 H-07) ) Site: Kuparuk 1 H Pad MD Reference: 1 H-07 @ 85.00usft (1 H-07) j Well: 1 H-07 North Reference: True Wellbore: 1 H -07A Survey Calculation Method: Minimum Curvature Design: 1 H -07A Database EDM Alaska NSK Sandbox Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1 H-07 Well Position +N/ -S 0.00 usft Northing: 5,979,935.13 usft Latitude: 70° 21'21,476 N +E/ -W 0.00 usft Easting: 549,560.55 usft Longitude: 149° 35' 51.058 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1 H -07A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) BG G M2016 9/1/2016 18.07 80.98 57,554 e Design 1H -07A _ .. r Audit Notes: . Version: 1.0 Phase: ACTUAL Tie On Depth: 8,600.77 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction !! (usft) (usft) (usft) (°) 85.00 0.00 0.00 200.00 Survey Program Date 10/19/2016 From To Survey 3 Survey i (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 100.00 7,800.00 1H-07 (1H-07) BOSS -GYRO Sperry -Sun BOSS gyro multishot 1/8/2001 7,840.50 7,930.52 1H-07APB1 (1H-07APB1) MWD MWD- Standard 10/1/2016 10/6/2016 7,936.00 8,600.77 1 H-07APB3 (1 H-07APB3) MWD MWD - Standard 10/13/2016 10/16/2016 8,607.00 9,225.47 1 H -07A (1 H -07A) MWD MWD - Standard 10/16/2016 10/19/2016 10/24/2016 5:24:31PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 1 H-07 Wellbore: 1 H -07A Design: 1 H -07A Survey (°) ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: MAP .9 BAKER HUGHES Well 11-1-07 1 H-07 @ 85.00usft (1 H-07) 1 H-07 @ 85.00usft (1 H-07) True Minimum Curvature EDM Alaska NSK Sandbox MD Inc Azi TVD TVDSS +N/ -S +E/ -W Map Map DLS Vertical (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (°/100') Section Survey Tool Name (ft) (ft) (ft) 8,600.77 85.60 202.88 6,689.07 6,604.07 3,313.03 1,646.91 5,983,258.66 551,185.35 35.57 -3,676.50 MWD (3) 8,607.00 85.62 201.74 6,689.55 6,604.55 3,307.28 1,644.55 5,983,252.90 551,183.03 18.31 -3,670.30 MWD (4) 8,630.49 85.42 199.61 6,691.38 6,606.38 3,285.37 1,636.28 5,983,230.94 551,174.91 9.08 -3,646.88 MWD (4) 8,660.55 85.11 197.02 6,693.87 6,608.87 3,256.94 1,626.87 5,983,202.44 551,165.68 8.65 -3,616.94 MWD (4) 8,685.97 85.82 196.14 6,695.88 6,610.88 3,232.65 1,619.64 5,983,178.11 551,158.61 4.44 -3,591.65 MWD (4) 8,715.72 86.68 196.02 6,697.82 6,612.82 3,204.12 1,611.42 5,983,149.53 551,150.58 2.92 -3,562.03 MWD (4) 8,745.97 87.20 198.03 6,699.44 6,614.44 3,175.24 1,602.57 5,983,120.60 551,141.93 6.85 -3,531.86 MWD (4) 8,775.37 87.79 200.41 6,700.72 6,615.72 3,147.51 1,592.90 5,983,092.80 551,132.44 8.33 -3,502.50 MWD (4) 8,805.09 87.79 201.75 6,701.87 6,616.87 3,119.80 1,582.22 5,983,065.03 551,121.95 4.51 -3,472.81 MWD (4) 8,835.41 87.85 203.10 6,703.02 6,618.02 3,091.79 1,570.67 5,983,036.95 551,110.58 4.45 -3,442.54 MWD (4) 8,865.76 89.29 207.16 6,703.78 6,618.78 3,064.33 1,557.78 5,983,009.40 551,097.88 14.19 -3,412.32 MWD (4) 8,895.40 88.89 209.42 6,704.25 6,619.25 3,038.24 1,543.74 5,982,983.22 551,084.01 7.74 -3,383.00 MWD (4) 8,925.36 88.62 210.99 6,704.90 6,619.90 3,012.35 1,528.67 5,982,957.24 551,069.11 5.32 -3,353.52 MWD (4) 8,955.85 88.99 212.69 6,705.54 6,620.54 2,986.46 1,512.59 5,982,931.24 551,053.20 5.70 -3,323.69 MWD (4) 8,985.67 90.43 215.88 6,705.69 6,620.69 2,961.82 1,495.79 5,982,906.49 551,.036.57 11.74 -3,294.79 MWD (4) 9,018.15 90.00 219.39 6,705.57 6,620.57 2,936.11 1,475.96 5,982,880.65 551,016.92 10.89 -3,263.85 MWD (4) 9,046.13 88.96 222.60 6,705.82 6,620.82 2,914.99 1,457.61 5,982,859.42 550,998.71 12.06 -3,237.73 MWD (4) 9,076.01 87.67 225.40 6,706.70 6,621.70 2,893.51 1,436.87 5,982,837.80 550,978.11 10.31 -3,210.45 MWD (4) 9,105.95 87.36 228.70 6,708.00 6,623.00 2,873.13 1,414.98 5,982,817.28 550,956.35 11.06 -3,183.81 MWD (4) 9,135.75 87.58 230.06 6,709.31 6,624.31 2,853.75 1,392.38 5,982,797.75 550,933.89 4.62 -3,157.87 MWD (4) 9,166.20 88.74 231.94 6,710.29 6,625.29 2,834.60 1,368.73 5,982,778.44 550,910.37 7.25 -3,131.78 MWD (4) 9,195.45 90.12 234.51 6,710.58 6,625.58 2,817.09 1,345.31 5,982,760.78 550,887.06 9.97 -3,107.32 MWD (4) 9,225.47 88.71 231.46 6,710.89 6,625.89 2,799.02 1,321.34 5,982,742.56 550,863.22 11.19 -3,082.14 MWD (4) 9,263.00 88.71 231.46 6,711.73 6,626.73 2,775.64 1,291.99 5,982,718.99 550,834.03 0.00 -3,050.14 PROJECTED to TO Annotation TIP KOP 10/24/2016 5.24.31 PM Page 3 COMPASS 5000.1 Build 74 21 60 11 2771 1 ConocoPhilli s p NOV 0 9 2�1v ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1 H Pad 1 H-07APB1 50-029-20755-70 Baker Hughes INTEQ F&AFA I Definitive Survey Report BAKER 24 October, 2016 �- ConocoPhillips W/a2 ConocoPhillips HUGHES Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1H-07 Project: Kuparuk River Unit TVD Reference: 1 H-07 @ 85.00usft (1 H-07) Site: Kuparuk 1 H Pad MD Reference: 1 H-07 @ 85.00usft (1 H-07) Well: 1 H-07 North Reference: True Wellbore: 1 H-07APB1 Survey Calculation Method: Minimum Curvature Design: 1 H-07APB1 Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit, North Slope Alaska, United States ..,- .:..�.......: ,...,»..., ..-...0 �:..........,..W..<.«.-....-�..+*www.,....,,.+.+-�w.»....o....._.:...,w-,. 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 IH -07 Well Position +N/ -S 0.00 usft Northing: 5,979,935.13 usft Latitude: 70° 21'21.476 N +E/ -W 0.00 usft Easting: 549,560.55 usft Longitude: 149° 35'51.058 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1 H-07APB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength ) (°) (°) (nT) BGGM2016 9/1/2016 18.07 80.98 57,554 Design 1 H-07APB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,800.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 4 (usft) (usft) (usft) (°) 85.00 0.00. 0.00 200.00 Survey Program Date 10/6/2016 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 100.00 7,800.00 1 H-07 (1 H-07) BOSS -GYRO Sperry -Sun BOSS gyro multishot 1/8/2001 7,840.50 9,338.22 1H-07APB1 (11-1-07AP131) MWD MWD- Standard 10/1/2016 10/6/2016 1012412016 5:25:36PM Page 2 COMPASS 5000.1 Build 74 10124/2016 5:25:36PM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips Woks ConocoPhillips BHKER Definitive Survey Report UGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1H-07 Project: Kuparuk River Unit TVD Reference: 1 H-07 @ 85.00usft (1 H-07) Site: Kuparuk 1 H Pad MD Reference: 1 H-07 @ 85.00usft (1 H-07) Well: 1 H-07 North Reference: True Wellbore: 1 H-07APB1 Survey Calculation Method: Minimum Curvature Design: 1 H-07APBl Database: EDM Alaska NSK Sandbox Survey Map Map Vertical MD Inc ) TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (1 (°) (usft) (usft) (usft) (usft) (°/100') Survey Tool Name y Annotation (ft) (ft) (ft) 7,800.00 31.97 55.69 6,529.91 6,444.91 2,999.74 1,862.27 5,982,946.83 551,402.75 0.37 -3,455.77 MWD (2) TIP 7,840.50 31.77 55.94 6,564.31 6,479.31 3,011.76 1,879.96 5,982,958.96 551,420.36 0.59 -3,473.11 MWD (2) KOP 7,871.39 43.90 40.32 6,588.71 6,503.71 3,024.55 1,893.70 5,982,971.85 551,434.02 49.78 -3,489.84 MWD (2) 7,900.08 53.42 30.09 6,607.67 6,522.67 3,042.17 1,905.96 5,982,989.55 551,446.16 42.56 -3,510.58 MWD (2) 7,930.52 62.75 21.96 6,623.76 6,538.76 3,065.37 1,917.19 5,983,012.82 551,457.23 38.09 -3,536.23 MWD (2) 7,960.31 67.69 15.58 6,636.26 6,551.26 3,090.97 1,925.85 5,983,038.47 551,465.73 25.55 -3,563.24 MWD (2) 7,989.53 72.23 5.17 6,646.29 6,561.29 3,117.92 1,930.75 5,983,065.45 551,470.45 36.88 -3,590.24 MWD (2) 8,019.45 72.36 352.95 6,655.42 6,570.42 3,146.36 1,930.28 5,983,093.88 551,469.79 38.91 -3,616.81 MWD (2) 8,049.41 70.40 341.46 6,665.01 6,580.01 3,173.99 1,924.03 5,983,121.47 551,463.35 36.93 -3,640.63 MWD (2) 8,080.19 68.31 328.89 6,675.90 6,590.90 3,200.08 1,911.98 5,983,147.47 551,451.14 38.80 -3,661.03 MWD (2) 8,104.59 67.74 319.72 6,685.04 6,600.04 3,218.43 1,898.80 5,983,165.74 551,437.84 34.92 -3,673.76 MWD (2) 8,135.61 69.43 308.05 6,696.40 6,611.40 3,238.39 1,878.02 5,983,185.56 551,416.93 35.43 -3,685.42 MWD (2) 8,165.59 71.94 297.35 6,706.34 6,621.34 3,253.63 1,854.25 5,983,200.64 551,393.05 34.70 -3,691.60 MWD (2) 8,195.54 75.29 287.52 6,714.81 6,629.81 3,264.56 1,827.72 5,983,211.39 551,366.46 33.41 -3,692.80 MWD (2) 8,226.35 75.86 276.56 6,722.51 6,637.51 3,270.77 1,798.59 5,983,217.41 551,337.29 34.50 -3,688.67 MWD (2) 8,255.61 76.88 264.25 6,729.43 6,644.43 3,270.97 1,770.22 5,983,217.42 551,308.92 41.03 -3,679.15 MWD (2) 8,286.45 79.01 253.66 6,735.89 6,650.89 3,265.19 1,740.66 5,983,211.44 551,279.41 34.28 -3,663.61 MWD (2) 8,316.02 81.84 240.80 6,740.82 6,655.82 3,253.91 1,713.85 5,983,199.99 551,252.67 43.93 -3,643.85 MWD (2) ) 8,360.84 88.13 224.01 6,744.77 6,659.77 3,226.76 1,678.63 5,983,172.61 551,217.64 39.85 -3,606.29 MWD (2) 8,392.67 90.37 220.63 6,745.19 6,660.19 3,203.23 1,657.21 5,983,148.95 551,196.37 12.74 -3,576.85 MWD (2) 8,420.50 90.18 219.24 6,745.05 6,660.05 3,181.90 1,639.35 5,983,127.49 551,178.65 5.04 -3,550.69 MWD (2) 8,451.01 90.15 216.52 6,744.96 6,659.96 3,157.82 1,620.61 5,983,103.29 551,160.08 8.92 -3,521.66 MWD (2) 8,480.36 90.21 214.41 6,744.87 6,659.87 3,133.91 1,603.59 5,983,079.28 551,143.21 7.19 -3,493.37 MWD (2) 3 m 8,512.46 89.42 211.83 6,744.98 6,659.98 3,107.03 1,586.05 5,983,052.28 551,125.86 8.41 -3,462.12 MWD (2) 8,540.92 88.71 208.95 6,745.44 6,660.44 3,082.49 1,571.66 5,983,027.65 551,111.63 10.42 -3,434.13 MWD (2) 8,569.88 90.03 206.85 6,745.76 6,660.76 3,056.90 1,558.11 5,983,001.97 551,098.25 8.56 -3,405.45 MWD (2) 8,600.11 90.71 208.59 6,745.56 6,660.56 3,030.14 1,544.05 5,982,975.12 551,084.37 6.18 -3,375.49 MWD (2) 8,629.63 91.81 211.27 6,744.91 6,659.91 3,004.56 1,529.32 5,982,949.45 551,069.81 9.81 -3,346.43 MWD (2) 8,659.66 91.38 213.03 6,744.08 6,659.08 2,979.15 1,513.35 5,982,923.94 551,054.01 6.03 -3,317.08 MWD (2) 8,687.39 92.67 214.80 6,743.10 6,658.10 2,956.15 1,497.89 5,982,900.84 551.038.70 7.89 -3,290.18 MWD (2) 10124/2016 5:25:36PM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 1 H-07 Wellbore: 1 H-07APB1 Design: 1 H-07APB1 Survey (°) ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: FeAFA2 BAKER HUGHES Well I H-07 1 H-07 @ 85.00usft (1 H-07) 1 H-07 @ 85.00usft (1 H-07) True Minimum Curvature EDM Alaska NSK Sandbox MD Inc Azi TVD TVDSS +N/ -S +E/ -W Map Map DLS Vertical (usft) (°) (°) (usft (usft) (usft) (usft) Northing Easting (°/loo.) Section Survey Tool Name (ft) (ft) (ft) 8,720.21 92.52 216.10 6,741.61 6,656.61 2,929.45 1,478.87 5,982,874.01 551,019.87 3.98 -3,258.58 MWD (2) 8,744.58 92.49 219.42 6,740.55 6,655.55 2,910.20 1,463.96 5,982,854.67 551,005.09 13.61 -3,235.40 MWD (2) 8,774.58 94.33 221.98 