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219-085
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, October 15, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3R-112 KUPARUK RIV U WSAK 3R-112 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/15/2024 3R-112 50-029-23637-00-00 219-085-0 W SPT 3626 2190850 1500 250 250 250 250 400 400 400 400 4YRTST P Adam Earl 8/10/2024 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U WSAK 3R-112 Inspection Date: Tubing OA Packer Depth 970 1830 1785 1780IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240812140249 BBL Pumped:0.6 BBL Returned:0.7 Tuesday, October 15, 2024 Page 1 of 1 9 9 9 9 9 9 999 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.15 15:15:55 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: LPP/SSV Returned to Service on CPAI Well 3R-112 (PTD# 219-085) on 12/09/2021 Date:Friday, December 10, 2021 3:41:12 PM Attachments:image001.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Thursday, December 9, 2021 5:26 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com>; NSK Prod Engr Specialist <n1139@conocophillips.com>; NSK Optimization Engr <n2046@conocophillips.com>; CPF3 Ops Supv <n2070@conocophillips.com>; CPF3 DS Lead Techs <n1105@conocophillips.com>; Braun, Michael (Alaska) <Michael.Braun@conocophillips.com>; Kholeif, Will <Will.Kholeif@conocophillips.com> Subject: LPP/SSV Returned to Service on CPAI Well 3R-112 (PTD# 219-085) on 12/09/2021 Mr. Regg, The low-pressure pilot on injection well 3R-112 (PTD# 219-085) is back in service as of 12/09/2021. The well is currently injecting 1225 BWPD at 153psi wellhead pressure. This notification is in accordance with “Administrative Approval No. CO 406B.001.” Thank you, Brian Lewis Senior Production Engineer – CPF3 Phone: (907) 263-4535 | Cell: (918) 521-8990 From:Regg, James B (CED) To:AOGCC Records (CED sponsored) Subject:FW: Defeated LPP/SSV on well 3R-112 (PTD# 219-085) Date:Thursday, September 9, 2021 8:21:05 AM Attachments:image001.png reviewed Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Wednesday, September 8, 2021 5:08 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com>; NSK Prod Engr Specialist <n1139@conocophillips.com>; NSK Optimization Engr <n2046@conocophillips.com>; CPF3 Ops Supv <n2070@conocophillips.com>; CPF3 DS Lead Techs <n1105@conocophillips.com>; Braun, Michael (Alaska) <Michael.Braun@conocophillips.com>; Kholeif, Will <Will.Kholeif@conocophillips.com> Subject: Defeated LPP/SSV on well 3R-112 (PTD# 219-085) Mr. Regg, The low pressure pilot (LPP) on injection well 3R-112 (PTD# 219-085) was defeated today, 09/08/2021. The injector had been shut in due to facility operations on the seawater injection line. It was returned to service today, and the injection pressure is still below the pressure required for the LPP to reset. The well is currently at a wellhead injection pressure of 139 psig at an injection rate of 1400 bwpd. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the “Drill Site Defeated Safety Device Log.” The AOGCC will be notified when the injection pressure has increased to above 250 psig and the LPP/SSV function is returned to normal, in accordance with “Administrative Approval No. CO 406B.001.” Please let me know if you have any questions, Brian Lewis Regg, James B (CED) From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Saturday, June 19, 2021 10:36 AM l f. To: Regg, James B (CED) j Cc: Well Integrity Specialist CPF2; NSK Prod Engr Specialist; NSK Optimization Engr; CPF3 Ops Supv; CPF3 DS Lead Techs; CPF3 Prod Engrs; Braun, Michael (Alaska); Kholeif, Will Subject: Defeated LPP/SSV on well 3R-112 (PTD# 219-085 ) Mr. Regg, I'm filling in as the emergency contact this weekend, so apologies if this has already been reported. i/ The low pressure pilot (LPP) on injection well 311-112 (PTD# 219-085) is defeated as of approximately 1900 hrs 18 -Jun - 21 1 - The- The injector had been shut in due to well work on the nearby producer. It was returned to service last night and the injection pressure is, not surprisingly, still below the pressure required for the LPP to reset. The well is currently at a wellhead injection pressure of 15 psig at an injection rate of 1400 bwpd. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Drill Site Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 250 psig and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Thanks, 9lesuief�i ,t°ea�d Kenneth Lloyd Martin PERA for the CPF3 Production Engineers Ph: (907) 659-7871 1 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Oct 13, 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jessie Chmielowski: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, Roger Mouser ConocoPhillips Well Integrity Field Supervisor Roger Mouser Digitally signed by Roger Mouser Date: 2020.10.13 13:10:42 -08'00' By Samantha Carlisle at 1:21 pm, Oct 13, 2020 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 10/13/20 2K 2M 3K 3O 3Q 3R 3S pad Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal 2K-30 50103207580000 2170720 22" 0.3 6" 3/8/2020 2.5 9/29/2020 2K-32 50103207570000 2170420 29" 0.5 6" 3/8/2020 3 9/29/2020 2M-37 50103207450000 2160820 30" 0.4 9" 7/31/2020 2.1 9/29/2020 2M-38 50103207460000 2160830 4" N/A 4" N/A 2.5 9/29/2020 3K-32 50029227630000 1970760 10"Conductor extension 10" 4/27/2019 2.5 9/27/2020 3K-34 50029228790000 1980770 14" Conductor extension 14" 4/27/2019 9 9/27/2020 3O-01A 50029218360000 2151910 62" 0.70 11" 3/8/2020 4.25 9/27/2020 3O-19 50029227530000 1970500 13"Conductor extension 13" 4/27/2019 4.25 9/27/2020 3O-20 50029227500000 1970450 21 5.00 17" 9/27/2020 6 9/27/2020 3Q-22 50029226250000 1951860 20' 3.25 8" 3/8/2020 4.25 9/26/2020 3R-101 50029235740000 2170130 21" 0.40 8" 8/14/2020 1 9/26/2020 3R-102 50029235720000 2161570 54" 1.10 6" 8/14/2020 6 9/26/2020 3R-105 50029236510000 2191340 22" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-106 50029236410000 2190970 36" 0.60 9" 8/14/2020 3.5 9/26/2020 3R-107 50029236600000 2191810 32" 0.60 9.5" 8/14/2020 1 9/26/2020 3R-111 50029236430000 2191050 25" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-112 50029236370000 2190850 36" 0.60 14"8/14/2020 7 9/26/2020 3S-611 50103207740000 2181030 11' 10" 2.50 8"6/30/2019 2.5 9/27/2020 3S-612 50103207770000 2181110 43" 0.75 8" 6/30/2019 3.5 9/27/2020 3S-613 50103207350000 2160200 22" 0.75 8" 6/30/2019 1.7 9/27/2020 MEMORANDUM TO: Jim Regg I r I 17 P.I. Supervisor FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, August 17, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3R-112 KUPARUK R1V U WSAK 3R-112 Src: Inspector Reviewed jy P.I. Suprv� Comm Well Name KUPARUK RIV U WSAK 3R-112 API Well Number 50-029-23637-00-00 Inspector Name: Brian Bixby Permit Number: 219-085-0 Inspection Date: 8/13/2020 i Insp Num: mitBDB2008 13160040 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well '� 3R-112 Type Inj I W ' !TVD 3626 Tubing 725 725 725 725 PTD 2190850 Type Test SPT psi 1500 IA 240 1810 - 1730 1720 11 ,Test BBL Pumped 1.2 —13131, Returned: 1.1 OA 400 400 - 400 400 Interval 4YRTST P/F P Notes: Monday, August 17, 2020 Page I of 1 z— Regg, James B (CED) p7b zq IO560 From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Saturday, December 28, 2019 8:53 AM/lt9 To: Regg, James B (CED) ap Cc: Well Integrity Compliance Specialist WINS & CPF3; NSK Prod Engr Specialist; NSK Optimization Engr; CPF3 Ops Supv; CPF3 Ops & DOT Pipelines Supt; CPF3 DS Lead Techs; Valentine, Doug K Subject: RE: Defeated LPP/SSV on well 3R-112 (PTD# 219-085 ) Mr. Regg, Perthe message below, the low pressure pilot (LPP) on injection well 311-112 (PTD# 219-085) has been retLrrned to service as of 28 -Dec -2019. Please let me know if you have any questions. Thanks, Kaelin Ellis/ Kenneth Lloyd Martin CPF3 Production Engineer ConocoPhillips Alaska Ph: 907-659-7871 From: CPF3 Prod Engrs Sent: Tuesday, November 26, 2019 7:01 PM To: jim.regg@alaska.gov Cc: Well Integrity Compliance Specialist WINS & CPF3 <n2549@conocophillips.com>; NSK Prod Engr Specialist <nll39@conocophillips.com>; NSK Optimization Engr<n2046@conocophillips.com>; CPF3 Ops Supv <n2070@conocophillips.com>; CPF3 Ops & DOT Pipelines Supt <nll75@conocophillips.com>; CPF3 DS Lead Techs <n1105@conocophillips.com>; Valentine, Doug K <Doug.K.Valentine@conocophillips.com>; CPF3 Prod Engrs <n1223@conocoph ill i ps.com> Subject: Defeated LPP/SSV on well 3R-112 (PTD# 219-085 ) Mr. Regg, The low pressure pilot (LPP) on injection well 3R-112 (PTD# 219-085) is now defeated as of 26 -Nov -2019. The well was shut in 15 -Nov -19 for conversion from a pre -production state to it new status as an injector. After returning the well to injection, the wellhead pressure has not risen high enough to place the low pressure pilot in service. The well is currently at a wellhead injection pressure 260 prig and declining as the tubing loads up an injection rate of 550 bwpd. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Drill Site Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 250 psig and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. R1=C1=oVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 11 2019 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon LJ Plug Perforations LJ Fracture Stimulate Li Pull TubingOperations s ut wn Li Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Prod to WI ❑-' 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: DevelopmentEx lorato ❑ P ry ❑ Stratigraphic ❑ Service ❑ 219-085-0 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-029-23637-00 7. Property Designation (Lease Number): 8. Well Name and Number. ADI -355023, ADL355024, ADL373301 KRU 3R-112 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Ku aruk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12,697 feet Plugs measured None feet true vertical 3,503 feet Junk measured None feet Effective Depth measured 12,695 feet Packer measured 6182, 6239, 6240 feet true vertical 3,503 feet true vertical 6182, 6239, 6240 feet Casing Length Size MD TVD Burst Collapse Conductor 134 20 173 173 Surface 2,392 11 2,392 2200 Intermediate 6,347 13 6,385 3642 Production 6,464 7 12,695 3503 Perforation depth Measured depth 6231' - 12695' feet (Slotted Liner, No Perforations) True Vertical depth 36261- 3503' feet (Slotted Liner, No Perforations) Tubing (size, grade, measured and true vertical depth) 4.5 L-80 6239 3627 Packers and SSSV (type, measured and true vertical depth) ZXP Liner Top Packer 6231 3626 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -B61 Casing Pressure I Tubing Pressure Priorto well operation: 1032 792 144 1324 Subsequent to operation:10 0 11487 144 14. Attachments (required per20 Me 25.070, 25.071, 825.283) 15. Well Class after work: Daily Report of Well Operations ❑Q Exploratory ❑ Development p ❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas Li WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ Q WAG p GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-514 Authorized NameDouglas K Valentine Contact Name: Doug Valentine : 9 Authorized Title: Senior D�nrills/�ite Petroleum Engineer Contact Email: doug.k.valentine@cop.com ' Ytt(lo/ �q Contact Phone: 907-263-4146 Authorized Signature: Date Form 10-404 Revised 4/2017 /2-I/6IIq Submit Original Only `L 1.7-Ae f I MSH�4/DEC 12 2019 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg n DATE: Tuesday, December 10, 2019 P.I. Supervisor I ` l�llG/f 9 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3R-112 FROM: Adam Earl KUPARUK RIV U WSAK 3R-112 Petroleum Inspector Ste: Inspector Reviewed By: P.I. Suprv;-1$>�! NON -CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 3R-112 API Well Number 50-029-23637-00-00 Inspector Name: Adam Earl Permit Number: 219-085-0 Inspection Date: 12/7/2019 Insp Num: mitAGE191207203147 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 3R-uz 'Type Inj W 'TVD ez2 Tubing o 0 0 0 [BBLWell PTD zleoaso Type Test sPT Test psi soo - IA sso nls - eao - wo BBL Pumped: 0.6 "BBL Returned: o.e -OT--T- lee tae - 231 - z22 Interval txlrAl p/F I P Notes: Sundry # 319-514 conversion from producer to water Inj. The well was on water injection although it hadn't caught pressure yet. Tuesday, December 10, 2019 Page 1 of I C®noc®Phillip.rz December 10, 2019 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave. Ste. 100 Anchorage, AK 99501 Dear Commissioner, Douglas K Valentine Petroleum Engineer ANC 1352 700 G Street Anchorage, AK 99501-3448 Phone: (907) 263-4146 Doug.K.Valentine@conocophillips.com Enclosed you will find 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. regarding 3R-112 (PTD# 219-085) If you have any questions regarding this matter, please contact me at 907-263-4146. Sincerely, � (�. V Doug Valentine Attachments Report of Sundry Well Operations Daily Report of Well Operations 3R-112 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/15/19 SI and Freeze Protected Well For Conversion to Water Injector 11119/191 Measured BHP, pulled orifice valve and circ out tubing/IA 11/20/19 Continue with circ out 11/21/19 Pull remaining gas lift valves and replace with dummy valves. Install A-1 Injection valve 12/07/1913R-1 12 (ISM State witnessed (Adam Earl) MIT -IA (Passed to 1715 psi) Winston, Hugh E (CED) From: Valentine, Doug K <Doug.K.Valentine@conocophillips.com> Sent: Thursday, December 12, 2019 12:23 PM To: Winston, Hugh E (CED) Subject: Re: [EXTERNAL]KRU 3R-112 Injection Begin Date Hi Hugh, 311-112 was brought onto injection on Nov 26, 2019 at 14:55. Please let me know if you have any more questions Doug Valentine 208-932-5280 From: Winston, Hugh E (CED) <hugh.winston@alaska.gov> Sent: Thursday, December 12, 2019 12:04:32 PM To: Valentine, Doug K <Doug.K.Valentine@conocophillips.com> Subject: [EXTERNAL]KRU 313-112 Injection Begin Date Hi Doug, I'm processing a sundrywell report for well KRU 311-112, sundry number 319-514, forthe conversion to water injection. I am trying to verify the precise date that water injection began in order to get the date of status correct in our database. I see on the work summary that an injection valve was installed on 11/21/19 and the MIT -IA was completed on 12/7/19. Could you please let me know the exact day in between those times that water injection commenced? Thanks HueV Winston Statistical Technician Alaska Oil and Gas Conservation Commission huzh.w i nston @ alaska.aov 907-793-1241 Regg, James B (CED) From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Tuesday, November 26, 2019 7:01 PM To: Regg, James B (CED) Cc: Well Integrity Compliance Specialist WNS & CPF3; NSK Prod Engr Specialist; NSK Optimization Engr; CPF3 Ops Supv; CPF3 Ops & DOT Pipelines Supt; CPF3 DS Lead Techs; Valentine, Doug K; CPF3 Prod Engrs Subject: Defeated LPP/SSV on well 3R-112 (PTD# 219-085 ) Mr. Regg, The low pressure pilot (LPP) on injection well 311-112 (PTD# 219-085) is now defeated as of 26 -Nov -2019. The well was shut in 15 -Nov -19 for conversion from a pre -production state to it new status as an injector. After returning the well to injection, the wellhead pressure has not risen high enough to place the low pressure pilot in service. The well is currently at a wellhead injection pressure 260 psig and declining as the tubing loads up an injection rate of 550 bwpd. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Drill Site Defeated Safety Device Log" The AOGCC will be notified when the injection pressure has increased to above 250 psig and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No, CO 4068.001." Please let me know if you have any questions. Thanks, .%e� ffogd Kenneth Lloyd Martin/Kaelin Ellis PERA/CPF3 Production Engineers Ph: (907) 659-7871 Pager: (907)659-7000 pp# 328 0 w L O N O m 0 O A m N r O Q N N N d n E E U U No > N pl pl ❑I n n a � � � � � h m M I M M M > ❑ > W W C N N D N p N N y ~I ~I N N Z Z E E p E p E p E 0 NI 0 M 0 NI NI NI NI ❑ ❑ m ° o 0 0 i z z L Q 5 y d_ J d_ J d_ J d_ f a m N N N u y 2 z N Z N Z T,c. J d N t� N N N M ..a M M ..T: M> M� M> M N m 0 m 0 M W m M N M N m M M .=. m Q ❑ N N (n C ip 2 (A 2 y A fnN ,65 N N N H N N (A d d Q 0 p Z p Z p Z ❑ Z IL N IL N IL N E Z E Z ii Z E Z C IL m LL O E E 0L 0— 0— 09 0� u� u� 09 09 09 0L 0L 02 w 0 E 'c tq 'E W "c W 'E N 'E z z c o c c 0 c o c c x U0 0> 0j 05 oz of of of o o v 0,v NUJ Nw N N- 0 0 0o v 0 -- lYlr� y W W W- W W> W J W5; W W- W- W- W to W 0 OQ U m m m m ma m m m m m m m m y 9 do o s o 0 0 0 0 o s s s a N N N N N N N N N N N N ro ro ro ro m m m m m ro ro m LLIM a/ 0. - - 0 0 0 - 0 0 0 0 0 0 - 0 W 0 U 0 J 2 2 oU U o Zo o w o o m m m w I.L O U0 d r1 c Z CO n d E n N U m r J N U w c rcz0 M `a q r N m O a C � N G ) m m a 0 C N 7 N a ❑ \ > a > c w a O E z01 E Q 0 0 U rn U E ❑ m Z ?� � J V N N N N N l0 N N N @ @ N N 0 C W N N N N N (0 N N N (0 N N N Mo O E ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ N N N N N (0 N N N N N N (0 M N m L m m m m m m m m m m m m irm 0 0 0 0 0 0 0 0 0 0 0 0 0 '^ > z O � _ � d °' m co c0 c0 c0 c0 c0 c0 c0 c0 c0 c0 c0 a Q Z a f O C W O Z N ar N m O f Q n c rn9 'm0 o 00 O r K Z J U U U U U U U U U U U U U 0 rn:° a ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ CL � z o '.�'� � o� w w w w w w w w w w w w w 3 0 w L O O O O r th N N O N u VI N N Vl f/1 b VI N O N l6 N N N N N N J z E E E E E E E E r' U U U U U U U U U O O O O O O w w a r r r M M M M M 3 Q Q Q Q Q Q Q Q D z z z z z z z z > m w � O IL O LL O LL LL m LE IL N E O IL 7 m 0 d u N u a u U u 0 a u N u a Y U E 1/ C ti C N C 0 C N C N C N C iA O W O p p p O O p p WO U uZu� 'uZ uz uZ U) uZ uZ �Z oQ m) N] N> p 0 p � W W N W N W N W N W (n W to W N N S � rn rn m m m m m rn U o 0 0 0 0 0 0 0 N N N N N N N N QQ W W W \N M N N N N NQ N N N O O O O O O O O O N O N O o E U 77 0 N m d ❑ C d E E U m m m m m m m m m m m m m m w m M ❑ ❑ ❑ ❑ ❑ 0 0 0 O m 75 .m.. v M O) D7 OI 01 OI OI OI OI ❑ o 0 0 'o 0 0 0 0 M M M M M M M M M M M M C} M M M r CA !0 r U U U U U U U U w ❑ ❑ w ❑ w ww w Q z (� c N c ar } E lJ o @ ° E 0 U 0 y o m m � ami E 0 t T E E 7 N v N C � c m p ❑ C � ° m N p O U V D � T ❑ n 4 N�N O CL W W U Z Q J c. 0 ON r U J Q I~- V/ Q Q `1 2i J 0 :3 d a O voi O J m o m m ; N N n O � iri a v d m E E E 0 0 0 0 31376 STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil Q • Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended [3 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: 1b. Well Class: Development l] • Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Aband.: 8/19/2019 14. Permit to Drill Number / Sundry: 219-085 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 7/29/2019 15. API Number: 50.029-23637-00-00 ' 4a. Location of Well (Governmental Section): Surface: 1782' FNL, 2908' FEL, Sec 9, T13N, R9E, UM Top of Productive Interval: 4499' FNL, 2213' FEL, Sec 4, T13N, R9E, UM Total Depth: 4430' FNL, 3311' FEL, Sec 5, T13N, R9E, UM 8. Date TO Reached: 8113/2019 16. Well Name and Number: KRU 31R-112 ' 9. Ref Elevations: KB:49.25 ' GL: 9.8 . BF: 17. Field / Pool(s): Kuparuk River FieldNyest Salk Oil Pool ' 10. Plug Back Depth MD1fVD: N/A 18. Property Designation: ADL 355023, ADL 355024, ADL 373301 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 520678 y- 6031581. Zone- 4 - TPI: x- 521359 y- 6034145 Zone- 4 Total Depth: x- 514982 y- 6034198 Zone- 4 11. Total Depth Ni • 12697/3503 • 19. DNR Approval Number: 931933000, 931934000, 931953000 12. SSSV Depth MD1rVD: 214712013 20. Thickness of Permafrost Ni 1846/1757 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: 1 N/A (ft MSL) 21. Re-drill/Lateral Top Window MDf VD: N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res/Sonic LWD (Cement Eval) 23, CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE FT TOP BOTTOM TOP BOTTOM CEMENTING RECORD AMOUNT PULLED 20 94 H-40 Surface 173 Surface 173 42 Existing Cement to Surface 10314 45.5 L-80 Surface 2392 Surface 2200 13 112 1316sx 11.0ppg Class G, 217sx 12.0ppg Class G 75/8 29.7 L-80 Surface 6385 Surface 3642 97/8 721 sx 15.8ppg Class G 4112 12.6 L-80 6231 12695 3626 3503 63/4 Slotted Liner 24. Open to production or injection? Yes 0 No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SLOTTED LINER @: 6288-7832 MD and 3633-3654 TVD .... 8116/2019 COMPLETION 8496-9909 MD and 3594-3584 N.......8/16I2019 TE 10370-10817 MD and 3576-3561 TVD ..... 8 /1 612 01 9 11460.12571 MD and 3530-3508 ND.....8116/2019 � velq VMDL 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MDTFVD) 41/2 6278 N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No E] 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: 812612019 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 6127/2019 Hours Tested: 12hrs Production for Test Period Oil -Bbl: 30 Gas -MCF: 292 Water -Bbl: 333 Choke Size: 17beans Gas -Oil Ratio: 9716 Flow Tubing Press. 496 Casing Press 1191 ICalculated 24 -Hour Rae Oil -Bbl: 60 Gas -MCF: 583 Water -Bbl: 1 665 Oil Gravity - API (torr): 19.1 Form 10407 Revised 5/2017 VI-` /0/+/19 CONT/ Ep ON PAGE 2bmit ORIGINIAL only-� �o /� RBDMS SEP 12104 _,><ta�t (�/.•1 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� ' Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MD/ VD, FromTFo), 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 0 - If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1846 1757 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 6296 3634 information, including reports, per 20 AAC 25.071. Formation Q TPI - West Salk D K-15 2016 1906 Ugnu C 3456 2894 Ugnu B 4098 3193 Ugnu A 4556 3312 West Sak D 6296 3634 TD 12697 3503 Formation at total depth: West Bak D ' 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontolooical report production or well test results, per 20 AAC 25V0. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: G.L. Alvord Contact Name: Madeline Woodard Authorized Title: Alaska Drilling Manager Contact Email: madeline.e.woodard co .com Authorized >A/ Contact Phone: 265-6066 vl It t Signature: '�J--I — Date: 2,(C, INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10407 well completion report and 10404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item lb Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Sat 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 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. 