6,738.76 6,653.76 2,887.50 1,444.44 5,982,831.84 550,985.72 10.50 -3,207.39 MWD (2) 8,804.44 94.24 224.65 6,736.53 6,651.53 2,865.84 1,424.01 5,982,810.04 550,965.44 8.92 -3,180.05 MWD (2) 8,834.70 94.39 227.01 6,734.25 6,649.25 2,844.81 1,402.37 5,982,788.88 550,943.94 7.79 -3,152.89 MWD (2) 8,866.07 94.39 229.76 6,731.85 6,646.85 2,824.04 1,378.99 5,982,767.96 550,920.69 8.74 -3,125.37 MWD (2) 8,896.18 94.92 230.67 6,729.41 6,644.41 2,804.84 1,355.93 5,982,748.60 550,897.76 3.49 -3,099.44 MWD (2) 8,926.13 95.63 233.32 6,726.65 6,641.65 2,786.48 1,332.43 5,982,730.09 550,874.39 9.12 -3,074.15 MWD (2) 8,956.06 96.03 236.01 6,723.61 6,638.61 2,769.26 1,308.14 5,982,712.71 550,850.22 9.04 -3,049.66 MWD (2) 8,986.05 96.25 238.19 6,720.41 6,635.41 2,753.06 1,283.11 5,982,696.35 550,825.30 7.26 -3,025.88 MWD (2) 9,016.57 96.43 240.32 6,717.03 6,632.03 2,737.56 1,257.04 5,982,680.68 550,799.33 6.96 -3,002.39 MWD (2) 9,046.26 95.69 237.67 6,713.90 6,628.90 2,722.35 1,231.74 5,982,665.30 550,774.13 9.22 -2,979.45 MWD (2) 9,076.10 94.74 236.06 6,711.19 6,626.19 2,706.11 1,206.86 5,982,648.90 550,749.36 6.25 -2,955.68 MWD (2) 9,107.87 90.95 234.27 6,709.61 6,624.61 2,687.98 1,180.82 5,982,630.60 550,723.45 13.19 -2,929.74 MWD (2) 9,138.78 89.63 233.96 6,709.45 6,624.45 2,669.87 1,155.78 5,982,612.32 550,698.53 4.39 -2,904.15 MWD (2) 9,170.29 90.86 231.84 6,709.32 6,624.32 2,650.86 1,130.65 5,982,593.15 550,673.53 7.78 -2,877.70 MWD (2) 9,200.50 92.09 231.37 6,708.54 6,623.54 2,632.10 1,106.98 5,982,574.24 550,649.98 4.36 -2,851.98 MWD (2) 9,230.58 93.68 230.13 6,707.03 6,622.03 2,613.10 1,083.71 5,982,555.09 550,626.85 6.70 -2,826.16 MWD (2) 9,260.58 95.01 229.62 6,704.76 6,619.76 2,593.82 1,060.84 5,982,535.66 550,604.11 4.75 -2,800.22 MWD (2) 9,290.40 96.18 229.42 6,701.85 6,616.85 2,574.55 1,038.27 5,982,516.25 550,581.66 3.98 -2,774.40 MWD (2) 9,320.29 96.40 228.85 6,698.57 6,613.57 2,555.12 1,015.80 5,982,496.66 550,559.33 2.03 -2,748.45 MWD (2) 9,338.22 95.04 227.79 6,696.79 6,611.79 2,543.25 1,002.48 5,982,484.71 550,546.08 9.60 -2,732.74 MWD (2) 9,378.00 95.04 227.79 6,693.29 6,608.29 2,516.63 973.12 5,982,457.90 550,516.91 0.00 -2,697.69 PROJECTED to TD Annotation 10/24/2016 5:25:36PM Page 4 COMPASS 5000.1 Build 74 21 60.11 27712 ConocoPhillips NO ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad 1 H-07APB2 50-029-20755-71 Baker Hughes INTEQ WE R I Definitive Survey Report NUGHES 24 October, 2016 ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 1 H-07 Wellbore: 1 H-07APB2 Design: 1 H-07APB2 ConocoPhillips (A&I Definitive Survey Report BAKER HUGHES Local Co-ordinate Reference: Well 1H-07 TVD Reference: 1 H-07 @ 85.00usft (1 H-07) MD Reference: 1 H-07 @ 85.00usft (1 H-07) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point _ Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1 H-07 Well Position +N/ -S 0.00 usft Northing: 5,979,935.13 usft Latitude: 700 21'21.476 N +E/ -W 0.00 usft Easting: 549,560.55 usft Longitude: 1490 35' 51.058 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1 H-07APB2 ( Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2016 9/1/2016 18.07 80.98 57,554 Design 1H-07APB2 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,989.53 a Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 3 85.00 0.00 0.00 200.00 Survey Program Date 10/12/2016 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 100.00 7,800.00 1 H-07 (1 H-07) BOSS -GYRO Sperry -Sun BOSS gyro multishot 1/8/2001 7,840.50 7,989.53 1H-07APB1 (1H-07APB1) MWD MWD - Standard 10/1/2016 10/6/2016 7,999 00 8,965.89 1 H 07APB2 (1H 07APB2) MWD MWD - Standard 10/7/2016 10/12/2016 10/24/2016 5:26:32PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kupl +E/ -W Northing Project: Kuparuk River Unit 5,983,065.45 1,931.26 5,983,074.46 Site: Kuparuk 1H Pad 5,983,135.00 1,915.08 5,983,162.87 Well: 1 H-07 1,876.07 5,983,206.81 1,849.82 5,983,221.13 Wellbore: 1 H-07APB2 1,791.61 5,983,231.19 1,762.60 5,983,226.25 Design: 1 H-07APB2 1,712.22 5,983,196.98 1,691.01 5,983,175.29 Survey 5,983,153.35 1,652.63 5,983,130.63 1,633.41 5,983, 107.76 MD Inc Azi TVD TVDSS +N/ -S (usft) (I (°) (usft) (usft) (usft) 7,989.53 72.23 5.17 6,646.29 6,561.29 3,117.92 7,999.00 72.19 1.30 6,649.19 6,564.19 3,126.92 8,030.90 84.09 357.37 6,655.73 6,570.73 3,158.08 8,060.84 87.39 344.81 6,657.96 6,572.96 3,187.51 i 8,091.05 86.34 331.59 6,659.62 6,574.62 3,215.45 8,120.83 86.31 318.80 6,661.54 6,576.54 3,239.81 8,150.64 87.08 305.12 6,663.27 6,578.27 3,259.66 8,180.72 87.85 292.68 6,664.60 6,579.60 3,274.15 8,210.61 83.29 280.36 6,666.92 6,581.92 3,282.61 8,240.74 80.87 267.24 6,671.09 6,586.09 3,284.60 8,270.62 79.94 254.16 6,676.09 6,591.09 3,279.85 8,300.88 80.60 239.87 6,681.23 6,596.23 3,268.23 8,330.13 80.72 226.15 6,686.00 6,601.00 3,250.91 8,360.77 80.76 222.94 6,690.93 6,605.93 3,229.36 8,390.28 81.44 220.14 6,695.50 6,610.50 3,207.54 8,420.09 83.61 220.14 6,699.37 6,614.37 3,184.95 8,449.99 86.04 220.27 6,702.07 6,617.07 3,162.21 6,480.30 88.59 220.71 6,703.49 6,618.49 3,139.18 8,510.61 88.65 223.34 6,704.22 6,619.22 3,116.67 pp i 8,541.39 tt 89.29 226.17 6,704.77 6,619.77 3,094.82 8,570.99 90.12 225.24 6,704.93 6,619.93 3,074.15 8,600.58 89.26 223.80 6,705.09 6,620.09 3,053.06 8,630.79 88.68 220.73 6,705.63 6,620.63 3,030.71 8,660.51 88.83 217.82 6,706.28 6,621.28 3,007.71 8,691.11 88.28 215.22 6,707.05 6,622.05 2,983.12 I 8,721.19 89.08 214.15 6,707.74 6,622.74 2,958.40 8,751.35 91.10 216.53 6,707.69 6,622.69 2,933.80 8,781.19 90.12 218.66 6,707.38 6,622.38 2,910.16 8,811.19 89.72 221.18 6,707.42 6,622.42 2,887.15 8,841.19 89.20 222.47 6,707.70 6,622.70 2,854.80 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 11-1-07 1 H-07 @ 85.00usft (1 H-07) 1 H-07 @ 85.00usft (1 H-07) True Minimum Curvature EDM Alaska NSK Sandbox Map Vertical Easting DLS Section Survey Tool Name Annotation (ft) (°/100') (ft) 551,470.45 Map +E/ -W Northing (usft) (ft) 1,930.75 5,983,065.45 1,931.26 5,983,074.46 1,930.88 5,983,105.60 1,926.26 5,983,135.00 1,915.08 5,983,162.87 1,898.15 5,983,187.11 1,876.07 5,983,206.81 1,849.82 5,983,221.13 1,821.31 5,983,229.40 1,791.61 5,983,231.19 1,762.60 5,983,226.25 1,735.22 5,983,214.45 1,712.22 5,983,196.98 1,691.01 5,983,175.29 1,671.68 5,983,153.35 1,652.63 5,983,130.63 1,633.41 5,983, 107.76 1,613.75 5,983,084.61 1,593.47 5,983,061.97 1,571.80 5,983,039.98 1,550.62 5,983,019.17 1,529.87 5,982,997.94 1,509.56 5,982,975.46 1,490.75 5,982,952.34 1,472.55 5,982,927.64 1,455.43 5,982,902.80 1,437.99 5,982,878.09 1,419.79 5,982,854.33 1,400.54 51982,831.20 1,380.53 5,982,808.72 Well 11-1-07 1 H-07 @ 85.00usft (1 H-07) 1 H-07 @ 85.00usft (1 H-07) True Minimum Curvature EDM Alaska NSK Sandbox Map Vertical Easting DLS Section Survey Tool Name Annotation (ft) (°/100') (ft) 551,470.45 36.88 -3,590.24 MWD (2) TIP 551,470.90 38.90 -3,598.88 MWD (3) KOP 551,470.31 39.18 -3,628.02 MWD (3) 551,465.49 43.26 -3,654.10 MWD (3) 551,454.13 43.83 -3,676.54 MWD (3) 551,437.04 42.86 -3,693.63 MWD (3) 551,414.84 45.89 -3,704.73 MWD (3) 551,388.49 41.39 -3,709.37 MWD (3) 551,359.93 43.82 -3,707.57 MWD (3) 551,330.21 43.87 -3,699.28 MWD (3) 551,301.24 43.27 -3,684.90 MWD (3) 551,273.94 46.59 -3,664.61 MWD (3) 551,251.06 46.28 -3,640.47 MWD (3) 551,230.00 10.34 -3,612.97 MWD (3) 551,210.81 9.65 -3,585.85 MWD (3) 551,191.91 7.28 -3,558.10 MWD (3) 551,172.84 8.14 -3,530.16 MWD (3) 551,153.34 8.54 -3,501.80 MWD (3) 551,133.21 8.68 -3,473.71 MWD (3) 551,111.69 9.42 -3,445.77 MWD (3) 551,090.64 4.21 -3,419.10 MWD (3) 551,070.04 5.67 -3,392.18 MWD (3) 551,049.88 10.34 -3,364.23 MWD (3) 551,031.22 9.80 -3,336.19 MWD (3) 551,013.19 8.68 -3,306.86 MWD (3) 550,996.24 4.44 -3,277.77 MWD (3) 550,978.96 10.35 -3,248.69 MWD (3) 550,960.92 7.86 -3,220.25 MWD (3) 550,941.82 8.51 -3,192.05 MWD (3) 550,921.97 4.64 -3,164.20 MWD (3) r/il. BAKER HUGHES 10124/2016 5:26:32PM Page 3 COMPASS 5000.1 Build 74 10/24/2016 5:26:32PM Page 4 COMPASS 5000.1 Build 74 - ConocoPhillips rel iiI ConocoPhillips BAKER Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Co-ordinate Reference: Well 11-1-07 Project: Kuparuk River Unit TVD Reference: 1 H-07 @ 85.00usft (1 H-07) Site: Kuparuk 1H Pad MD Reference: 1 H-07 @ 85.00usft (1 H-07) Well: 1 H-07 North Reference: True Wellbore: 1 H-07APB2 Survey Calculation Method: Minimum Curvature 1 Design: 1 H-07APB2 Database: EDM Alaska NSK Sandbox Survey MD Inc Azi TVD TVDSS +N/ -S Map +E/ -W Map Vertical DLS (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting Section (°/100') Survey Tool Name Annotation (ft) (ft) (ft) 8,870.49 88.43 224.73 6,708.31 6,623.31 2,843.58 1,360.33 5,982,787.38 550,901.91 8.15 -3,137.36 MWD (3) 8,905.03 87.97 228.19 61709.39 6,624.39 2,819.81 1,335.31 5,982,763.43 550,877.05 10.10 -3,106.46 MWD (3) 8,935.25 89.26 232.33 6,710.12 6,625.12 2,800.50 1,312.09 5,982,743.97 550,853.95 14.35 -3,080.37 MWD (3) 8,965.89 88.80 235.71 6,710.64 6,625.64 2,782.50 1,287.30 5,982,725.82 550,829.29 11.13 -3,054.98 MWD (3) 9,013.00 88.80 235.71 6,711.63 6,626.63 2,755.97 1,248.39 5,982,699.03 550,790.56 0.00 -3,016.73 PROJECTED to TO 10/24/2016 5:26:32PM Page 4 COMPASS 5000.1 Build 74 ConocoPhilli s p ,3 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad 1 H-07APB3 50-029-20755-72 Baker Hughes INTEQ Definitive Survey Report 24 October, 2016 WE BAKER HUGHES 21 60 11 27713 ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 1 H-07 Wellbore: 1 H-07APB3 Design: 1 H -07A P B 3 Project Map System: Geo Datum: Map Zone: Well ConocoPhillips 1 H-07APB3 WIPA&V Definitive Survey Report _. BAKER HUGHES Local Co-ordinate Reference: Well 1H-07 Magnetics TVD Reference: 1 H-07 @ 85.00usft (1 H-07) MD Reference: 1 H-07 @ 85.00usft (1 H-07) Field Strength North Reference: True Survey Calculation Method: Minimum Curvature (°) (°) Database: EDM Alaska NSK Sandbox Kuparuk River Unit, North Slope Alaska, United States US State Plane 1927 (Exact solution) System Datum: Mean Sea Level NAD 1927 (NADCON CONUS) Using Well Reference Point 3 Alaska Zone 04 Using geodetic scale factor 8 1 H-07 Well Position +N/ -S 0.00 usft +E/ -W 0.00 usft Position Uncertainty 0.00 usft Northing: 5,979,935.13 usft Latitude: Easting: 549,560.55usft Longitude: Wellhead Elevation: usft Ground Level: 700 21'21.476 N 149° 35'51.058 W 0.00 usft Wellbore 1 H-07APB3 _. a Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) B G G M2016 9/1/2016 18.07 80.98 57,554 Design 1 H-07APB3 .w Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,930.52 3 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) 85.00 0.00 0.00 200.00 Survey Program Date 10/19/2016 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Start Date Survey End Date 100.00 7,800.00 1H-07 (1H-07) BOSS -GYRO Sperry -Sun BOSS gyro multishot 1/8/2001 7,840.50 7,930.52 1H-07APB1 (1H-07AP81) MWD MWD- Standard 10/1/2016 10/6/2016 7,936.00 8,750.61 1 H-07APB3 (lH-07APB3) MWD MWD- Standard 10/13/2016 10/16/2016 10/24/2016 5:27:27PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips FGk2 ConocoPhillips Definitive Survey Report BAKER Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 1 H-07 Wellbore: 1 H-D7APB3 Design: 1 H-07APB3 Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 1 H-07 1 H-07 @ 85.00usft (1 H-07) 1 H-07 @ 85.00usft (1 H-07) True Minimum Curvature EDM Alaska NSK Sandbox MD Inc Azi TVD TVDSS +N/ -S +E/ -W Map Map DLS Vertical (usft) (I C) (usft) (usft) (usft) (usft) Northing Easting (°/100') Section Survey Tool Name (ft) (ft) (ft) 7,930.52 62.75 21.96 6,623.76 6,538.76 3,065.37 1,917.19 5,983,012.82 551,457.23 38.09 -3,536.23 MWD (2) 7,936.00 63.64 20.75 6,626.23 6,541.24 3,069.93 1,918.97 5,983,017.39 551,458.98 25.54 -3,541.12 MWD (3) 7,965.76 75.21 27.00 6,636.68 6,551.69 3,095.32 1,930.27 5,983,042.86 551,470.12 43.54 -3,568.85 MWD (3) 7,990.15 84.01 31.55 6,641.08 6,556.08 3,116.22 1,942.00 5,983,063.82 551,481.70 40.47 -3,592.49 MWD (3) 8,015.33 91.26 31.06 6,642.12 6,557.12 3,137.70 1,955.06 5,983,085.39 551,494.62 28.84 -3,617.14 MWD (3) 8,035.24 91.62 24.37 6,641.62 6,556.62 3,155.31 1,964.32 5,983,103.06 551,503.76 33.63 -3,636.86 MWD (3) 8,060.34 91.35 15.91 6,640.97 6,555.97 3,178.85 1,972.95 5,983,126.65 551,512.23 33.72 -3,661.93 MWD (3) 8,090.30 91.01 7.42 6,640.35 6,555.35 3,208.15 1,979.00 5,983,155.99 551,518.09 28.36 -3,691.54 MWD (3) 8,120.31 88.83 358.78 6,640.39 6,555.39 3,238.09 1,980.62 5,983,185.94 551,519.51 29.69 -3,720.22 MWD (3) 8,150.29 86.41 350.40 6,641.63 6,556.63 3,267.88 1,977.80 5,983,215.71 551,516.49 29.05 -3,747.25 MWD (3) 8,180.75 83.02 342.01 6,644.44 6,559.44 3,297.31 1,970.58 5,983,245.08 551,509.08 29.61 -3,772.43 MWD (3) 8,210.29 80.85 331.75 6,648.60 6,563.60 3,324.17 1,959.11 5,983,271.86 551,497.44 35.17 -3,793.75 MWD (3) 8,240.40 81.22 321.75 6,653.30 6,568.30 3,349.01 1,942.83 5,983,296.59 551,480.99 32.82 -3,811.52 MWD (3) 8,270.37 81.32 311.77 6,657.86 6,572.86 3,370.56 1,922.56 5,983,318.01 551,460.58 32.89 -3,824.85 MWD (3) 8,300.86 81.75 302.21 6,662.36 6,577.36 3,388.68 1,898.50 5,983,335.97 551,436.41 31.06 -3,833.65 MWD (3) 8,330.29 82.49 292.68 6,666.40 6,581.40 3,402.10 1,872.66 5,983,349.21 551,410.48 32.18 -3,837.42 MWD (3) 8,360.41 82.80 283.07 6,670.26 6,585.26 3,411.26 1,844.26 5,983,358.18 551,382.03 31.66 -3,836.31 MWD (3) 8,390.52 84.38 273.61 6,673.63 6,588.63 3,415.59 1,814.69 5,983,362.32 551,352.43 31.66 -3,830.26 MWD (3) 8,420.33 85.21 263.80 6,676.34 6,591.34 3,414.91 1,785.05 5,983,361.45 551,322.80 32.88 -3,819.49 MWD (3) 8,450.47 85.36 253.88 6,678.83 6,593.83 3,409.11 1,755.62 5,983,355.45 551,293.41 32.80 -3,803.97 MWD (3) 8,481.01 85.70 243.81 6,681.21 6,596.21 3,398.13 1,727.26 5,983,344.28 551,265.12 32.91 -3,783.96 MWD (3) 8,510.31 85.92 233.48 6,683.36 6,598.36 3,382.95 1,702.34 5,983,328.93 551,240.31 35.15 -3,761.16 MWD (3) 8,540.33 86.81 223.49 6,685.27 6,600.27 3,363.11 1,679.94 5,983,308.96 551,218.04 33.36 -3,734.87 MWD (3) 8,570.67 86.59 213.57 6,687.02 6,602.02 3,339.45 1,661.09 5,983,285.17 551,199.35 32.64 -3,706.18 MWD (3) 8,600.77 85.60 202.88 6,689.07 6,604.07 3,313.03 1,646.91 5,983,258.66 551,185.35 35.57 -3,676.50 MWD (3) 8,630.82 85.72 197.38 6,691.35 6,606.35 3,284.91 1,636.60 5,983,230.47 551,175.22 18.26 -3,646.55 MWD (3) 8,660.41 86.16 194.41 6,693.44 6,608.44 3,256.52 1,628.52 5,983,202.04 551,167.33 10.13 -3,617.12 MWD (3) 8,690.57 86.89 192.14 6,695.27 6,610.27 3,227.22 1,621.60 5,983,172.70 551,160.61 7.90 -3,587.22 MWD (3) 8,720.59 87.08 193.88 6,696.85 6,611.85 3,198.02 1,614.86 5,983,143.45 551,154.06 5.82 -3,557.47 MWD (3) 8,750.61 87.36 197.01 6,698.31 6,613.31 3,169.12 1,606.87 5,983,114.50 551,146.27 10.46 -3,527.58 MWD (3) Annotation TIP KOP 10/24/2016 5.27:27PM Page 3 COMPASS 5000.1 Build 74 '.- ConocoPhillips F1.r2 ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Ku 1 Local Co-ordinate Reference: Well 11-1-07 Project: Kuparuk River Unit TVD Reference: 1 H-07 @ 85.00usft (1 H-07) Site: Kuparuk 1 H Pad MD Reference: 1 H-07 @ 85.00usft (1 H-07) Well: 1 H-07 North Reference: True Wellbore: 1 H-07APB3 Survey Calculation Method: Minimum Curvature Design: 1 H-07APB3 Database: EDM Alaska NSK Sandbox e Survey MD Inc Azi TVD TVDSS Map +Nl-S +El -W Map Vertical DLS _ (usft) (1 (1) (usft) (usft) Northing (usft) (usft) Easting Section Survey Tool Name (°/100') Annotation (ft) (ft) (ft) 8,790.00 87.36 197.01 6,700.12 6,615.12 3,131.49 1,595.36 5,983,076.80 551,135.01 0.00 -3,488.29 PROJECTED to TO 10/24/2016 5:27:27PM Page 4 COMPASS 5000.1 Build 74 TIDE STATE Of ALASKA GOVERNOR BILL WALKER Daniel Venhaus CTD Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1 H -07A ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-011 Surface Location: 768' FNL, 787' FEL, SEC. 33, T12N, R10E, UM Bottomhole Location: 5146' FNL, 387' FEL, SEC. 28, T12N, R10E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to redrill the above referenced service 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 Chair J - DATED this a day of January, 2016. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 'RECEIVE[ JAN 14 2016 A0 GCC 1a. Tyoe of Work: 1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - DisF ❑ 1c. Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑ Service - Winj Q Single Zone Q Coalbed Gas ❑ Gas Hydrates ❑ Redrill Q • Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska Inc Bond No. 8Q0B_-2&,2;?— s / Z_ 1.:x'/1' KRU 1H -07A - 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 11100' • TVD: 6582' Kuparuk River Field / Kuparuk Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 768' FNL, 787' FEL, Sec. 33, T12N, R10E, UM ADL 25639 ' Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2783' FNL, 4252' FEL, Sec. 27, T12N, R10E, UM ALK 464 3/1/2016 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 5146' FNL, 387' FEL, Sec 28, T12N, RI OE, UM 2560 6990' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 85' 15. Distance to Nearest Well Open Surface: x- 549561 y-5979935 Zone -4 GL Elevation above MSL (ft): 35' to Same Pool: 1080' 1H-14 16. Deviated wells: Kickoff depth: 7842' ' feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 104 degrees Downhole: 3721 psi Surface: 3065 psi 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling I Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L-80 ST -L 2846' 8254 6481' 11100' 6582' Slotted 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): 8300' 6959' None 8194' 6867' None Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 315 sxs AS II 80' 80' Surface 2365' 10-3/4" 1000 sx AS III & 250 sx AS 11 2365' 2340' Intermediate Production 8274' 7" 962 sx Class G 8274' 6937' Liner Perforation Depth MD (ft): 7696' - 7755', 7805' - 7830', 8015' - Perforation Depth TVD (ft): 6442'- 6492', 6534' - 6555', 6713'- 6720'& 6727' - 8023' & 8031'- 8051' 6744' 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis[] Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements0 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Jason Burke @ 265-6097 Email Iason.burke(ftOp.Com Printed Name Daniel Venhaus Title CTD Manager / Signature Phone 265-6120 Date l — Commission Use Only Permit to Drill / / Number: � / —0 f / API Number: 50-ej�- � j —61--,00 Permit Approval Date: a ` See cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, .gas hydrates, or gas contained in shales: other:0 d p ft�f /Z'��O �S-/ Samples req'd: Yes ❑ Nod Mud log req'd: Yes❑ No Fa' /— )v 2 SGV A2� �--yi vy cl ) 57,{- d k—e VCv1 ?'f—P"15 asures: Yes No ❑ Directional svy req'd: Yes g No❑ It ,t' C7,W{ l'1 f 55'r L� Li 1,4 Spacinq exception req'd: Yes ❑ No[V Inclination -only svy req'd: Yes ❑ No 5r - j{G` v) Yfo� Q is �R j r j1 / J t G f/dY1 Post initial injection MIT req'd: Yes F; APPROVED BY / Approved by: COMMISSIONER THE COMMISSION Date:/ -22, VT1_ /r r, Submit Form and Form 10401 (Revised 11/2015) This permit is valid for 24 months from the date of approval (20 AAC 25.005(g)) Attachments in Duplicate ORIGINAL -' �'•'� ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 13, 2016 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for permits to drill a two lateral well out of the Kuparuk well 1 H-07 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin in March 2016. The CTD objective will be to drill three laterals (1H -07A & 1H- 07AL1), targeting the A sand intervals. A cement plug must be placed and squeezed in the3.5" x 7" annulus of well 1 H-07 to facilitate a casing exit for these laterals, which will likewise effectively plug off the existing perforations. ConocoPhillips requests a variance from the plugging requirements of 20 AAC 25.112 (c) to facilitate the casing exit of the 1H-07 horizontal laterals. The proposed plugging procedure meets the overall objective of this section, providing an equally effective plugging of the well to prevent migration of fluids to other hydrocarbon zones or freshwater. Attached to this application are the following documents: — 10-403 Sundry application to plug A/C -sand perfs in 1 H-07 — Summary of the operations — Permit to Drill Application Form 10-401 for 1 H -07A & 1 H-07AL1 — Detailed Summary of Operations — Directional Plans — Current Schematic — Proposed Schematic If you have any questions or require additional information please contact me at 907-265-6097. Sincerely, Jason Burke Coiled Tubing Drilling Engineer 907-231-4568 U III -07 CTD Summary for Plugging Sundry (10-403) Summary of Operations: Well KRU 1H-07 is a Kuparuk A-sand/C-sand injection (service) well equipped with 3'/z" tubing and 7" production casing. The CTD laterals drilled from the injector well will target the Kuparuk A -sands . in fault blocks adjacent and corresponding to the wells current locations. KRU 1H-07 is planned for 2 laterals or 4,245' of total hole in the A -sand reservoir. Prior to drilling, the existing C -sand perforations in 1H-07 will be plugged with cement, and the A -sand will need to be permanently abandoned with sand and cement on top of a plug set in the 2%8" tubing tail. The purpose of this is to provide a means to kick out of the 3-1/2" and 7" casing and also to isolate the C -sand and A -sand perfs from the newly drilled laterals in the A -sand. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A/C -sand perfs in this manner. Cement will be laid in from the tubing tail plug at 7910' MD and then squeezed into the C1 & C3/C4 - perforations through the AVA'ported nipples located at 7781' & 7874' MD. The cement will be milled out using CT down to 7857' MD which will leave a 32' cement plug on top of the sand and plug in the 2%8" tailpipe. A mechanical whip -stock will then be set at 7842' MD to perform the CT sidetrack for 1H -07A & AL1. CTI) Drill and Complete 1H-07 Laterals: April 2016 Pre -CTD Work 1. RU slick -line i. Set plug in D -nipple at 7899` MD. ii. Dump 10' of sand on top of tubing tail plug 2. RU coil i. Cement squeeze C -sand perforations, and fill 3-1/2" x 7" annuli allow cement to harden. ii. Mill down to 7857' MD iii. Under ream down to 7857' MD iv. Pressure test cement. 3. RU E -Line i. Dummy WS drift to 7842' ii. Run and set WS at 7842' MD. 4. Prep site for Nabors CDR2-AC, including setting BPV RiLy Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 111-07A Side Track (A4 sand south) a. Mill 2.80" window at 7,842' MD. b. Drill 2.74" x 3.00" bi-center lateral to TD of 11,100' MD - c. Run 2%" slotted liner with an aluminum billet from TD up to 8,254' MD 3. 111-07AL1 Lateral (A4 sand south) a. Kick off of the aluminum billet at 8,254' MD b. Drill 2.74" x 3.00" bi-center lateral to TD of 9,250' MD Page 1 of 2 1/11/2016 c. Run 2%" slotted liner from TD up to 7830' MD, inside the 3'/z" tubing. Liner includes a swell packer at 7832' MD and a liner -top packer inside the 3'/2" tubing. 4. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CRD2-AC. Post -Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV's. 3. Produce well for more than 30 days 4. Re -sundry to turn back to injection Page 2 of 2 1/11/2016 uaaonsacnsnn Kuparuk CTD Laterals Ii 1 H -07A & AL1 Application for Permit to Drill Document VAC 1. Well Name and Classification...........................................................................................................2 (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b))......................................................................................................................2 2. Location Summary.............................................................................................................................2 (Requirements of 20 AAC 25.005(c)(2))......................................................................................................................................................2 3. Blowout Prevention Equipment Information...................................................................................2 (Requirements of 20 AAC 25.005(c)(3)).....................................................................................................................................................2 4. Drilling Hazards Information and Reservoir Pressure....................................................................2 (Requirements of 20 AAC 25.005(c)(4)).....................................................................................................................................................2 5. Procedure for Conducting Formation Integrity tests.....................................................................2 (Requirements of 20 AAC 25.005(c)(5))......................................................................................................................................................2 6. Casing and Cementing Program......................................................................................................3 (Requirements of 20 AAC 25.005(c)(6))......................................................................................................................................................3 7. Diverter System Information.............................................................................................................3 (Requirements of 20 AAC 25.005(c)(7))..............................................................................................................................-......................3 8. Drilling Fluids Program.....................................................................................................................3 (Requirements of 20 AAC 25.005(c)(8))......................................................................................................................................................3 9. Abnormally Pressured Formation Information...............................................................................4 (Requirements of 20 AAC 25,005(c)(9)) ......................................................................................................................................................4 10. Seismic Analysis................................................................................................................................4 (Requirements of 20 AAC 25.005(c)(10))....................................................................................................................................................4 11. Seabed Condition Analysis...............................................................................................................4 (Requirements of 20 AAC 25.005(c)(11))....................................................................................................................................................4 12. Evidence of Bonding.........................................................................................................................4 (Requirements of 20 AAC 25.005(c)(12))....................................................................................................................................................4 13. Proposed Drilling Program...............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13))- ............................................ ..................................................................................................... 4 Summaryof Operations.................................................................................................................................................. 4 LinerRunning.................................................................................................................................................................. 6 14. Disposal of Drilling Mud and Cuttings.............................................................................................6 (Requirements of 20 AAC 25.005(c)(14)).................................................................................................................................................... 6 15. Directional Plans for Intentionally Deviated Wells..........................................................................6 (Requirements of 20 AAC 25.050(b)).......................................................................................................................................................... 6 16. Quarter Mile Injection Review (for injection wells only).................................................................7 (Requirements of 20 AAC 25.402).............................................................................................................................................................. 7 17. Attachments.......................................................................................................................................7 Attachment 1: Directional Plans for 1 H -07A & AL1........................................................................................................ 7 Attachment 2: Current Well Schematic for 1 H-07........................................................................................................... 7 Attachment 3: Proposed Well Schematic for 1 H -07A & AL1.......................................................................................... 7 Page 1 of 7 January 11, 2016 1. Well Name and Classification (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) The proposed laterals described in this document are 1 H -07A & L1. All laterals will be classified as "Service — Injection" wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 1 H -07A & 1-1. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. Using the maximum formation pressure in the area of 3721 psi in 1 H-07 (i.e. 10.9 ppg , the maximum potential surface pressure in 1 H-07, assuming a gas gradient of 0.1 psi/ft, would be 3065 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details: — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 1 H-07 was measured to be 3721 psi (10.9 ppg EMW) on 11/27/2015. The maximum downhole pressure in the 1 H-07 vicinity is the 1 H-07. The well will be drilled toward lower pressure. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No gas injection performed at 1 H pad however, if significant gas is detected in the returns, the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems is 1 large fault crossing. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with the fault crossing. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1 H-07 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 7 January 11, 2016 PTD Application: 1 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Liner Details Name MD MD TVDSS TVDSS Conductor 16" 65.0 H-40 Welded 30' 2%", 4.7#, L-80, ST -L slotted liner; 1 H -07A 8254' 11100' 6481' 6582' aluminum billet on top 45.5 K-55 BTC 29' 2365' 2%", 4.7#, L-80, ST -L slotted liner; 1 H-07ALI 7830' 9250' 6650' 6659' with a swell packer in the `B' shale K-55 BTC 29' 8274' 0' and a liner top packer on top Existing Casing/Liner Information Category OD Weight Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 65.0 H-40 Welded 30' 80' 0' 80' 1640 630 Surface 10-3/4" 45.5 K-55 BTC 29' 2365' 0' 2340' 3580 2090 Production 7" 26.0 K-55 BTC 29' 8274' 0' 6937' 4980 4330 Tubing 3-1/2" 9.3 L-80 8rd EUE 25' 1 7662' 0' 1 6413' 1 10160 10530 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride -based RoVis mud (9.7 ppg) — Drilling operations: Chloride -based PowerVis mud (9.6 ppg). This mud weight will not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: BHA's will be deployed using standard pressure deployments and the well will be loaded with 11.8 ppg NaBr completion fluid in order to provide formation over -balance and maintain wellbore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 1 H-07 laterals we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 7 January 11, 2016 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 1H-07 is a Kuparuk A -sand injection well equipped with 3 %2" tubing and 7" production casing. Two laterals will be drilled to the south of the parent well with the laterals targeting the A4 sand. A thru- tubing whip -stock will be set inside the 3%2' liner at the planned kickoff point of 7842' MD to drill both laterals. The 1H -07A southern sidetrack will exit through the 3%2" liner and 7" production casing at 7842' MD and TD at 11,100' MD, targeting the A4 sand. It will be completed with 2%" slotted liner from TD up to 8254' MD with an aluminum billet for kicking off the 1H-07AL1 lateral. The 1H-07AL1 will drill south to a TD of 9250' MD targeting the A4 sand. It will be completed with 2%" slotted liner from TD up to 7830' MD with a swell packer in the `B' shale and a liner top production packer on top. Page 4 of 7 January 11, 2016 Pumps On (1.5 bpm) Pumps Off A -sand Formation Pressure 10.9 3721 psi 3721 psi Mud Hydrostatic 9.6 3278 psi 3278 psi Annular friction i.e. ECD, 0.060 si/ft 471 psi 0 psi Mud + ECD Combined 3748 psi 3278 psi (no choke pressure) (overbalanced (underbalanced —27psi) —444psi) Target BHP at Window (11.8 ppg) 4029 psi 4029 psi Choke Pressure Required to Maintain 281 psi 751 psi Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 1H-07 is a Kuparuk A -sand injection well equipped with 3 %2" tubing and 7" production casing. Two laterals will be drilled to the south of the parent well with the laterals targeting the A4 sand. A thru- tubing whip -stock will be set inside the 3%2' liner at the planned kickoff point of 7842' MD to drill both laterals. The 1H -07A southern sidetrack will exit through the 3%2" liner and 7" production casing at 7842' MD and TD at 11,100' MD, targeting the A4 sand. It will be completed with 2%" slotted liner from TD up to 8254' MD with an aluminum billet for kicking off the 1H-07AL1 lateral. The 1H-07AL1 will drill south to a TD of 9250' MD targeting the A4 sand. It will be completed with 2%" slotted liner from TD up to 7830' MD with a swell packer in the `B' shale and a liner top production packer on top. Page 4 of 7 January 11, 2016 Pre -CTD Work 1. RU slickline. a. Pull lower most AVA isolation sleeve at 7874` MD b. Dummy ofGLV's 2. RU pumping a. Perform injectivity test using diesel on the C1 perfs 3. RU slick -line a. Pull AVA isolation sleeve at 7781 ` MD allowing the C 1 & C3/C4 to equalize 4. RU coil a. Cement squeeze C -sand perforations, and fill 3-1/2" x 7" annuli allow cement to harden. b.Mill down to 7857' MD c. Under ream down to 7857' MD d.Pressure test cement. 5. RU E -Line a. Dummy WS drift to 7842' - b.Run and set WS at 7842' MD. 6. Prep site for Nabors CDR2-AC, including setting BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPS, test. 1H -07A Side Track (A4 sand south) a. Mill 2.80" window at 7,842' MD. b. Drill 2.74" x 3.00" bi-center lateral to TD of 11,100' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 8,254' MD 3. 1H-07AL1 Lateral (A4 sand south) a. Kick off of the aluminum billet at 8,254' MD b. Drill 2.74" x 3.00" bi-center lateral to TD of 9,250' MD c. Run 2%" slotted liner with swell packer at 7832' MD from TD up to 7830' MD, inside the 3%Z" tubing with a liner top packer Freeze protect. Set BPV, ND BOPE. RDMO Nabors CRD2-AC. Post -Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV's. 3. Produce well for more than 30 days 4. Re -sundry to turn back to injection Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. Page 5 of 7 January 11, 2016 — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slick -line. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — The 1 H-07 CTD laterals will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. — While running 2s/" slotted liner, a joint of 2'/" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AA 25.005(c)(14)) • No annular injection on this well. . • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AA 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plan — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 1 H -07A 6990' 1 H-07AL1 6990' Page 6 of 7 January 11, 2016 - Distance to Nearest Well within Pool Lateral Name Distance Well 1 H -07A 1H-14 1080' 1 H-07AL1 11-1-14 730' 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) 1 H-14 & 1 H-16 are within %4 -mile of the IH -07A & L1 wells ® See Attached AOR sheet 17. Attachments Attachment 1: Directional Plans for 1H -07A & AL I Attachment 2: Current Well Schematic for 1H-07 Attachment 3: Proposed Well Schematic for 1H -07A & AL_1 Page 7 of 7 January 11, 2016 Area of Review Well Name I'-. o}q_santl Tap of A -Sand Dil Top of Cement Topo(Cement Tpppf4ment Pio APIWELL NAME STANS Oil P-1(MD) P-1 (TV=) (MD) (NO65) Determined By Reservoir Status Zpwllsolation Cement Operddons Summary Mechantollntegriry 182-084 56079-20755 1H-07 Suspended 7696 6441' 6850' 555V CBL Pedscementedand Packer@7880'MD 962 so Class G cement Statewitnessed passing MIT abandoned M m 2820 psi D. 8/11/13 192-131 Sa.029.22315 SH -16 Producing 7185' 6632' 6300' 5798' CET Peds open for Packer@6804'MD 590 so Class Gcemen[ 51-MFL Passed. Initial T/1/0= pmduRion si 150/1250/780 Dn 5/30/15 193.052 56029-22359 11414 Producing 8691' 6554' 8330' 6412' CET has Dpen fpr packer@8172'MD 520 so Class Gcement Campetentpmdurerwith 'd..ion passing TIFL KUP INJ 1H-07 ConocoPhiffiPS , Aieske,Ina. •• Well AttributesMax Angle & MD JTD WellboreAPIIUWI Field Name Wellbore Status 500292075500 KUPARUK RIVER UNIT INJ nclI') MD(ftKB) ActBt. (ftKB) 53.77 5,200.00 8,300.0 Comment H2S (ppm) I Date SSSV: NIPPLE Annotation Entl Date Last WO: 11/11/2007 KB-Grd (ft) Rig Release Date 35.49 6/16/1982 1H07, 11n 1120136:47:34 PM - eVftmai sc emalrc(actual) Annotation Depth (ftKB) EDate Annotation Last Mod By End Date Last Tag: SLM 8,079.0 11/3/2013 Rev Reason: GLV C/O, TAG, RESET BPC lehallf 1 111 1/2 01 3 .......... ............................. _......... _......... HANGER; 24.9 Mn. CONDUCTOR; 30.080.0 NIPPLE; 503.4 SURFACE; 29.0-2,365.0 GAS LIFT; 7,5720 NIPPLE; 7,620.0-7,661.6 SEAL ASSY; 7,659.4 PBR; 7,661.6 PACKER; 7,675.4 r'- INJECTION; 7,699.7 (PERF; 7,696.0.7,755.0- ,787.3 SLEEVE; 7,781.3'\ NIPPLE; 7,781.3 SEAL ASSY; 7,788.1 PACKER; 7,789.0 INJECTION; 7,800.7 (PERF; 7,1105.0-7,830.0-.� SLEEVE; 7,9742 NIPPLE; 7,874.2 �. SEAL ASSY; 7,879.1 PACKER; 7,880.7 SBE;7,883.8 NIPPLE; 7,898.9 WLEG; 7,910.7 RPERF; 8,015.08,023.0 IPERF; .1:111 01 IPERF; 9,031.0Aa51.0 RPERF; 8,037.08,051.0 FISH; 9,1620 PRODUCTION 29.0.8,274.0- ... Ip� I 5/24/1994 3/2/2011 r 3/27/2012 Casing rings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.060 Top (ftKB) 30.0 Set Depth (ftKB) 80.0 Set Depth (TVD)... 80.0 WULen (I... 65.00 Grade H-40 Top Thread WELDED Casing Description PRODUCTION OD (in) ID(in) 7 6.276 Told("") 29.0 Set Depth(mol 8,274.0 Set Depth(IVO)... 6,936.9 WULen(L 26.00 Grade K-55 Top Thread BTC Tubing Strings Tubing Description String Ma... ID (in) Top (ftKB) Set Depth (ft.. Set Depth (TVD) (... Wt (INR) Grade Top Connection TUBING 2007 WO 3112 2.992 24.9 7,6620 6,413.2 9.30 L -BO EUE 8RD Completion Details Nominal ID Top (ftKB) Top (TVD) (ftKB) Top Incl (") Item Des Com (in) 24.9 24.9 0.15 HANGER CAMERON GEN 4 TUBING HANGER 3.500 503.4 503.3 0.49 NIPPLE CAMCO DS NIPPLE 2.875 7,620.0 6,377.7 32.41 NIPPLE CAMCO DS NIPPLE 2.813 7,658.4 6,410.1 32.37 SEAL ASSY LOCATOR SEAL ASSEMBLY 3.000 Tubing Description String Ma... ID TUBING 1994 WO 41/2 3.5x2.875 (in) 2.992 Top (ftKB) 7,661.6 Set Depth (ft.. 7,910.7 Set Depth (TVD) (... 6,624.2 Wt pitift) Grade 9.30 L-80 Top Connection EUE8RDMCD Completion Details Nominal 10 Top (ftKB) Top (TVD) (ftKB) Top Incl (") Item Des Com (in) 6,412.8 32.36 PBR BAKER 80-00 PBR w/ 10' STROKE 3.000 7,675.4 6,424.5 32,35 PACKER BAKER THL' RETRIEVABLE PACKER 2.992 7,702.9 6,447.8 32.31 BLASTJTS STEEL BLAST JOINTS 2.992 7,781.3 6,514.0 32.03 NIPPLE AVA BPL PORTED NIPPLE 2.812 7,788.1 6,519.8 32.01 SEAL ASSY BAKER KBG-22 ANCHOR SEAL ASSY 3.000 7,789.0 6,520.6 32.01 PACKER BAKER 80-00'SAB-3' PERMANENT PACKER 3.250 7,815.0 6,542.7 31.89 BLASTJTS STEEL BLAST JOINTS 2.992 7,874.2 6,593.0 31.61 NIPPLE AVA BPL PORTED NIPPLE 2.750 7,876.9 6,595.3 31.60 XO Reducing CROSSOVER 3.5 x 2.875, ID 2.441, #6.5, L-80, 2.875 EUE8RDMOD 7,879,1 6,597.2 31.56 SEALASSY BAKER 80-32 GBH -22 LOCATOR SEAL ASSEMBLY 2.437 7,880.1 6,598.1 31.58 PACKER BAKER 84-32 MODEL'D' PERMANENT PACKER 3.250 7,883.8 6,601.2 31.56 SBE SEAL BORE EXTENSION 3.250 7,698.9 6,614.1 31.49 NIPPLE OTIS'XN' NIPPLE 2.250 7,910.2 6,623.7 31.43 1 WLEG BAKER WIRELINE ENTRY GUIDE 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (TV DI Top Incl Top (ftKB) (ftKB) (') Des Co. Run Date ID (in) 7,781.3 6,514.0 3203 SLEEVE SET 2.81" BPC = COMMINGLING OR OPEN 11/3120132.310 7,874.2 6,593.0 31.61 SLEEVE SET 2.75" BPI = ISOLATION OR CLOSED 5/6/2009 2.310 8,1620 6,839.7 29.83 FISH Vann Gun Left in Hole after original pert 6/16/1982 Perforations & Slots Shot Den Top (TVD) Btm (TVD) (shots/f Tap (ftKB) Bt. (ftKB) (ftKB) (ftKB) Zone Date 0 Type Com 71696.0 7,755.0 6,441.9 6,491.8 C-4, C-3, 1H- 6/20/1988 8.0 IPERF 21/8" EnerJet; 30 deg 07 ph 7,805.0 7,830.0 6,534.2 6,555.4 C-1, UNIT B, 620/1988 4.0 IPERF 21/8" EnerJet 1H-07 8,015.0 8,023.0 6,713.4 6,720.2 A-5, 1H-07 2116/2007 6.0 RPERF 21/8" EnerJet, 0 deg phase 8,015.0 8,023.0 6,713.4 6,720.2 A-5. 