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 10407 Revised 5/2017 Submit ORIGINAL Only O 3 O M 0t T „'O � N Hww wfnawwwr Cniny.W.I43F. 16]5' W IE3'AIlII I]3'TVO� 1.%45 59, LEO, H,063 _,7 w ,l ITobwq lk IT—I4W,4%% s,mo w. 3R-112 Tobi S33 4 -la\ 12G fi, L.SO Hv063 AP4I Hwlnu4<NipPk W3 tl13 BB pulib 8 uolYwnfktn wwlb6 (A 3,14T bN/3U1)'T`N Ga LiM1MUNCI. CAMC04-ln" 1' ISOV P=W w 2."Pf Slotted Liner Infector FINAL Schematic E?91'A0/3.19Y ND 2,1]9601 2$33'TVO G r m E3 n Gss LiB Men6rtl, CAMC04-1Wx P(0V) t-4, 13P M0/3,SU3' TM 3 813' M nlPPb a'/GUJ Pbple+ LJBI'Fm/)p30'ND Lirc441'. 13 fi0LM �HVE5633b Ye1 61EY Sue11vb1e Psskn lWawrBryvdM)� 6.314"BanElLv+l 13,69T MU/),503'TW� v ZXPLioer TnPW�ktimllenya ' f _______________ 6,331'M0/)636'TVB _ - ............... ..._ ______ .... _ ___ -- ..- ]-SB-, 21A. LM, H16563.Cf&� I.irce, JI/1". 1360 L&I 0.5"Witle SM1a 13,695'IM/3,503'NU 6135'FtDI),W I'TVD IIy6563Bb zi KUP PROD WELLNAME 3R-112 WELLBORE 3R-112 �(�(� Well Attribute Max TO /����/yr�T r� CbnocO• hills e� - IDC. Fred Name WeIICore APVUWI Wellbore Slalus n[I I°)ACI TRACT OPERATION 5002923fi3]00 Pn00 J4312,69].0BI) RIm 1111181Ata6ka, R1p Releaze DaleWSV'NIPPLE LASTWO'. Last Tag 8/19120193R M3R -I IS, W VAI8SNW pat ,knee' lr, 0didel Amwetbn D¢PIn 11VLB1 End Dadere IasIMW BYLASTTAG: )ennee....................................... __... Last Rev Reason ..5� .................._.............................. ................. Annoblron End Daledve LasIMW By...........- Rev Reason: Instilled GLVS, Pulle00FCV6 Installed SSSV d? zui9 zem0aej Casing Strings Casing Des[riplbn DO(in) lD[n) Top(IIHeI Sed DeptM1 MKB1 Sel Depin lrv0l._-1- p_. Gratle CONDUCTOR 20 18.65 39.5 1]3.0 1]3.0 162.00 TopTnn— .........._...........__.__................. ....._... ......._.. .. CeslnB Des[riplbn OD lint ml hepYd"" Set Dew(XRS, SN DeptM1 (N01... WBlm 11... GrW SURFACE 10314 9.95 40.2 2,391.9 2,1998 45.50 L430 Tap Tereatl Hyd 563 Casep Deenlptlon O011nl IDgn) Tpp KB) Set DeptM1 laRB) SN DeptM1 nVDI... WIM1en II...GMe Taplbroe4 INTERMEDIATE 7518 6.88 3].4IR 6,384] 3,641.9 29.]0 t80 H563 Casing0ea[ripeM OD lin) ID enl TOP ImIBI $at CepIM1 IRRBI SH DepN jND).. WIILen B... Gratla Top Tneeatl PROOUCTION LINET 4112 d.00 6,231.3 12,fi99.9 3,503.0 12.60 L-80 Hyd 563 Tubing Will Tabmg Desaipteenstring M•-. 4112"UPPER Ono 10 (in) 3.96 rov (Idhel 34.5 S u Dept' (IL. 6,2]83 set D. (rvDl 1... 3,631.6 WI jut 12.60 Grade L-80 Tov Connection Hytl 563 COMPLETION coni on Details CONDUCTCR:A.S1730 T,(10) Topin[I Nominal TapleKel PIKE) M Item Des Com ID (in) 34.5 3Tb0.00 HANGER VET OI MB 2421-1/2"x -1/2" tubing hanger (4909MCA 3900 Ss.v;214La Be. UP) 2,147.4 2,013,51 37.29 5 V 412' BP61 Hydraulic Nipple, 3812 DB Profile. 3.812 ,181.6 3,620. 8290 NIPPLE NipPle,4-112. Camm,%N,3818' Profile,SNJ99528] 3]50 9.3 3,62] J 83.54 LO TOR Locales, Baker BH -22 3.860 6, .8 3,627,4 83.55 SEALA SV ea Asselnby, er GBH- , 5'Olswallow-placed2. 3870 Of No-go SURFACE) 44u92, 3913 Mandrel Inserts a e Tdp ITVDI an taco N Tap(DKal `PSC Make MPdel ODllnl dery type Tres Pwl9ke TRO Run Ilnl IVW RunDm Com ws upT.?m90 1 2,8]9.0 2,533.5 Camm 1 1 GASLIPT LV BK NBMG 88 15320 Udell 81222019 2 4,12].3 3"`02] CamCd 1 1 GAS LIFT OV BK 0.313 0.0 8/222019 KBMG Notes: General & Safety End Dew Annotation GAs upT: a.tnd 911012019 NOTP. View bCremaee wl Au,rka5chrmdC10.0 durRUE;a1010 LOCATOR; 0.239.9 0 SEAAE. &ZW B INTERMEDATE;T40,3B1.] PRODUCTION DNET: B.]313 IL ..... _J� 12W9B Operations Summary (with Timelog Depths) 3R-112 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start oepm start Time EM Time our (hd Phase Op Coes ActWRy Code Time P -T -X Operation (11Ke) Emi Dep (flKB) 7/28/2019 7/28/2019 1.00 MIRU MOVE MOB P Skid rig floor. Raise stompers. 0.0 0.0 06:00 07:00 7/28/2019 7/28/2019 0.50 MIRU MOVE MOB P Jack up sub and pull off of well 3G-28. 0.0 0.0 07:00 07:30 Stage sub on pad. 7/28/2019 7/28/2019 1.50 MIRU MOVE MOB P Remove back cellar wall for 0.0 0.0 07:30 09:00 modification. 7/28/2019 7/28/2019 5.00 MIRU MOVE MOB P Move all rig modules T/ 3R. 0.0 0.0 09:00 14:00 7/28/2019 7/28/2019 2.00 MIRU MOVE MOB P Set cellar mats, spread herculite. 0.0 0.0 14:00 16:00 7/28/2019 7/28/2019 1.25 MIRU MOVE MOB P Spot sub. Lower stompers. 0.0 0.0 16:00 17:15 7/28/2019 7/28/2019 0.50 MIRU MOVE MOB P Skid rig floor. 0.0 0.0 17:15 17:45 7/28/2019 7/28/2019 0.25 MIRU MOVE MOB P Set mats for pits and pump modules. 0.0 0.0 17:45 18:00 7/28/2019 7/28/2019 2.50 MIRU MOVE MOB P Set pit mod, pump mod, motor mod, 0.0 0.0 18:00 20:30 pipe shed and rock washer. 7/28/2019 7/29/2019 3.50 MIRU MOVE MOB P Work on rig acceptance check list. 0.0 0.0 20:30 00:00 Test gas alarms - Good test. Repairing secondary injection line between pits and sub. 7/29/2019 7/29/2019 3.50 MIRU MOVE MOB P Continue with rig acceptance 0.0 TO 00:00 03:30 checklist. Install mouse hole. Load SLB BHA in pipe shed. Repairing secondary injection line between pits and sub. Rig accepted @ 03:30 7/29/2019 7/29/2019 1.50 MIRU MOVE RURD P Tighten slip bolts on GE diverter 0.0 0.0 03:30 05:00 adaptor. Install 4" valves on conductor. Install 2" drain valve on adaptor. Install non diverter riser. Repairing secondary injection line between pits and sub. 7/29/2019 7/29/2019 8.00 MIRU MOVE RURD P Load pipe shed, P/U & stand back 0.0 0.0 05:00 13:00 clean out run BHA. Process 77 joints 5" drill pipe in shed, and BHA. P/U & stand back 25 stands 5", 2 stands 5" HWDP, 1 jar stand, 1 stand drill collars. Repairing secondary injection line between pits and sub. 7/29/2019 7/29/2019 1.75 MIRU MOVE RURD P P/U 10 3/4" casing handling 0.0 0.0 13:00 14:45 equipment and hanger. Perform dummy run. Tagged load shoulder @ 39.93'. On hi -line power @ 14:00 Hrs. Test secondary injection line and mud lines T/ 5000 PSI for 5 Min - Good test. 7/29/2019 7/29/2019 0.75 MIRU MOVE SFTY P Hold Pre -spud meeting. 0.0 0.0 14:45 15:30 7/29/2019 7/29/2019 1.00 MIRU MOVE BHAH P RIH with clean out BHA, Bit, Motor, 0.0 0.0 15:30 16:30 and stabilizer. 7/29/2019 7/29/2019 1.50 MIRU MOVE CIRC P Fill riser and check for leaks. 0.0 0.0 16:30 18:00 Charge pump would not turn on in auto. Loose connection causing charge pump to operate in auto. Repaired problem. 7/29/2019 7/29/2019 1.00 MIRU MOVE DRLG P Clean out conductor. Drill out 20" 0.0 133.0 18:00 19:00 conductor with 13 % bit F/ ground level T/ 133' MD r@ 447 GPM. 375 PSI. 18% F/O 40 RPM 1.8K Tq. 5K WOB Page 111116 ReportPrinted: 911212019 Operations Summary (with Timelog Depths) h 3R-112 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time Entl Time Cur (hr) Phase Op Code Activity Code Time P -T -X Operation (W[3) End Doidh(MB) 7/29/2019 7/29/2019 2.00 MIRU MOVE BHAH P M/U BHA#1 133.0 133.0 1900 21:00 7/29/2019 7/29/2019 0.50 MIRU MOVE DRLG P Clean out contluctor. Drill out 20" 133.0 173.0 21:00 21:30 conductor with 13 % bit F/133' T/ 173' MD @ 440 GPM. 512 PSI, 18% F/O 40 RPM 3K Tq. 8K WOB 7/29/2019 7/30/2019 2.50 SURFAC DRILL DDRL P Directionaly Drill 13 112" surface hole 173.0 304.0 21:30 00:00 F/ 173' T/ 304' @ 475 GPM, 718 PSI, 20% F/O, 40 RPM, 3K Tq, 15K WOB, P/U=70K, S/0=75K, ROT=71 K. Off bottom 605 PSI, 1 K Tq 7/30/2019 7/30/2019 1.00 SURFAC DRILL DDRL P Drill 13 1/2" Surface Hole F/304'- TI 304.0 402.0 00.00 01:00 402'@ 475 GPM, 718 PSI, 20% F/O, 40 RPM, 3K Tq, 15K WOB, P/U=70K, S/0=75K, ROT=71 K. Off bottom 605 PSI, 1KTq. 7/30/2019 7/30/2019 1.00 SURFAC DRILL OTHR T Flow line returns packed off, Jet flow 402.0 402.0 01:00 02:00 line clear. 7/30/2019 7/30/2019 4.00 SURFAC DRILL DDRL P Drill 13 1/2" Surface Hole F/402' -T/ 402.0 687.0 0200 06:00 687'@ 500 GPM, 837 PSI, 20% F/0, 40 RPM, 2K Tq, 15K WOB, P/U=83K, S/0=79K, ROT=83K. Off bottom 765 PSI, 1KTq. 7/30/2019 7/30/2019r2.25 SURFAC DRILL DDRL P Drill 13 1/2" Surface Hole F/68T - T/ 687.0 782.0 0600 06:30 782' @ 500 GPM, 900 PSI, 22°% F/O, 40 RPM, 2K Tq, 17K WOB, P/U=83K, S/0=79K, ROT=83K. Off bottom 765 PSI, 1 K Tq. 7/30/2019 7/30/2019 SURFAC DRILL DDRL T Observed 14 bbl loss. Troubleshoot 782.0 593.0 0630 08:45 where mud is going. Pull out of the hole F/780'- T/593' MD. Circ @ 500 gpm 722 psi. After investigating, found that the flow box was packed off. Jetted flow line and open inspection hatches after jetting flow line. All clear. (14 bbl was not down hole losses) 7/30/2019 7/30/2019 0.25 SURFAC DRILL TRIP T RIH on elevators F/593'-T/780MD 593.0 782.0 0845 09:00 S/0 WT=88k 7/30/2019 7/30/2019 3.00 SURFAC DRILL DDRL P Drill 13 1/2" Surface Hole F/782'- T/ 782.0 1,002.0 0900 12:00 1002' MD @ 550 GPM, 1058 PSI, 22% F/O, 40 RPM, 4K Tq, 22K WOB, P/U=88K, S/0=86K, ROT=87K. Off bottom 930 PSI, 2K Tq. 7/30/2019 7/30/2019 4.50 SURFAC DRILL DDRL P Drill 13 112" Surface Hole F/1002' -T/ 1,002.0 1,255.0 12:00 16:30 1255' MD @ 550 GPM, 1058 PSI, 22% F/0, 40 RPM, 4K Tq, 22K WOB, P/U=88K, S/0=86K, ROT=87K. Off bottom 930 PSI, 2K Tq. 7/30/2019 7/30/2019 1.50 SURFAC DRILL BKRM T BROOH F/1254'-T/1006'MD 1,254.0 1,066.0 16:30 18:00 working through 6 deg DL @ 550 GPM 920 psi. 22% F/O 60 RPM . Orient high side of the hole, RIH F/1066 - T/116' MD @ 84 gpm, 143 psi. BROOH F/1161' - T/1066' MD @ 550 GPM, 920 psi. 22% F/O 60 RPM 7/30/2019 7/30/2019 1.75 SURFAC DRILL WASH T Orient high side of the hole, Wash 1,066.0 1,255.0 1800 19:45 F/1066' - T/1255' MD @ 83 GPM, 124 psi. 94k S/O 7/30/2019 7/31/2019 4.25 SURFAC DRILL DDRL P Drill 13 1/2" Surface Hole F/12,55' - 1,255.0 1,540.0 19:45 00:00 T/1,540' @ 550 GPM, 1160 PSI, 23% F/O, 40 RPM, 4K Tq, 20K WOB, P/U=100K, S/0=93K, ROT=97K. Off bottom 996 PSI, 2K Tq, Page 2116 Report Printed: 911 212 01 9 Operations Summary (with Timelog Depths) 3R-112 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Stan Time End Time Dur (m) Phase Op Code Ac Vfty Code- Time P -T -X Operation (ftKB) End DepN (ftKB) 7/31/2019 7131/2019 6.00 SURFAC DRILL DDRL P Drill 13 1/2" Surface Hole F/1,540' - 1,540.0 2,081.0 0000 06:00 T/2,081' MD 1979' TVD @ 550 GPM, 1066 PSI, 22% F/O, 40 RPM, 6K Tq, 20K WOB, P/U=110K, S/0=99K, ROT=105K. Off bottom 926 PSI, 3K Tq. 7/31/2019 7/31/2019 4.50 SURFAC DRILL DDRL P Drill 13 1/2" Surface Hole F/2,08 r - 2,081.0 2,406.0 06:00 10:30 T/2,406' MD @ 550 GPM, 1147 PSI, 22% F/Q, 40 RPM, 8K Tq, 35K WOB, P/U=120K, S/0=101 K, ROT=109K. Off bottom 998 PSI, 3K Tq. 7/31/2019 7/31/2019 2.00 SURFAC CASING BKRM P Backream stand # 20 and a single. 2.406.0 2,406.0 10:30 12:30 BROOH FI2,406'-T/2,323'MD@ 650 GPM 1545 psi. 25% F/O, 60 rpm 7k Tq. Hole packing off. Wash dawn from 2,323' to 2,406'@400 gpm 706 psi. 40 rpm. Obtain final torque and drag. Lay down single. 7/31/2019 7/31/2019 4.50 SURFAC CASING BKRM P BROOH F/2,323'-T/1,824'MID@ 2,406.0 1,824.0 12:30 17:00 650 GPM 1422 psi. 25% FIO, 60 rpm 5k Tq. 7/31/2019 7/31/2019 1.00 SURFAC CASING TRIP P POOH on elevators F/1,824'-1,259' 1,824.0 1,259.0 17:00 18:00 MD P/U 112k S/O 92k. Observed 20 k over pull, dropped down and wiped up through with no over pull. 7/31/2019 7131/2019 2.00 SURFAC CASING TRIP P Continue POOH on elevators 1-11,259' 1,259.0 501.0 18:00 20:00 -T/501'MD 7/31/2019 8/1/2019 4.00 SURFAC CASING BHAH P UD BHA #1 from 501'-to313' 501.0 313.0 20:00 00:00 8/112019 8/1/2019 0.75 SURFAC CASING BHAH P Continue L/D BHA F/313' MD. Clean & 313.0 0.0 00:00 00:45 clear off rig floor 8/1/2019 8/1/2019 1.75 SURFAC CASING RURD P Rig up casing equipment. Test Volant 0.0 0.0 00:45 02:30 CRT, 8/1/2019 8/1/2019 6.25 SURFAC CASING PUTB P RIH with 10'/. "HYD. 563, L-80, 45.5# 0.0 1,119.0 02:30 08:45 T 1,119' MD (JT. #28) S/0= 60k Monitor displacement. Fill on the fly, Tap off every 5 jnts. 8/1/2019 8/1/2019 1.00 SURFAC CASING CIRC P Clrc. & Condition Mud, reciprocating 1,119.0 1,160.0 08:45 09:45 F/ 1,119'-T/1,160' MD, Stage pumps up to 7.5 BPM, P/U= 106k S10= 73k. Total 1255 strokes pumped. 8/1/2019 8/1/2019 3.50 SURFAC CASING PUTB P RIH with 10'/. "HYD. 563, L-80,45.5# 1,160.0 1,874.0 09:45 13:15 F/1,160' -T/1,874' MD (JT. #40) S/0= 84k Monitor displacement. Fill on the fly, top off every 5 jnts. 8/1/2019 8/1/2019 1.25 SURFAC CASING CIRC P Circ. &Condition Mud, reciprocating 1,874.0 1,954.0 13:15 14:30 F/ 1,874'-T/1,954' MD, Stage pumps up to 8 BPM, P/U= 141k S/0= 87k. Total 3270 strokes pumped. 8/1/2019 8/1/2019 2.00 SURFAC CASING PUTB P RIH with 10 %"HYD. 563, L-80,45,5# 1,954.0 2,356.0 1430 16:30 F/1,954'- T12,356' MD S/0= 92k Monitor displacement. Fill on the fly, top off every 5 jnts. Make up Dopeless connection to 19,400 FT/LBS Doped connection to 16,200 FT/LBS. 8/1/2019 8/1/2019 1.00 SURFAC CASING PUTB P Make up Hanger to landing jnt. 2,356.0 2,356.0 16:30 17:30 8/1/2019 8/1/2019 1.00 SURFAC CEMENT PUTB P Observed 20k loss in hook load @ 2,356.0 2,400.O 17:30 18:30 2,370' MD Work pipe free and landed the hanger. 8/1/2019 8/1/2019 2.00 SURFAC CEMENT CIRC P Circ. and condition mud for Cement 2,4000 2,400.0 18:30 20:30 Job. Easing rate up to 9 bpm.377 psi. 16% F/O reciprocating pipe 18'to 20' Page 3/16 Report Printed: 9/1212019 Operations Summary (with Timelog Depths) 3R-112 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time End Time Our (hr) Phase Op Cafe Activity Code Time P -T -X Operation (WB) End Depth MKB) 8/1/2019 811/2019 0.50 SURFAC CEMENT CMNT P PJSM on cement job 2,400.0 2,400.0 20:30 21:00 8/1/2019 8/2/2019 3.00 SURFAC CEMENT CMNT P Line up & SLB pump 5 bbls CW 100. 2,400.0 2,391.0 21:00 00:00 Pressure test lines to 3500 psi, good. Pump 40.7 bbls of CW 100 @ 4.5 bpm, 246 psi, FO 8%. Batch up and pump 79.4 bbls of 10.5 ppg MP II @ 4.5 bpm, 175 psi, drop bottom plug & start batching lead. Pump 445.5 bbls of 11.0 ppg lead cement at 6.2 bpm, 449 psi, FO 12%. Land bottom plug at 220 bbls pumped. While reciprocating, the casing string took weight 9' off the landing ring. Attempted to work pipe free with no success. (At the time the string took weight 89bbl. of Lead cement had passed the shoe) 11.0 ppg Lead cement to surface 443bbl pumped. 8/2/2019 8/2/2019 2.00 SURFAC CEMENT CMNT P Continue working pipe while Tail was 2,391.0 2,391.0 00:00 02:00 being batched up. Pump 63.4 bbls of 12 ppg tail cement @ 2-6 bpm, 510 psi, FO 11%. Drop top plug & kick out With 10.3 bbls of fresh H2O. Swap to rig & displace w/ 9.5 ppg spud mud @ 70 bpm, 487 psi, FO 11%. Reduced rate to 2bpm. Bump plug with 2106 strokes, Pressure up from 275 psi. to 795 psi. & hold for 5 minutes. Bleed off pressure, Check Floats (good). CIP 02:00 hrs 08/02/19. 287 bbl. 11 ppg cement to surface. 8/2/2019 8/2/2019 1.00 SURFAC CEMENT RURD P Rig down cement lines, drain stack, 2,391.0 2,391.0 02:00 03:00 empty cellar box, blow down surface lines. Clean and clear dg floor. 812/2019 8/2/2019 1.75 SURFAC CEMENT RURD T Prep. to set emergency slips. 2,391.0 2,391.0 03:00 04:45 8/2/2019 8/2/2019 1.25 SURFAC CEMENT RURD T Lift surface riser with vetco speed 2,391.0 2,391.0 04:45 06:00 head. Landing ring stuck in vetco speed head. 8/2/2019 8/2/2019 2.00 SURFAC CEMENT RURD T Continue working to free up landing 2,391.0 2,391.0 06:00 08:00 ring from Vetco speed head. SIMOPS: mix and fill conductor with 36 gal of 17ppg SLB Cement. 8/2/2019 8/2/2019 2.75 SURFAC CEMENT RURD T Perp landing ring/CSG, pick up 143k 2,391.0 2,391.0 08:00 10:45 Tention (100k in string, Set slips @ 09:00 hrs. Cut joint at desired hight, Per Vetco Rep. 8/2/2019 8/2/2019 3.25 SURFAC CEMENT NUND P Rig down remaining casing 2,391.0 2,391.0 10:45 14:00 equipment, 8/2/2019 8/2/2019 5.00 SURFAC CEMENT NUND T Prep. casing stump, Install and weld 2,391.0 2,391.0 14:00 19:00 GENetco starter ring. and heat to 650° and wrapped in insulation for cooling process. 8/2/2019 8/3/2019 5.00 SURFAC CEMENT NUND T Wait on Vetco/GE Starting Head cool 2,391.0 2,391.0 19:00 00:00 down to 100 deg. Crew work on cleaning Pits, and processing 7 5/8 casing 8/3/2019 8/3/2019 9.00 SURFAC CEMENT WAIT T Wait for Vetco/GE Starting ring to cool 2,391.0 2,391.0 00:00 09:00 down to 100 Deg. SIMOPS: Strap, Tally & Drift 7 5/8 casing (Starting Ring Temp 205 deg.) 8/3/2019 8/3/2019 0.50 SURFAC CEMENT WAIT T Test socket weld on starting ring to 2,391.0 2,391.0 09:00 09:30 1 2000 psi. for 10 min. (Good Test) Page 4/16 Report Printed: 9/12/2019 Operations Summary (with Timelog Depths) 3R-112 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depth Start Time End Time Dur (hr) Phase Op code Ac ivnty Code Time P -T -X Operston W13) End Depth (OKB) 8/3/2019 813/2019 1.50 SURFAC WHDBOP NUND P Install thread ring to starting ring and 2,391.0 2,391.0 09:30 11:00 orient as per plan 8/3/2019 813/2019 0.75 SURFAC WHDBOP PRTS P Test well head seal ring to 2000 psi. 2,391.0 2,391.0 11:00 11:45 hold for 10 min. (Good Test) 8/3/2019 8/3/2019 5.25 SURFAC WHDBOP NUND P Make up adaptor spool to well head. 2,391.0 2,391.0 11:45 17:00 Nipple up BOP with 7 5/8 solid body rams in the top, 3 112 x 6" in the bottom, make up choke and kill line. Install riser to BOP. Record RKB's. Change out Pop off on Koomey. 8/3/2019 813/2019 0.50 SURFAC WHDBOP CLEN P Clean and Clear Rig floor, and cellar. 2,391.0 2,391.0 17:00 17:30 8/3/2019 8/3/2019 0.50 SURFAC WHDBOP RURD P Rig up to test BOPE. 2,391.0 2,391.0 17:30 18:00 8/312019 8/4/2019 6.00 SURFAC WHDBOP BOPE P Perform Initial BOPE test. Al tests at 2,391.0 2,391.0 18:00 00:00 250/3500 psi. Test with 7 5/8", 5" and 4" test joints. Test annular prevenler with 7 5/8" & 4" test joint. Test upper pipe rams with 7 5/8 test joint. Test the Lower pipe rams with 4" Test joint. Test choke valves #1 to #14, upper and lower top drive IBOP's, test & 5" dart and TIW valves, test rig floor, mezzanine, HCR and manual kill valves, test HCR and manual choke valves, hydraulic and manual chokes to 1500 psi and demonstrate bleed off. Perform accumulator lest. Starting pressure=3000 psi, after function= 1700 psi, 200 psi attained=7 sec's, full recovery=64 sec. 6 nitrogen bottles at 2031 psi. Test gas alarms, PVT and flow show. Test was waived to witnessed by AOGCC Rep. Adam Earl. 8/4/2019 8/4/2019 0.75 SURFAC WHDBOP BOPE P Continue Testing ROPE, blind rams 2,391.0 2,391.0 00:00 00:45 250/3500, Test 4" FOSV, 5" test joint LPR's. Attempt to lest 4" Dart valve but failed 8/4/2019 8/4/2019 1.25 SURFAC WHDBOP RURD P Rig down testing equipment, install 2,391.0 2,391.0 00:45 02:00 12.375" wear ring. 8142019 814/2019 1.00 SURFAC DRILLOUT PULD P Pick up BHA tools to the rig floor 2,391.0 2,391.0 02:00 03:00 8/4/2019 8/4/2019 2.25 SURFAC DRILLOUT SHAH P Make up 9.875 Dill Assembly, RIH to 2,391.0 402.0 03:00 05:15 402' MD 8/4/2019 8/4/2019 2.50 SURFAC DRILLOUT TRIP P RIH with up 9.875 Dilling Assembly 402.0 1,850.0 05:15 07:45 F/402 -T/1,850' MD P/U WT=' S/O WT=90k 8/4/2019 8/4/2019 0.75 SURFAC DRILLOUT ROPE P Rig up and Test 4" Dart valve 250 low 1,850.0 1,850.0 07:45 08:30 j 3500 high 8/4/2019 8142019 1.00 SURFAC DRILLOUT SFTY P PJSM on Casing Test, Safety Stand 1,850.0 1,850.0 08:30 09:30 Down 8/412019 8/412019 0.50 SURFAC DRILLOUT TRIP P Continue RIH with up 9.875 Dilling 1,850.0 2,200.0 09:30 10:00 Assembly F/1,850'- 2,200' MD 8/412019 8/412019 1.25 SURFAC DRILLOUT CIRC P Circ. and condition mud while rotating 2,200.0 2,100.0 10:00 11:15 & reciprocating F/ 2,200' — 2,100' MD P/U WT= 108k SIO WT=90k ROT WT=104 8/4/2019 8/4/2019 0.25 SURFAC DRILLOUT RURD P Rig up to test 10.75 casing. 