11-1-07 6/20/1988 12.0 IPERF 21/8"EnerJet 8,031.0 8,051.0 6,727.1 6,744.2 A -4,1H-07 2116/2007 6.0 RPERF 21/8" EnerJet, 0 deg phase 8,031.0 8,051.0 6,727.1 6,744.2 1 A-4, 1H-07 6/20/1988 1 12.0 1 IPERF 2118" EnerJet Mandrel Inserts St at C No Top (ND) Valve Latch Port Site TRO Run Top (ftKB) (ftKB) Make Model OD (in) Se, Type Type (in) (psi) Run Date m 1 7,572.0 6,3372 CAMCO KBMG 1 GAS LIFT DMY BK 0.0001 0.0 11/1512007 2 7,688.7 6,435.7 CAMCO MMM 11/2 INJ DMY RK 0.000 0.0 5/25/1994 3 7,800.7 6,530.5 CAMCO MMM 11/2 INJ CV RK 0.1881 0.0 11/312013 Notes: General & Safety End Data Annotation NOTE: WORKOVER 217/2004 NOTE: WAIVERED WELL: TxIA COMMUNICATION NOTE: View Schematic w/ Alaska Schematic9.0 NOTE: The 2007 tubing detail did not include the RKB; adjusted for RKB, but need verifying Pzmomal^Te�n^+e WELLBORE DETAILS: IH -07A REFERENCE WFORMATION Project:it Kuparuk River Unit Mapml,c xenn teao F/,' Site: Kupar111-07 k,H Pad Iraaee,c Feb Parent Wellbore: 1H-07 Coar3male INC Pehrence: Wee 1HO7,Tme Nxlh Well: 1H-07 seVp -7 ami VeNml Re(menre: Mean Sea Laval BAKER '��Te on MD: 7800.00 PVOI y� Wellbore: 1H�7A aonepa et%' S"" (V5)Relerenm: Val -(O.95 O.M Conoco_ I li'lips Plan: 1H.07A_wpO5 IV meGB-20is Mea metlO�IhRe(ereuce: t L7.D'veme(tNA HUGHES Glniheon Melho3 Mnimum Curcabre West( -)/East(+) (250 usft/in) NADConversion Kuparuk River Unit Kuparuk 1H Pad 1 H-07 1 H -07A Plan: 1 H-07A_wp05 Standard Planning Report 07 January, 2016 FfAA F k 2 BAKER HUGHES CcinocoMillips Database: EDM Alaska ANC Prod Company: NADConversion Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: 1 H-07 Wellbore: 1 H -07A Design: 1 H-07A_wp05 ConocoPhillips war al Planning Report BAKER HUGHES Local Co-ordinate Reference: Well 1 H-07 TVD Reference: Mean Sea Level MD Reference: 1 H-07 @ 85.00usft (1 H-07) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1 H Pad Site Position: Northing: 5,979,968.84 usft Latitude: 70° 21'21.831 N From: Map Easting: 549,197.16usft Longitude: 149° 36'1.675 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.38 ° Well 1 H-07 Well Position +Nl-S 0.00 usft Northing: 5,979,935.13 usft Latitude: 70° 21'21.476 N +El -W 0.00 usft Easting: 549,560.55 usft Longitude: 149° 35'51.058 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1 H -07A Magnetics Model Name Sample Date Declination Dip Angle Field Strength V) (I (nT) BGGM2015 4/1/2016 18.60 81.00 57,498 Design 1 H-07A_wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,800.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (1) 0.00 0.00 0.00 200.00 1/7/2016 11.44:43AM Page 2 COMPASS 5000.1 Build 74 rF ConocoPhillips Has Planning Report BAKER HUGHES Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 1 H-07 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 H-07 @ 85.00usft (1 H-07) Site: Kuparuk 1 H Pad North Reference: True Well: 1H-07 Survey Calculation Method: Minimum Curvature Wellbore: 1 H -07A Azimuth System Design: 1 H-07A_wp05 Rate Rate Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +Nl-S +E/ -W Rate Rate Rate TFO (usft) (1) (1) (usft) (usft) (usft) (*1100usft) (°/100usft) (*1100usft) (1) Target 7,800.00 31.97 55.69 6,444.91 2,999.74 1,862.27 0.00 0.00 0.00 0.00 7,842.00 31.76 55.94 6,480.58 3,012.20 1,880.61 0.59 -0.50 0.60 147.96 7,867.00 39.55 49.08 6,500.89 3,021.11 1,892.10 35.00 31.18 -27.44 330.00 7,937.00 65.05 34.08' 6,543.49 3,062.83 1,927.42 40.00 36.42 -21.44 330.00 8,007.00 74.79 6.05 6,567.92 3,123.92 1,949.19 40.00 13.92 -40.04 285.00 8,347.07 90.00 227.81 6,661.00 3,226.12 1,722.36 40.00 4.47 -40.65 -106.37 8,387.07 90.00 224.61 6,661.00 3,198.45 1,693.49 8.00 0.00 -8.00 270.00 8,460.00 91.00 221.87 6,660.37 3,145.32 1,643.53 4.00 1.37 -3.76 290.00 8,550.00 94.54 222.50 6,656.02 3,078.72 1,583.18 4.00 3.94 0.70 10.00 8,690.00 89.95 225.70 6,650.53 2,978.30 1,485.86 4.00 -3.28 2.29 145.00 8,890.00 89.81 233.70 6,650.94 2,849.06 1,333.45 4.00 -0.07 4.00 91.00 9,175.00 89.82 222.30 6,651.87 2,658.68 1,121.99 4.00 0.00 -4.00 270.00 9,425.00 90.69 212.34 6,650.78 2,460.12 970.61 4.00 0.35 -3.98 275.00 9,750.00 90.67 199.34 6,646.92 2,168.27 829.27 4.00 -0.01 -4.00 270.00 9,950.00 104.45 196.85 6,620.67 1,980.30 767.78 7.00 6.89 -1.24 350.00 10,150.00 94.39 186.97 6,587.91 1,787.70 727.40 7.00 -5.03 -4.94 225.00 10,425.00 91.19 205.98 6,574.41 1,525.57 649.79 7.00 -1.16 6.91 99.00 10,600.00 89.47 193.85 6,573.39 1,361.35 590.29 7.00 -0.98 -6.93 262.00 10,850.00 88.89 211.34 6,576.98 1,131.46 494.61 7.00 -0.23 7.00 92.00 11,100.00 88.65 193.84 6,582.39 901.60 398.96 7.00 -0.10 -7.00 269.00 1/72016 11:44:43AM Page 3 COMPASS 5000.1 Build 74 s. ConocoPhillips ConocoPhrtllps Planning Report BAKER HUGHES Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 1 H-07 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 H-07 @ 85.00usft (1 H-07) Site: Kuparuk 1 H Pad North Reference: True Well: 1H-07 Survey Calculation Method: Minimum Curvature Wellbore: 1 H -07A Depth Inclination Design: 1 H-07A_wp05 +N/ -S +E/ -W Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°1100usft) (°) (usft) (usft) 7,800.00 31.97 55.69 6,444.91 2,999.74 1,862.27 -3,455.77 0.00 0.00 5,982,946.83 551,402.75 TIP 7,842.00 31.76 55.94 6,480.58 3,012.20 1,880.61 -3,473.75 0.59 147.96 5,982,959.41 551,421.01 KOP 7,867.00 39.55 49.08 6,500.89 3,021.11 1,892.10 -3,486.05 35.00 -30.00 5,982,968.40 551,432.44 End 35 dls, Start 40 dis 7,900.00 51.34 40.67 6,524.02 3,037.84 1,908.51 -3,507.39 40.00 -30.00 5,982,985.24 551,448.73 7,937.00 65.05 34.08 6,543.49 3,062.83 1,927.42 -3,537.34 40.00 -24.06 5,983,010.35 551,467.48 4 8,000.00 73.63 8.69 6,566.02 3,117.24 1,948.33 -3,595.62 40.00 -75.00 5,983,064.89 551,488.03 8,007.00 74.79 6.05 6,567.92 3,123.92 1,949.19 -3,602.19 40.00 -65.89 5,983,071.58 551,488.85 5 8,100.00 68.08 327.34 6,598.57 3,207.83 1,929.96 -3,674.46 40.00 -106.37 5,983,155.35 551,469.06 8,200.00 71.14 284.65 6,634.89 3,261.03 1,856.13 -3,699.20 40.00 -93.59 5,983,208.05 551,394.88 8,300.00 83.00 245.33 6,658.10 3,251.91 1,761.37 -3,658.22 40.00 -78.07 5,983,198.30 551,300.20 8,347.07 90.00 227.81 6,661.00 3,226.12 1,722:36 -3,620.64 40.00 -68.88 5,983,172.26 551,261.36 End 40 dis, Start RSM 8,387.07 90.00 224.61 6,661.00 3,198.45 1,693.49 -3,584.76 8.00 -90.00 5,983,144.40 551,232.68 7 8,400.00 90.18 224.12 6,660.98 3,189.20 1,684.44 -3,572.98 4.00 -70.00 5,983,135.10 551,223.70 8,460.00 91.00 221.87 6,660.37 3,145.32 1,643.53 -3,517.76 4.00 -70.00 5,983,090.95 551,183.08 8 8,500.00 92.57 222.15 6,659.12 3,115.62 1,616.78 -3,480.69 4.00 10.00 5,983,061.07 551,156.52 8,550.00 94.54 222.50 6,656.02 3,078.72 1,583.18 -3,434.53 4.00 10.01 5,983,023.96 551,123.17 9 8,600.00 92.90 223.64 6,652.77 3,042.27 1,549.11 -3,388.63 4.00 145.00 5,982,987.29 551,089.35 8,690.00 89.95 225.70 6,650.53 2,978.30 1,485.86 -3,306.88 4.00 145.07 5,982,922.91 551,026.53 10 8,700.00 89.94 226.10 6,650.54 2,971.34 1,478.68 -3,297.89 4.00 91.00 5,982,915.90 551,019.40 8,800.00 89.87 230.10 6,650.70 2,904.58 1,404.26 -3,209.70 4.00 91.00 5,982,848.65 550,945.43 8,890.00 89.81 233.70 6,650.94 2,849.06 1,333.45 -3,133.30 4.00 90.99 5,982,792.67 550,874.99 11 8,900.00 89.81 233.30 6,650.98 2,843.11 1,325.41 -3,124.97 4.00 -90.00 5,982,786.67 550,866.99 9,000.00 89.81 229.30 6,651.30 2,780.60 1,247.38 -3,039.54 4.00 -90.00 5,982,723.65 550,789.38 9,100.00 89.81 225.30 6,651.63 2,712.80 1,173.90 -2,950.70 4.00 -89.99 5,982,655.38 550,716.36 9,175.00 89.82 222.30 6,651.87 2,658.68 1,121.99 -2,882.09 4.00 -89.97 5,982,600.92 550,664.82 12 9,200.00 89.90 221.31 6,651.93 2,640.05 1,105.33 -2,858.88 4.00 -85.00 5,982,582.17 550,648.28 9,300.00 90.25 217.32 6,651.80 2,562.69 1,041.98 -2,764.52 4.00 -85.00 5,982,504.41 550,585.46 9,400.00 90.60 213.34 6,651.06 2,481.13 984.17 -2,668.10 4.00 -85.00 5,982,422.47 550,528.19 9,425.00 90.69 212.34 6,650.78 2,460.12 970.61 -2,643.73 4.00 -85.03 5,982,401.38 550,514.77 13 9,500.00 90.68 209.34 6,649.88 2,395.74 932,17 -2,570.08 4.00 -90.00 5,982,336.75 550,476.76 9,600.00 90.68 205.34 6,648.69 2,306.94 886.26 -2,470.93 4.00 -90.04 5,982,247.65 550,431.44 9,700.00 90.67 201.34 6,647.51 2,215.14 846.65 -2,371.13 4.00 -90.08 5,982,155.61 550,392.45 9,750.00 90.67 199.34 6,646.92 2,168.27 829.27 -2,321.13 4.00 -90.13 5,982,108.62 550,375.38 End RSM, Start 7 dis 9,800.00 94.11 198.73 6,644.84 2,121.05 812.98 -2,271.19 7.00 -10.00 5,982,061.30 550,359.40 9,900.00 101.01 197.49 6,631.69 2,026.89 782.18 -2,172.18 7.00 -10.03 5,981,966.95 550,329.23 9,950.00 104.45 196.85 6,620.67 1,980.30 767.78 -2,123.47 7.00 -10.19 5,981,920.28 550,315.14 15 10,000.00 101.96 194.32 6,609.25 1,933.42 754.71 -2,074.95 7.00 -135.00 5,981,873.31 550,302.38 117/2016 11:44:43AM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips FfkI CZ)I oll:tiM1 ips Planning Repoli BAKER HUGHES Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 1 H-07 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 H-07 @ 85.00usft (1 H-07) Site: Kuparuk 1H Pad North Reference: True Well: 1 H-07 Survey Calculation Method: Minimum Curvature Wellbore: 1 H -07A Depth Inclination Design: 1 H-07A_wp05 +N/ -S +E/ -W Planned Survey Measured Vertical Local Coordinates Depth Depth Measured +E/ -W TVD Below (usft) (usft) Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (o) (a) (usft) (usft) (usft) (usft) (°/100usft) (1) (usft) (usft) 10,100.00 96.93 189.39 6,592.83 1,836.94 734.48 -1,977.36 7.00 -135.58 5,981,776.71 550,282.79 10,150.00 94.39 186.97 6,587.91 1,787.70 727.40 -1,928.67 7.00 -136.39 5,981,727.42 550,276.03 16 1,485.86 10 8,890.00 6,650.94 2,849.06 1,333.45 11 9,175.00 6,651.87 2,658.68 10,200.00 93.83 190.44 6,584.32 1,738.41 719.85 -1,879.77 7.00 99.00 5,981,678.09 550,268.81 10,300.00 92.68 197.35 6,578.64 1,641.55 695.88 -1,780.56 7.00 99.25 5,981,581.09 550,245.49 10,400.00 91.49 204.26 6,574.99 1,548.19 660.40 -1,680.70 7.00 99.64 5,981,487.51 550,210.63 10,425.00 91.19 205.98 6,574.41 1,525.57 649.79 -1,655.81 7.00 99.89 5,981,464.81 550,200.18 17 10,500.00 90.46 200.78 6,573.33 1,456.76 620.04 -1,580.97 7.00 -98.00 5,981,395.81 550,170.88 10,600.00 89.47 193.85 6,573.39 1,361.35 590.29 -1,481.14 7.00 -98.07 5,981,300.22 550,141.77 18 10,700.00 89.23 200.85 6,574.52 1,265.97 560.49 -1,381.32 7.00 92.00 5,981,204.65 550,112.60 10,800.00 89.00 207.85 6,576.07 1,174.93 519.30 -1,281.68 7.00 91.92 5,981,113.35 550,072.01 10,850.00 88.89 211.34 6,576.98 1,131.46 494.61 -1,232.39 7.00 91.81 5,981,069.73 550,047.62 19 10,900.00 88.84 207.84 6,577.97 1,088.00 469.93 -1,183.11 7.00 -91.00 5,981,026.11 550,023.22 11,000.00 88.73 200.84 6,580.10 996.97 428.74 -1,083.48 7.00 -90.93 5,980,934.82 549,982.64 11,100.00 88.65 193.84 , 6,582.39 901.60 398.96 -983.68 7.00 -90.78 5,980,839.26 549,953.49 Planned TD at 11100.00 rasing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name () ( ) 11,100.00 6,582.39 23/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 7,800.00 6,444.91 2,999.74 1,862.27 TIP 7,842.00 6,480.58 3,012.20 1,880.61 KOP 7,867.00 6,500.89 3,021.11 1,892.10 End 35 dls, Start 40 dls 7,937.00 6,543.49 3,062.83 1,927.42 4 8,007.00 6,567.92 3,123.92 1,949.1'9 5 8,347.07 6,661.00 3,226.12 1,722.36 End 40 dls, Start RSM 8,387.07 6,661.00 3,198.45 1,693.49 7 8,460.00 6,660.37 3,145.32 1,643.53 8 8,550.00 6,656.02 3,078.72 1,583.18 9 8,690.00 6,650.53 2,978.30 1,485.86 10 8,890.00 6,650.94 2,849.06 1,333.45 11 9,175.00 6,651.87 2,658.68 1,121.99 12 9,425.00 6,650.78 2,460.12 970.61 13 9,750.00 6,646.92 2,168.27 829.27 End RSM, Start 7 dls 9,950.00 6,620.67 1,980.30 767.78 15 10,150.00 6,587.91 1,787.70 727.40 16 10,425.00 6,574.41 1,525.57 649.79 17 10,600.00 6,573.39 1,361.35 590.29 18 10,850.00 6,576.98 1,131.46 494.61 19 11,100.00 6,582.39 901.60 398.96 Planned TD at 11100.00 117/2016 11:44:43AM Page 5 COMPASS 5000.1 Build 74 Baker Hughes INTEQ S/ kv COnocoPhillips Travelling Cylinder Report BAKER HUGHES company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Reference Site: Kuparuk 1H Pad Site Error. 0.00 usft Reference Well: 11-1-07 Well Error. 0.00 usft Reference Wellbore 1H -07A Reference Design: 1H-07A_wp05 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 11-1-07 1 H-07 @ 85.00usft (1 H-07) 1 H-07 @ 85.00usft (1 H-07) True Minimum Curvature 1.00 sigma OAKEDMP2 Offset Datum Reference 1 H-07A_wp05 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,800.00 to 11,100.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,301.50 usft Error Surface: Elliptical Conic Survey Tool Program Date 1/7/2016 From To (usft) (usft) Survey (Wellbore) Tool Name Description 100.00 7,800.00 1 H-07 (1 H-07) BOSS -GYRO Sperry -Sun BOSS gyro multishot 7,800.00 11,100.00 1 H-07A_wp05 (1 H -07A) MWD MWD - Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 11,100.00 6,667.39 2 3/8" 2-3/8 3 Summary Site Name Offset Well - Wellbore - Design Kuparuk 1 H Pad 1 H-05 - 1 H-05 - 1 H-05 1 H-05 - 1 H-105 - 1 H-105 1 H-07 - 1 H-07 - 1 H-07 1 H-07 - 1 H-07ALl - 1 H-07AL1_wp04 1 H-10 - 1 H-10 - 1 H-10 1 H-12 - i H-12 - 1 H-12 1H -13 -1H -13-1H-13 1H -14 -1H -14-1H-14 1H -15 -1H -15-1H-15 1H -16 -1H -16-1H-16 1 H-21 - 1 H-21 - 1 H-21 Plan: 1 H-104 (formerly 101 and 27) - Plan: 1 H-104 Plan: 1 H-104 (formerly 101 and 27) - Plan:1 H-104 Plan: 1 H-104 (formerly 101 and 27) - Plan:1 H-104 Plan: 1 H-104 (formerly 101 and 27) - Plan:1 H-104 Plan: 1 H-104 (formerly 101 and 27) - Plan:1 H-104 Plan: 1 H-112 (formerly 106 and 28E) - Plan: 1 H-11 Reference Offset Measured Measured Depth Depth (usft) (usft) 7,849.99 7,850.00 8,274.73 8,275.00 8,370.87 7,925.00 10,050.00 7,150.00 Centre to Centre Distance (usft) 0.20 2.37 1,088.83 1.130.82 No -Go Allowable Distance Deviation Warning (usft) from Plan (usft) Out of range Out of range 2.08 -1.60 FAIL - Major Risk 0.46 2.02 Pass - Minor 1110 Out of range Out of range Out of range 264.13 843.98 Pass - Major Risk Out of range 259.81 874.93 Pass - Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Offset Design Kuparuk 1 H Pad - 1 H-07 - 1 H-07 - 1 H-07 Offset site Error: 0.00 usft survey Program: 100 -BOSS -GYRO Rule Assigned: Major Risk Offset Well Error: 0.00 usft Reference Offset Semi MajorAxis Measured Vertical Measured Vertical Reference Offset Toolface + Offset Wellbore Centre Casing - Centre to No Go Allocable Warning Depth Depth Depth Depth Azimuth -NIS +Ef-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (°) (usft) (usft) f) (usft) (usft) (usft) 7,825.00 6,551.13 7,825.00 6,551.13 0.08 0.15 85.54 3,007.17 1,873.19 2-11116 0.00 1.08 -0.86 FAIL - Major Risk, CC 7,849.99 6,572.29 7,850.00 6,572.38 0.13 0.31 -155.07 3,014.55 1,884.10 2-11/16 0.20 2.08 -1.60 FAIL - Major Risk, ES, SF 7,874.53 6,591.58 7,875.00 6,593.66 0.13 0.46 -156.33 3,021.88 1,894.99 2-11/16 3.37 3.60 0.01 Pass -Major Risk 7,897.41 6,607.39 7,900.00 6,614.97 0.14 0.62 -159.51 3,029.15 1,905.86 2-11/16 10.53 5.15 5.63 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 1/7/2076 10:47:47AM Page 2 COMPASS 5000.1 Build 74 Project: Kuparuk River Unit WELLBORE DETAILS: IH -07A Site: Kuparuk 1H Pad Me ex F.n Parent Wellbore: 1H-07 Well: 1H-07 sup �s7rs7s,e COIIOC®f]�iI�1�35 Wellbore: 1H -07A pMpbelaa• Te on MD: 7BnB.00 fPh Plan: 1H-07Awp05 (1 H -0711H -07A) t�-IY-Y uoa�l'eccunis Mean E REFERENCE INFORMATION E)R ae- Wdl IH47. True NaN HIM M- sm-(O.Wen �"eW BAKER 5)Rdaerce: Sld-10. 9 0 ( btimm mt IH47=4540ueA(IH47) NUGNES lellon Mdlwd MinmuT Cwdw Vertical Section at 200.00° (95 usft/in) WELL DETAILS: 1H-07 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 5979935.13 549560.55 70' 21' 21.476 N 149" 35'51.058 W Sec MD Inc Azi TOSS +N/ -S +EJ -W Dleg TFace VSect Annotation 1 7800.00 31.97 55.69 6444.91 2999.74 1862.27 0.00 0.00-3455.77 TIP 2 7842.00 31.76 55.94 6480.58 3012.20 1880.61 0.59 147.96-3473.75 KOP 3 7867.00 39.55 49.08 6500.89 3021.11 1892.10 35.00 330.00 -3486.05 End 35 dls, Start 40 dls 4 7937.00 65.05 34.08 6543.49 3062.83 1927.42 40.00 330.00-3537.34 4 5 8007.00 74.79 6.05 6567.92 3123.92 1949.19 40.00 285.00-3602.19 5 6 8347.07 90.00 227.81 6661.00 3226.12 1722.36 40.00 -106.37-3620.64 End 40 dls, Start RSM 7 8387.07 90.00 224.61 6661.00 3198.45 1693.49 8.00 270.00-3584.76 7 8 8460.00 91.00 221.87 6660.37 3145.32 1643.53 4.00 290.00-3517.76 8 9 8550.00 94.54 222.50 6656.02 3078.72 1583.18 4.00 10.00-3434.53 9 10 8690.00 89.95 225.70 6650.53 2978.30 1485.86 4.00 145.00-3306.88 10 11 8890.00 89.81 233.70 6650.94 2849.06 1333.45 4.00 91.00 -3133.30 11 12 9175.00 89.82 222.30 6651.87 2658.68 1121.99 4.00 270.00-2882.09 12 13 9425.00 90.69 212.34 6650.78 2460.12 970.61 4.00 275.00-2643.73 13 14 9750.00 90.67 199.34 6646.92 2168.27 829.27 4.00 270.00-2321.13 End RSM, Start 7 dls 15 9950.00 104.45 196.85 6620.67 1980.30 767.78 7.00 350.00-2123.47 15 1610150.00 94.39 186.97 6587.91 1787.70 727.40 7.00 225.00-1928.67 16 17 10425.00 91.19 205.98 6574.41 1525.57 649.79 7.00 99.00-1655.81 17 18 10600.00 89.47 193.85 6573.39 1361.35 590.29 7.00 262.00-1481.14 18 19 10850.00 88.89 211.34 6576.98 1131.46 494.61 7.00 92.00-1232.39 19 20 11100.00 88.65 193.84 6562.39 901.60 398.96 7.00 269.00 -983.68 Planned TD at 11100.00 Mean E REFERENCE INFORMATION E)R ae- Wdl IH47. True NaN HIM M- sm-(O.Wen �"eW BAKER 5)Rdaerce: Sld-10. 9 0 ( btimm mt IH47=4540ueA(IH47) NUGNES lellon Mdlwd MinmuT Cwdw Vertical Section at 200.00° (95 usft/in) Kuparuk River Unit Kuparuk 1 H Pad 1 H-07 1 H-07AL1 Plan: 1 H-07AL1_wp04 Standard Planning Report 07 January, 2016 Database: EDM Alaska ANC Prod Company: NADConversion Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: 1 H-07 Wellbore: 1 H-07AL1 Design: 1 H-07AL1_wp04 ConocoPhilli(95 Planning Report Local Co-ordinate Reference: Well 11-1-07 TVD Reference: Mean Sea Level MD Reference: 1 H-07 @ 85.00usft (1 H-07) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1 H Pad Site Position: Northing: 5,979,968.84 usft Latitude: 700 21' 21.831 N From: Map Easting: 549,197.16 usft Longitude: 149° 36' 1.675 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.38 ° Well 1 H-07 Well Position +N/ -S 0.00 usft Northing: 5,979,935.13 usft Latitude: 70° 21'21.476 N +E/ -W 0.00 usft Easting: 549,560.55 usft Longitude: 1490 35'51.058 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1H-07AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I (I (nT) BGGM2015 4/1/2016 18.60 81.00 57,498 Design 1 H-07AL1_wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,254.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (1) 0.00 0.00 0.00 350.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate TFO (usft) (1 (1) (usft) (usft) (usft) (°1100usft) (°/I00usft) (°1100usft) (1) Target 8,254.00 76.78 262.94 6,649.97 3,264.30 1,804.71 0.00 0.00 0.00 0.00 8,324.00 101.18 276.78 6,651.21 3,264.16 1,735.42 40.00 34.86 19.78 30.00 8,394.00 86.62 300.82 6,646.39 3,286.56 1,670.01 40.00 -20.81 34.33 120.00 8,530.00 88.03 355.26 6,653.26 3,397.53 1,600.82 40.00 1.04 40.03 90.00 8,630.00 89.85 2.02 6,655.11 3,497.42 1,598.46 7.00 1.82 6.76 75.00 8,730.00 94.35 7.40 6,651.45 3,596.95 1,606.65 7.00 4.49 5.37 50.00 8,830.00 90.83 13.46 6,646.93 3,695.14 1,624.73 7.00 -3.52 6.06 120.00 8,900.00 88.38 9.21 6,647.42 3,763.75 1,638.48 7.00 -3.50 -6.06 240.00 9,075.00 88.41 356.96 6,652.33 3,938.10 1,647.87 7.00 0.02 -7.00 270.00 9,250.00 87.39 344.74 6,658.76 4,110.43 1,620.12 7.00 -0.59 -6.98 265.00 1/7/2016 11:39:OOAM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska ANC Prod Local Co-ordinate Reference: Well 1 H-07 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 H-07 @ 85.00usft (1 H-07) Site: Kuparuk 1H Pad North Reference: True Well: 1H-07 Survey Calculation Method: Minimum Curvature Wellbore: 1 H-07AL1 Depth Inclination Azimuth Design: 1 H-07AL1_wp04 +E/ -W Section Planned Survey Measured Vertical Local Coordinates Depth Depth Measured +E/ -W TVD Below (usft) (usft) Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (a) (o) (usft) (usft) (usft) (usft) (°/100usft) (°) (usft) (usft) 8,254.00 76.78 262.94 6,649.97 3,264.30 1,804.71 2,901.32 0.00 0.00 5,983,210.98 551,343.45 TIP/K0P 6,647.42 3,763.75 1,638.48 8 9,075.00 6,652.33 3,938.10 1,647.87 9 9,250.00 8,300.00 92.82 272.03 6,654.13 3,262.34 1,759.14 2,907.31 40.00 30.00 5,983,208.72 551,297.90 8,324.00 101.18 276.78 6,651.21 3,264.16 1,735.42 2,913.22 40.00 29.17 5,983,210.38 551,274.17 Start 40 ills 8,394.00 86.62 300.82 6,646.39 3,286.56 1,670.01 2,946.64 40.00 120.00 5,983,232.35 551,208.62 3 8,400.00 86.62 303.22 6,646.74 3,289.74 1,664.93 2,950.65 40.00 90.00 5,983,235.49 551,203.52 8,500.00 87.50 343.27 6,652.09 3,368.13 1,606.40 3,038.01 40.00 89.86 5,983,313.48 551,144.47 8,530.00 88.03 355.26 6,653.26 3,397.53 1,600.82 3,067.93 40.00 87.72 5,983,342.84 551,138.71 End 40 ills, Start 7 ills 8,600.00 89.30 360.00 6,654.89 3,467.43 1,597.93 3,137.27 7.00 75.00 5,983,412.71 551,135.35 8,630.00 89.85 2.02 6,655.11 3,497.42 1,598.46 3,166.72 7.00 74.89 5,983,442.71 551,135.68 5 8,700.00 93.00 5.78 6,653.37 3,567.21 1,603.22 3,234.62 7.00 50.00 5,983,512.53 551,139.98 8,730.00 94.35 7.40 6,651.45 3,596.95 1,606.65 3,263.32 7.00 50.09 5,983,542.28 551,143.22 6 8,800.00 91.89 11.64 6,647.64 3,665.87 1,618.21 3,329.17 7.00 120.00 5,983,611.26 551,154.32 8,830.00 90.83 13.46 6,646.93 3,695.14 1,624.73 3,356.87 7.00 120.23 5,983,640.58 551,160.64 7 8,900.00 88.38 9.21 6,647.42 3,763.75 1,638.48 3,422.05 7.00 -120.00 5,983,709.27 551,173.94 8 9,000.00 88.39 2.21 6,650.24 3,863.15 1,648.42 3,518.22 7.00 -90.00 5,983,808.73 551,183.22 9,075.00 88.41 356.96 6,652.33 3,938.10 1,647.87 3,592.12 7.00 -89.80 5,983,883.66 551,182.17 9 9,100.00 88.26 355.21 6,653.06 3,963.03 1,646.17 3,616.97 7.00 -95.00 5,983,908.58 551,180.30 9,200.00 87.67 348.23 6,656.61 4,061.86 1,631.79 3,716.80 7.00 -94.95 5,984,007.30 551,165.27 9,250.00 87.39 344.74 6,658.76 4,110.43 1,620.12 3,766.65 7.00 -94.70 5,984,055.78 551,153.28 Planned TD at 9250.00 -asing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 11,100.00 2 3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 8,254.00 6,649.97 3,264.30 1,804.71 TIP/KOP 8,324.00 6,651.21 3,264.16 1,735.42 Start 40 dls 8,394.00 6,646.39 3,286.56 1,670.01 3 8,530.00 6,653.26 3,397.53 1,600.82 End 40 dls, Start 7 dls 8,630.00 6,655.11 3,497.42 1,598.46 5 8,730.00 6,651.45 3,596.95 1,606.65 6 8,830.00 6,646.93 3,695.14 1,624.73 7 8,900.00 6,647.42 3,763.75 1,638.48 8 9,075.00 6,652.33 3,938.10 1,647.87 9 9,250.00 6,658.76 4,110.43 1,620.12 Planned TD at 9250.00 1/7/2016 11:39:OOAM Page 3 COMPASS 5000.1 Build 74 Reference Baker Hughes INTEQ Fitter type: rel as CoBiocdlIIS Travelling Cylinder Report Depth Range: X RIE Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Co-ordinate Reference: Well 1 H-07 Description Project Kuparuk River Unit TVD Reference: 1 H-07 @ 85.00usft (1 H-07) Sperry -Sun BOSS gyro multishot Reference Site: Kuparuk 1 H Pad MD Reference: 1 H-07 @ 85.00usft (1 H-07) MWD -Standard Site Error. 