2,100.0 2,200.0 11:15 11:30 8/4/2019 8/4/2019 0.75 SURFAC DRILLOUT PRTS P Test 10.75 casing to 3000 psi. hold for 2,200.0 2,200.0 11:30 12:15 30 min. (Good Test) 8/4/2019 8/4/2019 0.50 SURFAC DRILLOUT RURD P Rig down and Blow down test 2,200.0 2,200.0 12:15 12:45 equipment. Page 5116 Report Printed: 9/12/2019 Operations Summary (with Timelog Depths) 3R-112 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Ac fty Code Time P -T -X Operation Start Depfh (ftKB) End Depth (f KB) 8/4/2019 8/412019 0.50 SURFAC DRILLOUT TRIP P RIH with up 9.875 Dilling Assembly 2,200.0 2,295.0 12:45 13:15 F/2,200 - T/2,295' MD P/U WT=108k 8/0 WT=90k Tagged up @ 2,295 8/4/2019 8/4/2019 4.00 SURFAC DRILLOUT COCF P Drill cement, Plugs and 20' of new 2,295.0 2,426.0 13:15 17:15 hole. F/2,295 - T/2,426' MD @ 400- 650 GPM 598-1318 psi. 12/23% Flo 40-60 rpm 8-17 WOB P/U WT=108k SIO WT =90 ROT WT =105k 8/4/2019 8/4/2019 0.75 SURFAC DRILLOUT CIRC P Circ. and condition mud while rotating 2,426.0 2,426.0 17:15 18:00 & reciprocating F/ 2,426'— 2,388' MD P/U WT= 108k S/O WT=90k ROT WT=104 work through shoe X2 8/4/2019 8/4/2019 2.75 SURFAC DRILLOUT FIT P R/U and preform a FIT/LOT, Pumped 2,426.0 2,426.0 18:00 20:45 7 strk. @ 3bpm down drill string and O/A 250 psi was achieved = 11.7 EMW 8/4/2019 8/4/2019 1.25 INTRMI DRILL DDRL P 06119 7/8" Surface Hole F/2,426" - T/ 2,426.0 2,481.0 20:45 22:00 2,481' @ 648 GPM, 1305 PSI, 22% F/O, 80 RPM, 51K Tq, 1 K WOB, SPR'S @ 2,481' MD, 2,276' TVD MW - 9.2 PPG, HRS -22:00 MP #1) 20 SPM- 80 PSI, 30 SPM- 100 PSI MP #2) 20 SPM- 75 PSI, 30 SPM- 100 PSI 8/4/2019 8/5/2019 2.00 INTRMI DRILL DDRL P Drill 9 7/8" Surface Hole F/2,481 T/ 2,481.0 2,670.0 22:00 00:00 2,670' @ 648 GPM, 1305 PSI, 22% F/O, 80 RPM, 5K Tq, 5K WOB, ECD's =9.93, P/U=118K, S/0=97K, ROT=103K. Off bottom 930 PSI, 2K Tq. 8/5/2019 8/512019 3.00 INTRMI DRILL DDRL P Drill 9-718" Hole F/2,670'- T/ 2,983'@ 2,670.0 2,983.0 00:00 03:00 648 GPM, 988 PSI, 21 % F/0, 80 RPM, 6K Tq, 41K WOB, Off bottom psi. 987 5k Tq. ECD's =9.93, P/U=129K, S/0=100K, ROT=107K. 8/512019 8/5/2019 2.50 INTRMI DRILL BKRM T Pumped out of the hole F/ 2,983'- 2,983.0 2,696.0 03:00 05:30 T/2,766' BROOH F/2,766' -T]2,696' attempt to knock down dog legs with NO success. @ 648 GPM, 988 PSI, 21% F/O, 80 RPM, 61K Tq, P/U=129K, S/O=100K, ROT=107K. 8/5/2019 8/5/2019 1.25 INTRMI DRILL WASH T Wash to bottom F/2,696' -T/2,983'@ 2,696.0 2,983.0 05:30 06:45 648 GPM, 988 PSI, 21 % F/O, 80 RPM, 6K Tq, P/U=129K, S/0=100K, ROT=107K. 8/5/2019 8/5/2019 5.25 INTRMI DRILL DDRL P Drill 9-7/8" Hole F/2,983' -T/ 3,711' @ 2,983.0 3,711.0 06:45 12:00 648 GPM, 1082 PSI, 21% F/O, 80 RPM, 5K Tq, 41K WOB, Off bottom psi. 1080 5k Tq. ECD's =10.05, P/U=137K, S/0=104K, ROT=115K. (Pump weighted sweeps every 500') SPR'S @ 3,712' MD, 3,028' TVD MW - 9.1+ PPG, HRS -11:45 MID #1) 20 SPM- 140 PSI, 30 SPM - 170 PSI MP #2) 20 SPM- 140 PSI, 30 SPM - 160 PSI Page 6/16 Report Printed: 9/12/2019 Operations Summary (with Timelog Depths) 3R-112 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Ad ity Code Time P -T -X Operadoo(NKS) End DepN(N(B) 8/5/2019 8/5/2019 6.00 INTRM1 DRILL DDRL P Drill 9-7/8" Hole F/3,711, - T/ 4,477' 3,711.0 4,477.0 12:00 18:00 MD @ 648 GPM, 1266 PSI, 21% F/O, 80 RPM, 10K Tq, 4K WOB, OR bottom psi. 1260 5k Tq. ECD's =10.15, P/U=154K, S/0=93K, ROT=115K. (Pump weighted sweeps every 500') Max gas =30 units. Brought Lubes up to 1% 8-5/2019 8/6/2019 6.00 INTRM1 DRILL DDRL P Drill 9-7/8" Hole F/4,477' -T/5,155' 4,477.0 5,155.0 18:00 00:00 MD @ 648 GPM, 1306 PSI, 21 % F -O, 80 RPM, IOK Tq, 8K WOB, OH bottom psi. 1300 5k Tq. ECD's =10.33, P-U=135K, S10=110K, ROT=118K. (Pump weighted sweeps every 500') Max gas =213 units SPR'S @ 4,852' MD, 3,442' TVD MW - 9.2 PPG, HRS -21:00 MP #1) 20 SPM- 160 PSI, 30 SPM - 180 PSI MP #2) 20 SPM- 140 PSI, 30 SPM - 180 PSI 8/6/2019 8/6/2019 6.00 INTRMI DRILL DDRL P Drill 9-7/8" Hole Fly, 155'-T/5,616' 5,155.0 5,616.0 00:00 06:00 MD @ 650 GPM, 1398 PSI, 21 % F -O, 120 RPM, 10K Tq, 15K WOB, Off bottom psi. 1300 5k Tq. ECD's =10.29, P-U=136K, S/O=110K, ROT=120K. (Pump weighted sweeps every 500') Max gas =314 units 8/6/2019 8/6/2019 6.00 INTRM1 DRILL DDRL P Drill 9-7/8" Hole F/5,616' -T/6,270' 5,616.0 6,207.0 0600 12:00 MD @ 650 GPM, 1506 PSI, 21% F/O, 120 RPM, IOK Tq, 8K WOB, Off bottom psi. 1495 5k Tq. ECD's =10.49, P/U=145K, S10=110K, ROT=120K. (Pump weighted sweeps every 500') Max gas =314 units SPR'S @ 5,702' MD, 3,548' TVD MW - 9.2 PPG, HRS -06:00 MP #1) 20 SPM- 200 PSI, 30 SPM - 240 PSI MP #2) 20 SPM- 200 PSI, 30 SPM - 240 PSI 8/6/2019 8/6/2019 1.25 INTRM1 DRILL DDRL P Drill 9-7/8" Hole F/6,270' -T/6,390' 6,207.0 6,390.0 12:00 13:15 MD @ 650 GPM, 1544 PSI, 21% NO, 125 RPM, 9K Tq, 10K WOB, Off bottom psi. 1524, 5k Tq. ECD's =10.68, PIU=145K, S/0=110K, ROT=120K. Max gas =314 units SPR'S @ 6360' MD, 3,642' TVD MW - 9.2 PPG, HRS -12:50 MP #1) 20 SPM- 210 PSI, 30 SPM - 250 PSI MP #2) 20 SPM- 220 PSI, 30 SPM - 260 PSI 2019 1.00 INTRM1 CASING CIRC P Pump a Low -High vis sweep. Circ. 6,390.0 6,230.0 15 hole clean while BROOH F/6,390 — T/6,230' @ 650 gpm 1544 psi. 21% F/O 140 rpm 7K Tq. /2019 0.25 INTRMI CASING OWFF P Monitor Well (Static) 6,230.0 6,230.030/2019 K8/6/20198/6/2019 3.50 INTRM1 CASING BKRM P BROOH, Lay down drill pipe in the 6,230.0 5,324.0 00 mousehole F/6,230 -T/5,324' MD @ 646 gpm, 1400 psi. 125rpm.7 Tq. 10.5 ppg ECD Page 7116 Report Printed: 9/1 212 01 9 Operations Summary (with Timelog Depths) 3R-112 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sian Depth Stan Time End Time Dur (hr) Phase Op Code Addy Code Time P -T -X Operation (aKB) End Depth (RKB) 8/6/2019 8/7/2019 6.00 INTRMI CASING BKRM P BROOH, Lay down drill pipe in the 5,324.0 3,185.0 18:00 00:00 mousehole-F/5,324'-T/3,185'MD@ 646 gpm,1400 psi. 125 rpm.7 Tq. ECD =10.5 ppg 8/7/2019 817/2019 2.25 INTRMI CASING BKRM P Continue BROOH, Lay down drill pipe 3,185.0 2,392.0 00:00 02:15 in the mousehole-F/3,185'-T/2,392' MD @ 646 gpm,1400 psi. 125 rpm.7 Tq. ECD =10.3 817/2019 8/7/2019 1.26 INTRMI CASING CIRC P Circ. Low/High sweep @ 10.314 shoe 2,392.0 2,392.0 02:15 03:30 @ 650 gpm 40 rpm. ( sweep brough back 75% more cuttings) 8/712019 8/712019 0.25 INTRMI CASING OWFF P Monitor well for flow (Static) 2,392.0 2,392.0 03:30 03:45 8/712019 8/712019 3.00 INTRMI CASING PULD P POOH on elevators F/2,392' -T/ 2,392.0 427.0 03:45 06:45 427' (No Problems) 8/7/2019 8/7/2019 2.00 INTRMI CASING BHAH P Lay down BHA: HWDP, Jars, NMDC, 427.0 0.0 06:45 08:45 Stabilizers, MWD and Power Drive. 817/2019 617/2019 1.25 INTRMI CASING RURD P Rig up BOP wash up tool & wash 0.0 0.0 08:45 10:00 BOPE. Clean and Gear dg floor. 8/712019 8/7/2019 1.25 INTRMI CASING RURD P Drain ROPE, and pull wear bushing, 0.0 0.0 10:00 11:15 UD 3 jnts of 5" DP. 8/7/2019 817/2019 1.50 INTRMI CASING RURD P Rig up to run 7 518 rasing 0.0 0.0 11:15 12:45 8/7/2019 8/7/2019 0.50 INTRM1 CASING SVRG P Service Lay down machine and casing 0.0 0.0 12:45 13:15 Hyd. Unit 8/7/2019 8/7/2019 4.75 INTRMI CASING PUTB P Run 7 5/8" 29.7ppf. L-80 HYD 563 0.0 2,392.0 13:15 18:00 casing F/ Surface - T/ 2,341' MD. Make up connections to 10,300 ft/lbs. with power tongs. Fill on the fly, Top off casing up every 10 jnts. 8/7/2019 817/2019 0.50 INTRMI CASING CIRC P Circ. bottoms up, staging rate up to 8 2,392.0 2,350.0 18:00 18:30 bpm 193 psi. P/U WT= 104k Recp. pipe F/ 2,392'- T/ 2.350 8/7/2019 8/8/2019 5.50 INTRMI CASING PUTB P Run 7 5/8" 29.7ppf. L-80 HYD 563 2,350.0 4,904.0 18:30 00:00 rasing F/ 2,350' - T/4,904' MD. Make up connection 10,300 ft/lbs. with power tongs. Fill on the fly, Tap off casing up every 10 jnts. 81812019 8/812019 1.00 INTRMI CASING CIRC P Circ. bottoms up, staging rate up to 6 4,904.0 4,904.0 00:00 01:00 bpm 276 psi. P/U WT= 104k Reciprocate. pipe F/ 4,904'- 714,858' 8/8/2019 8/8/2019 2.00 INTRMI CASING PUTS P Run 7 5/8" 29.7ppf. L-80 HYD 563 4,904.0 6,348.0 01:00 03:00 casing F/ 4,904'-T/6,384' MD. Make up connection 10,300 ft/Ibs. with power tongs. Fill on the fly, Top off casing up every 10 jnts. P/U = 155k SIO = 108k 818/2019 8/8/2019 0.50 INTRMI CASING HOSO P Make up GE/Vetco Hanger to landing 6,348.0 6,348.0 03:00 03:30 1 joint. 8/8/2019 8/8/2019 2.00 INTRMI CEMENT CIRC P Break circ. @ 2bpm, 266 psi. 2% F/O, 6,348.0 6,384.0 03:30 05:30 and wash casing down to 6,384' and land, Circ. bottoms up, staging rale up Po 8 bpm 395 psi. 10% F/O 8/8/2019 8/8/2019 0.50 INTRMI CEMENT RURD P Blow down Top Drive & R/U cemnet 6,384.0 6,364.0 05:30 06:00 line 8/8/2019 8/8/2019 1.50 INTRMI CEMENT CIRC P Establish circ. with cement line, 6,384.0 6,364.0 06:00 0730 staging rate up to 8 bpm 395 psi. 10% F/0 reciprocate casing from 6,384-T/ 6,364' P/U 158k SIO =101k . Circ until Mud engineer mud rheology is good for cement job. Page 8116 Report Printed: 9/12/2019 Operations Summary (with Timelog Depths) 3R-112 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sun Depth Sten Time End Time our (hr) phase DP Code Acbviity Cade Tune P -T -X Dperadon (fIKB) End Depth (ftKB) 8/6/2019 818/2019 2.75 INTRMI CEMENT CMNT P Load 1st bottom plug. Pump 5 bbls 6,364.0 6,384.0 07:30 10:15 Mud Push. Test lines to 4000 psi. Pump 46.8 bbls of 13.5 ppg Mud Push II, 3 bpm, 260 psi -160, 2-3% Flow out. Load 2nd bottom plug. Batch up and pump 149 bbls 15.8 ppg Class G cement - pump rate 6 bpm, 296 psi, 7% Flow out. Load top plug. Schlumberger pump 10.0 bbls water. Swap to dg and displace with 9.2 ppg. 289.6 bbl. LSND. @ 8 bpm. 115/909 psi. 21% flow out. Stop reciprocating and landed hanger @ 2100 strokes. Slowed to 3 bpm, 909 psi. bump plug @ 2756 strokes. Pressure up to 1700 psi and hold for 5 mins. CIP at 09:46 hm. Checked floats (good). 8/8/2019 8/8/2019 1.25 INTRMI CEMENT RURD P Rig down crt tool and clean rig floor , 6,384.0 6,384.0 10:15 11:30 j j drain slack- lay down landing joint. 8/8/2019 8/8/2019 1.50 INTRMI CEMENT WWSP P Rig up and Install Pack -off, Test 6,384.0 6,384.5- 11:30 13:00 T/5000 psi. hold for 10 mim. (good test) 8/8/2019 8/8/2019 0.50 INTRMI CEMENT UT -HR P Flush O/A with 7bbl. @ 400 psi. 6,384.0 0.0 13:00 13:30 8/8/2019 8/8/2019 0.50 INTRMI CEMENT TURD P Install wear ring an run in two lock 0.0 0.0 13:30 14:00 downs. Length= 15", ID=9" OD =13.32" 8/812019 8/8/2019 2.50 INTRMI CEMENT RURD P Change out saver sub to 4" XT39 0.0 0.0 14:00 16:30 Replace batteries on deep sub. 8/6/2019 8/8/2019 5.50 INTRMICEMENT PULD P Make up mule shoe and run in the 0.0 2,946.0 16:30 22:00 hole with 96 joints of 4" HWDP F/Surface - T/2,946' 8/8/2019 8/9/2019 2.00 INTRMI CEMENT TRIP P POOH with 32 standsof 4" HWDP, 2,946.0 0.0 22:00 00:00 rack back 32 stands in the derrinck 8/9/2019 8/9/2019 1.25 INTRMI CEMENT PULD P Load pipe shed with 4" Drill pipe, strap 0.0 0.0 00:00 01:15 and tally 8/9/2019 8/9/2019 1.25 INTRMI CEMENT PRTS P Rig up and test 7 5/8 casing to 3500 0.0 0.0 01:15 02:30 1 psi. hold for 30 min. (good test) 8/912019 8/9/2019 0.50 INTRMI DRILLOUT BHAH P Load Pipe shed with 6 3/4 BHA 0.0 0.0 02:30 03:00 8/9/2019 8/9/2019 2.50 INTRMI DRILLOUT BHAH P Make up 6 3/4 BHA F/ surface T/ 488' 0.0 488.0 03:00 05:30 8/9/2019 8/9/2019 2.25 INTRMI DRILLOUT PULD P Pick up 4" Drill pipe and RIH with 6 3/4 488.0 2,387.0 05:30 07:45 BHA Drilling assembly F/488 - T/ 2,387' MD 8/9/2019 8/9/2019 0.50 INTRMI DRILLOUT DHEQ P Shallow hole test MWD @ 2,387' MD 2,387.0 2,387.0 07:45 08:15 250 gpm, 1314 psi. 11 % F/O 8/9/2019 8/9/2019 1.00 INTRMI DRILLOUT QEVL P Mad Pass log F/2,387' -T/2,482' P/U 2,387.0 2,482.0 08:15 09:15 84k S/O 81k 8/9/2019 8/9/2019 0.50 INTRMI DRILLOUT SVRG P Service Top Drive, Crown and 2,482.0 2,482.0 09:15 09:45 Traveling blocks 8/9/2019 8/912019 6.25 INTRMI DRILLOUT QEVL P Continue Mad Pass log F/ 2,482'- T/ 2,482.0 6,080.0 09:45 16:00 6,080' @ 750' FPH SIMOPS: Freeze protect O/A pumped 140bbl. of H2O followed by 90 bbl. of diesel @ 1 bpm ICP = 610 psi. FCP = 750 8/9/2019 8/9/2019 1.25 INTRMI DRILLOUT CIRC P Break circulation @ 250 gpm 1490 6,080.0 6,080.0 16:00 17:15 psi., F/O = 16% cycle pumps for MWD and down link to put tool in memory saver mode. 81912019 8/9/2019 1.75 INTRMI DRILLOUT SLPC P Secure traveling blocks/Top Drive. Slip 6,080.0 6,080.0 17:15 19:00 1 I 8 Cut 60' of drilling line. Calibrate hook loadiblocks height. Page 9116 Report Printed: 911212019 operations Summary (with Timelog Depths) r 3R-112 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log stare Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P4 -X operation We) End Depth (fixe) 8/9/2019 8/9/2019 1.25 INTRMI DRILLOUT OEVL P Establish circulation, downlink to turn 6,080.0 6,225.0 19:00 20:15 MWD on @ 250 gpm 1490 psi. shut pumps down, Mad Pass log F/6,080'— T/ 6,225' MD PIU =129k S/O= 8/9/2019 8/9/2019 0.75 INTRMI DRILLOUT COCF P Tagged cement @ 6,325', wash down 6,225.0 6,252.0 20:15 21:00 to 6,252' MD @ 250 gpm 1553 psi. 40 16,352' rpm, 61k TO. I WOB, Tagged plugs at 8/9/2019 8/10/2019 3.00 INTRMI DRILLOUT DRLG P Drill Plugs and float equipment 6,252.0 6,281.0 21:00 00:00 F/5,252'- T/ 6,281' MD @ 250 gpm, 40 rpm, 1546 psi. TO. 8k 13k WOB 5%F/O 8/10/2019 8/10/2019 1.00 INTRMI DRILLOUT DRLG P Drill Cement F/6,281'-T/6,372'MD 6,281.0 6,372.0 00:00 01:00 250 GPM, 40 rpm, 1627 psi., 2k wob, 4k Tq. 5% Flo 8/10/2019 8/10/2019 0.50 INTRMI DRILLOUT SFTY P Safety Stand Up with all hands on the 6,372.0 6,372.0 01:00 01:30 rig 8/10/2019 8/10/2019 1.75 INTRMI DRILLOUT DRLG P Drill Cement F/6,372'- T/ 6,4.10' MD 6,372.0 6,410.0 01:30 03:15 250 GPM, 40 rpm, 1627 psi., 2k wob, 4k Tq. 5% F/O 8/10/2019 8/10/2019 0.75 INTRMI DRILLOUT CMNT P Circulate and condition mud for YF 6,410.0 6,380.0 03:15 04:00 200 gpm, 40 rpm 1158 psi. 7k Tq. Reciprocating pipe F/6,410'—T/6,380' MD 8/10/2019 8/10/2019r5.75 INTRMI DRILLOUT FIT P Pull back to the shoe. Rig up and 6,380.0 6,380.0 04:00 05:30 preform a F.I.T. 13.0 EMW 8/10/2019 8/10/2019 INTRMI DRILLOUT RURD P Rig down/Blow down test equipment. 6,380.0 6,380.0 05:30 06:00 8/10/2019 8/10/2019 PROD1 DRILL TRIP P Trip in the hole to 6,410' 6,380.0 6,410.0 06:00 06:15 8/10/2019 8/10/2019 PROD1 DRILL DDRL P Drill 6 % Production hale F/6,410'— T/ 6,410.0 6,741.0 06:15 12:00 6,741' MD 3,661'TVD Displace well on the fly to 9.2 ppg. Flo -Pro mud system. 266 gpm, 1637 psi. 9% FIO, 140 rpm, 6k Tq., 3 WOB, ECD= 10.37, off bottom = 1640 psi. 61k Tq. Max Gas= 378 units. SPR'S @ 6,560' MD, 3,655' TVD MW - 9.2 PPG, HRS -09:30 MP #1) 20 SPM- 295 PSI, 30 SPM - 440 PSI MP #2) 20 SPM -270 PSI, 30 SPM - 435 PSI 8/10/2019 8/10/2019 6.00 PROD1 DRILL DDRL P Drill 6 % Production hole F/6,741'— T/ 6,741.0 7,330.0 12:00 18:00 7,330' MD 3,665'TVD. 268 gpm, 1700 psi. 11 % F/O, 150 rpm, 7k Tq., 3 WOB, ECD= 10.35, off bottom = 1700 psi. 6k Tq. Max Gas= 688 units. PIU = 125k S/O= 74K, ROT= 97k 8/10/2019 8/11/2019 6.00 PROD1 DRILL DDRL P Drill 6 % Production hole F/7,330'—T/ 7,330.0 7,772.0 18:00 00:00 7,772' MD 3,665'TVD. 268 gpm, 1815 psi. 10% F/O, 150 rpm, 8k Tq., 1 WOB, ECD= 10.76, off bottom = 1810 psi. 7k Tq. Max Gas= 365 units. P/U = 131 k S/O= 70K, ROT= 95k SPR'S @ 7,705 MD, 3,655' TVD MW - 9.3 PPG, HRS -22:25 MP #1) 20 SPM- 380 PSI, 30 SPM - 560 PSI MP #2) 20 SPM -380 PSI, 30 SPM - 520 PSI Page 10/16 Report Printed: 9/12/2019 operations Summary (with Timelog Depths) 3R-112 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depth Start Time End Time our (hr) Phase Op Code Ac Wy Code Time P-T-X operatian (110) End Depth (aKB) 8/11/2019 8/11/2019 6.00 PROD1 DRILL DDRL P Drill 6 % "Hole F/ 7,772'— T/ 8,292' 7,772.0 8,292.0 00:00 06:00 MD, 3,608 TVD @ 268 gpm, 1874 psi. 10% NO, 150 rpm 8k Tq. 1 k WOB, ECD= 11.02, Off Bottom = 1862 psi. 7k Tq.Max Gas 238 units. 8/11/2019 8/11/2019 6.00 PROD1 DRILL DDRL P Drill 6%"Hole F/8,292'—T/8,746' 8,292.0 8,746.0 06:00 12:00 MD, 3,599 TVD @ 268 gpm, 2015 psi. 10% NO, 150 rpm 8k Tq. 1k WOB, ECD= 11.08, Off Bottom = 2015psi. 7k Tq. Max Gas 441 units P/U WT=133k SIO WT= 60k, ROT WT=93k 8/11/2019 8/11/2019 6.00 PROD1 DRILL DDRL P Drill 6 % "Hole F/ 8,746'—T/ 9,261' 8,746.0 9,216.0 12:00 18:00 MD, 3,597 TVD @ 368 gpm, 2135 psi. 10% F/O, 150 rpm 8k Tq. 1k WOB, ECD= 11.30, Off Bottom = 2141 psi. 7k Tq. Max Gas 398 units. P/U WT=134k S/O WT= 0 ROT WT=94k 8/11/2019 8/1212019 6.00 PROD1 DRILL DDRL P Drill 6e/."Hole F/9,261'—T/9,610' 9,216.0 9,610.0 1800 00:00 MD, 3,583 TVD @ 268 gpm, 2096 psi. 10% F/O, 150 rpm 9k Tq. 3k WOB, ECD= 11.21, Off Bottom = 2090psi. 7k Tq. Max Gas 484 units. P/U WT=134k S/O WT= N/A ROT WT=91 k SPR'S @ 9,405 MD, 3,586' TVD MW- 9.3 PPG, HRS-20:45 MP #1) 20 SPM- 540 PSI, 30 SPM- 720 PSI MP #2) 20 SPM-520 PSI, 30 SPM- 700 PSI 8/12/2019 8/12/2019 6.00 PROD? DRILL DDRL P Drill 63%"Hole F/9,261'—T/10,051' 9,610.0 10,051.0 00:00 06:00 MD, 3,587 TVD @ 268 gpm, 2163 psi. 10% FIO, 150 rpm 9k Tq. 3k WOB, ECD= 11.38, Off Bottom = 2163psi. 7k Tq. Max Gas 178 units. P/U WT=140k S/O WT= 54 ROT WT=93k 8/12/2019 8/12/2019 6.00 PROD1 DRILL DDRL P Drill 6 e/. "Hole F/ 10,051'—T/ 10,399' 10,051.0 10,399.0 06:00 12:00 MD, 3,573 TVD @ 268 gpm, 2155 psi. 10% NO, 150 rpm 9k Tq. 3k WOB, ECD= 11.43, Off Bottom = 2151 psi. 7k Tq. Max Gas 235 units. P/U WT=140k S/O WT= 54 ROT WT=93k SPITS @ 10,159 MD, 3,588' TVD MW - 9.3 PPG, HRS-07:15 MP #1) 20 SPM- 560 PSI, 30 SPM- 800 PSI MP #2) 20 SPM-540 PSI, 30 SPM- 760 PSI Page 11/16 ReportPrinted: 9/1212019 Operations Summary (with Timelog Depths) 3R-112 Rig: DOYON 142 Job: DRILLING ORIGINAL Tirna Lop Start Depth Stat Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operedon (fiKB) End Depth (WB) 8/12/2019 8/12/2019 6.00 PRODI DRILL DDRL P Drill 6'%"Hole F/10,399'—T/10,946' 10,399.0 10,946.0 12:00 18:00 MD, 3,561 TVD @ 269 gpm, 2218 psi. 10% F/O, 150 rpm 7k Tq. 2k WOB, ECD= 11.38, Off Bottom = 2215 psi. 6k Tq. Max Gas 856 units. SPR'S @ 10,987 MD, 3,561' TVD MW -9.3 PPG, HRS -06:00 MP #1) 20 SPM- 575 PSI, 30 SPM - 800 PSI MP #2) 20 SPM -570 PSI, 30 SPM - 830 PSI 8/12/2019 8/13/2019 6.00 PROD1 DRILL DDRL P Drill 6%"Hole F/10,946'—T/11,491' 10,946.0 11,491.0 18:00 00:00 MD, 3,561 TVD @ 265 gpm, 2572 psi. 10% F/O, 150 rpm 7k Tq. 1k WOB, ECD= 11.95, Off Bottom = 2564 psi. 6k Tq. Max Gas 968 units. P/U WT=141 k SIO WT= 68 ROT WT=104k 8/13/2019 8/13/2019 6.00 PRODI DRILL DDRL P Drill 6 %"Hole F/ 11491'T/ 11909' MD, 11,491.0 11,909.0 00:00 06:00 3529' TVD @ 268 GPM, 2631 PSI, 10% F/O, 150 RPM 81K Tq. 1 K WOB, ECD= 11.95, Max Gas 968. P/U=150K SIO= 64K, ROT=108K. Off Bottom 2626 PSI, 7K Tq. 8/13/2019 8/13/2019 6.00 PRODI DRILL DDRL P Drill 6 %"Hole F/ 11909'T/ 12278' 11,909.0 12,278.0 06:00 12:00 MD, 3520' TVD @ 268 GPM, 2460 PSI, 10% F/O, 150 RPM 8K Tq. 1 K WOB, ECD= 11.45, Max Gas 847. P/U=153K SIO= 74K, ROT=112K. Off Bottom 2458, PSI, 7K Tq. SPR'S @ 12001 MD, 3527' TVD MW - 9.3 PPG, HRS -09:30 MP #1) 20 SPM -620 PSI, 30 SPM -820 PSI MP #2) 20 SPM -605 PSI, 30 SPM -780 PSI 8/13/2019 8/13/2019 6.00 PRODI DRILL DDRL P Drill 6 %"Hole F/ 12278'T/ 12510' 12,278.0 12,510.0 12:00 18:00 MD, 3513' TVD @ 268 GPM, 2595 PSI, 10% F/0, 150 RPM 81K Tq. 1 K WOB, ECD= 11.64, Max Gas 226. P/U=153K S/0= 74K, ROT=112K. Off Bottom 2565, PSI, 7K Tq. 8/13/2019 8/13/2019 3.25 PROD1 DRILL DDRL P Drill 6 % "Hole F/ 12510' T/ 12697' 12,510.0 12,697.0 18:00 21:15 MD, 3502' TVD @ 268 GPM, 2581 PSI, 10% F/O, 150 RPM 81K Tq. 2K WOB, ECD= 11.63, Max Gas 187. PIU=157K S/0= 76K, ROT=114K. Off Bottom 2580, PSI, 7K Tq. 8/13/2019 8/13/2019 1.25 PROD1 CASING CIRC P Circulate BU @ 268 GPM, 2531 PSI, 12,697.0 12,649.0 21:15 22:30 10% F/O, IOORPM, 7K Tq, ECD=11.63, PIU=154K, S/0=63K (NO PUMPS) Rotate and reciprocate F/ 12697' T/ 12649' Top drive quit rotating. SPR'S @ 12698 MD, 3502' TVD MW - 9.3 PPG, HRS -22:05 MP #1) 20 SPM -560 PSI, 30 SPM -800 PSI MP #2) 20 SPM -540 PSI, 30 SPM -820 PSI Page 12/16 Report Printed: 9/12/2019 _ Operations Summary (with Timelog Depths) 3R-112 Rig: DOYON 142 Job: DRILLING ORIGINAL Time log Stan Depth Stan Time End Time Dur (hr) phase Op Code Activity Code Time P -T -x Operation (WB) End Depth (flKB) 8/13/2019 8/13/2019 0.50 PROD1 CASING SVRG P Inspect lop drive brakes. Grease 12,649.0 12,649.0 22:30 23:00 blocks, and wash pipe 8/13/2019 8/14/2019 1.00 PRODt CASING RGRP T Troubleshoot top drive. Pump @ 268 12,649.0 12,544.0 23:00 00:00 GPM, 2522 PSI. Pump OOH F/ 12649' T/ 12544'. P/U 154K, S/O 64K. Move pipe every 15 Min break over in each direction. 8/14/2019 8114/2019 9.50 PROD1 CASING RGRP T Troubleshoot top drive. Pump @268 12,544.0 12,544.0 00:00 09:30 GPM, 2500 PSI. P/U 151K, S/O 70K. Move pipe every 15 Min break over in each direction. 8/14/2019 8/1412019 12.00 PRODt CASING PMPO P Pump out of hole F/ 12544' T/ 6370'@ 12,544.0 6,370.0 09:30 21:30 268 GPM, 1820 PSI, 9% F/0, P/U 117K, S/O 71 K 8/14/2019 8114/2019 0.50 PROW CASING OWFF T Install TIW in string. Observe well for 6,370.0 6,370.0 21:30 22:00 flow- No flow 8/14/2019 8/15/2019 2.00 PROD1 CASING RGRP T Remove equipment from top drive to 6,370.0 6,370.0 22:00 00:00 allow for removal of traction motor 8/15/2019 8/15/2019 18.00 PROD? CASING RGRP T R/U scaffolding on rig floor. Remove 6,370.0 6,370.0 00:00 18:00 traction motor. Replace with rebuilt traction motor. Re -install components stripped off of top drive. R/D scaffolding. Test traction motor - Good test - top drive rotates. Monitor well via trip tank throughout operation - No loss / No gain 8/15/2019 8/15/2019 1.00 PROD1 CASING SVRG T Service blocks, wash pipe and install 6,370.0 6,370.0 18:00 19:00 Kelly hose. Inspect derrick and lop drive for potential dropped objects as per CPAI drilling supervisor. 8/1512019 8/15/2019 0.50 PROD1 CASING RGRP T Pressure lest Kelly hose T/ 3500 PSI - 6,370.0 6,370.0 19:00 19:30 Good test 8/15/2019 8/15/2019 2.00 PROD1 CASING CIRC T Pump low/hi vis sweep, circ STS plus 6,370.0 6,370.0 19:30 21:30 additional BU @ 265 GPM, 1746 PSI, 80 RPM, 3K Tq, Reciprocating pipe 90'. 10% additional cuttings at shaker as sweep exited hole. 8/15/2019 8/15/2019 0.50 PROD1 CASING OWFF T Observe well for flow - No flow. 6,370.0 6,370.0 21:30 22:00 B/D top drive. 8/15/2019 8/16/2019 2.00 PROD1 CASING TRIP P POOH F/ 6370' T/ 5150' MD. P/U 6,370.0 5,150.0 22:00 00:00 106K, S/O 91 K 8/1612019 8/16/2019 3.75 PROD1 CASING TRIP P POOH F/ 5150'T/ 393' MD. 5,150.0 393.0 00:00 03:45 8/16/2019 8116/2019 0.25 PRODt CASING OWFF P Observe well for flow - No flow 393.0 393.0 03:45 04:00 8/16/2019 8/1612019 1.50 PRODt CASING BHAH P UD BHA F1393' T/ surface. 393.0 0.0 04:00 05:30 8116/2019 8116/2019 0.50 COMPZN CASING CLEN P Clean and clear rig floor. Remove 0.0 0.0 05:30 06:00 SLB tools from rig floor. 8/16/2019 8/16/2019 1.00 COMPZN CASING RURD P R/U liner running equipment. Verify 0.0 0.0 06:00 07:00 tally and joint count. 8/16/2019 8/16/2019 6.50 COMPZN CASING RCST P M/U and RIH with 4 1/2", 12.6#, L -B0, 0.0 6,403.0 07:00 13:30 HYD 563 lower completion string T/ 6403' MD. Install tea 4 1/2" x 6.125 OD Composite centralizers free floating on every joint. M/U Tq 3800- 4000 Ft/Lbs verifying each connection with make up marks. P/U=95K, S/0=74K. Page 13116 Report Printed: 9/1212019 Operations Summary (with Timelog Depths) 3R-112 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log smd Deptn Start Time End Time Dur (h) Phase Op Code Activity Code Time P-T-XOperatlen (WB) End Depth (WB)8/16/2019 8116/2019 2.00 COMPZN CASING RCST P M/U Baker seal bore assembly, liner 6,403.0 6,403.0 13:30 15:30 hanger / packer. Fill liner tie back sleeve W/ Xan-plex D. M/U Rubicon swivel. 8/16/2019 8/16/2019 4.50 COMPZN CASING RUNL P RIH W/ 4 1/2" liner on DP F/ 6403' T/ 6,403.0 12,697.0 15:30 20:00 12697", P/U=160K, S/0=91 K Confirmed bottom @ 12697' MD. Set down 10K. P/U TI 12964.86', P/U=160K to lake string out of compression. Rabbit all drill pipe W/ 2" drift from derrick. 8/16/2019 8/16/2019 0.50 COMPZN CASING CIRC P Drop 1.625" liner hanger setting ball 12,697.0 12,697.0 20:00 20:30 and circ @ ball down. Initial circ rate 167 GPM, 181 PSI. Final circ rate 64 GPM 181 PSI. Ball on seat @ 440 Stks. 8/16/2019 8/1612019 1.00 COMPZN ?5ASING CASINGHOSO P Cont pressure up T/ 2000 PSI & hold 12,697.0 6,222.0 2030 21:30 for 5 Min. Pressure up T/ 2600 PSI & hold for 5 Min. S/0 T/ 49K and verify hanger is set. Pressure up T/ 4000 PSI & hold for 5 Min, S/O T/ 40K, P/U and verify liner running tool was released. P/U=160K. P/U and expose dogs. S/0 T/ 43K to set packer. P/U 10'. Liner Top @ 6231.22' 8/16/2019 8/16/2019 0.50 COMPZN CASING PRTS P R/U and test liner top packer T/ 3580 6,222.0 6,222.0 21:30 22:00 PSI for 10 Min. - Good test. Pump 2.9 bbls. Bleed back 2.9 bbls. Blow down lines and RID test equipment. 8/16/2019 8/17/2019 2.00 COMPZN WELLPR CIRC P P/U 50' T/ expose liner running tool. 6,222.0 6,172-0- 22:00 00:00 Displace well with 9.2 PPG brine. Pump 60 Bbls Hi -Vis sweep, followed by 9.2 PPG brine (x1338 GPM, 1481 PSI. 11%F/0. P/U=135K S/0=115K 8/17/2019 8/17/2019 1.00 COMPZN WELLPR CRIH P Spot 155 Bbls Corrosion inhibited 6,172.0 6,172.0 00:00 01:00 brine @ 252 GPM, 772 PSI, 8% F/O. Followed by 36 Bbls 9,2 PPG Brine. 