0.00 usft North Reference: True MWD - Standard Reference Well: 1H-07 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1H-07AL1 Database: OAKEDMP2 Reference Design: 1 H-07AL1_wp04 Offset TVD Reference. Offset Datum Reference 1 H-07AL1_wp04 Fitter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 8,254.00 to 9,250.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,116.50 usft Error Surface: Elliptical Conic Survey Tool Program Date 1/7/2016 From To (usft) (usft) Survey (Wellbore) Tool Name Description 100.00 7,800.00 1 H-07 (1 H-07) BOSS -GYRO Sperry -Sun BOSS gyro multishot 7,800.00 8,254.00 1H -07A wp05(1H-07A) MWD MWD -Standard 8,254.00 9,250.00 1H-07AL1 wp04(1H-07AL1) MWD MWD - Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 11,100.00 2 3/8" 2-3/8 3 Summary Site Name Offset Well - Wellbore - Design Kuparuk 1 H Pad 1 H-01 -1 H-01 -1 H-01 I H-05 - 1 H-05 -1 H-05 1 H-05 -1 H-105 - 1 H-105 1 H-06 - 1 H-06 - 1 H-06 1 H-07 -1 H-07 -1 H-07 1 H-07 - 1 H -07A - 1 H -07A wp05 1 H-08 - 1 H-08 - 1 H-08 1 H-09 - i H-09 -1 H-09 1 H-10 - i H-10 - 1 H-10 1 H-11 -1 H-11 - 1 H-11 1 H-12 -1 H-12 - i H-12 1 H-13 -1 H-13 -1 H-13 1 H-14 -1 H-14 - 1 H-14 1H -15 -1H -15-1H-15 1H -18 -1H -18-1H-18 1 H-21 - i H-21 - 1 H-21 1 H-22 -1 H-22 -1 H-22 Plan: 1 H-104 (formerly 101 and 27) - Plan: 1 H-104 Plan: 1 H-104 (formerly 101 and 27) - Plan:1 H-104 Plan: 1 H-104 (formerly 101 and 27) - Plan:1 H-104 Plan: 1 H-104 (formerly 101 and 27) - PlanA H-104 Plan: 1 H-104 (formerly 101 and 27) - Plan:1 H-104 Plan: 1 H-106 (formerly 107 and 28D) - Plan: 1 H-10 Plan: 1 H-107 (formerly 108 and 30E) - Plan: 1H-10 Plan: 1 H-112 (formerly 106 and 28E) - Plan: 1 H-11 Reference Offset Centre to Measured Measured Centre Depth Depth Distance (usft) (usft) (usft) 8,330.00 7,550.00 539.74 8,274.73 8,275.00 2.37 No -Go Allowable Distance Deviation Warning (usft) from Plan (usft) 11.69 0.66 9,212.89 8,050.00 739.52 246.65 Out of range Out of range Out of range Out of range 533.64 Pass - Major Risk 1.82 Pass - Major Risk Out of range Out of range Out of range Out of range Out of range Out of range 544.07 Pass - Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 117/2016 10:59:56AM Page 2 COMPASS 5000.1 Build 74 Avmwe mN xe xex� WELLBORE DETAILS: 11-07AL7 Project: KuparuN River Unit Mme om mso Site: Kuparuk 1H Pad a Exn Parent Wellbore: 1H -07A Well: 111-07 Ase o¢yw. siin ssnT Wellbore: 1H-07AL1 oA.Ne ei oo Te on MD: 8254.00 Plan: 1H-07AL7_wp04 (1H-07/11-1-07ALt) NOGIreGGiniois I Mean E 800 900 REFERENCE INFORMATION Gad.W(NIE) Weenw: Well lHd7. Twe Nu@ Flas VSf (VO)Refeenie Mean SwN 0 BA Sei n(VS)ReI.- Sld-10 M, O." Measuretl OeaRemdw wo-C50Ws9 (1NUn HUGHES GY.uNGon ldelAo4 MNinum Cwalee Vertical Section at 350.00° (35 usfUin) WELL DETAILS: 1H-07 +N/ -S +E/ -W Northing Easting LaOtude Longitude 0.00 0.00 5979935.13 549560.55 70° 21'21.476 N 149°35'51.058 W Sec MD Inc Azi TVDSS -NI-S +E/ -W Meg TFace VSect Annotation 1 8254.00 76.78 26294 6649.97 3264.30 1804.71 0.00 0.00 2901.32 TIP/KOP 2 8324.00 101.18 276.78 6651.21 3264.16 1735.42 40.00 30.00 2913.22 Start 40 dls 3 8394.00 86.62 300.82 6646.39 3286.56 1670.01 40.00 120.00 2946.64 3 4 8530.00 88.03 355.26 6653.26 3397.53 1600.82 40.00 90.00 3067.93 End 40 d1s, Start 7 dls 5 8630.00 89.85 2.02 6655.11 3497.42 1598.46 7.00 75.00 3166.72 5 6 8730.00 94.35 7.40 6651.45 3596.95 1606.65 7.00 50.00 3263.32 6 7 8830.00 90.83 13.46 6646.93 3695.14 1624.73 7.00 120.00 3356.87 7 8 8900.00 88.38 9.21 6647.42 3763.75 1638.48 7.00 240.00 3422.05 8 9 9075.00 88.41 356.96 665233 3938.10 1647.87 7.00 270.00 359212 9 10 9250.00 87.39 344.74 6658.76 4110.43 1620.12 7.00 265.00 3766.65 Planned TD at 9250.00 I Mean E 800 900 REFERENCE INFORMATION Gad.W(NIE) Weenw: Well lHd7. Twe Nu@ Flas VSf (VO)Refeenie Mean SwN 0 BA Sei n(VS)ReI.- Sld-10 M, O." Measuretl OeaRemdw wo-C50Ws9 (1NUn HUGHES GY.uNGon ldelAo4 MNinum Cwalee Vertical Section at 350.00° (35 usfUin) IH -07 Proposed CTD Schematic 16" 65# H-40 at 80' MD III 10-3/4" 45.5# K-55 at 2365' MD C3/4 perfs (sgz'd) 7696'-7755' MD t C4 straddle cement squeezed unless injectivity low C1 perfs 7805'-7830' MD C1 straddle cement squeezed KOP @ 7842' MD Annulus of C1 straddle assembly cement squeezed A-sandperfs 8015'-8051' MD 7" 29# K-55 at 8274' MD DS nipple at 503' MD (2.875" min ID) 3%" 9.3# L-80 ELIE 8rd Tubing to surface 3M." Camco KBMG gas lift mandrel at 7572' MD DS landing nipple at 7620' MD (2.812" min ID) Baker 3%" PBR at 7662' MD Baker FHL packer at 7675' MD 3%" Camco MMM production mandrel at 7689' MD AVA ported nipple at 7781'(2.813" ID) Baker KBG-22 anchor seal assembly at 7788' MD Baker SAB -3 packer at 7789' MD 3'/:" Camco MMM production mandrel at 7801' MD AVA ported nipple at 7874'(2.7511 ID) x/o to 2'/" tubing at 7877' MD Baker D packer at 7880' MD XN landing nipple at 7899' MD (2.25" min ID) Plug set to abandon A -sand perfs, capped with cement 2%" tubing tail at 7910' MD 1 H -07A, wp04 Liner -top packer at -7832' MD & TD @ 11,100' MD swell packer in B -shale to ensure Liner top at 8254' MD no behind -pipe comm to C1 1H-07AL1, wp04 TD @ 9250' MD Liner top at 7845' MD Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Wednesday, January 20, 2016 10:53 AM To: 'Jason.burke@cop.com' Cc: Colombie, Jody J (DOA); Bettis, Patricia K (DOA) Subject: KRU 1H -07A (PTD #216-011) Corrected Bond Number Jason, According to the AOGCC's records, the correct bond number for ConocoPhillips' Permit to Drill applications for all North Slope wells is Statewide Blanket Bond No. 5952180, NOT 8088-26-27. The latter may the number for a bond that ConocoPhillips has on file with a different state agency. Please specify Bond No. 5952180 on future applications to the AOGCC. Please let me know if you have any questions or if I can help further. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: r Development /Service Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: V_Z" a'c _ 1 POOL: r Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , 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 onpen-nit). 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 (Compan_y 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) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK RIV UNIT 1H -07A Well bore se —_Program SER_ g ❑ PTD#:2160110 Company-C_ONOCOPHILLIPS ALASKA INC _ - Initial Class/Type SER / PEND GeoArea 890_ Unit 11160 —_ On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31.05.0300A.A),0.2.A-D) NA 1 Permit fee attached NA 2 Lease number appropriate Yes 3 Unique well name and number Yes 4 Well located in a defined pool Yes 15 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes Appr Date 11 Permit can be issued without conservation order_ Yes 12 Permit can be issued without administrative approval Yes SFD 1/20/2016 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For Yes 15 All wells within 1/4 mile area of review identified (For service well only) Yes 16 Pre -produced injector; duration of pre -production less than 3 months (For service well only) Yes 18 Conductor string provided NA Engineering19 Surface casing protects all known USDWs NA 120 CMT vol_ adequate to circulate on conductor & surf csg NA 21 CMT vol adequate to tie-in long string to surf csg NA 22 CMT will coverall known productive horizons No 23 Casing designs adequate for C, T, B &_ permafrost Yes 24 Adequate tankage or reserve pit Yes 25 If a re -drill, has a 10-403 for abandonment been approved Yes 26 Adequate wellbore separation proposed Yes 27 If diverter re uired does it meet re ulations NA Appr VTL Geology Appr SFD Entire Well lies within ADL0025639. KUPARUK RIVER, KUPARUK RIV OIL - 4901-00 Kuparuk River Oil Pool, governed by Conservation Order No. 432D Conservation Order No. 432D has no interwell spacing restrictions. Wellbore will be more than 500' from an external property line where ownership or landownership changes. As proposed, well will conform conform to spacing requirements. Area Injection Order No. 2C - Kuparuk River Unit KRU 111-1-07, 1 H-14, 111-1-16 Per page 2 of the KRU 1_1-1-71 CDT Summary For Plugging Sundry (10-403) that accompanies the PTD application Conductor set in KRU 1 H-07 Surface casing set in KRU 1 H-07 Surface casing set and fully cemented Productive interval will be completed with uncemented slotted liner Rig has steel tanks; all waste to approved disposal wells PTD 182-084, Sundry 316-024 Anti -collision analysis complete; no major risk failures Geologic q , g Engineering Public Commissioner: Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure is 3721 psig(10.9 ppg EMW); will drill w/ 9.6 ppg EMW & maintain overbal w/ MPD_ 1/22/2016 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 3065 psig; will test BOPs to 3500 psig 31 Choke manifold complies w/API RP -53 (May 84) Yes 132 Work will occur without operation shutdown Yes 33 Is presence of 1-12S gas probable Yes 1-12S measures required 34 Mechanical condition of wells within AOR verified (For service well only) Yes AOR completed; mechanical condition verified 35 Permit can be issued w/o hydrogen sulfide measures No Wells on 1H -Pad are H2S-bearing. 1-12S measures required. 36 Data presented on potential overpressure zones Yes Expected reservoir pressure is 10.8 ppg EMW; well will be drilled using 9.6 ppg mud, a Date 37 Seismic analysis of shallow gas zones NA coiled -tubing rig, and managed pressure drilling technique to control formation pressures. 1/20/2016 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date