8/17/2019 8/17/2019 0.50 COMPZN WELLPR OWFF P Observe well for flow - No flow. B/D 6,172.0 6,172.0 01:00 01:30 top drive and kill line. 8/17/2019 8/17/2019 7.00 COMPZN WELLPR PULD P LDDP F/ 6172'T/ 50'. PIU 74K, S/O 6,172.0 50.0 01:30 08:30 76K 8/17/2019 8/1712019 0.50 COMPZN WELLPR BHAH P UD Rubicon swivel and liner running 50.0 0.0 08:30 09:00 tool. Verify dog sub sheared, all seal intact on running tool. 8/17/2019 8/17/2019 2.00 COMPZN WELLPR TRIP P RIH out of derrick T/ 4800' 0.0 4,800.0 09:00 11:00 8/17/2019 8/17/2019 2.50 COMPZN WELLPR PULD P LDDP F/ 4800'T/ 2564' 4,800.0 2,564.0 11:00 13:30 8117/2019 8117/2019 0.50 COMPZN WELLPR TRIP P RIH out of derrick FI 2564' T/ 3955' 2,564.0 3,955.0 13:30 14:00 8/17/2019 8/1712019 3.00 COMPZN WELLPR PULD P LDDP F/ 4955' T/ surface 3,955.0 0.0 14:00 17:00 8/17/2019 8/17/2019 1.00 COMPZN RPCOMP WWWH P Pull wear bushing. M/U jetting tool. 0.0 0.0 17:00 18:00 Jet stack. UD jetting tool. 8/17/2019 8/17/2019 0.50 COMPZN RPCOMP CLEN P Clean and clear rig floor. 0.0 0.0 18:00 18:30 8/17/2019 8/17/2019 1.00 COMPZN RPCOMP RURD P R/U completion running equipment. 0.0 0.0 18:30 19:30 Stage control line spooler on rig floor 8/1712019 8/1712019 0.50 COMPZN WPCOMP P PJSM on running 4 1/2" upper 0.0 0.0 19:30 20:00 completion with control line from SSSV to surface. Page 14116 Report Printed: 911212019 Operations Summary (with Timelog Depths) 3R-112 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log smn Depth Stan Time End Time Dur (hr) Phase Op Code Activity Code Tana P-TA Operation (NCB) End Depth (ftKB) 8/17/2019 8/18/2019 4.00 COMPZN RPCOMP RCST P Run 4 1/2", 12.6#, L-80, Hyd 563 0.0 3,885.0 20:00 00:00 completion T/ 3885'. M/U Tq 3800- 4000 Ft/Lbs. P/U 80K, SIO 75K. Damaged box on joint# 47 replaced with joint# 153 in tally. 8/18/2019 8/18/2019 0.50 COMPZN RPCOMP RCST P Run 4 1/2", 12.6#, L-80, Hyd 563 3,885.0 4,126.0 00:00 00:30 completion F/ 3885'T/ 4126'. M/U Tq 38004000 Ft/Lbs. P/U 80K, SIO 75K. 8/18/2019 8/18/2019 0.50 COMPZN RPCOMP RURD P R/U SLB control line spooler. Conned 4,126.0 4,126.0 00:30 01:00 control line to SSSV 8/18/2019 8/18/2019 0.50 COMPZN RPCOMP PRTS P Test control line and SSSV T/ 250 PSI 4,126.0 4,126.0 01:00 01:30 for 5 Min, 5000 PSI for 15 Min. - Good test. 8/18/2019 8/18/2019 0.50 COMPZN RPCOMP RCST P Run 41/2", 12.6#, L-80, Hyd 563 4,126.0 4,251.0 01:30 02:00 completion F/ 4126' T/ 4251'. M/U Tq 3800-4000 Ft/Lbs. P/U 80K, SIO 75K. Took weigh @ 4251' 8/18/2019 8/18/2019 0.50 COMPZN RPCOMP RCST T Pull 1/2" completion F/ 4251' T/ 4,251.0 4,126.0 02:00 02:30 4126'. Identify SSSV OD=6.92" 8/18/2019 8/18/2019 10.50 COMPZN RPCOMP RCST T Consult town. Order new SSSV with 4,126.0 4,126.0 02:30 13:00 smaller OD. Prep shaker for repair. Replace lights in derrick. 8/18/2019 8/18/2019 0.50 COMPZN RPCOMP PRTS P M/U DB61 SSSV. Test control line and 4,126.0 4,126.0 13:00 13:30 SSSV T/ 250 PSI for 5 Min, 5000 PSI for 15 Min. - Good lest. 8/18/2019 8/18/2019 2.00 COMPZN RPCOMP RCST P Run 4 1/2", 12.6#, L-80, Hyd 563 4,126.0 6,262.0 13:30 15:30 completion F/ 4126'T/ 6262". M/U Tq 3800-4000 Ft/Lbs. P/U 93K, SID 77K. Install 1 full cannon clamp on each joint. 8/18/2019 8/18/2019 1.50 COMPZN RPCOMP HOSO P RIH tag No-go @ 6231.22'. Set down 6,262.0 6,235.0 15:30 17:00 10 K T/ confirm on depth. L/D 3 joints. M/U space out pups 9.99', 7.84', 7.79' and 3.78'. M/U joint# 150. 8/18/2019 8/18/2019 1.50 COMPZN RPCOMP HOSO P P/U GE- MB 242 13 1/2" x 4 1/2' 6,235.0 6,278.0 17:00 18:30 tubing hanger. Terminate control line. M/U landing joint. Drain slack. RIH and land hanger. RILDS. Bottom of seal assembly @ 6278.32. Spaced out 2.61' off of No-go. Total 55 full damps run with 110 pins. 8/18/2019 8/18/2019 0.25 COMPZN RPCOMP PRTS P Test hanger seal T/ 5000 PSI for 15 6,278.0 6,278.0 18:30 18:45 1 Min - Good test 8/18/2019 8/18/2019 0.25 COMPZN RPCOMP RURD P Rig up T/ test tubing and IA. 6,278.0 6,278.0 18:45 19:00 8/18/2019 8/18/2019 1.50 COMPZN RPCOMP PRTS P Test tubing T/ 3500 PSI for 10 Min. 6,278.0 6,278.0 19:00 20:30 Bleed tubing down T/ 2000 PSI. Test IA T/ 3500 PSI for 30 MIN - Good test. 8/18/2019 8/18/2019 0.50 COMPZN RPCOMP CIRC P Bleed tubing to 0 PSI. Shear out SOV. 6,278.0 6,278.0 20:30 21:00 Establish circulation to verify shear @ 84 GPM. 300 PSI. @ 125 GPM, 500 PSI. Observe well for flow - No flow. 8/18/2019 8/18/2019 0.75 COMPZN WHDBOP RURD P R/D test equipment. B/D surface 6,278.0 6,278.0 21:00 21:45 lines. Drain stack. 8/18/2019 8/18/2019 0.25 COMPZN WHDBOP MPSP P Install HP BPV 6,278.0 6,278.0 21:45 22:00 8/18/2019 8/18/2019 0.25 COMPZN WHDBOP PRTS P Test BPV and lower hanger seals for 6,278.0 6,278.0 22:00 22:15 1 T/ 2500 PSI for 10 MIN - Good test. 8/18/2019 8/19/2019 1.75 COMPZN WHDBOP NUND P Pull riser. N/D BOP's 6,278.0 6,278.0 22:15 00:00 Page 15116 Report Printed: 911212019 Operations Summary (with Timelog Depths) 3R-112 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log State Depth Stan Time End Time our (ho Phase Op Code Activity Cade Time P -T -X Operation (flKB) End Depth(IKB) 8/19/2019 8/19/2019 1.00 COMPZN WHDBOP NUND P Continue N/D stack, rack back in BOP 6,278.0 6,278.0 00:00 01:00 deck and secure. 8/19/2019 8/19/2019 3.00 COMPZN WHDBOP NUND P N/U adaptor flange. Install tree test 6,278.0 6,278.0 01:00 04:00 dart. N/U GE- MB 222/242 5K tree. 8/19/2019 8/19/2019 2.00 COMPZN WHDBOP PRTS P Test pack off T/5000 PSI for 10 Min- 6,278.0 6,278.0 04:00 06:00 Good test. Test tree T/ 250 PSI for 5 Min, 5000 PSI for 10 Min - Good test 8/19/2019 8/19/2019 2.50 COMPZN WHDBOP RURD P R/D testing equipment. R/U LRS to 6,278.0 6,278.0 0600 08:30 freeze protect well. 8/19/2019 8/19/2019 0.50 COMPZN WHDBOP SFTY P PJSM with rig crew and LRS on freeze 6,278.0 6,278.0 08:30 09:00 protect. 8/19/2019 8/19/2019 2.00 COMPZN WHDBOP FRZP P Pressure test lines T/ 2500 PSI - Good 6,278.0 6,278.0 09:00 11:00 test. LRS pump 120 Bbls diesel down IA@ 2 BPM, ICP=50 PSI, FCP=350 PSI. Place tubing and IA in communication allowing well to U - Tube. Bleed off excess pressure. Pressure increased form well T/ 100 PSI, 8/19/2019 8/19/2019 1.00 COMPZN WHDBOP MPSP P R/U lubricator and install H BPV. R/D 6,278.0 6,278.0 11:00 12:00 lubricator. Tubing= 100 PSI IA= 150 PSI OA= 150 PSI 8/19/2019 8/19/2019 2.00 DEMOB MOVE DMOB P R/D circulating equipment. Secure 6,278.0 6,278.0 12:00 14:00 tree, install blanking flanges, close all valves, cap all ports. Release rig @ 14:00 Page 16116 ReportPrinted: 9/1 212 01 9 NADConversion Kuparuk River Unit Kuparuk 3R Pad 3R-112 NAD 27 ASP 4 ConocoPhillips Definitive Survey Report 27 August, 2019 Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. i-_ Yes No I have checked to the best of my ability that the following data is correct: Surface Coordinates ] Declination & Convergence stephen.fell i] GRS Survey Corrections @contractor Mm- — El Survey Tool Codes .conocophilli=—" SLB DE: ps.corn Client Representative: Madeline Woodard Date: ConocoPhillips ConocoPhiilips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 3R-112 Project: Kuparuk River Unit TVD Reference: 3R-112 Actual @ 49.25usft (D142) Site: Kuparuk 3R Pad MD Reference: 3R-112 Actual @ 49.25usft (0142) Weil: 3R-112 North Reference: True Wellbore: 3R-112 Survey Calculation Method: Minimum Curvature Design: 3R-112 Database: EDT 14 Alaska Production >roject Kuparuk River Unit, North Slope Alaska, United States Nap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Nap Zone: Alaska Zone 04 Using geodetic scale factor Well 3R-112 Date From Audit Notes: Well Position +WS 0.00 usft Northing: 6,031,581.19 usft Latitude: 70° 29'50.785 N +E/ -W 0.00 usft Easting: 520,678.16 usft Longitude: 149'49'51.251 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 9.80usft (9 6,324.85 3R-112Srvy4-SLB_MWD+GMAG (3R- 39.45 0.00 0.00 Nellbore 3R-112 rlagnetica Model Name Sample Date Declination Dip Angle Field Strength (1) (% (nT) BGGM2018 7/30/2019 16.50 80.95 57,418 Design 3R-112 Date From Audit Notes: (wit) (Wit) Survey (Wellbore) Version: 1.0 Phase: ACTUAL Tie On Depth: 39.45 Vertical Section: Depth From (TVD) +N1S +E/ -W Direction 2,400.16 (usft) (unit) (usft) (9 6,324.85 3R-112Srvy4-SLB_MWD+GMAG (3R- 39.45 0.00 0.00 270.00 Survey Program Date From To (wit) (Wit) Survey (Wellbore) Tool Name Description Survey Date 123.31 1,394.87 3R-112 Srvy 1 - SLB _GWD70 (3R-112) GYD-GCSS Gyrodata gyro single shots 7/29/2019 8:53'- 1,434.65 2,301.443R-112Srvy 2-SLB_MWD+GMAG(3R- MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Corred7/30/2019 8:57: 2,400.16 2,400.163R-112 Srvy 3-SLB_MWD-Inc-Only-Fille MWD -INC -ONLY MWD-INC_ONLY_FILLER 8/4/2019 9:07:D 2,499.30 6,324.85 3R-112Srvy4-SLB_MWD+GMAG (3R- MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correde/4/2019 9:08:0 6,424.02 12,636.213R-112 Srvy 5-SLB_MWD+GMAG(3R- MWD+IFR2+SAG+MS OWSG MWD +IFR2+Sag+Mufti-Station CorrectB/10/2019 9:08: Survey Map Map Vertical MD Inc Azl TVD TVDSS *N1 -S +E/ -W Northing Easting DLS Section (usft) PI P) (usft) (usft) (wit) (usft) (ft) (in (°1100) (R) Survey Tool Name 39.45 0.00 0.00 39.45 5.80 0.00 0.w 6,031,581.19 520,678.16 0.00 0.00 UNDEFINED 123.31 0.57 344.63 123.31 74.06 0.40 -0.11 6,031,581.59 520,678.05 0.68 0.11 GYD-GC-SS(1) 171.82 1.33 104.06 171.81 122.56 0.50 0.37 6,031,581.69 520,678.53 347 -0.37 GYD-GC-SS(1) 260.16 2.82 107.62 260.09 210.84 -0.41 3.44 6,031,500.79 520,681.60 1.69 -3.44 GYD-GCSS(1) 356.04 3.48 112.31 355.83 306.58 -2.23 8.38 6,031,578.99 520,686.54 0.74 5.38 GYD-GCSS(1) 447.77 3.88 114.19 447.37 398.12 4.56 13.78 6,031,576.67 520,691.96 0.46 -13.78 GYD-GCSS(1) 542.58 5.70 106.20 541.85 492.60 -7.18 21.23 6,031,574.07 520,699.41 2.04 -21.23 GYD-GCSS(1) 638.05 6.80 110.93 635.76 587.51 -10.53 31.07 6,031,570.75 520,709.25 1.27 .71.07 GYD-GG-SS(1) 733.28 9.50 112.53 731.01 681.76 -15.55 43.59 6,031,565.76 520,721.79 2.85 -03.59 GYD-GC-SS(1) 831.05 11.12 113.01 627.19 777.94 -22.33 59.72 6,031559.03 520,737.94 1.66 -59.72 GYD-GCSS(1) 8272019 3:48:17PM Page 2 COMPASS 5000.14 Build 85H Survey ConocoPhillips Definitive Survey Report Map Company: NADConversion Local Co-ordinate Reference: Well 3R-112 Project: Kuparuk River Unit TVD Reference: 311-112 Actual @ 49.25usfl (D142) Site: Kuparuk 3R Pad MD Reference: 3R-112 Actual @ 49.25usft (D142) Well: 3R-112 North Reference: True Wellbore: 3R-112 Survey Calculation Method: Minimum Curvature Design: 3R-112 Database: EDT 14 Alaska Production Survey 82712019 3:48:17PM Page 3 COMPASS 5000.14 Build 85H Map NAP vertical MD Inc Azi TVD TVOSS +N/ -S +E/ -W Northing Eaal DLS Section (usft) r) (') (usft) (caR) (usft) (waft) (it) Ift) r/1001 (1t) Survey Tool Name 921.17 15.37 107.82 914.90 865.65 -29.38 79.10 6,031,552.03 520,757.34 4.89 -79.10 GYD-GC-SS (1) 1,016.45 16.08 107.67 1,006.61 957.36 -37.25 103.70 6,031,644.23 520,781.95 0.75 -103.70 GYD-GC-SS(1) 1,066.75 18.36 106.53 1,054.66 1,005.41 4162 117.93 6,031,539.90 520,796.19 4.58 -117.93 GYD-GCSS(1) 1,111.38 21.50 100.74 1,096.61 1,047.36 -05.15 132.71 6,031,536.42 520,810.98 8.30 -132.71 GYD-GCSS(1) 1,156.59 24.61 97.93 1,138.21 1,088.96 47.99 150.18 6.031,533.62 520,828.45 7.30 -150.18 GYD-GCSS(1) 1,205.34 26.83 95.26 1,182.13 1,132.88 50.40 171.19 6,031,531.27 520,849.47 5.14 -171.19 GYD-GCSS(1) 1,300.21 26.63 100.43 1,266.87 1,217.62 56.21 213.42 6,031,525.58 520,891.72 2.46 -213.42 GYD-GC-SS(1) 1,394.87 26.98 109.88 1,351.40 1,302.15 57.36 254.50 6,031,514.54 520,932.82 4.51 -254.50 GYD-GC-SS(1) 1434.66 27.33 109.27 1,386.80 1,337.55 -73.45 271.61 6,031,508.51 520,949.95 1.12 -271.61 MWD+IFR2+SAG+MS (2) 1,480.17 27.52 109.85 1,427.20 1,377.95 50.46 291.36 6,031,501.55 520,969.72 0.72 -291.36 MWD+IFR2+SAG+MS(2) 1,529.23 26.28 109.78 1,470.95 1,421.70 57.99 312.24 6,031,494.08 520,990.62 2.53 -312.24 MWD+IFR2+SAG+MS(2) 1,624.80 24.87 110.77 1,557.15 1,507.90 -102.27 350.95 6,031,479.90 521,029.35 1.54 350.95 MWD+IFR2+SAG+MS(2) 1,718.86 25.23 110.79 1,642.36 1,593.11 -116.40 388.18 6,031,465.88 521,066.62 0.38 .388.18 MWD+IFR2+SAG+MS(2) 1,812.63 25.82 110.08 1,726.98 1,677.73 -130.51 426.04 6,031,451.88 521,104.52 0.71 426.04 MWD+IFR2+SAG+MS(2) 1,907.22 27.46 109.74 1,811.53 1,762.28 -144.95 465.92 6,031,437.55 521,144.44 1.74 465.92 MWD+IFR2+SAG+MS (2) 2,001.25 31.71 104.64 1,893.29 1,844.04 -158.53 510.26 6,031,424.10 521,188.81 5.25 510.26 MWD+IFR2+SAG+MS(2) 2,096.83 35.60 102.31 1,972.84 1,923.59 -170.81 561.77 6,031,411.96 521,240.35 4.29 561.77 MWO+IFR2+SAG+MS(2) 2,191.35 38.76 99.62 2,048.14 1,998.89 -181.62 617.84 6,031,401.30 521,296.44 3.76 517.84 MWD+IFR2+SAG+MS(2) 2,285.39 40.90 92.87 2,120.39 2,071.14 -188.09 677.64 6,031,395.01 521,355.26 5.13 577.64 MWD+IFR2+SAG+MS(2) 2,301.44 41.56 92.20 2,132.46 2,083.21 -188.56 688.21 6,031,394.57 521,366.83 4.95 588.21 MWD+IFR2+SAG+MS(2) 2,391.85 42.28 88.35 2,199.75 2,150.50 -180.83 748.59 6,031,394.46 521,427.20 2.95 -748.59 Interpolatec Station 10 314" 2,400.16 42.35 88.0 2,205.89 2,156.64 -188.65 754.18 6,031,394+66 521,432.79 2.95 -754.18 MWD -INC _ONLY (3) 2,499.30 46.14 84.31 2,276.91 2,227.66 -183.94 823.15 6,031,399.55 521501.74 4.62 523.15 MWO+IFR2+SAG+MS(4) 2,548.03 46.88 80.95 2,310.45 2,261.20 -179.40 858.20 6,031404.20 521,536.78 5.23 558.20 MWD+IFR2+SAG+MS(4) 2,605.98 47.77 74.91 2,349.75 2,300.50 -170.48 899.83 6,031,413.23 521,578.37 7.81 599.83 MWD+IFR2+SAG+MS(4) 2,70126 47.45 WAS 2,414.05 2,364.80 -147.25 %6.13 6.031,436.64 521,644.59 6.56 -956.13 MWD+IFR2+SAG+MS(4) 2,795.53 47.71 57.53 2,4T7.71 2,428.46 -114.63 1,027.44 6,031469.43 521,705.81 6.99 -1,02244 MWD+IFR2+SAG+MS(4) 2,890.21 48.52 51.27 2,540.96 2,491.71 -73.61 1,084.69 6,031,510.60 521,762.94 4.99 -1084.69 MWD+IFR2+SAG+MS(4) 2,985.10 49.51 48.39 2,603.20 2,553.95 -27.41 1,139.40 6,031,556.96 521,817.52 2.52 -1,139.40 MWD+IFR2+SAG+MS(4) 3,079.65 50.42 45.37 2,664.03 2,614.78 22.07 1,192.22 6,031,606.58 521,870.20 2.63 -1,192.22 MWD+IFR2+SAG+MS(4) 3,174.32 51.03 41.03 2,723.97 2,674.72 75.48 1,242.36 6,031,660.12 521,920.18 3.61 -1,242.36 MWD+IFR2+SAG+MS(4) 3,269.51 51.79 36.94 2,783.36 2,734.11 133.30 1,289.14 6,031,718.07 521,966.79 3.45 -1,289.14 MWD+IFR2+SAG+MS (4) 3,363.47 53.36 34.17 2,840.47 2,791.22 194.01 1,332.50 6,031,778.89 522,009.99 2.88 -1,332.50 MWD+IFR2+SAG+MS(4) 3,458.74 56.22 30.87 2,895.41 2,846.16 259.64 1,374.30 6,031,844.63 522,051.60 4.13 -1,374.30 MWD+IFR2+SAG+MS(4) 3,552.08 59.01 27.30 2,945.41 2,896.16 328.52 1,412.57 6,031,913.61 522,089.67 4.40 -1,412.57 MWD+IFR2+SAG+MS (4) 3.646.16 60.44 22.27 2,992.86 2,943.61 402.26 1,446.59 6,031,987.43 522,123.48 4.86 -1,446.59 MWO+IFR2+SAG+MS (4) 3,741.18 61.39 18.34 3,039.06 2,989.81 480.12 1,475.39 6,032,065.38 522,152.06 3.75 -1,475.39 MWD+IFR2+SAG+MS(4) 3,835.27 61.78 15.72 3,083.84 3,034.59 559.23 1.499.62 6,032,144.54 522,176.07 2.48 -1,499.62 MWD+IFR2+SAG+MS(4) 3,931.41 64.36 12.81 3,127.39 3,078.14 642.29 1,520.71 6,032,227.65 522,196.92 3.81 -1,520.71 MWD+IFR2+SAG+MS(4) 4,025.03 67.24 9.02 3,165.77 3,116.52 726.12 1,536.84 6,032,311.51 522,212.82 4.81 -1536.84 MWD+IFR2+SAG+MS(4) 82712019 3:48:17PM Page 3 COMPASS 5000.14 Build 85H ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 3R-112 Project Kuparuk River Unit TVD Reference: 3R-112 Actual @ 49.25usft (D142) Site: Kuparuk 3R Pad MD Reference: 3R-112 Actual @ 49.25usft (D142) Well: 3R-112 North Reference: True Wellbore: 3R-112 Survey Calculation Method: Minimum Curvature Design: 3R-112 Database: EDT 14 Alaska Production Survey Map hap Vertical No Inc Azi TVD TVDSS +N/-5 +E/.W Northing Eaagng DLS Section (usR) (0) (°) (usft) (usR) (usR) (uslt) (it) (R) (1/1001 (R) Survey Tool Name 4,120.20 70.25 4.84 3,200.28 3,151.03 814.13 1,647.51 6,032,399.54 522,223.24 5.17 -1,547.51 MWD.IFR2+SAG+MS(4) 4,215.04 72.86 2.35 3,230.29 3,181.04 903.91 1,553.13 6,032,489.33 1 3.71 -1,553.13 MWD+IFR2+SAG+MS(4) 4,309.12 75.72 0.62 3,255.76 3,206.51 994.43 1,555.47 6,032,579.85 522,230.70 3.52 -1,555.47 MWD+IFR2+SAG+MS(4) 4,404.81 77.22 1.57 3,278.15 3,228.90 1,087.45 1,557.25 6,032,672.85 522,232.22 1.84 -1,557.25 MWD+IFR2+SAG+MS (4) 4,499.70 77.00 0.55 3,299.32 3,250.07 1,179.93 1,558.96 6,032,765.33 522,233.68 1.07 -1,55B.96 MWD+IFR2+SAG+MS(4) 4,594.53 77.18 358.81 3,320.51 3,271.26 1,272.35 1,558.44 6,032,857.75 522,232.90 1.80 -1,55BA4 MWD+IFR2+SAG+MS(4) 4,688.13 77.54 356.57 3,340.99 3,291.74 1,363.61 1,554.76 6,032,948.98 522,228.97 2.37 -1,554.76 MWD+IFR2+SAG+MS(4) 4,782.44 77.54 353.94 3,361.34 3,312.09 1,455.37 1547.14 6,033,090.71 522,221+10 2.72 -1,547.14 MWD+IFR2+SAG+MS(4) 4,877.51 77.57 351.02 3,381.83 3,332.58 1,547.40 1,535.00 6,033,132.70 522,208.69 3.00 -1,535+0 MWD+IFR2+SAG+MS(4) 4,971.76 77.34 346.78 3,402.31 3,353+6 1,637.65 1,517.29 6,033,222.89 522,190.74 4.40 -1,517.29 MWD+IFR2+SAG+MS(4) 5,066.48 77.93 342.79 3,422.61 3,373.35 1,726.91 1,493.01 6,033,312.08 522,166.21 4.16 -1,493.01 MWD+IFR2+SAG+MS(4) 5,161.50 77.94 339.39 3,442.47 3,393.22 1,814.80 1,462.90 6,033,399.88 522,135.86 3.50 -1,462.80 MWD+IFR2+SAG+MS(4) 5,255.48 78.17 336.20 3,461.93 3,412.68 1,899.92 1,428.16 6,033,484.88 522,100.88 3.33 -1,428.16 MWD+IFR2+SAG+MS(4) 5,350.61 78.75 332.40 3,480.97 3,431.72 1,983.89 1,387.74 6,033,568.73 522,060.24 3.96 -1,387.74 MWD+IFR2+SAG+MS(4) 5,445.92 78.79 328.80 3,499.53 3,450.28 2,065.32 1,341.86 6,033,650.03 522,014.13 3.71 -1,341.86 MWD+IFR2+SAG+MS(4) 5,539.74 7907 323.65 3,517.56 3,468.31 2,141.82 1,290.69 6,033,726.38 521,962.76 5.40 -1,290.69 MWD+IFR2+SAG+MS(4) 5,634.34 79.90 318.96 3,534.83 3,485.68 2,214.39 1,232.55 6,033,798]8 521,904.43 4.95 -1,232.55 MWD+IFR2+SAG+MS(4) 5,728.88 80.45 313.42 3,550.98 3,501.73 2,281.58 1,168.09 6,033,865.79 521,839.78 5.80 -1,168+9 MWD+IFR2+SAG+MS(4) 5,823.76 80.92 309.30 3,566.34 3,517.09 2,343.44 1,097.83 6,033,927.44 521,769.35 4.31 -1,097.83 MWD+IFR2+SAG+MS(4) 5,918.84 80.85 304.82 3,581.41 3,532.16 2,400.00 1,022.93 6,033,983.79 521,694.31 4.65 -1,022.93 MWD+IFR2+SAG+MS(4) 6,013.52 80.96 299.30 3,596.39 3,547.14 2,449.60 943.73 6,034,033.16 521,614.98 5.76 643.73 MWD+IFR2+SAG+MS(4) 6,108.69 81.64 295.62 3,610.79 3,561.54 2,492.97 860.27 6,034,076.30 521,531.41 3.89 460.27 MWD+IFR2+SAG+MS(4) 6,202.76 83.27 291.87 3,623.14 3,573.89 2,530.51 774.93 6,034,113.59 521,445.97 4.31 -774.93 MWD+IFR2+SAG+MS(4) 6,298.22 83.98 288.18 3,633.75 3,584.50 2,562.99 685.81 6,034,145.82 521,356.77 3.91 685.81 MWD+IFR2+SAG+MS(4) 6,324.85 84.37 267.38 3,636.45 3,587.20 2,571.08 650.58 6,034,153.84 521,331.52 3.33 660.58 MWD+IFR2+SAG+MS(4) 6,384.65 85.18 286.50 3,641.90 3,592.65 2,588.43 603.61 6,034,171.03 521,274.51 1.99 603.61 Interpolated Station 7 Sri 6,424.02 85.71 285.92 3,645.02 3,595.77 2,599.38 665.93 6,034,181.88 521236.80 1.99 665.93 MWD+IFR2+SAG+MS(5) 6,523.44 66.59 281.39 3,651.70 3,602.45 2,622.79 469.56 6,034,205.02 521,140.38 4.63 469.56 MWD+IFR2+SAG+MS(5) 6,596.35 87.79 279.95 3,655.28 3,606.03 2,636.27 398.00 6,034,218.30 521,068.79 2.57 J98.00 MWD+IFR2+SAG+MS(5) 6,691.40 87.71 274.38 3,659.01 3.609.76 2,648.12 303.80 6,034229.88 520,974.57 5.86 -303.80 MVaD+IFR2+SAG+MS (5) 6,723.58 88.18 274.02 3,660.17 3,610.92 2,650.47 271.73 6,034,232.14 520,942.49 1.84 -271.73 MWD+IFR2+SAG+MS(5) 6,754.81 88.68 273.08 3,661.02 3,611.77 2,652.40 240.57 6,034233.99 520,911.33 3.41 -240.57 MW13+1FR2+SAG+MS(5) 6,786.24 88.49 272.08 3,661.80 3,612.55 2,653.82 209.19 6,034,235.32 520,879.99 3.24 -209.19 MWD+IFR2+SAG+MS(5) 6,880.01 87.92 270.33 3,664.74 3,615.49 2,655.79 115.49 6,034,237.03 520,786.25 1.96 -115.49 MWD+IFR2+SAG+MS(5) 6,976.52 88.66 269.11 3,667.62 3,61B.37 2,655.32 19.02 6,034236.29 520,689.80 1.48 -19.02 MWD+IFR2+SAG+MS(5) 7,071.40 88.99 266.15 3,669.55 3,620.31 2,651.40 -75.74 6,034,232.10 520,595.05 3.14 75.74 MWD+IFR2+SAG+MS(5) 7,166.44 90.44 266.09 3,670.03 3,620.78 2,644.97 -170.55 6,034,225.41 520,500.26 1.53 170.56 MWD+IFR2+SAG+MS(5) 7,261.56 91.71 265.96 3,668.25 3,619+0 2,638.37 -265.44 6,034,218.55 520,405.41 1.34 265.44 MWD+IFR2+SAG+MS(5) 7,356.61 92.86 265.16 3,664.46 3,615.21 2,631.02 -360.12 6,034210.94 520,310.76 1.47 360.12 MWD+IFR2+SAG+MS(5) &272019 3:48:17PM Page 4 COMPASS 5000.14 Build 85H ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 3R-112 Project: Kuparuk River Unit TVD Reference: 3R-112 Actual @ 49.25us0 (D142) Site: Kuparuk 3R Pad MD Reference: 3R-112 Actual @ 49.25usft (D142) Well: 3R-112 North Reference: True Wellbore: 3R-112 Survey Calculation Method: Minimum Curvature Design: 3R-112 Database: EDT 14 Alaska Production Survey 827/2019 3:48.17PM Page 5 COMPASS 5000.14 Build 85H Map Map Vertical MD Inc Azi TVD TVDSS -NI-3 +PJ -W Northing Easting DLS Section (MR) P) P) Nam (MR) (MM (MM (R) (M (°1100') (R) Survey Tool Name 7,462.38 92.75 264.80 3,659.77 3,610.52 2,622.65 -155.41 6,034,202.30 520,215.50 0.39 455.41 MND+IFR2+SAG+MS (5) 7,547.22 91.86 265.16 3,655.96 3,6W.71 2,614.35 -549.B1 6,034,193.75 520,121.13 1.01 549.81 MWD+IFR2+SAG+MS(5) 7,643.14 89.54 268.72 3,654.79 3,605.54 2,609.24 -W+56 6,03.188.37 520,025.40 4.43 645.56 MWD+IFR2+SAG+MS(5) 7,737.11 90.66 266.83 3,654.62 3,665.37 2,605.59 -739.46 6,034,184.46 519,931.53 2.34 739.46 MWD+IFR2+SAG+MS(5) 7,832.64 90.51 267.59 3,653.65 3,604.40 2,600.94 -834.67 6,03.179.54 519,836.14 0.81 834.87 MWD+IFR2+SAG+MS(5) 7,926.84 92.89 269.76 3,650.85 3,601.60 2,598.76 -928.99 6,034.177.10 519,742.04 3.42 928.99 MWD+IFR2+SAG+MS (5) 8,021.52 97.06 267.43 3,642.64 3,593.39 2,59646 -1,023.26 6,03.174.53 519,647.79 5.04 1,023.26 MWD+IFR2+SAG+MS (5) 8,116.69 97.36 270.67 3,630.69 3,581.44 2,594.89 -1,11T.65 6,03.172.71 519,553.41 3.39 1,117.65 MND+IFR2+SAG+MS(5) 8,210.65 97.43 272.02 3,618.60 3,569.35 2,597.08 -1,210.80 6,034,174.63 519,460.26 743 1,210.60 MWD+IFR2+SAG+MS(5) 8,306.28 96.67 272.67 3,606.86 3,557.61 2,600.96 -1,305.62 6,03.17B.25 519,365.43 1.04 1,305.62 MND+IFR2+SAG+MS (5) 8,401.29 94.84 272.65 3,597.34 3,548.09 2,605.35 -1,465.05 6,034,182.38 519,271.01 1.93 1,400.05 MND+IFR2+SAG+MS(5) 8,495.11 89.53 273.54 3,593.76 3,544.51 2,610.41 -1,493.63 6,034,187.18 519177.42 5.74 1,493.63 MND+IFR2+SAG+MS(5) 8,590.68 88.58 271.79 3,595.34 3,546.09 2,614.85 -1,589.08 6,034,191.35 519,081.97 2.08 1,589,08 MWD+IFR2+SAG+MS(5) 8,666.04 88.14 270.97 3,598.07 3,548.82 2,617.15 -1,684.37 6,03.193.38 518,986.68 0.98 1,684.37 MND+IFR2+SAG+MS (5) 8,780.13 87.52 270.79 3,601.63 3,552.36 2,618.59 -1,778.38 6,034,194.57 518,892.6B 0.69 1,77838 MND+IFR2+BAG+MS(5) 8,875.08 87.00 269.79 3,606.17 3,556.92 2,619.07 -1,873.22 6,034,194.78 518,797.85 1.19 1,873.22 MND+IFR2+SAG+MS(5) 8,969.83 90.23 269.04 3,608.46 3,559.21 2,618.11 -1,967.93 6,034,193.55 518,703.15 3.50 1,967.93 MND+IFR2+SAG+MS (5) 9,063.41 90.90 270.68 3,607.54 3,558.29 2,617.88 -2,061.50 6,034,193.06 518,609.59 1.89 2,051.50 MND+IFR2+SAG+MS (5) 9,160.15 93.17 271.70 3,604.10 3,554.85 2,619.89 -2,158.15 6,034,194.80 518,512.95 2.57 2,158.15 MND+IFR2+SAG+MS(5) 9,254.33 94.33 270.67 3,597.94 3,54669 2,621.83 -2,252.10 6,034,196.48 518,419.00 1.65 2,252.10 MND+IFR2+SAG+MS (5) 9,348.70 91.67 272.24 3,593.00 3,543.75 2,624.22 -2,346.30 6,034,198.62 518,324.80 3.27 2,346.30 MWD+IFR2+SAG+MS(5) 9,444.71 92.65 271.35 3,589.38 3,540.13 2,627.23 -2,442.19 6,034,201.35 518,228.91 1.38 2,442.19 MND+IFR2+SAG+MS (5) 9,539.46 92.16 270.90 3,585.41 3,536.16 2,629.09 -2,536.84 6,034,202.95 518,134.27 0.70 2,5%M MN4D+IFR2+SAG+MS(5) 9,633.67 91.20 270.15 3,582.64 3533.39 2,629.95 -2,631.01 6,034,203.55 518,040.11 1.29 2,631.01 MND+IFR2+SAG+MS (5) 9,728.12 89.96 270.93 3,581.69 3,532.44 2,630.84 -2,725.44 6,034,204.18 517,945.68 1.55 2,725.44 MWD+IFR2+SAG+MS(5) 9,823.96 88.81 269.09 3,582.72 3,533.47 2,630.86 -2,821.11 6,03.203.93 517,850.02 2.27 2,821.11 MWD+IFR2+SAG+MS(5) 9,914.61 88.86 268.34 3,584.56 3535.31 2628.82 -2,911.88 6,034,201.64 517,759.27 0.83 2,911.88 MND+IFR2+SAG+MS(5) 10,007.19 88.97 267.08 3,586.32 3,537.07 2,625.12 -3,004.37 6,03.197.68 517,666.80 1.37 3,004.37 MWD+IFR2+SAG+MS(5) 10,098.08 91.19 267.57 3,586.19 3,536.94 2,620.88 -3,095.15 6,034,193.19 517,576.04 2.50 3,095.15 MND+IFR2+SAG+MS (5) 10,189.26 94.44 269.99 3,581.71 3,532.46 2,618.94 3,186.18 6,03.191.00 517,485.02 4.44 3,186.18 MND+IFR2+SAG+MS(5) 10,279.42 91.27 269.09 3,577.22 3,527.97 2,618.22 -3,276.22 6,034,190.02 517,395.00 3.65 3,276.22 MWD+IFR2+SAG+MS(5) 10,372.10 90.39 270.02 3,575.88 3,526.63 2,617.50 -3,368.88 6,034,189.04 517,302.35 1.38 3,358.88 MND+IFR2+SAG+MS (5) 10,464.33 90.90 272.03 3,574.84 3,525.59 2,619.15 -,461.09 6,034,190.44 517,210.15 2.25 3,461.09 MWD+IFR2+SAG+MS(5) 10,556.19 90.60 273.13 3,57364 3,524.39 2,623.28 3,552.84 6,034,194.32 517,118.39 1.24 3,552,84 MWD+IFR2+SAG+MS(5) 10,649.51 93.96 272.74 3,569.92 3,520.67 2,628.05 -3,645.95 6,03.198.83 517,025.27 3.62 3,645.95 MND+IFR2+SAG+MS (5) 10,741.07 93.61 271.74 3,563.88 3,514.63 2,631.63 -,737.24 6,034,202.15 516,933.98 1.15 3,737,24 MND+IFR2+SAG.MS (5) 10,833.30 89.57 271.21 3,561.32 3,512.07 2,634.00 -3,829.39 6,03.204.26 516,841.84 4.42 3,829.39 MND+IFR2+SAG+MS (5) 10,926.24 88.94 269.83 3,562.53 3,513.28 2,634.84 -3,922.31 6,034,204.85 516,748.92 1.63 3,922.31 MND+IFR2+SAG+MS (5) 11,018.79 90.51 270.79 3,562.97 3,513.72 2,635.34 4,014.86 6,03.205.09 516,656.39 1.99 4,014.86 MND+IFR2+SAG+MS (5) 11,109.83 92.41 269.81 3,560.66 3,511.41 2,635.82 4,105.86 6,034,205.31 516,565.39 2.35 4,105.86 MND+IFR2+SAG+MS(5) 827/2019 3:48.17PM Page 5 COMPASS 5000.14 Build 85H ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 3R-112 Project: Kuparuk River Unit TVD Reference: 3R-112 Actual @ 49,25usft (D142) Site: Kuparuk 3R Pad MD Reference: 3R-112 Actual @ 49.251(D142) Well: 3R-112 North Reference: True Wellbore: 3R-112 Survey Calculation Method Minimum Curvature Design: 3R-112 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc A[i TVD TVDSS +NIS *El -W Northing Earning OLS Section (uaft) (•) (1) (wiry (usft) (waft) (osft) If" (ft) (°1100') (ft) Survey Tool Name 11,201.06 96.50 270.69 3,553.57 3,504.32 2,635.21 4,196.79 6,034,205.46 516,474.47 4.59 4,196.79 MWD+IFR2+SAG+MS(5) 11,293.02 97.05 272.79 3,542.72 3,493.47 2,638.99 4,288.06 6,034,207.97 516,383.20 2.35 4,288.03 MWD+IFR2+SAG+MS(5) 11,386.49 94.45 272.27 3,533.36 3,484.11 2,643.09 -4,380.97 6,034,211.82 516,290.30 2.84 4,380.97 MWD+IFR2+SAG+MS(5) 11,478.85 89.15 271.86 3,530.46 3,481.21 2,646.41 4,473.19 6,034,214.89 516,198.07 5.76 4,473.19 MWD+IFR2+SAG+MS(5) 11,528.46 HAS 272.70 3,531.48 3,482.23 2,648.39 -4,522.75 6,034,216.72 516,148.51 2.17 4,522.75 MWD+IFR2+SAG+MS(5) 11,571.23 88.04 271.42 3,532.78 3,483.53 2.649.92 -4,565.47 6,034,218.14 516,105.79 3.16 4,565.47 MWD+IFR2+SAG+MS(5) 11,663.24 89,47 269.96 3,534.78 3,485.53 2,651.03 4,657.44 6,034,218.99 516,013.82 2.22 4,657.44 MWD+IFR2+SAG+MS (5) 11,756.40 91.71 267.60 3,533.82 3,484.57 2,649.05 -4,750.57 6,034,216.75 515,920.72 3.49 4,750.57 MWD+IFR2+SAG+MS (5) 11,847.93 91.34 267.04 3,531.39 3,482.14 2,644.77 4,841.96 6,034,212.22 515,829.34 0.73 4,841.96 MWD+IFR2+SAG+MS (5) 11,939.33 93.21 267.4 3,527.76 3,478.51 2,640.05 4,933.16 6,034,207.25 515,738.16 2.05 4,933.16 MWD+IFR2+SAG+MS(5) 12,031.92 93.47 268.43 3,522.36 3,473.11 2,636.40 5,025.52 6,034,203.34 515,645.82 1.52 5,025.52 MWD+IFR2+SAG+MS(5) 12,124.30 90.28 267.14 3,519.34 3,470.09 2,632.83 5,117.77 6,034,199.51 515,553.59 3.72 5,117.77 MWD+IFR2+SAG+MS(5) 12,215.31 WAS 265.80 3,520.17 3,470.92 2,627.23 5,208.60 6,034,193.66 515,462.79 2.29 5,208.60 MWD+IFR2+SAG+MS(5) 12,307.70 90.33 268.17 3,520.96 3,471.71 2,622.37 5,300.85 6,034,188.54 515,370.57 3.13 5,300.85 MWD+IFR2+SAG+MS(5) 12400.73 92.44 270.07 3,518.72 3,469.47 2,620.94 5,393.83 6,034,186.86 515,277.60 3.05 5,393.63 MWD+IFR2+SAG+MS(5) 12,492.48 94.16 273.77 3,513.43 3,464.18 2,624.01 5,485.36 6,034,189.67 1 4.44 5,485,36 MWD+IFR2+SAG+MS(5) 12,583.09 92.94 272.12 3,507.82 3,456.57 2,628.65 5,576.67 6,034194.03 515,095.75 2.26 5,575.67 MWD+IFR2+SAG+MS(51 12,636.21 92.35 271.% 3,505.37 3,456.12 2,630.54 5,628.70 6,034,195.80 1 1.15 5,628.70 MWD+IFR2+SAG+MS(5) 12,694.86 92.35 271.96 3,502.97 3,453.72 2,632.55 5,687.27 6,1 514,984.16 0.00 5,687.27 Interpolated Station 4112" 12,697.00 92.35 271.% 3,502.88 3,453.63 2,632.62 5,689.40 6,034,197.71 514,982.02 0.00 5,689.40 PROJECTED W TD 8272019 3:48:17PM Page 6 COMPASS 5000.14 Build 85H Cement Detail Report 3R-112 String: Conductor Cement Job: Cement Details Description Conductor Cement Cementing Start Date 4/30/2019 10:30 Cementing End Date 4/30/2019 14:30 Wellbore Name 3R-112 Comment Cement Stages Stage # <Stage Nuntl Description Conductor Cement ObjectiveTop Cement to Surface Depth (ftKB) 8.0 Bottom Depth (ftKB) 173.0 Full Return? Yes Vol Cement... Top Plug? Yes Btm Plug? No O Pump Init (bbl/m... O Pump Final (bbl/... O Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Fill Cement Fluid Description Estimated Top (ftKB) 8.0 Est Btm (ftKB) 173.0 Amount (sacks) Class Volume Pumped (bbl) Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1/1 ReportPrinted: 9/11/2019 Cement Detail Report 3R-112 String: Surface Casing Cement Job: Cement Details Description Cerner ting Start Date Cementing End Date Wellbore Name Surface Casing Cement 8/112019 22:30 8/2/2019 02:00 3R-112 Comment Line up & SLB pump 5 bbls CW 100. Pressure test lines to 3500 psi, good. Pump 40.7 bbis of CW 100 @ 4.5 bpm, 246 psi, FO 8%. Batch up and pump 79.4 bbls of 10.5 ppg MP II @ 4.5 bpm, 175 psi, drop bottom plug & start batching lead. Pump 445.5 bbls of 11.0 ppg lead cement at 6.2 bpm, 449 psi, FO 12%. Land bottom plug at 220 bbls pumped. While reciprocating, the casing string took weight 9' off the landing ring. Attempted to work pipe free with no success. (At the time the string took weight 891bbl. of Lead cement had passed the shoe) 11.0 ppg Lead cement to surface 443bbl pumped. Continue working pipe while Tail was being batched up. Pump 63.4 bbls of 12 ppg tail cement @ 2-6 bpm, 510 psi, FO 11%. Drop top plug & kick outwith 10.3 bbls of fresh H2O. Swap to rig & displace w/ 9.5 ppg spud mud @ 70 bpm, 487 psi, FO 11%. Reduced rale to 2bpm. Bump plug with 2106 strokes, Pressure up from 275 psi. to 795 psi. & hold for 5 minutes. Bleed off pressure, Check Floats (good). CIP 02:00 his 08102/19. 287 bbl. 11 ppg cement to surface. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Bum Plug? Surface Casing Cement Cement to Surface 40.0 2,391.9 No 287.0 Yes Yes Q Pump Init (bbllm.. O Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 5 2 6 275.0 795.0 Yes 18.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) 19718 Drill OM Diameter (in) 2,295.0 Drill Bit 2,406.0 Comment Bumped plug at 2106 stks. 287 bbls cement back to surface. Floats held. Emergency slip were set. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Stat (ftKB) Amount (sacks) Class Volume Pumped (bbl) CW100 0.0 0.0 0 0 40.7 Yield (f -Isack) Mix H2O Ratio (galisa... Free Water (%) Density (Ib/gal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Deacdption Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) 1 Class Volume Pumped (bbl) MudPush II 0.0 0.0 79.4 Yield (ft /sack) Mix H2O Ratio (gallsa... Free Water (%) Density (lblgal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 40.0 1,901.0 1,316 1445.5 Yield (felsack) Mix H2O Ratio (gallsa... Free Water (%) Density (Iblgal) Plastic Viscosity (cP) Thickening Time (hr) jCmpr3tr 1 (psi) 1.90 6.( 1 11.00 78.8 7.36 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 1,901.0 2,405.0 217 163.4 Yield (ftYsack) Mia H2O Ratio (gallsa... Free Water (%) Density (Iblgal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr t (psi) 1.65 5.60 12.00 108.8 3.27 Additives Additive Type Concentration Conc Unit label Page 111 ReportPrinted: 9111/2019 Cement Detail Report - 3R-112 String: Intermediate Casing Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 8/8/2019 07:30 8/8/2019 09:48 3R-112 Comment Load tat bottom plug. Pump 5 bbls Mud Push. Test lines to 4000 psi. Pump 46.8 bbis of 13.5 ppg Mud Push II, 3 bpm, 260 psi -160, 2-3% Flow out. Load 2nd bottom plug. Batch up and pump 149 bbls 15.8 ppg Class G cement - pump rate 6 bpm, 296 psi, 7% Flow out. Load top plug. Schlumberger pump 10.0 bbls water. Swap to rig and displace with 9.2 ppg. 289.6 bbl. LSND. @ 8 bpm. 115/909 psi. 21% flow out. Stop reciprocating and landed hanger @ 2100 strokes. Slowed to 3 bpm, 909 psi. bump plug @ 2756 strokes. Pressure up to 1700 psi and hold for 5 mins. CIP at 09:48 hrs. Checked floats (good). Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Retum? Vol Cement... Top Piug? Btm Plug? Intermediate Casing 3,728.0 6,390.0 No 0.0 Yes Yes Cement O Pump Init (bbl/m... O Pump Final (bbl/... O Pump Avg (bbl/...P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 6 3 6 909.0 1,700.0 Yes 120.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est BIT(ftKB) Amount (sacks) Class Volume Pumped (bbl) Mud Push II 2,548.0 3,728.0 46.8 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) Cmprmr 1 (psi) 13.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 3,728.0 6,390.0 721 G 149.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) 1.18 5.0 1 15.80 184.4 4.50 Additives Additive Type Conc Unit label `Concentration IJ Page 1/1 ReportPrinted: 9/11/2019 P7 -P 219-095- Loepp Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Saturday, August 17, 2019 5:12 PM To: Woodard, Madeline E Subject: Re: 311-112 Intermediate Cement Job Evaluation Thank you. Cement looks good. Sent from my iPhone On Aug 17, 2019, at 4:23 PM, Woodard, Madeline E <Madeline E Woodard@conocophillips.com> wrote: Victoria, Please see the attached document on the 3R-112 intermediate cement job per the PTD Conditions of Approval. Let me know if you would like any more information. Thanks, Madeline Woodard Drilling Engineer ConocoPhillips Alaska, Inc Office: 907-265-6086 Mobile: 907-764-8095 <311-112 Intrm Cement Review.pdf> 11 ]CL ' w ��W/ Ye CL E a N �-i M c w O ,Q 0 CL M 0 O ` al F _ S N 5 O �' m C O \ a >O 9 dA o E 9 p ~ .N c 3 ca 0) o0 lV a) (, a N N U o 3 00 9 _ aa) L c�a M L Q Ln i N p O ate+ 9 � O O_ a) O ^ a ("O p to Q o e O_ a 8 s 8 8 8 v 8 8 8 tf Zn >- ao 4� a O "a °�° M =3 M CL E N O �' m C O \ >O dA o E p ~ .N c 3 ca 0) o0 lV a) (, N N U o 00 _ aa) L c�a M L Q Ln i N p O ate+ O O_ a) O ^ O ("O p to Q o OD O_ C �, '� O �' v p °° CU Zn >- ao 4� a O "a °�° M =3 O 0 0 00 L V1 w s _ O LnL tip dA m .Q �' E c Eto Ln O C m U c p .� N O v +�. v t v 3 ra p M -' OI O 00 N N n V 'a OC w N m N O N H m H 0 s • o • a . o • • • e � I� U a tri LL V • o e o Schlumberger SonicScope Top of Cement m $ c 25 412 h J E E 2300'to 11) n � E .: • ConocoPhillips 11It 1 m �3 € � Imams API# 500292i5t71g00 Elevah'ms: Field: KWWk Reser 7' XE 1,660,703.56 T� D.F. 49.3 ft (;L981 9.6ft ; 2 12 1 m N M n o J$ o �u V:N 6,031,333.24 ryry a > z g COMPANY: ConocoPhillips Alaska LLC. WELL: 3R-112 a FIELD: Kuparuk River v STATE: Alaska § g � COUNTRY: USA .. V y 4 0 a 0 H 0 o 0 v cn ■ 0 cn 0 0 ! # ! ! § §! �! ( # | f | ® | ! ƒ ! ! i/ ! t k! ! \! ! m , . ! �§ a- f!!' . � #/ _!!! / // ) Ing 7 R \/\; @ }/| Hit � )\ THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, West Sak Oil Pool, KRU 3R-112 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-085 Surface Location: 1782' FNL, 2908' FEL, SEC. 9, T1 3N, R9E, UM Bottomhole Location: 4595' 3310' FEL, SEC. 5, T13N, R9E, UM Dear Mr. Alvord: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .00gcc.alaska.gov Enclosed is the approved application for the permit to drill the above referenced service well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Commissioneer,�i� DATED thisw" day of June, 2019. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL on AAr 99 ring RECEIVED JUN 0 4 2019 1 a. Type of Work: 1 1 b. Proposed Well Class: Exploratory - Gas ❑�VService -'WAG ❑ Service -Disp ❑ Drill Q Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑ Service- Winj El Single Zone ❑ Rednll ❑ Reentry ❑ Exploratory -Oil ❑ Development -Gas ❑ Service -Supply ❑ Multiple Zone ❑ 2. Operator Name: 5. Bond: Blanket ❑ Single Well �] ConocoPhillips Alaska, Inc. Bond No. 59-52-180 1c. Spec i is r: Coalbed Gas ❑ Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 11. Well Name and Number: KRU 3R-112 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 12,359' ND: 3,464' 12. Field/Pool(s): Kuparak River Field West Salk Oil Pool 4a. Location of Well (Governmental Section): Surface: 1782' FNL & 2908' FEL, Sec 9, T13N, R9E, UM Top of Productive Horizon: 4887' FNL & 2049' FEL, Sec 4, T13N, R9E, UM Total Depth: 4595' FNL & 3310' FEL, Sec 5, T13N, R9E, UM 7. Property Designation: ADL355023, ADL355024, ADL373301 8. DNR Approval Number: 31933000 931934000 9319530007/18/2079 931933000,931934000,931953000L/ 13. Approximate Spud Date: 9. Acres in Property: 3255, 1817, & 677 14. Distance to Nearest Property: 4595'to ADL390616 - 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 520678.16 y- 6,031,581.19 Zone- 4 10. KB Elevation above MSL (ft): 48.9' GL / BF Elevation above MSL (ft): 9.8' 15. Distance to Nearest Well Open to Same Pool: 2402'to 3R-102 16. Deviated wells: Kickoff depth: 300 feet Maximum Hole Angle: 98.78 degrees 17. Maximum Pots tial Pressures Downhole: 1 psi ' /6�a in psig (see 20 AAC 25.035) /2 �8 Surface: 1 psi '' 18. Casing Program: Specifications Hole Casing Weight Grade Coupling Length 42" 20" 94# H-40 Welded 80' Top - Setting Depth - B 6m MD ND MD ND Surf Surf 119' 119' I Cement Quantity, c.f. or sacks (including stage data) Existing, cement to surface 13-1/2" 10-3/4" 45.5# L-80 HYD563 2495' Surf Surf 2495' 2238' 1sx 11.0 ppg, 192 sx 12.0 ppg 27567 9-7/6" 7-5/8" 29.7# L-80 HY0563 5963' Surf Surf 5963' 3648' 6 sx Clas'G1 G 15.8 ppg 6-3/4" 4-1/2" 12.6# L-80 HYD563 6547' 5812' 3632' 12359' 3464' N/A 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth ND (ft): Junk (measured): Casing Length Size Cement Volume MD ND Perforation Depth MD (ft): Perforation Depth ND (ft): Hydraulic Fracture planned? Yes❑ No ❑- 20. Attachments: Property Plat ❑ BOP Sketch Diverter Sketch Drilling Program Seabed Report Time v. Depth,Plot Ddlling Fluid Program Shallow Hazard Analysis 20 AAC 25.050 requirements 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 Name: Madeline Woodard Authorized Name: Chip Alvord Contact Email madeline.e.woodard c0 .com Authorized Title: Alaska Drilling Manager Contact Phone: 907-265-6086 Authorized Signature: -� Date: ` 1201 Commission Use Only Permit to Drill API Number: Permit Approva See cover letter for other Number: 2,11 -0,85 50- Q - OO - OO Date: requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methan✓e, gas hydrates, or gas contained in shales. [� Other: ©QP t' -Of /0 3800 3-r Samples req'd: Yes❑ No[q Mud log req'd: Yes❑ Note / ei o r.la rP rew- trr 7t to 25-oc p -S J12S measures: YesE1 Noy ❑ Directional svy req'd: Yes [VNO[][VNO[]Spacing exception req'd: Yes No Inclination -only svy req'd: YesNo Eg" proVJd,r tht/ CCSr-r Qf Post initial injection MIT req'd: Yes [3"No❑ X06 S�mY' a-� a5 S �to4cc . C'Cmtr-ri'�obJC'rlmplct� � z5', o351ti) lZ, ,fi1tGQ}fG1LHfC/ .Ci�<C /� �tr-d ���ro20aff�C y)Y Z✓ V R APPROVED BY G I r Za I �. .__.,.....,. w.,. COMMISSIONER THE COMMISSION Date:Submit Form and 110111 the date OvelIVI'MITIMM, --- %al Hems F1 uuyn— lql-c 10/2'0/m r) " ;9 ORIGINAL .�'�'�i a>tl- ft KRU 3R-112(PTD 219-085) Conditions of Approval: Approval is granted to run the (USIT)Sonic on upcoming well KRU 311-112 (with the following provisions: 1. CPA] will provide a written log evaluation/interpretation to the AOGCC along with the log as soon as they become available. The evaluation is to include/highlight the intervals of competent cement (and lengths) that CPAI is using to meet the objective requirements for annular isolation, reservoir isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation is not acceptable. 2. (USIT)Sonic logs must show free pipe and Top of Cement, just as the a -line log does. CPAI must start the log at a depth to insure the free pipe above the TOC is captured as well as the TOC. Starting the log below the actual TOC based on calculations predicting a different TOC will not be acceptable. 3. CPAI will provide a cement job summary report and evaluation along with the cement log and — evaluation to the AOGCC when they become available 4. CPAI will provide the results of the FIT when available. 5. Depending on the cement job results indicated by the cement job report, the logs and the FIT, remedial measures or additional logging may be required. Application for Permit to Drill, Well 3R-112 Saved: 4 -Jun -19 June 4, 2019 Alaska Oil and Gas Conservation Commission 333 West Th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill Well 3R-112, a West Sak D Sand Injector Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a permit to drill an onshore grassroots injector well from the 3R pad. The expected spud date for this well is July A 2019. It is planned to use rig Doyon 13 =360'k 3R-112 is planned to be a horizontal injector in the West Sak D sand. The surface section will be drilled with a 13-1/2" bit and cased with 10-3/4" casing to ±2,495' MD / 2,238' TVD. The intermediate section will be drilled with a 9-7/8" bit and cased with 7-5/8" casing to±5,963'MD / 3,648' TVD. The production section will be drilled with a 6-3/4" bit in the West Sak D sand +/- 12,359' MD / 3,464' TVD and lined with a 4-1/2" slotted liner. The upper completion will be run with 4-1/2" tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser setup. If you have any questions or require further information, please contact Madeline Woodard at 265-6086 (madeline.e.woodard@cop.com) or Chip Alvord at 265-6120. Sincerely, A--- a-�- Chip Alvord Drilling Manager Application for Permit to Drill Document Kuparuk Well 311-112 Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as KRU 3R-112 Dr0ling =� &Wells ConocoPhilllpi Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of die following items. evicepi for an itent ah'eady on file with the commission and identified in the application: (2) a plat identif)'ing the properqand the property's owners and shoring (A) the coo, dinates of the proposed location of the well at the surface, at the top of each abjeetire formalion. and at total depth referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Ot'eanic and Atmospheric Administration; (C) the proposed depth of the hell at the top of each objective formation and at total depth; Location at Surface 1782' FNL & 2908' FEL, Sec 9, T13N, R9E UM NGSCoordmates Northings: 6,031,581.19' Eastings: 520678.16' RK11, 48.9' AMSL Pad Elevation 9.8'AMSL Location at Top of 4887' FNL & 2049' FEL, Sec 4, TI 3N, R9E, UM Productive Interval (West Sak D Sand) NGS Coordinates Northings: 6,033,757.4' Eastings: 521525.6' Location at Total Depth 4595' FNL & 3310' FEL, Sec 5, T13N R9E, UM NGS Coordinates Northings: 6,034,033.08' Eastings: 514983.46' Measured De th, RKB: 1 12,359' 1 Total Vertical Depth, RKB: I3,464' Total Vertical Depth, SS: 1 3,415' and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Fain, 10-401) ,trust (1) include a plat, drairn to a suitable scale, shoring the path of the proposed wellbore, including all adjacent a ellbores within 100 jeer of any portion of the proposed well: Please see Attachment: Directional Plan And (1) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to tie extent that those names are known or discorerable in public records, and shoe that each named operator las been furnished a copy of the application by certified nail: or (B) state that the applicant is the am) affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the follmring items, excepl for' an item already on file with the commission and identified in the application: (3) a diagram and description of tire blowout prerention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, 0'.20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 142 and attachment. r Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) .An applicaian far a Permit to Drill must be occompamed by each of the following items, except far on item alreadv on file with the commission and identified in the application: (4) information on drilling hacards, including (.4) the maximum downhole pressure that may be encountered. criteria used to determine it, and maximum potential surface pressure based on a methane gradient The maximum potential surface pressure (MPSP) while drilling 3R-112 is calculated using an estimated maximum reservoir pressure of 1,640 psi (based on 3R-102 downhole gauge data and reservoir modeling), a gas gradient of 0.10 psi/ft, and the estimated depth of the West Sak D sand at 3,625' TVD: D Sand Estimated. BHP = 1,640 psi D Sand estimated depth = 3,625' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 362 psi (3,625 TVD * 0.10 psi/ft) C� MPSP = BHP — gas column =1278 psi 1640 psi — 362psi) (B) data on potential gas =ones: The well bore is not expected to penetrate any shallow gas zones. And (C) data concerning polential (arses of hole problems such as abnoorall_v geo pressured snag, lost circulation cones, and =ones thal have a propensm' for differential slicking; See attached 3R-112 Drilling Hazards Summary Reauirements of 20 AAC 25.005 (c)(5) An application fora Permit to Drdi mast be accompanied by each of the following items, except for an item already on file with the commission and identified in the applicalam (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(flr A procedure is on file with the commission for performing LOT'S. Casing and Cementing Program Requirements of 20 AAC 25.005(()(6) An application far a Permit to Drill must be accompanied by each of the following items, except for an item already on fife with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description ofany slopped liner. pre -perforated liner, or sm'een to be installed Casing and Cement Program Casio and Cementin P ram Csg/Tbg OD Hole Sze Weight Grade Conn. I Length Top MD/TVD Btm AID/2'VD CementProgram (in) f7blft) 0�) �) 20 42 94 H-40 Welded 80 Surf 119/119 Existing Cement to Surface with 10-3/4 13-I2 45.5 L-80 HYD563 2,495 Surf 2,495/2,238 1275 sx LiteCRETE Lead 11.0 ppg, 192 sx DeepCRETE Tail 12.0 667 sx Class Gat 15.8 ppg 7-5/8 9-7/8 29.7 L-80 HYD563 5,963 Sud 5,963 13,648 w/ TOC at 3,403' MD 4-12 63/4 12.6 L-80 HYD563 6,547 5,812 / 3,632 12,359 / 3,464 N/A 10-3/4" Surface casine run to 2,495' MD / 2,238' TVD Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except foran identified in the application.' (4) information on drilling hacards, including (A) the maximum downhole pressure that ma)' be encmmtei ed, criteria used to delermine it andl, methane gradient; The maximum potential surface pressure (MPSP) while drilling maximum reservoir pressure of 1,565 psi (based on 3R-102 dov 1539 psi, 8.3 ppg equivalent, and corrected to depth), a gas grad of the West Sak D sand at 3,625' TVD: D Sand Estimated. BHP= 1,565 psi D Sand estimated depth = 3,625' TVD ahead), on file with lire commission and potential surface pressure based on a 112 is calculated using an estimated le gauge data giving a pressure of of 0.10 psi/ft, and the estimated depth *- 8.3 M W9 Gas Gradient = 0.10 pIflygeo-pi per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 362 p,625 TVD * 0.10 psi/ft) MPSP = BHP — gas column =1,203 ,565 psi — 362 psi) $.3 FF1 (B) data on potential gas cones: The well bore is not expected to penetrate any shalloes. 323 And (C) data concerning potential causes ofhole problems such, abnmessured strata. lost cucidation cones and=ones that have a propensity for dii fer'email sticking; See attached 3R-112 Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by identified in the application.: (5) a description of the procedure for conducting formation i. A procedure is on file with the commission Casing and Cementing Program Requirements of 20 AAC 25.005(cl(61 An applicalion,(or a Permit to Drill otos; be accampim by each identified in the application: (6) a complete proposed casing and cementing progran as require screen to be installed Casing and Cement Program items. except fm' an item already on file with the commission and as required under 20 AAC 25.030(t): LOT'S. of tre folloring items. except for an item already on file with the commission and it by M AAC 25.030, and a description of any slotted liner, pre -perforated liner, or Ca ing and ementing Pro ram Cs /Tb OD g g Hole Size Weight g Grade C nn. Length g To MD/TVD P Bum MD/TVD Cement Program (in) in PIP (f) 00 Ut) 20 42 94 H-40 elded 80 Surf 119/119 Existing Cement to Surface with 10-3/4 13-1/2 45.5 L-80 I HYD563 2,495 Surf 2,495 / 2,238 1275 sx LiteCRETE Lead 11.0 ppg, 192 sx Dee CRETE Tail 12.0 ppg 667 sx Class G at 15.8 ppg 7-5/8 9-7/8 29.7 L-80 HYD563 5,963 Surf 5,963 / 3,648 w/ TOC at 3,403' MD 4-1/2 6-3/4 12.6 L-80 HYD563 6,547 5,812 / 3,632 12,359 / 3,464 N/A fM'tj 10-3/4" Surface casine run to 2,495' MD / 2,238' TVD Cement from 2,495' MD to 1,995'(500' of tail) with 12.0 ppg DeepCRETE, and from 1,995' to surface with 11.0 ppg LiteCRETE. Assume 250% excess annular volume for lead in the permafrost and 50% annular excess below the permafrost, 0% excess in 20" conductor, and 50% excess for tail. 10-3/4" Surface Casing Design: Single stage 15.8 ppg Class G slurry with 35% excess in OH Design: 11.0 ppg lead slurry from 1995' to surface and 500' of 12.0 ppg tail slurry Cement yield Lead Cement yield= 1 1.91 ft3/sk I Tail Cement yield = 1.65 ft3/sk 11.0 ppg LiteCRETE Lead Slurry Shoetrack Conductor 5.5 bbls 119'x 0.24302 bbl/ft x 1.0 (0% excess) 28.9 bbls Base permafrost to conductor 667 sx (1837'- 119) x 0.06478 bbl/ft x 3.5 (250% excess) 389.5 bbls Btm of lead to base permafrost (1995'- 1837) x 0.06478 bbl/ft x 1.5 (50% excess) 15.4 bbls Total Lead Cement 433.8 bbls 2435.7 ft3 1275 sx 12.0 ppg DeepCRETE Tail Slurry Shoe to Top of Tail 500'x 0.06478 bbl/ftx 1.5 (50916 excess) 48.6 bbls Shoetrack 80'x 0.096175 bbl/ft x 1 (0% excess) 7.7 bbls Total Tail Cement 56.3 bbls 316.0 ft3 192 sx 7-5/8" Intermediate casing run to 5,963' MD / 3,648' TVD Single stage slurry is designed to be placed from TD to 3,403' NM, which is 500' MD above top of the Ugnu B with 35% excess annular volume. 7-5/8" Intermediate Casing Design: Single stage 15.8 ppg Class G slurry with 35% excess in OH Cement yield I 1.16 ft3/sk 15.8 ppg Class G Slurry Shoeto TOC (5963'- 3403')'x 0.03825 bbl/ft x 1.35 (35% excess) 132.2 bbls Shoetrack 120' x 0.0.04592 bbl/ftx 1 (0% excess) 5.5 bbls Total Tail Cement 137.7 bbis 773.1 ft3 667 sx Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the follmving items, except for an item already on file a ith the commission and identified in the application: (7) it diagram and description of the diverter system as required by 20 AAC 25.035. unless this, eguirenreni is it owed by the commission under 20 AAC 25.035(h)(2): It is requested that a variance of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. At 3R, there has not been an indication of shallow gas or gas hydrates through the surface hole interval. The previously drilled 3R-20 well is within 500' (208') from the proposed 3R-112 base of permafrost location, this well did not encounter any shallow gas. r\ 06(19ly Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An appllmhon for a Permit to Drill most be accompanied by each of the follmving items. except fur an item ah-eady on file ivith the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drillingflurd system, as required b} 20 AAC 25.033: Mud Program Summary Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Penrrit to Drill must be acconryanied by each of the following Reins. except for an item already on file with the corrrmission anal identified in the application: Surface Intermediate Production 13-1/2" Hole 9-7/8" Hole 6-3/4" Hole 10-3/4" Casing 7-5/8" Casin 4-1/2" Liner Mud System Spud WBM) LSND (WBM) FloPro NT (WBM Density 8.8-9.5 9.0-9.5 9.0 — 9.5 ppg PV ALAP ALAP ALAP YP 30-80 20-30 15-20 Funnel Viscosity 250-300 Permafrost Base 100-150 to TD N/A N/A Initial Gel 30-50 9-11 7-10 10 -minute Gel 30-50 <20 8-16 API Filtrate NC <6 <6 HTHP Fluid Loss at 160° F N/A < 10 <10 H 10.8-11.2 9.5-10.0 9.5-10.0 Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Penrrit to Drill must be acconryanied by each of the following Reins. except for an item already on file with the corrrmission anal identified in the application: r The proposed drilling program is included below. Please refer to Attachment 4 for proposed well schematic. 1. Move in / rig up Doyon Rig 142. Install Annular with 16" diverter line and function test. Notify AOGCC 24 Ins before test. 2. Spud and directionally drill 13-1/2" hole to surface TD as per directional plan. Run MWD/LWD tools [gamma ray & resistivity] required for directional monitoring. 3. Run and cement 10-3/4", 45.5#, L80, HYD563 casing to surface. Displace cement with mud and check floats upon bumping plug. Notify AOGCC if top job is required. 4. Remove diverter system and install wellhead. Install and test 13-5/8" x 5,000 psi BOP'S to 250 psi low and 3,500 psi high (annular preventer to 3,500 psi). Notify AOGCC 24 Ins before test. 5. PU 9-7/8" bit and 6-3/4" drilling assembly, with MWD/LWD [gamma ray & resistivity]. RIH, clean out cement to top of float equipment and test casing to 3,000 psi for 30 min. 6. Drill out shoe track and 20' of new hole. Perform shoe test to a minimum of 11.5ppg EMW LOT and maximum 14.0 ppg EMW FIT, recording results. 7. Displace to 9.0 - 9.2 ppg LSND water-based drilling fluid. �O C C_ 8. Directionally drill to intermediate TD. 9. Circulate hole clean. BROOH. 10. Run and cement 7-5/8", 29.7#, L80, HYD563 ca/sing to surface. (Top of cement to be 500' MD above the Ugnu B sand) 11. Install 7-5/8" packoff and test to 5,000 psi. 12. Flush 10.75" x 7.625" annulus with water and freeze protect. 13. PU 6-3/4" bit and 4-3/4" drilling assembly, with MWD/LWD [gamma ray, resistivity, and sonic (only for cement evaluation)]. Log top of cement. Clean out cement to shoe track and test casing to 3,000 psi for 30 min. 14. Drill out shoe track and 20' of new hole. Perform shoe test to a minimum of 11.5 ppg EMW LOT and maximum 13.5 ppg EMW FIT, recording results. 15. Directionally drill to production TD. 16. Circulate hole clean. BROOH. 17. P/U and run 4-1/2", 12.6#, slotted liner, swell packers, and liner -top packer. 18. Set liner -top packer and pressure test for 10 minutes, chart results. 19. POOH and lay down running tools. 20. Pull wear bushing & run 4-1/2" 12.64 upper completion tubing. 21. Land hanger, run in lock screws, and test seals to 5,000 psi. 22. Set BPV and test in the direction of flow. 23. Nipple down BOPE, nipple up tree and test. Pull BPV. 24. Freeze protect 4.5" x 7.625" annulus 25. Set BPV and move off rig. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a permit to Drill roust be accompanied by each of the following items, except for an item ah'eady on file with the commission and identified in the application: (1 J) ageneral description ofhov the operator plans to dispose ofdrilling mud and cuttings and statement of whether the operator intends to request oulhoriration under 20 AAC' 25.OS0 for an annular disposal operation in the well.: Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class 11 disposal well (DS 1 B CRI), Milne Point, Prudhoe DS4. All cuttings generated will be hauled to the DS 1B CRI, Milne Point, Prudhoe Bay Grind and Inject Facility (for temporary storage and eventual processing for injection down an approved disposal well), or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 AOR Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 Well Schematic Attachment 5 BOP Configuration Attachment 1 AOR An Area of Review plot is shown below of the 3R-112 planned wellpath and offset wells. The included table identifies any of the offset wellbores within the 1/4 -mile review. pI° Mile View -0-a ,.� ME Quarter Tp-0pVRM AM£.p¢ii:.1+YN 1Y� FC��,yyy l4di..a'i r4LX�'Iet NN M¢ W Yl�Y ds IRAs, m�ua:rs..a': xeacnws�e vx �x �.. _ _ __T—... _ '.-ern m.'a'7 � • °� +'xsaz cicsv.-.,. �0. NSW# Ognt Sd ♦aoueu wff +x Mff, x-ec•aw. 5000 Q� 21000 __....... _.._ 3909 N 3 O 8 w � `„3000 + L I Z0 >2000-- 000 0 O � l000 b �P i n 0 i I � � -7000 I 9 -2000 -1000 ao0 1000 -6000 -5000 -4000 -36o0 Well Top of West SakDSand TOC TOC Determined Reservoir Zonal Isolation Cement Operations Name Status (MD/ (MD/TVD) By Status Summa Summary TVD) Pump 15.8 ppg Class G abandonment plug#I from Cement @ 11,037' MD to 10,700' MD. Oliktok Point Abandoned 7,776' MD / Planned: 6,992' MD / surface and abandonment Abandoned Abandoned well Pump 17 ppg Class G abandonment plug #2 from State 1 Well 3631'TVD , 3,381' TVD plug 42 6,650' to 6,350' MD. Pump tagged. cement from 270'MD to ground level. Pump 373 bbls of 12.3 ppg Class E lead cement 4,224' MD / Returns to Producing from Column of cement from followed by 95 bbls of 15.7 3R-14 Producer 3,522' TVD Surface surface Kuparuk A sand 4,120' TVD to surface ppg Class G tail cement. Saw cement at surface with 70 bids returned. Plugs 9,348' MD / 4,943' MD / bumped and Producing from Column of cement 250' TVD Pum 388 bbls of 15.8 ppg P 3R-101 Producer 3,601' TVD 2,983' TVD 24 bbls of Westnd. D above Ugnu B sand. Class G cement. cement lost sand. donna ic' v e 0 3R-112wp04 131/2" x 10-3/4" 9 7/8" x 7-5/8" Measured 0 A N F 6-3/4" x 4-1/2" o N ooD 6 60 I —Plan D142: 39.1 4 U.b L 4d.WUSTr (UDyon I o ti°o° -1 9w ed Up' ate i j ° j '^ 60 h0 O O O O 1410 — leao r O I O Plan Summa OlAtok PdntSMle� j'i--3R-111L1wpa3 ]8 25a "o 1500 3000 4500 6000 7500 9000 1050 30 ass — 440 fi-3/4" x 4-112" 3R-106xp03 iP9 pj 9 440 — 849 x 10-3/4" 9 7/8" x 7-5/8" Horizontal Depanure 3R-1 WL1wP91 640 830 0 ' - 6 60 830 1020 1020 1220 1220 —tato o -1 9w ed Up' ate '^ 60 3R-111L1w g 3R-107wy0at 1410 — leao 1050 — 2650 mR-111wp 4 2500 tot 3 2050 v 2500 — 2950 96 — 34. 030 - - — 3490 — 3850 saw saw 850 — 4300 270 4]00 1]50 m Equivalent Magnetic Distance 3 3 4750 — 5200 U52)0 BIDO 6100 — 8990 0 240 6 120 6996 — 7690 0 1750 3500 5250 7000 8750 10500 12250 890 — 6] 80 Measured Depth 3R- 150 105]0 87M — 9660 was 10570 HOO 114]0 12359 SURVEY `Hcvv�!V Surface _oration Pad Elevation'. 9.80 peplM1 From OepM1 Ta aurreyyRWn Ta01 39.10 1100.00 au"T u1r"4 (Plan: 3R-1121 G)%GC-ss 1100.00 2494.87 3R-1126"4 (Plan: 31-112) MWD OWSG 180 1100"0 2494.87 3R-112•.{"4 (Phis: 3R-112) MWDHFR2+SAG+MS TVD MD Name 2494+8] 3994.87 3R -112x1"4 (Phin: 3R-112) MWD OVmG 2237.802494.8713-1/2". 10-314" 2494.87 5962.63 3R-112xp04 (Plan: 3R-112) MWD«IFR2+SAG+MS 7462.63 314-112mp04 (Plan: 3R-112) MWD OW9G 3647.905982.63 9718'.7-50' Magnetic Model & Date: BGGM2018 30 -Jul -19 5962.83 5962.63 12359.18 3R-112wp04 (Plan: 3R-112) MWD+IFR2+SAG+MS 3463.902359.18 6s/4".4 -1n" Magnetic North is 16.50° East of True North (Magnetic Declination) Magnetic Dip & Field Strength: 80.95° 57417nT m am m.r,f.wmn nm m 6.m Lithology Calumn n Ana, m m mm oiwn rraw a'� msawuw Iosse,n um a:w .gym zwo w w ,mu.onesielw a. .3 sBase �� sum xm m,.m mem ama� w 'worms mew assmnonre Penna ,}.gym ..m m,.m }mss aw s�.xm��m msrtl.b.Xw ea a.mwmems s:m«.��,sa ' ®`.m }mre �;mu mom Fa b,ua f mY9 W X19 �m M4Y .tea 9 AY ffiIDL M1[.FR boort mm W .iaarmga�emv atl 3n4`1 O.IR[e, m�•6atl 9KM1[Kertd�6,9 Hl�mm }�9.19ffiam ..m .Ra�xr9 mmww 'ffiYm1YA44.bab ffi96m K15 .a'waii:�..w nm +m acztl.bvr mma�mux oras zn.mam m }am.n� zm!w`m �'m�',m 31p °Aosrw wase mm ua Xwm aunrwwx�atl. as.zn.b me }azo 1141 .1 n }'w'wo:m e° amm w® rma`os is' acne �Im}esa�nm auw}wawu m. s "mwzrrbam a om <rorwv,f.bmm a1.1.1ww nnnX } 'u Top Ugnu C ra n?g 2.1. in:eaa Or m.�maa o�+e m .sse'm'n wrnwzuux svnxnm aaFre.bnea. >,m.} rwms.z%sT Top Ugnu B Town. m .o` n: yim Top Ugnu A eim .}awns a�mm nn.a,wiamv n a" �`amo�u num mm w�am ass,. ere m an•,s v ,.e m manor%° r. �mm. as �.nsaXlems . a",.v "' �mnsv}rb Top N Sands m.me.imm vue m.s.zn.m,uaa visn y,'gt;Sak _a,wmw,sw eu m mw: nua am Ail By signing this Insure edge that have been fiforinned of all risks checked that thrto s aYm zum amaa.m}wnw completeness, and ietl,.' ,a ssims }wvss awY o dela is wrreG, ensured Its - all surrounding well] are assigned to urro ... ,:: M raw a.m }waw+w.Y more}rewacw .m rs.arwnm a eneam.,,mYn the proper position, and I approve the scan and collision avoidance plan as set gut it .. _ M wrs awm msm au,s the audit the basisfor the seal wellplanantiv plan tedrzteral Medapproveitas 'r"06Y1a" v13 RO am ms mw 'am,am also acknowledge that unless notified othervnse 100 all targets have a 100 feet lateral ■■ ,.w <`u.a - repared by zi e�ii� u v am oma..., Y„nw a ccd'eit�l I .. Approved by: J. Ryan M. Woodard V. Osara H. Bui L J O O"� d r g 3 0O 30�� y N M O Q �O N G g Q 6M M O� Q ryj O O N N O co W o M no rn v Os h M M p O M Q Oy ER o O M S LO M O �O', O' 009 V S M N O O N he o gb w 0 4- O a � a 0 0 M.O.. Oi9 M O m w M M M to RO f_ n : 09-- J 44�L- 09Q. q �o � "C� 0 M 6 M N. 2O p - �QCb Oc's D M M Y p O CL Os R N 0s 09 r 0C 09 rN 09P' Ma O J O Q N MM M M M � o O M 6 s 3 s (ui/ysn 009S) bu'gPON t O O O `7 O� Op O 00 0Z 000009 000 0001 RORM v O , n x ao b00 x N FLrn M o m 0008 0 0 + � N W 0006 o L N N i 00006 0 O V co i V ' /O/ i� ii O LO 3 00066 N V N ' Tom r o Lo M OOOU 65£Z6LO bOdMZ66 2�E O (V O O O V <LO LV Lx O O O O r O O O O Mi Cl) c - "v T+)ylJON/(-)43noS Cl) r O I I rn I � 59 I I 100 0 30 I i I I x W II II i I � M ■`J , I I O I LON � O 0 i I a I I x . I a I: II i I I ff u e r I I I I O O '^ v / � M I O O O a li I � N N b00 m p c 01000 I I ;6 I I U O O � II M r ' II I I I I � U II I o c I s 0 Ln � I co u! , W Q CL 3 ,I 3 :IL N r r o 00 W M O O O � O � O tto 00 Lr) LO 00 U0N M It 41daa leopeA anil 0 0. � II c O a I I x . I a r I I, m r I II M r ' ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit -2 Kuparuk 3R Pad Plan: 3R-112 50029xxxxx00 Plan: 3R-112 Plan: 3R-112wp04 Standard Proposal Report 29 May, 2019 ConocoPhillips ConocoPhillips Database: OAKEDMPI Company: ConocoPhillips Alaska lnc_Kupawk Project: Kuparuk River Unit -2 Site: Kuparuk 3R Pad Well: Plan: 3R-112 Wellbore: Plan: 3R-112 Design: 3R-112wp04 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: 3R-112 TVD Reference: Plan D142: 39.1 + 9.8 Q 48.90usft (Doyon Audit Notes: 142) MD Reference: Plan D142: 39.1 +9.8 @ 48.90usft (Doyon Easting; 142) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit 2, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor site Kuparuk 3R Pad Site Position: Audit Notes: Northing: From: Map Easting; Position Uncertainty: 0.00 usft Slot Radius: Vertical Section: Depth From (TVD) +NIS Well Plan: 3R-112 (usft) Well Position +N/ -S Northing: 39.10 +EI -W Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Latitude: Longitude: 0.000 in Grid Convergence: 0.16' Latitude: Longitude: Ground Level: 9.80 usft Wellbore Plan: 3R-112 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°l 1°l K) BGGM2018 7/30/2019 16.50 80.95 57,417 Design 3R-112wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.10 Vertical Section: Depth From (TVD) +NIS +E/ -W Direction (usft) (usft) (usft) (°) 39.10 0.00 coo 270.00 529/2019 11:1836AM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips Database: OAKEDMPI Local Co-ordinate Reference: Company: ConocoPhillips Alaska Inc_Kupamk ND Reference: Project: Kuparuk River Unit -2 MD Reference: Site: Kuparuk 3R Pad North Reference: Well: Plan: 3R-112 Survey Calculation Method: Wellbore: Plan: 3R-112 Design: 3R-112wp04 Plan Survey Tool Program Date 5/29/2019 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 39.10 1,100.00 3R-112wp04 (Plain 3R-112) GYD-GC-SS Gyrodata gyro single shots 2 1,100.00 2,494.87 3R-112wp04(Plan: 3R-112) MWD OWSG OWSG MWD - Standard 3 1,100.00 2,494.87 3R-112wp04(Plan: 3R-112) MWD+IFR2+SAG+MS OWSG MAID +IFR2+Sag +A 4 2,494.87 3,994.87 3R-112wp04(Plan: 3R-112) MWD OWSG OWSG MWD -Standard 5 2,494.87 5,962.63 3R-112wp04 (Plan: 3R-112) MWD+IFR2+SAG+MS OWSG MWD+ IFR2+Sag +h 6 5,962.63 7,462.63 3R-112wp04(Plan: 3R-112) MWD OWSG OWSG MWD - Standard 7 5,962.63 12,359.18 3R-112wp04(Plan: 3R-112) MWD+IFR2+SAG+MS OWSG MWD +IFR2+Sag +A ConocoPhillips Standard Proposal Report Well Plan: 311-112 Plan D142: 39.1 +9.8 @ 48.90usft (Doyon 142) Plan D142: 39.1 + 9.8 @ 48.90usft (Doyon 142) True Minimum Curvature 5/292019 tY 1896AM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips Database: 0AKEDMP1 Company: ConowPhillips Alaska Inc_Kupawk Project: Kuparuk River Unit -2 Site: Kupawk 3R Pad Well: Plan: 3R-112 Wellbore: Plan: 3R-112 Design: 3R-112wp04 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: 3R-112 TVD Reference: Plan D142: 39.1 + 9.8 @ 48.90usft (Doyon 142) MD Reference: Plan D142: 39.1 +9.8 @ 48.90usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature 0.00 0.00 105.00 0.00 0.00 -80.00 0.00 -95.32 0.00 -85.07 3R -B12 TOO WSD 04: 0.00 0.00 -77.78 0.00 -98.82 3R -B12 T03 042618 A -10.64 -170.52 -76.39 0.00 72.16 3R -B12 T05 042616 D 2.86 0.00 -178.86 3R -B12 T07 050318 1 -168.30 0.00 179.21 3R-812 TOB 0426181 -179.58 0.00 0.42 3R -B12 709 G426181 -0.19 0.00 179.81 3R -B12 T10 0426181 -178.88 0.00 1.12 3R -B12 T11 0426101 -0.05 0.00 179.94 3R -B12 712 042618 1 -179.87 0.00 0.28 3R -B12 T13042618 -0.13 0.00 0.74 3R -B12 T14042618 -0.06 0.00 5292019 11:18:36AM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips Database: OAKEDMPI Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kupawk River Unit -2 sue Kuparuk 3R Pad Well: Plan: 3R-112 Wellbore: Plan: 3R-112 Desian: 3R-112wp04 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: 3R-112 TVD Reference: Plan D142: 39.1 + 9.8 @ 48.90usft (Doyon 142) MD Reference: Plan D142: 39.1 + 9.8 @ 48.90usft (Doyon -3.75 142) North Reference: True Survey Calculation Method: Minimum Curvature 10,788.56 95.46 270.15 3,521.47 2,463.26 -4,120.56 3.75 -3.75 -0.04 -179.45 10,903.05 95.46 270.15 3,510.57 2,463.57 -4,234.52 0.00 0.00 0.00 0.00 11,085.09 90.00 270.16 3,501.90 2,464.07 -4,416.29 3.00 -3.00 0.00 179.95 3R -B12 T160426181% 11,085.34 89.99 270.16 3,501.90 2,464.07 -4,416.53 3.00 -2.46 -1.72 -144.99 11,260.43 89.99 270.16 3,501.92 2,464.54 -4,591.62 0.00 0.00 0.00 0.00 11,335.13 88.50 270.16 3,502.90 2,464.75 -4,666.31 2.00 -2.00 0.01 179.84 3R -B12 T17 042618 D 11,390.31 87.40 270.16 3,504.88 2,464.90 -4,721.46 2.00 -2.00 -0.01 -179.76 11,517.52 87.40 270.16 3,510.65 2,465.25 -4,846.54 0.00 0.00 0.00 0.00 11,572.34 90.00 270.16 3,511.90 2,465.40 -4,903.34 4.75 4.75 0.01 0.103R -B12 T18042618 t 11,721.54 97.09 270.15 3,502.68 2,465.80 -5,052.16 4.75 4.75 0.00 -0.05 11,731.07 97.09 270.15 3,501.51 2,465.83 -5,061.61 0.00 0.00 0.00 0.00 11,753.96 96.00 270.16 3,498.90 2,465.89 -5,084.35 4.75 -4.75 0.03 179.64 3R -B12 T19042618 A 11,851.46 91.37 270.16 3,492.64 2,466.16 -5,181.63 4.75 -4.75 0.00 -179.94 11,988.47 91.37 270.16 3,489.36 2,466.53 -5,318.60 0.00 0.00 0.00 0.00 12,004.26 92.00 270.16 3,488.90 2,466.57 -5,334.38 4.00 4.00 0.03 0.42 3R -B12 T20 042618 f 12,059.54 94.21 270.16 3,485.90 2,466.73 -5,389.58 4.00 4.00 -0.01 -0.10 12,359.18 94.21 270.16 3,463.90 2,467.54 -5,688.41 0.00 0.00 0.00 0.00 3R-812 T21 042618I, 5292019 11: 1896AM Page 5 COMPASS 5000.14 Build 66D ConocoPhillips Database: OAKEDMP7 Company: ConocoPhillips Alaska lnc_Kuparuk Project: Kuparuk River Unit -2 Site: Kuparuk 3R Pad Well: Plan: 3R-112 Wellbore: Plan: 3R-112 Design: 3R-112wp04 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Plan: 3R-112 Plan D142: 39.1 + 9,8 @ 48.90usft (Doyon 142) Plan D142: 39.1 + 9.8 @ 48.90usft (Doyon 142) True Minimum Curvature Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (weft) (') {°) (usft) (usft) (usft) (usft) (°1100usft) (°1100usft) (°/100us11) 39.10 0.00 0.00 39.10 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 0.00 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 0.00 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 0.00 KOP: Start 5.06'1100' DLS, 1.5° TF, for 200' 300.00 0.75 105.00 300.00 -0.08 0.32 -0.32 1.50 1.50 0.00 400.00 2.25 105.00 399.96 -0.76 2.84 -2.84 1.50 1.50 0.00 450.00 3.00 105.00 449.91 -1.35 5.06 -5.06 1.50 1.50 0.00 Start Build 2.50 500.00 4.25 105.00 499.81 -2.17 8.11 -8.11 2.50 2.50 0.00 600.00 6.75 105.00 599.34 -4.65 17.37 -17.37 2.50 2.50 0.00 700.00 9.25 105.00 698.36 -8.26 30.81 -30.81 2.50 2.50 0.00 800.00 11.75 105.00 796.68 -12.97 48.41 -48.41 2.50 2.50 0.00 900.00 14.25 105.00 894.11 -18.79 70.14 -70.14 2.50 2.50 0.00 1,000.00 16.75 105.00 990.46 -25.71 95.95 -95.95 2.50 2.50 0.00 1,100.00 19.25 105.00 1,085.56 -33.71 125.79 -125.79 2.50 2.50 0.00 1,200.00 21.75 105.00 1,179.22 -42.77 159.62 -159.62 2.50 2.50 0.00 1,300.00 24.25 105.00 1,271.26 -52.88 197.36 -197.36 2.50 2.50 0.00 1,400.00 26.75 105.00 1,361.51 -64.02 238.94 -238.94 2.50 2.50 0.00 1,500.00 29.25 105.00 1,449.80 -76.17 284.28 -284.28 2.50 2.50 0.00 1,600.00 31.75 105.00 1,535.96 -89.31 333.30 -333.30 2.50 2.50 0.00 1,700.00 34.25 105.00 1,619.82 -103.40 385.91 -385.91 2.50 2.50 0.00 1,769.10 35.98 105.00 1,676.34 -113.69 424.30 -424.30 2.50 2.50 0.00 T3 1,800.00 36.75 105.00 1,701.22 -118.43 441.99 -441.99 2.50 2.50 0.00 1,808.22 36.96 105.00 1,707.80 -119.71 446.76 446.76 2.50 2.50 0.00 Start 125.14 hold at 1808.22 MD 1,837.23 36.96 105.00 1,730.98 -124.22 463.60 463.60 0.00 0.00 0.00 Base Permafrost 1,900.00 36.96 105.00 1,781.14 -133.99 500.05 -500.05 0.00 0.00 0.00 1,933.36 36.96 105.00 1,807.80 -139.18 519.43 -519.43 0.00 0.00 0.00 Start DLS 3.60 TFO -80.00 2,000.00 37.42 101.22 1,860.90 -148.30 558.64 -558.64 3.50 0.70 -5.67 2,100.00 38.34 95.72 1,939.85 -157.31 619.32 -619.32 3.50 0.92 -5.50 2,108.31 38.43 95.27 1,946.36 -157.80 624.46 -624.46 3.50 1.05 -5.38 K15 2,200.00 39.50 90.46 2,017.67 -160.65 682.01 -682.01 3.50 1.17 -5.24 2,300.00 40.89 85.48 2,094.07 -158.33 746.46 -746.46 3.50 1.39 4.98 2,400.00 42.48 80.79 2,168.77 -150.34 812.45 -812.45 3.50 1.59 4.69 2,494.87 44.16 76.61 2,237.80 -137.56 876.23 -876.23 3.50 1.77 -4.41 Start 20.00 hold at 2494.87 MD -13-112" x 10-3/4" 2,500.00 44.16 76.61 2,241.48 -136.73 879.71 -879.71 0.00 0.00 0.00 2,514.87 44.16 76.61 2,252.15 -134.34 889.78 -889.78 0.00 0.00 0.00 Start DLS 4.00 TFO -96.32 2,600.00 43.94 71.72 2,313.35 -118.20 946.70 -946.70 4.00 -0.25 5.74 2,700.00 43.96 65.96 2,385.37 -93.17 1,011.37 -1,011.37 4.00 0.02 -5.76 2,800.00 44.27 60.23 2,457.19 -61.68 1,073.39 -1,073.39 4.00 0.31 -5.73 2,900.00 44.86 54.59 2,528.47 -23.90 1,132.45 -1,132.45 4.00 0.59 -5.64 3,000.00 45.72 49.09 2,598.85 20.00 1,188.27 -1,188.27 4.00 0.86 -5.50 3,100.00 46.84 43.77 2,667.99 69.79 1,240.58 -1,240.58 4.00 1.12 -5.32 3,200.00 48.19 38.67 2,735.55 125.25 1,289.11 -1,289.11 4.00 1.35 -5.11 5292019 11:18:36AM Page 6 COMPASS 5000.14 Build 85D ConocoPhillips Database: OAKEDMPI Company: ConocoPhillips Alaska lnc_Kuparuk Project: Kuparuk River Unit -2 Site: Kuparuk 3R Pad Well: Plan: 3R-112 Wellbore: Plan: 3R-112 Desitin: 3R-112vtp04 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Plan: 3R-112 Plan D142: 39.1 +9.8 @ 48.90usft (Doyon 142) Plan D142: 39.1 +9.8 @ 48.90usft (Doyon 142) True Minimum Curvature Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth -NIS +E/ -W Section Rate Rate Rate (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) 3,300.00 49.76 33.79 2,801.21 186.09 1,333.64 -1,333.64 4.00 1.57 4.88 3,400.00 51.52 29.15 2,864.65 252.02 1,373.95 -1,373.95 4.00 1.76 -4.64 3,439.69 52.27 27.37 2,889.14 279.53 1,388.73 -1,388.73 4.00 1.89 -4.48 Top Ugnu C 3,500.00 53.46 24.73 2,925.55 322.73 1,409.84 -1,409.84 4.00 1.97 -4.37 3,600.00 55.55 20.55 2,983.63 397.85 1,441.13 -1,441.13 4.00 2.09 4.19 3,700.00 57.78 16.57 3,038.59 477.04 1,467.67 -1,467.67 4.00 2.23 -3.98 3,800.00 60.13 12.79 3,090.17 559.90 1,489.34 -1,489.34 4.00 2.35 -3.78 3,900.00 62.58 9.18 3,138.12 646.03 1,506.03 -1,506.03 4.00 2.45 -3.60 3,903.40 62.66 9.06 3,139.68 649.01 1,506.51 -1,506.51 4.00 2.50 -3.52 Top Ugnu B 4,000.00 65.12 5.74 3,182.20 735.01 1,517.66 -1,517.66 4.00 2.54 -3.44 4,100.00 67.73 2.44 3,222.20 826.41 1,524.16 -1,524.16 4.00 2.61 -3.30 4,200.00 70.41 359.25 3,257.93 919.77 1,525.51 -1,525.51 4.00 2.68 -3.18 4,237.31 71.42 358.09 3,270.13 955.02 1,524.70 -1,524.70 4.00 2.72 -3.11 Top Ugnu A 4,248.52 71.73 357.75 3,273.68 965.66 1,524.31 -1,524.31 4.00 2.73 -3.08 Start 98.37 hold at 4248.52 MD 4,300.00 71.73 357.75 3,289.81 1,014.50 1,522.39 -1,522.39 0.00 0.00 0.00 4,346.90 71.73 357.75 3,304.52 1,059.00 1,520.64 -1,520.64 0.00 0.00 0.00 Start DLS 4.00 TFO -85.07 4,400.00 71.92 355.52 3,321.08 1,109.36 1,517.68 -1,517.68 4.00 0.37 4.19 4,500.00 72.36 351.35 3,351.76 1,203.89 1,506.80 -1,506.80 4.00 0.44 -4.18 4,600.00 72.88 347.19 3,381.64 1,297.63 1,489.02 -1,489.02 4.00 0.52 -4.16 4,700.00 73.49 343.06 3,410.57 1,390.13 1,464.45 -1,464.45 4.00 0.61 -4.13 4,704.25 73.52 342.89 3,411.78 1,394.02 1,463.26 -1,463.26 4.00 0.65 -4.12 Top N Sands 4,800.00 74.18 338.96 3,438.42 1,480.92 1,433.20 -1,433.20 4.00 0.69 4.10 4,900.00 74.95 334.88 3,465.05 1,569.57 1,395.42 -1,395.42 4.00 0.77 -4.07 5,000.00 75.78 330.84 3,490.32 1,655.65 1,351.29 -1,351.29 4.00 0.84 -4.04 5,100.00 76.69 326.83 3,514.12 1,738.74 1,301.03 -1,301.03 4.00 0.90 -4.01 5,200.00 77.66 322.85 3,536.33 1,818.43 1,244.89 -1,244.89 4.00 0.97 -3.98 5,300.00 78.68 318.90 3,556.85 1,894.34 1,183.14 -1,183.14 4.00 1.02 -3.95 5,400.00 79.76 314.98 3,575.56 1,966.09 1,116.07 -1,116.07 4.00 1.08 -3.92 5,500.00 80.88 311.08 3,592.38 2,033.34 1,044.03 -1,044.03 4.00 1.12 -3.89 5,600.00 82.04 307.21 3,607.23 2,095.75 967.35 -967.35 4.00 1.16 -3.87 5,700.00 83.24 303.37 3,620.04 2,153.03 886.41 -886.41 4.00 1.20 -3.85 5,739.47 83.73 301.85 3,624.52 2,174.16 853.38 -853.38 4.00 1.22 -3.83 Top West Sak D 5,761.73 84.00 301.00 3,626.90 2,185.70 834.49 -834.49 4.00 1.23 -3.83 Start 200.90 hold at 5761.73 MD 5,800.00 84.00 301.00 3,630.90 2,205.31 801.87 -801.87 0.00 0.00 0.00 5,900.00 84.00 301.00 3,641.35 2,256.53 716.62 -716.62 0.00 0.00 0.00 5,962.63 84.00 301.00 3,647.90 2,288.61 663.23 -663.23 0.00 0.00 0.00 Start 20.00 hold at 5962.63 MD - 9 718" x 7-5/8" 5,982.63 84.00 301.00 3,649.99 2,298.85 646.18 -646.18 0.00 0.00 0.00 Start DLS 5.00 TFO -77.78 6,000.00 84.18 300.15 3,651.78 2,307.64 631.30 -631.30 5.00 1.06 4.91 6,020.33 84.40 299.15 3,653.80 2,317.65 613.72 -613.72 5.00 1.07 4.91 Top WS -C 6,100.00 85.27 295.25 3,660.97 2,353.91 543.16 -543.16 5.00 1.09 4.90 5292019 11:18:36AM Page 7 COMPASS 5000.14 Build 85D I ConocoPhillips ConocoPhil I i ps Standard Proposal Report Database: OAKEDMP1 Local Co-ordinate Reference: Well Plan'. 3R-112 Company: ConocoPhillips Alaska Inc_Kuparuk ND Reference: Plan D142: 39.1 + 9,8 @ 48.90usft (Doyon Measured Vertical 142) Project Kupawk River Unit -2 MD Reference: Plan D142: 39.1 + 9,8 @ 48.90usft (Doyon Depth Inclination Azimuth Depth +NIS 142) Site: Kuparuk 3R Pad North Reference: True Well: Plan: 3R-112 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 3R-112 ('1100usft) (-1100usft) Desian: 3R-112wp04 2,392.54 451.25 Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +NIS +FJ -W Section Rate Rate Rate (usft) (°) (') (usft) (usft) (usft) (usft) ('1100usft) ('1100usft) (-1100usft) 6,200.00 86.39 290.36 3,668.25 2,392.54 451.25 451.25 5.00 1.12 -4.89 6,300.00 87.54 285.49 3,673.55 2,423.26 356.27 -356.27 5.00 1.15 4.87 6,400.00 88.70 280.62 3,676.83 2,445.83 258.93 -258.93 5.00 1.16 4.87 6,500.00 89.88 275.76 3,678.07 2,460.07 159.99 -159.99 5.00 1.17 4.86 6,589.11 90.92 271.43 3,677.45 2,465.65 71.08 -71.08 5.00 1.17 4.86 Start 55.69°1100' DLS, 0' TF, for 126.83' 6,600.00 90.92 271.43 3,677.28 2,465.92 60.20 -60.20 0.00 0.00 0.00 6,700.00 90.92 271.43 3,675.67 2,468.41 -39.76 39.76 0.00 0.00 0.00 6,715.94 90.92 271.43 3,675.41 2,468.81 -55.69 55.69 0.00 0.00 0.00 Start 91.83°1100' DLS, 4- TF, for 36.14' 6,752.08 90.70 270.00 3,674.90 2,469.26 -91.83 91.83 4.00 -0.61 -3.95 Start 226.37`1100' DLS, 4' TF, for 134.83' 6,800.00 92.58 269.65 3,673.53 2,469.11 -139.72 139.72 4.00 3.93 -0.74 6,886.91 96.00 269.00 3,667.02 2,468.09 -226.37 226.37 4.00 3.93 -0.74 Start 378.1.1100' DLS, 4' TF, for 162.06- 6,900.00 95.48 268.91 3,665.71 2,467.85 -239.39 239.39 4.00 -3.95 -0.66 7,000.00 91.54 268.26 3,659.59 2,465.39 -339.15 339.15 4.00 -3.95 -0.66 7,038.97 90.00 268.00 3,659.07 2,464.11 -378.10 378.10 4.00 -3.95 -0.66 Start 392.26*1100' DLS, 4.6' TF, for 14.16' 7,053.13 90.15 267.37 3,659.05 2,463.54 -392.25 392.25 4.60 1.08 4.47 Start 596.81°1100' DLS, 0' TF, for 203.78' 7,100.00 90.15 267.37 3,658.92 2,461.39 439.07 439.07 0.00 0.00 0.00 7,200.00 90.15 267.37 3,658.66 2,456.80 -538.96 538.96 0.00 0.00 0.00 7,256.91 90.15 267.37 3,658.51 2,454.18 -595.81 595.81 0.00 0.00 0.00 Start 655.93'1100' DLS, 4.6' TF, for 60.14' 7,300.00 90.76 269.25 3,658.16 2,452.91 -638.88 638.88 4.60 1.41 4.38 7,317.06 91.00 270.00 3,657.90 2,452.80 -655.93 655.93 4.60 1.41 4.38 Start 820.12'1100' OLS, 4' TF, for 164.74' 7,400.00 94.31 270.17 3,654.06 2,452.92 -738.77 738.77 4.00 4.00 0.20 7,481.80 97.58 270.33 3,645.58 2,453.27 -820.12 820.12 4.00 3.99 0.20 Start 1065.85'1100' DLS, 0' TF, for 237.81' 7,500.00 97.58 270.33 3,643.18 2,453.38 -838.16 838.16 0.00 0.00 0.00 7,600.00 97.58 270.33 3,629.99 2,453.95 -937.29 937.29 0.00 0.00 0.00 7,700.00 97.58 270.33 3,616.79 2,454.52 -1,036.41 1,036.41 0.00 0.00 0.00 7,719.61 97.58 270.33 3,614.21 2,454.63 -1,055.85 1,055.85 0.00 0.00 0.00 Start 1219.86'1100' DLS, 4' TF, for 164.57' 7,800.00 94.37 270.27 3,605.84 2,455.05 -1,135.79 1,135.79 4.00 -4.00 -0.08 7,884.18 91.00 270.20 3,601.90 2,455.39 -1,219.86 1,219.86 4.00 -4.00 -0.08 Start 1226.07'1100' DLS, 4- TF, for 6.21- 7,890.39 90.76 270.15 3,601.80 2,455.41 -1,226.07 1,226.07 4.00 -3.92 -0.81 Start 1654.19'1100' DLS, 0' TF, for 428.15' 7,900.00 90.76 270.15 3,601.68 2,455.43 -1,235.68 1,235.68 0.00 0.00 0.00 8,000.00 90.76 270.15 3,600.36 2,455.70 -1,335.68 1,335.68 0.00 0.00 0.00 8,100.00 90.76 270.15 3,599.04 2,455.96 -1,435.67 1,435.67 0.00 0.00 0.00 8,200.00 90.76 270.15 3,597.72 2,456.22 -1,535.66 1,535.66 0.00 0.00 0.00 8,300.00 90.76 270.15 3,596.39 2,456.48 -1,635.65 1,635.65 0.00 0.00 0.00 8,318.54 90.76 270.15 3,596.15 2,456.53 -1,654.19 1,654.19 0.00 0.00 0.00 Start 1692.03'/100' DLS, 2' TF, for 37.84' 8,356.38 90.00 270.16 3,595.90 2,456.63 -1,692.03 1,692.03 2.00 -2.00 0.03 Start 1717.99'1100' DLS, 2- TF, for 25.96' 8382.34 89.48 270.16 3,596.02 2,456.70 -1,717.99 1,717.99 2.00 -2.00 -0.01 5292019 11:18..36AM Page 8 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMPt Local Coordinate Reference: Well Plan: 3R-112 Company: ConocoPhillips Alaska Inc Kuparuk TVD Reference: Plan D142: 39.1 + 9.8 @ 48.90usft (Doyon 142) Project: Kuparuk River Unit -2 MD Reference: Plan D142: 39.1 + 9,8 @ 48.90usft (Doyon 142) Site: Kuparuk 3R Pad North Reference: True Well: Plan: 3R-112 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 3R-112 Design: 3R-112v+p04 Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +N/-5 +E/ -W Section Rate Rate Rate (waft) (1) (°) (usft) (usft) (usft) (usft) (°1100usft) (°1100usft) (°/100usft) Start 2023.1°/100' DLS, 0' TF, for 305.13' 8,400.00 89.48 270.16 3,596.18 2,456.75 -1,735.64 1,735.64 0.00 0.00 0.00 8,500.00 89.48 270.16 3,597.08 2,457.02 -1,835.64 1,835.64 0.00 0.00 0.00 8,600.00 89.48 270.16 3,597.99 2,457.29 -1,935.63 1,935.63 0.00 0.00 0.00 6,687.47 89.48 270.16 3,598.78 2,457.53 -2,023.10 2,023.10 0.00 0.00 0.00 Start 2049.06°/100' DLS, 2° TF, for 26.96- 8,700.00 89.73 270.16 3,598.87 2,457.57 -2,035.63 2,035.63 2.00 2.00 0.01 8,713.43 90.00 270.16 3,598.90 2,457.60 -2,049.06 2,049.06 2.00 2.00 0.01 Start 2119.66°/100' DLS, 2° TF, for 70.6' 8,784.03 91.41 270.16 3,598.03 2,457.80 -2,119.65 2,119.65 2.00 2.00 -0.01 Start 2292.6°/100' DLS, 0° TF, for 172.91' 8,800.00 91.41 270.16 3,597.64 2,457.84 -2,135.62 2,135.62 0.00 0.00 0.00 8,900.00 91.41 270.16 3,595.17 2,458.11 -2,235.59 2,235.59 0.00 0.00 0.00 8,956.93 91.41 270.16 3,593.77 2,458.27 -2,292.50 2,292.50 0.00 0.00 0.00 Start 2363.09°/100' DLS, 2° TF, for 70.6' 9,000.00 90.55 270.16 3,593.03 2,458.38 -2,335.56 2,335.56 2.00 -2.00 0.01 9,027.53 90.00 270.16 3,592.90 2,458.46 -2,363.09 2,363.09 2.00 -2.00 0.01 Start 2372.42°/100' DLS, 2° TF, for 9.33' 9,036.66 89.81 270.16 3,592.92 2,458.49 -2,372.42 2,372.42 2.00 -2.00 -0.04 Start 2672.46°/100' DLS, 0° TF, for 300.03' 9,100.00 89.81 270.16 3,593.12 2,458.66 -2,435.56 2,435.56 0.00 0.00 0.00 9,200.00 89.81 270.16 3,593.45 2,458.93 -2,535.56 2,535.56 0.00 0.00 0.00 9,300.00 89.81 270.16 3,593.77 2,459.21 -2,635.56 2,635.56 0.00 0.00 0.00 9,336.90 89.81 270.16 3,593.89 2,459.31 -2,672.46 2,672.46 0.00 0.00 0.00 Start 2677.12°/100' OLS, 4° TF, for 4.67' 9,341.56 90.00 270.16 3,593.90 2,459.32 -2,677.12 2,677.12 4.00 4.00 0.08 Start 28%.94°/100' DLS, 4° TF, for 178.28' 9,400.00 92.34 270.16 3,592.71 2,459.48 -2,735.54 2,735.54 4.00 4.00 0.00 9,500.00 96.34 270.15 3,585.15 2,459.75 -2,835.24 2,835.24 4.00 4.00 0.00 9,519.84 97.13 270.15 3,582.82 2,459.81 -2,854.94 2,854.94 4.00 4.00 0.00 Start 2927.34°1100' DLS, 0° TF, for 72.97' 9,592.81 97.13 270.15 3,573.76 2,460.00 -2,927.34 2,927.34 0.00 0.00 0.00 Start 3080.16°1100' DLS, 4° TF, for 153.28' 9,600.00 96.84 270.15 3,572.89 2,460.02 -2,934.48 2,934.48 4.00 -4.00 0.00 9,700.00 92.84 270.16 3,564.45 2,460.29 -3,034.10 3,034.10 4.00 -4.00 0.00 9,746.09 91.00 270.16 3,562.90 2,460.42 -3,080.16 3,080.16 4.00 -4.00 0.00 Start 3126.97°/100' DLS, 4° TF, for 46.81' 9,792.90 89.13 270.16 3,562.85 2,460.55 -3,126.97 3,126.97 4.00 -4.00 -0.01 Start 3306.66°/100' DLS, 0° TF, for 178.61' 9,800.00 89.13 270.16 3,562.96 2,460.57 -3,134.07 3,134.07 0.00 0.00 0.00 9,900.00 89.13 270.16 3,564.48 2,460.84 -3,234.06 3,234.06 0.00 0.00 0.00 9,971.51 89.13 270.16 3,565.57 2,461.03 -3,305.56 3,305.56 0.00 0.00 0.00 Start 3349.19°1100' DLS, 2° TF, for 43.63' 10,000.00 89.70 270.16 3,565.86 2,461.11 -3,334.05 3,334.05 2.00 2.00 0.01 10,015.14 90.00 270.16 3,565.90 2,461.15 -3,349.19 3,349.19 2.00 2.00 0.01 Start 3433.9°/100' DLS, 2° TF, for 84.73' 10,099.87 91.69 270.16 3,564.65 2,461.39 -3,433.90 3,433.90 2.00 2.00 0.00 Start 3822.09°/100' DLS, 0° TF, for 388.36' 10,100.00 91.69 270.16 3,564.64 2,461.39 -3,434.04 3,434.04 0.00 0.00 0.00 10,200.00 91.69 270.16 3,561.69 2,461.66 -3,533.99 3,533.99 0.00 0.00 0.00 5292019 11:18:36AM Page 9 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMPI Local Coordinate Reference: Well Plan: 3R-112 Company: ConocoPhillips Alaska Inc_Kupawk TVD Reference: Plan D142: 39.1 +9.8 @ 48.90usft (Doyon 142) Project: Kuparuk River Unit -2 MD Reference: Plan D142'. 39.1 + 9.8 @ 48.90usft (Doyon 142) Site: Kupamk 3R Pad North Reference: True Well: Plan: 3R-112 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 3R-112 Design: 3R-112wp04 Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inchnation Azimuth Depth +N/ -S +El.W Section Rate Rate Rate (usft) (^) (1) (usft) (usft) (usft) (usft) ('/100usftl ('NOOusft) ('/100usft) 10,300.00 91.69 270.16 3,558.73 2,461.93 -3,633.95 3,633.95 0.00 0.00 0.00 10,400.00 91.69 270.16 3,555.77 2,462.20 -3,733.90 3,733.90 0.00 0.00 0.00 10,488.23 91.69 270.16 3,553.16 2,462.44 -3,822.09 3,822.09 0.00 0.00 0.00 Start 3830.23°/100' DLS, 3.76° TF, for 8.14' 10,496.37 92.00 270.16 3,552.90 2,462.47 -3,830.23 3,830.23 3.75 3.75 0.05 Start 4010.02°/100' DLS, 3.75' TF, for 180.69' 10,500.00 92.14 270.16 3,552.77 2,462.48 -3,833.86 3,833.86 3.75 3.75 0.00 10,600.00 95.89 270.16 3,545.78 2,462.75 -3,933.60 3,933.60 3.75 3.75 0.00 10,677.06 98.78 270.15 3,535.94 2,462.96 -4,010.02 4,010.02 3.75 3.75 0.00 Start 4032.86°/100' DLS, 0' TF, for 23.11' 10,700.00 98.78 270.15 3,532.44 2,463.02 -4,032.69 4,032.69 0.00 0.00 0.00 10,700.17 98.78 270.15 3,532.42 2,463.02 -4,032.86 4,032.86 0.00 0.00 0.00 Start 4106.26'/100' DLS, 3.76° TF, for 74.02' 10,774.19 96.00 270.16 3,522.90 2,463.22 -4,106.26 4,106.26 3.75 -3.75 0.01 Start 4120.56°/100' OLS, 3.76' TF, for 14.37' 10,788.56 95.46 270.15 3,521.47 2,463.26 -4,120.56 4,120.56 3.75 -3.75 -0.04 Start 4234.52'/100' DLS, 0' TF, for 114.49' 10,800.00 95.46 270.15 3,520.38 2,463.29 4,131.94 4,131.94 0.00 0.00 0.00 10,900.00 95.46 270.15 3,510.86 2,463.56 -4,231.49 4,231.49 0.00 0.00 0.00 10,903.05 95.46 270.15 3,510.57 2,463.57 -4,234.52 4,234.52 0.00 0.00 0.00 Start 4416.29'1100' DLS, 3' TF, for 182.04' 11,000.00 92.55 270.16 3,503.80 2,463.83 4,331.22 4,331.23 3.00 -3.00 0.00 11,085.09 90.00 270.16 3,501.90 2,464.07 4,416.29 4,416.29 3.00 -3.00 0.00 11,085.34 89.99 270.16 3,501.90 2,464.07 4,416.53 4,416.53 3.00 -2.46 -1.72 Start 4416.63°/100' DLS, 3- TF, for 0.24' 11,100.00 69.99 270.16 3,501.90 2,464.11 -4,431.20 4,431.20 0.00 0.00 0.00 11,200.00 89.99 270.16 3,501.91 ;2,464.38 -4,531.20 4,531.20 0.00 0.00 0.00 11,260.43 89.99 270.16 3,501.92 2,464.54 4,591.62 4,591.62 0.00 0.00 0.00 Start DLS 2.00 TFO 179.84 11,300.00 89.20 270.16 3,502.20 2,464.65 4,631.19 4,631.19 2.00 -2.00 0.01 11,335.13 88.50 270.16 3,502.90 2,464.75 4,666.31 4,666.31 2.00 -2.00 0.01 Start DLS 2.00 TFO -179.76 11,390.31 87.40 270.16 3,504.88 2,464.90 -4,721.46 4,721.46 2.00 -2.00 -0.01 Start 127.21 hold at 11390.31 MD 11,400.00 87.40 270.16 3,505.32 2,464.93 4,731.14 4,731.14 0.00 0.00 0.00 11,500.00 87.40 270.16 3,509.86 2,465.20 -4,831.04 4,831.04 0.00 0.00 0.00 11,517.52 87.40 270.16 3,510.65 2,465.25 -4,848.54 4,848.54 0.00 0.00 0.00 Start DLS 4.75 TFO 0.10 11,572.34 90.00 270.16 3,511.90 2,465.40 4,903.34 4,903.34 4.75 4.75 0.01 Start DLS 4.76 TFO -0.05 11,600.00 91.31 270.16 3,511.58 2,465.47 4,931.00 4,931.00 4.75 4.75 0.00 11,700.00 96.06 270.15 3,505.15 2,465.75 -5,030.76 5,030.76 4.75 4.75 0.00 11,721.54 97.09 270.15 3,502.68 2,465.80 -5,052.16 5,052.16 4.75 4.75 0.00 Start 9.53 hold at 11721.54 MD 11,731.07 97.09 270.15 3,501.51 2,465.83 -5,061.61 5,061.61 0.00 0.00 0.00 Start DLS 4.76 TFO 179.64 11,753.96 96.00 270.16 3,498.90 2,465.89 -5,084.35 5,084.35 4.75 -4.75 0.03 Start DLS 4.76 TFO -179.94 11,800.00 93.81 270.16 3,494.96 2,466.02 -5,130.22 5,130.22 4.75 -4.75 0.00 11 R51 46 91 37 270.16 3.492.64 2,466.16 5,181.63 5,181.63 4.75 4.75 0.00 5292019 11:18.364M Page 10 COMPASS 5000.14 Build 85D ConocoPhillips Database: OAKEDMPI Company: ConocoPhillips Alaska Inc_ Kuparuk Project: Kuparuk River Unit -2 Site: Kuparuk 3R Pad Well: Plan: 3R-112 Wellbore: Plan: 3R-112 Design: 3R-112wp04 Planned Survey Build Tum Measured Depth -NI-S Depth Inclination Azimuth (usft) (usft) (') 19 Start 137.01 hold at 11851.46 MD -5,230.15 11,900.00 91.37 270.16 11,988.47 91.37 270.16 Start DLS 4.00 TFO 0.42 -5,330.12 12,000.00 91.83 270.16 12,004.26 92.00 270.16 Start DLS 4.00 TFO -0.10 -5,389.58 12,059.54 94.21 270.16 Start 299.64 hold at 12059.54 MD 3,475.59 12,100.00 94.21 270.16 12,200.00 94.21 270.16 12,300.00 94.21 270.16 12,359.18 94.21 270.16 TD at 12359.18.6.3/4" x 4-1/2" Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Vertical Build Tum Vertical Depth -NI-S +EI -W Section (usft) (usft) (usft) (usft) 3,491.48 2,466.29 -5,230.15 5,230.15 3,489.36 2,466.53 -5,318.60 5,318.60 3,489.04 2.466.56 -5,330.12 5,330.12 3,488.90 2,466.57 -5,334.38 5,334.38 3,485.90 2,466.73 -5,389.58 5,389.58 3,482.93 2,466.84 -5,429.93 5,429.93 3,475.59 2,467.11 -5,52966 5,529.66 3,468.25 2,467.38 -5,629.39 5,629.39 3,463.90 2,467.54 -5,688.41 5,688.41 ConocoPhillips Standard Proposal Report Well Plan: 3R-112 Plan D142: 39.1 +9.8 @ 48.90usft (Doyon 142) Plan D142: 39.1 +9.8 @ 48.90usft (Doyon 142) True Minimum Curvature Dogleg Build Tum Rate Rate Rate ("1100usft) (°1100usft) (°H00usftl 0.00 0.00 0.00 0.00 0.00 0.00 4.00 4.00 0.03 4.00 4.00 0.03 4.00 4.00 -0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5/292019 11: 18 36A Page 11 COMPASS 5000.14 Build 85D ConocoPhillips Database: OAKEDMP1 Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit -2 Site: Kuparuk 3R Pad Well: Plan: 3R-112 Wellbore: Plan: 3R-112 Design: 3R-112wp04 Design Targets ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: 3R-112 TVD Reference: Plan D142: 39.1 +9.8 @ 48.90usft (Doyon 2,467.54 142) MD Reference: Plan D142: 39.1 +9.8 @ 48.90usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature Target Name -hit)miss target Dip Angle Dip Dir. TVD -N/-S +E/ -W -Shape (°) V) (usft) (usft) (usft) 3R-1312 T21 042618 MN 0.00 0.00 3,463.90 2,467.54 -5,688.41 - plan hits target center - Circle (radius 100.00) 3R -B12 T20 042618 MtA 0.00 0.00 3,488.90 2,466.57 -5,334.38 - plan hits target center - Circle (radius 100.00) 3R -B12 T19042618 MV, 0.00 0.00 3,498.90 2,465.89 -5,084.35 - plan hits target center - Circle (radius 100.00) 3R -B12 T16042618 MV, 0.00 0.00 3,501.90 2,464.07 -4,416.29 - plan hits target center - Cimle (radius 100.00) 3R -B12717042618 MV, 0.00 0.00 3,502.90 2,464.75 4.666.31 - plan hits target center - Circle (radius 100.00) 3R-812 T18042618 MV, 0.00 0.00 3,511.90 2,465.40 -4,903.34 - plan hits target center - Circle (radius 100.00) 3R-1312715042618 MV 0.00 0.00 3,522.90 2,463.22 4.,106.26 - plan hits target center - Circle (radius 100.00) 3R-812 T14 042618 MN 0.00 0.00 3,552.90 2,462.47 -3,830.23 - plan hits target center - Circle (radius 100.00) 3R-1312 T12 042618 MVS 0.00 0.00 3,562.90 2,460.42 -3,080.16 - plan hits target center - Circle (radius 100.00) 3R-612 T13 042618 W 0.00 0.00 3,565.90 2,461.15 -3,349.19 - plan hits target center - Circle (radius 100.00) 3R -B12 T10 042618 MN 0.00 0.00 3,592.90 2,458.46 -2,363.09 - plan hits target center - Circle (radius 100.00) 3R -B12 T11 042618 MN 0.00 0.00 3,593.90 2,459.32 -2,677.12 - plan hits target center - Circle (radius 100.00) 3R -B12 T08 042618 MN 0.00 0.00 3,595.90 2,456.63 -1,692.03 - plan hits target center - Circle (radius 100.00) 3R-1312 T09 042618 WA 0.00 0.00 3,598.90 2,457.60 -2,049.06 - plan hits target center - Circle (radius 100.00) 3R -B12 T07 050318 MV, 0.00 0.00 3,601.90 2,455.39 -1,219.86 - plan hits target center - Circle (radius 100.00) 3R -B12 T07 042618 MN 0.00 0.00 3,607.90 2,454.54 -925.95 - plan misses target center by 23.40usft at 7591.68usft MD (3631.08 TVD, 2453.90 N, -929.04 E) -Circle (radius 100.00) &292019 11:18:36AM Page 12 COMPASS 5000.14 Build 85D ConocoPhillips Database: OAKEDMP7 Local Coordinate Reference: Company: ConocoPhillips Alaska lnc_Kuparuk TVD Reference: Project: Kuparuk River Unit -2 MD Reference: Site: Kuparuk 3R Pad North Reference: Well: Plan: 3R-112 Survey Calculation Method: Wellbore: Plan: 3R-112 Design: 3R-112wp04 - plan hits target center - Circle (radius 100.00) 3R -B12 TO6 042618 MN 0.00 0.00 3,642.90 2,453.08 -757.94 - plan misses target center by 9.54usft at 7420.22usft MD (3652.39 TVD, 2452.99 N. - Circle (radius 100.00) 3R -B12 TO7 Csg 04261E 0.00 0.00 3,647.90 2,268.06 707.71 - plan misses target center by 7.34usft at 5914.19usft MD (3642.84 TVD, 2263.80 N,' -Circle (radius 100.00) 3R -B72 T05 042618 MN 0.00 0.00 3,657.90 2,452.80 -655.93 - plan hits target center - Circle (radius 100.00) 3R -B12 T04 042618 MN 0.00 0.00 3,662.90 2,459.71 -255.87 - plan misses target center by 7.92usft at 6916.82usft MD (3664.20 TVD, 2467.52 N, - Circle (radius 100.00) 3R-012 T02 042618 MN 0.00 0.00 3,664.90 2,360.59 514.94 - plan misses target center by 5.88usft at 6128.83usft MD (3663.27 TVD, 2365.84 N, - Circle (radius 100.00) 3R -B12 T03 042618 MN 0.00 0.00 3,674.90 2,469.26 -91.83 - plan hits target center -Circle (radius 100.00) ConocoPhillips Standard Proposal Report Well Plan: 3R-112 Plan D142: 39.1 +9.8 @ 48.90usft (Doyon 142) Plan D142: 39.1 19.8 @ 48.90usft (Doyon 142) True Minimum Curvature Casing Points Measured Measured Vertical Dip Casing Hale Depth Depth (usft) Diameter Diameter (usft) (usft) Name (in) (in) 2,494.87 2,237.80 13412" x 10-3/4" 10.750 13.500 5,962.63 3,647.90 97/8"x7-5/8" 7.625 9.875 12,359.18 3,463.90 6-3/4"x4-1/2" 4.500 6750 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (1 (1) 1,769.10 1,676.34 T3 0.00 1,837.23 1,730.98 Base Permafrost 0.00 2,108.31 1,946.36 K15 0.00 3,439.69 2,889.14 Top Ugnu C 0.00 3,903.40 3,139.68 Top Ugnu B 0.00 4,237.31 3,270.13 Top Ugnu A 0.00 4,704.25 3,411.78 Top N Sands 0.00 5,739.47 3,624.52 Top West Bak D 0.00 6,020.33 3,653.80 Top WS -C 0.00 5292019 11: 18:36AM Page 13 COMPASS 5000.14 Build 85D Plan Annotations Measured Vertical ConocoPhillips ConocoPhillips Depth Depth Standard Proposal Report Database: OAKEDMPI Local Coordinate Reference: Well Plan: 3R-112 Company: ConocoPhillips Alaska Inc_Kuparuk TVD Reference: Plan D142: 39.1 + 9.8 @ 48.90usft (Doyon KOP: Start -5.06'/100' DLS, 1.5 -TF, for 200' 450.00 449.91 142) Project: Kupawk River Unit -2 MD Reference: Plan D142: 39.1 +9.8 @ 48.90usft (Doyon -119.71 446.76 Start 125.14 hold at 1808.22 MO 142) Site: Kuparuk 3R Pad North Reference: True Well: Plan: 3RA12 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 3R-112 2,252.15 -134.34 Design: 3R-112wp04 4,248.52 3,273.68 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 250.00 250.00 0.00 0.00 KOP: Start -5.06'/100' DLS, 1.5 -TF, for 200' 450.00 449.91 -1.35 5.06 Start Build 2.50 1,808.22 1,707.80 -119.71 446.76 Start 125.14 hold at 1808.22 MO 1,933.36 1,807.80 -139.18 519.43 Start DLS 3.50 TFO -80.00 2,494.87 2,237.80 -137.56 876.23 Start 20.00 hold at 2494.67 MD 2,514.87 2,252.15 -134.34 889.78 Start DLS 4.00 TFO -95.32 4,248.52 3,273.68 965.66 1,524.31 Start 98.37 hold at 4248.52 MD 4,346.90 3,304.52 1,059.00 1,520.64 Start DLS 4.00 TFO -85.07 5,761.73 3,626.90 2,185.70 834.49 Start 200.90 hold at 5761.73 MD 5,962.63 3,647.90 2,288.61 663.23 Start 20.00 hold at 5962.63 MD 5,982.63 3,649.99 2,298.85 646.18 Start DLS 5.00 TFO -77.78 6,589.11 3,677.45 2,465.65 71.08 Start 55.69°/100' DLS, 0" TF, for 126.83' 6,715.94 3,675.41 2,468.81 -55.69 Start 91.83°/100' DLS, 4" TF, for 36.14' 6,752.08 3,674.90 2,469.26 -91.83 Start 226.37°/100' DLS, 4- TF, for 134.83' 6,886.91 3,667.02 2,468.09 -226.37 Start 378.1°/100' DLS, 4" TF, for 152.06' 7,038.97 3,659.07 2,464.11 -378.10 Start 392.25°/100' DLS, 4.6° TF, for 14.16' 7,053.13 3,659.05 2,463.54 -392.25 Start 595.81°/100' DLS, 0- TF, for 203.78' 7,256.91 3,658.51 2,454.18 -595.81 Start 655.93°/100' DLS, 4.6° TF, for 60.14' 7,317.06 3,657.90 2,452.80 655.93 Start 820.12°/100' DLS, 4" TF, for 164.74' 7,481.80 3,645.58 2,453.27 -820.12 Start 1055.85°/100' DLS, 0- TF, for 237.81' 7,719.61 3,614.21 2,454.63 -1,055.85 Start 1219.86°/100' DLS, 4- TF, for 164.57' 7,884.18 3,601.90 2,455.39 -1,219.86 Start 1226.07°/100' DLS, 4- TF, for 6.21' 7,890.39 3,601.80 2,455.41 -1,226.07 Start 1654.19°/100' DLS, 0- TF, for 428.15' 8,318.54 3,596.15 2,456.53 -1,654.19 Start 1692.03°/100' DLS, 2" TF, for 37.84' 8,356.38 3,595.90 2.456.63 -1,692.03 Start 1717.99°/100' DLS, 2' TF, for 25.96' 8,382.34 3,596.02 2,456.70 -1,717.99 Start 2023.1 °/100' DLS, 0° TF, for 305.13' 8,687.47 3,598.78 2,457.53 -2,023.10 Start 2049.06°/100' DLS, 2" TF, for 25.96' 8,713.43 3,598.90 2,457.60 -2,049.06 Start 2119.65°/100' DLS, 2° TF, for 70.6' 8,784.03 3,598.03 2,457.80 -2,119.65 Start 2292.5°/100' DLS, 0° TF, for 172.91' 8,956.93 3,593.77 2,458.27 -2,292.50 Start 2363.09"/100'DLS, 2 -TF, for 70.6' 9,027.53 3,592.90 2,458.46 -2,363.09 Start 2372.42'/100' DLS, 2° TF, for 9.33' 9,036.86 3,592.92 2,458.49 -2,372.42 Start 2672.46"/100' DLS, 0° TF, for 300.03' 9,336.90 3,593.89 2,459.31 -2,672.46 Start 2677.12°/100' DLS, 4- TF, for 4.67' 9,341.56 3,593.90 2,459.32 -2,677.12 Start 2854.94°/100' DLS, 4" TF, for 178.28' 9,519.84 3,582.82 2,459.81 -2,854.94 Start 2927.34°/100' DLS, 0" TF, for 72.97' 9,592.81 3,573.76 2,460.00 -2,927.34 Start 3080.16°/100' DLS, 4" TF, for 153.28' 9,746.09 3,562.90 2,460.42 -3,080.16 Start 3126.97°/100' DLS, 4" TF, for 46.81' 9,792.90 3,562.85 2,460.55 -3,126.97 Start 3305.56°/100' DLS, 0' TF, for 178.61' 9,971.51 3,565.57 2,461.03 -3,305.56 Start 3349.19"/100' DLS, 2' TF, for 43.63' 10,015.14 3,565.90 2,461.15 -3,349.19 Start 3433.9'/100' DLS, 2- TF, for 84.73' 10,099.87 3,564.65 2,461.39 -3,433.90 Start 3822.09'/100' DLS, 0' TF, for 388.36' 10,488.23 3,553.16 2,462.44 -3,822.09 Start 3830.23'/100' DLS, 3.75° TF, for 8.14' 10,496.37 3,552.90 2,462.47 -3,830.23 Start 4010.02'/100' DLS, 3.75° TF, for 180.69' 10,677.06 3,535.94 2,462.96 -4,010.02 Start 4032.86'/100' DLS, 0° TF, for 23.11' 10,700.17 3,532.42 2,463.02 -4,032.86 Start 4106.26°/100' DLS, 3.75" TF, for 74.02' 10,774.19 3,522.90 2,463.22 -4,106.26 Start 4120.56°/100' DLS, 3.75" TF, for 14.37' 10,788.56 3,521.47 2,463.26 -4,120.56 Start 4234.52"/100' DLS, 0' TF, for 114.49' 10,903.05 3,510.57 2,463.57 4,234.52 Start 4416.29°/100' DLS, 3- TF, for 182.04' 11,085.34 3,501.90 2,464.07 -4,416.53 Start 4416.53°/100' DLS, 3" TF, for 0.24' 11,260.43 3,501.92 2,464.54 4,591.62 Start DLS 2.00 TFO 179.84 11,335.13 3,502.90 2,464.75 4,666.31 Start DLS 2.00 TFO -179.76 11,390.31 3,504.88 2,464.90 4,721.46 Start 127.21 hold at 11390.31 MD 11,517.52 3,510.65 2,465.25 4,848.54 Start DLS 4.75 TFO 0.10 11,572.34 3,511.90 2,465.40 4,903.34 Start DLS 4.75 TFO-0.05 11,721.54 3,502.68 2,465.80 -5,052.16 Start 9.53 hold at 11721.54 MD 11,731.07 3,501.51 2,465.83 -5,061.61 Start DLS 4.75 TFO 179.64 11,753.96 3,498.90 2,465.89 -5,084.35 Start DLS 4.75 TFO -179.94 5298019 11:18:36AM Page 14 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPh i I I i ps Standard Proposal Report Database: OAKEDMPI Local Co-ordinate Reference: Well Plan: 3R-112 Company: ConocoPhillips Alaska Inc_Kupawk TVD Reference: Plan D142: 39.1 + 9.8 (off 48.90usft (Doyon -5,318.60 Start DLS 4.00 TFO 0.42 12,004.26 142) Project: Kuparuk River Unit_2 MD Reference: Plan D142: 39.1 + 9,8 (0 48.90usft (Doyon 3,485.90 2,466.73 -5,389.58 142) Site: Kuparuk 3R Pad North Reference: True Well: Plan: 3R-112 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 3R-112 Design: 3R-112wp04 11,851.46 3,492.64 2,466.16 -5,181.63 Start 137.01 hold at 11851.46 MD 11,988.47 3,489.36 2,466.53 -5,318.60 Start DLS 4.00 TFO 0.42 12,004.26 3,488.90 2,466.57 -5,334.38 Start DLS 4.00 TFO-0.10 12,059.54 3,485.90 2,466.73 -5,389.58 Start 299.64 hold at 12059.54 MD 12,359.18 3,463.90 2,467.54 -5,688.41 TD at 12359.18 5/29/2019 11: 18:36AM Page 15 COMPASS 5000.14 Build 85D ia E ^ c u `d n d d C n a O d y O � r O • L � i L ❑ C O _ O N Q^ E A C > a aL,o m ❑ a 3 V/ ��//�� V/ y � ` n v m Q ^ CL cm iii. 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N N N N N N W W W W W W W W W w w W W W W W W W W W W W W W W W W W W a a a a a n a a a a a a a a a a a a a a LL a a a a a a a s a c 0 a m E 9 S o 0 0$ 4 o a o 0 5 0 0 0 0 0 5 0 0 0 `o Aq m vm �N v oN vaN °� "om dN v 'om om "oN oN v a 12 d v12 v d- w U W U w U U w U U W U U W U w0 U W6 U W U o w U U w U U O N I(I b W l0 W O N b W W N W Q OI Q W O M W W M N I� b W O O] W b N Cl r O M O W P Ol r Lp U r f N N N N N M N N M N N N W f W p d LL U 0 0 o O o o O O o o O o 0 o O o 0 0 0 0 o O o o O o 0 0 0 0 9 0 0 0 0 0 0 0 0- 0 0 0 O O O O O 0 0 0 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 N I 0 0 0 0 0 0 O O O O O 0 0 0 0 0 0 0 0 0 0 0 0 O O O - N Q b M P N N M n N - - -- - - - - - Q M M W W N W W O r P W O N W b N O N W M N n Q Q Q W n L r O M M O SS p d N a O P W h W P M GO W W O W t0 W h N P O W N O N N O N O W N O Ih O P M O W M M P N M W P r P n F P W W W j L O OI O W O O) O O M N O W N M M n O OW N W W OI W N W W b W p d a OI W O Co O O - P O N f` M O O M O O N M Q N M Q N N W p m - - - - - - - - N N N D N - � W N O W YI W b Q N N P Q N Q P N M W b W W O h O f` W N W Ol C 10 Q r N r P O O (p M M W N W N N N b W b VI W W b M W Q M E d 1p pa V OI m N CI 0 b n M Q O M O N r N N N Co W b W W b b b N N E L N N N N N N M N P C � CL a 3 N U d 9 O V W n W Q M O O f0V W O W W T n b P O W N O W N O W O W W O r N O 6 y O 01 O W O W O O M N O OI N M M t` O O W W Ol W 01 O1 W W S` W D• .0 6 W OI r ---- O N Q O N F M O O W O O N M Q N M Q N N d N W d 0� s � - - - - A i M v z Cy r ? 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W W W W W a s a a a W W W W W W a a a a a a W W W W W W a a a a a a a LL a a a LL a a a a a a LL L c 6i b C a C C C C C C C C C E o `o U W L-' m E W N N N m N N LL N � W LL N li LL LL .lS W IL � IL H W IL � W IILL IWi y8 m m E v m w v N v v E w N n»q m v v m } v m N p p n v v a v n n a n v n v n y n n N W w W W U U W U U w U U w U U W U U w U U W U U W U U U U U O W N m P M P N m r r W n OI m n w r W M m N M m r r w F N M m n W O w W m Q m m N O n M N W N w m m m f N W m m w r0 W q p ` w f � d LL U 0 0 0 0 0 0 0 0 0 0 0 O o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o p o O o 0 0 a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O o 0 0 0 0 o a o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o c a o c o 0 0 0 O p O O o 0 0 o O o 0 o O o L O o 0 0 0 0 0 0 0 o O o o O o 0 o O N M O N M N N r N M N M yb 7 m r Q Q Q N m Ct M Q n W w M w N m N w m O Q r O m m m m W O N W m N N M O Q N W m w W m l0 W N m m N N m N M w M N N Q W N m O C O M W M M r M M y r n m n n m r n N O O m m O N N W N N I(1 N N m m b n m r m m M m O O n r n O O b N N n N N w O O N P 0 W W d m n N O r M O n f O m O O N^ O N O O W m O W Q m W O m O N O N O m O N a W W O m W O m O O n O O O N M O P m O P m N m N (O N Y1 !OO m O n M m W W m w W j L w W N w n 01 w m O O w O n N N M m O N N M m by� Oi tU t0 N Q Q Cl M Q Y Y E N w N O W m O w r m n M O n m O N P O N Q M m w n m Q N Q w W n m w C 7 E d m P m w N Vl N m N b1 m w M m m M N N w w w m m m N m m O w w n w w m P m Q r A r r N (U L � CL n 3 N r N O r M O n^ O N O O N M O N O O w m O w P m w O m O O m O Q m O P N N N O N O N N Cl N M m N C'1 N N M m N M N m n N M N SC' W 6 W N N N M N n N V W M vrc r ? E D c W v v d v v v `J 6 YJ b J J N H r z ' N o Y a a g 3 r r r° o W o 3 3 g 3 3 n n m m m M M M P P Q •� o n n o o M M m M M M "' � d � � M 3 3 W3 3 3 W LL. m U �j M M N N m O O O N IW N m m m 0 0 0 0 0 0 r r n r r r 0 0 0 0 3 j /O/�� y, ,r M � � M M M m m m M M Cl M M O Q% m w w W W w U 2 X. M J Ed y O O O` O p p O M M M M M M M M M M M M M M M m O O O O O O O b ' ' c c �' c c c c .' c c cm a K K K K K K K K K K K 2 K K K K K K K K K K K K K K K tt 0 O c J o V C1 u c c c c W Wc cW W cW d E d d a a a a a d 2 2 d d 2 W N N U d a l d d d d d d d d d R a a > C C W W Q f K Ul N m O a S O 1� u d c v A A vLL M N N N N N N a a a a a a a Y v v 0 0 0 0 0 0 0 0 r P W O m m u < U' U Q Q Q m(7+�U' + + > LL 3 LL > LL 7 + + + 6000 0 0 0 0 0 0 0 0 M M M M M M M O r r r M M m O m m m m m O C O V N fV W O m m W m m m O O O r r M M 0 o m m m m O O O O V N N Q� M m o e a® m m u IV �' Y/ s a 0 u 0 0 u n z a N Q i CLm a. 0 0 r.0 U M R IL w Cl) , , O c x X o Q Y G 7 M M = 2 x X N C N r M 0 0 r.0 U m E cm _n W L WA r. 0 V El CD r 0 N a m E am N i H K A. N N' N N ' N N' m N' m N 1 I W. W N N N N N M N N N N W N N @ W m N N W W W@@@ W@@ W@@ W W@@ W W @ W W W W W W W W@ c c c c c O 0 `p o p` d o 0 0 0 c O n LL @ n LL @ d LL 9 a LL 5 a LL 9 0, LL 9 a u @ d LL N d LL 9 om join oln 2c; om morn oln �om } c m (p n c n v a y U W U U W U U W U U W U U W U U W U U W U U W U U W U U M V N M P N r r w P m O N N W m M m P N N P N M M w M m P M m P m m P P N m O N P m N W N V r N N Q ItJ m P m 0 0 0 o O o o O o 0 o O o o O o 0 o O O o o O O o O o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O O O O O O O O N m N m N N O N N O N N O N m 6 N 6 O O 0 0 0 0 0 0 O O O O N M O N M O O O O N M N N N M N M m m p p N Ill N N m N N m N P O m O r m m P O O O W N N O r O P m W m w W N w w m P m W m m� r m W O O N N O N N w P r m m N W m m w m m N m m N m W N r r M M O m r O m^ O r O m N O m N O W m O W m O W m Q m M 0 0 0 1q N O Id N w w W w W m O W m O W m O Q w m w w m W r m W r m Q N N O N N O Q n Q Q^ V Q r Q r W m w P Q Q w W Q w w N N M h N M r W W W N N V N m N Q N Q m Q P m m co m Of O 0 Oi O 0 Oi O t0 Oi C mO N O m w W CI P P M W r W r W O m N O m N O w m O w m O W (O P m M O O O m N O N N W w W w w m o w m o W m o Q w m W W io w r W w r W a N N O N N O P n Q Q n P P r P r w m w Q Q P w w P w w N V P m m m m J J J O O O Qo Qo 0 0 o m epi n 7 7 7 aI I I I Q Q Q 0 0 0 0 0 0 M o o O O o 0 K D K K tY K M M a0 0 0 0 0 0 0 0 0 0 0 0 Y M M M M M M M M M M M M ❑ ❑ ❑ N N N q.F O O O O O f M M M M M M K K K K K tr M M M M M M K K K LL' M M M M IA CL u c l� u a o U 3 e 0 q A d w r r r r r r r r r r r r r r r r r r r r r r r N N M N M N N M N N M N yN N N N N N N N M N N N N N N M b N N N W A W W W W A W W W A N N W W W A A W W W A W W W W W W W W W W a s a a a a a a aaa a a a a a a aaa a a a a a a a s a s c 0 9 ro m m m L E 12 0 N W W W W W W r N LL W W LL VO W LL «R LL W LL S0 W LL .IS W LL LL 6 ^N 4 LL },Q LL n y C 6 W y a N d y N om N a N d om �om M o n how d N n d ow Ei �'ou mom mom n A N vd- W W W U U W U U W U U W U U W U U W U U W U U W U W U U U U N N N P d U � Q O w 4(1 O P N W N m OI N w P N N W M I� P P 1i h O V V M M O N M P O O n N' O N N P r Y m w w N m O f0 P W O (O P N M' N 7 U r r r N N N N N N M N N N N d li U 0 o O O o 0 o O O o o O O O o o O o 0 0 o O o 0 0 0 0 0 o O d N O O N N N O m O IA O O N O O m O O OO A N O N O O O N N N O N r N O N 10 r J L rp d N N O N N W h W W O 1� O N O N O w O O O N N n N m N 10 O O N M W N N N r N h p mMN mN C0J) WM, (O O m V w w w N W (O m N N 10 a0 P V] N 10 10 b 0 >K m m w w m M M M N rt] fO r r w` m r W N !NO M N N Y F � nb W m N w O r N w N f7 1� O PN 1� m r0 Q P W W O M O M N 10 P m P P m M N m P P M N M 9 O M m m W W m P O w OJ f0 V w W M O O W O O W d i P M M I� M O P m N N O M M M r P m F N OI r(I M Ifl w r N w F N q J N N O N N O m O N' O M W W O 0 0- m m P w N' O O N M W h M O O O N W p n W O (`� M N P r M M W a Ry - - N -r N r e F c - - - - - - - - W W O N w r N O m M P O E C E N l0 w W Y M N N P� O M P f0 h N N P m W W w N N N O N N L E 0 m O C. n 3 ° N n W rn v m W o M o M W W a m P P m a s N d c o m .o � W W w a o W w� P m W M p o W o o W m N m M N d O L P M M n M O P w N N O M M M h P W r W W W M N m W n N m m O) V n n N P F r 6 d 6 L_ J 6 N N O N N w O^ O M W W m P m m' O O N M W V n h O w !� M O O O W O M M N M M W N W m O W O O p N N�- IL W �L M 1 L M 9 N E r z c 1 q M O M y a C c R � dM a "W d E J LL IC m `o a y m m u a adi /C/� y. �• M � N N 4) d Eb O O O N N N N N N N W W W N N N N N M q ^ A n' z K K CL 0_ K K K& K K K N N N K D: 0' K O: K N N N N K K K D: 0: K K K 0' K K r r N N LL M M M M M M M M M M M M M M M M M M M M M M M M M M M M Y N d r r r r r r r i r r r � � r N N N N N N N N N g r K D: K K K K K K K K N E M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M r y 0 y J A Ij Z.6 r r r r V^ h N m r r r n r w W m r r r W W W O O O r r r N N N r r r r r m N W W W r W W b C 9 E r ^ N N N N N N N N N N N N N N N N K K K D: 0' K K K K K 0_ 0: K K Y U m (° U M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M C > w m w Q f K !W N Ed L 0 8b'E m E r :E E E H b L u m LL U U E N W N N N W N M m N N o m N N b N 0 b m m N W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W C C C CC C G O` yp O yUy O O O O yUyU O O O O yUyU O O yUy O `p pUp�� O${$f1 yU 0 0 0 p W LL W d LL 9 4 LL W d LL W d LL }S d LL W d LL .R. d LL W d LL � a LL d LL m N N N d N W m N d N m y W W m N N W W N m 01 N C. N y N ry o N yCj 4 d y d v y d d N d d dn d N �' d N n U U w U U w U 0 w U U w U U w U U w U U w U U w U U w U w U N P O m M N0 M 0 O 0 0 0 O 0 0 N O Ol 0 0 W 0 0 m 0 N 0 N . N O 0 0 0 0 0 P 0 0 P 0 P 0 0 0 01 N 0 0 0 n P M M N Vi N Ol N 0 0 O P Q O P N 0 0 m 1� O 0 0 0 0 m 0 N O 0 Of 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Vl O N O O m O O N N O N 0 m N N m N N m N N Q N N m vi M r 0 0 0 0 0 0 N N O N 0 O a 6 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N N N VI Vl N O N P 0 0 M M 0 N W m N P m P O 0 0 0 C O Y O N O N V O N M M M M M M M M m M M N f� IF Of h M1 N n n n 0 N m 0 Y] O r N m O N O N 00 0 O m 0 O N O O N N O N N O O 0 0 0 m 0 0 0 0 O O 0 0 0 0 0 0 0 O P O O P O O N 0 O N O n O N n 0 0 m O 0 M O 0 N N W N N P O 0 P 0 N Q N N 4 P 0 m 0 m 0 N Q Q M m p 0 N 0 0 N m N O N01 m 0 0 O 0 01 O 0 O Q m I N 0 N m 0 N N M N N M N VI V' 0 0 I� Ol 0 n W 0 N m 0 M n h 0 h N Ih 0 h N N 01 N N W N N I� N N M m r N N M N m O N 0 N O m O O m m O N O O N N O N N O O O O N m 0 0 0 O OR O O P O O P O O 0 m O 0 O h O N n L QI W t7 O m M O 0 N N 0 N N P O 0 N O) P N N Q 0 N 0 O h N 0 N N N N N N N N N 0 m n L a 2 2 O V 9 rn n n n 0 0 d O O O 3 5 3 O Q n J J J d d O n O n J J J �€ mmm gs3000 a33g3 2 m 0 fO N N VI n n n 0 N m m m m 1` I� r7 7M M 7 3 m 0 0 � n M M M NYI N c? O: K O O O o 0 o O o 0 0 0 0 0 0 0 r M m M M M m m m m M m m J J J � ¢ ¢'¢' ¢' W M O O O O O O O O O O O O C C C C C C C C C C C C W N N W W W N N W K K yd N M M M M m M M M M M i m p p 7 0 0 0 0^ O O O O O- O O O O O m _ ¢ M m m M m m M M M M m M m M m m M m m M M m m m m m M m m 2 6 m .. .. .. .. .. .. .. .. .. .. N C C C C C G C C C L C C C C L C C C C e°i EO n'. W W W W W W W W W W W W W W W W W W W W W W W W W W W W W 1 d a a a a a a a a a a o. Q CL u c a CL 3 N r M N r Cl) l0 CL w O CL O y O V ao d C d LL U N N bW b b b b b ✓ N N M W W W W W W W W W W W W a a a a a a a a a a a a 0 0 0 0 0 0 0 0 0 0 0 0 D 0 0 0 0 0 0 0 0 0 0 0 0 O N O O N O O N O O VI Yf j L m r O N r O h r m N r r b QC N N N N N N W N N W O r O O n M M A CMJ M N 6 W d N 00 N O 00 N O O m fOp O 0 N N N M N N M N N M N N M W O W N O m v N m m N W 0 o rn o o m n M n .mn m CmJ N N N N N N O N O O N O 0 0 m ci m of m ro Q r m Q n m N N M N N M Q Q 0 6 .6 o e vi m r M N n VI N N M N N M N b M W W W a a a M W m Q N N M M N W W N o m r o 0 W W N a a a 0 0 0 K K K K K K K M M M M M M M o n n r M M m o m m m m m O Q Q P (V N W O W W W Cp m N F b P P W W P M O O O n n M M 0 o m m m m W O O el N N m k 0 0 0 0 0 0 3 3 3 J J J 3 3 3W O Op Opp.. o 0 o g' 3 3 N m w Q Q Q O O O N N N O O O J J J Y Y rn W rn O O O W W W epi e�J M M Chi M p d d d K K D! K K K g W W W W W O 12 T 12 W W W W W W O O O O o o Y c c c M M M M M M M M M M M M A a x W o W W W N W W W W W W W W Y 0 a a a a a a a a a a a a Y 0 00 K K K K K K K M M M M M M M o n n r M M m o m m m m m O Q Q P (V N W O W W W Cp m N F b P P W W P M O O O n n M M 0 o m m m m W O O el N N m k N M W w 0 3R-112wp04 P cc 150 U 0 0 c v U 0 -Ltr 3000 7500 9000 Measured Depth Ladder View 10500 1 Depth From Depth To Survey/Plan Tool Equivalent Magnetic Dis ce VD MD Name 39.10 1100.00 3R-112wp04 (Plan: 3R-112) GYD-GC-SS 2237.80 2494.87 13-1/2" x 10-3/4" 1100.00 2494.87 3R-112wp04 (Plan: 3R-112) MWD OWSG 3647.90 5962.63 9 7/8" x 7-5/8" 1100.00 2494.87 3R-112wp04 (Plan: 3R-112) MWD+IFR2+SAG+MS 3463.9012359.18 6-3/4" x 4-1/2" 2494.87 3994.87 3R-112wp04 (Plan: 3R-112) MWD OWSG 2494.87 5962.63 3R-112wp04 (Plan: 3R-112) MWD+IFR2+SAG+MS 5962.63 7462.63 3R-112wp04 (Plan: 3R-112) MWD OWSG ;r m 30- U 0 0 0 r Equivalent Magnetic Dis ce 550 1100 1650 2200 Partial Measured Depth 2750 11:12, Ma, 29 2019 1 1 3R-112wp04 TC View SURVEY PROGRAM SECTION DETAILS From To Tool MD Inc Azi TVD Dleg TFace Target Annotation 39.101100.00 GYD-GC-SS 39.10 0.00 0.00 39.10 0.00 0.00 1100.002494.87 MWD OWSG 250.00 0.00 0.00 250.00 0.00 0.00 KOP: Start -5.06°/100' DLS, 1.5° TF, for 200' 11 00.002494.87 MWD+IFR2+SAG+MS 450.00 3.00 105.00 449.91 1.50 105.00 Start Build 2.50 2494.873994.87 MVVD OWSG 1808.22 36.96 105.00 1707.80 2.50 0.00 Start 125.14 hold at 1808.22 MD 2494.875962.63 MWD+IFR2+SAG+MS 1933.36 36.96 105,00 1807.80 0.00 0.00 Start DLS 3.50 TFO-80.00 5962.637462.63 MWD OWSG 2494.87 44.16 76.61 2237.80 3.50 -80.00 Stan 20.00 hold at 2494.87 MD 5982.602359.18 MWD+IFR2+SAG+MS 2514.87 44.16 76.61 2252.15 0.00 0.00 Start DLS 4.00 TFO -95.32 4248.52 71.73 357.75 3273.68 4.00 -95.32 Start 98.37 hold at 4248.52 MD 4346.90 71.73 357.75 3304.52 0.00 0.00 Start DLS 4.00 TFO -85.07 5761.73 84.00 301.00 3626.90 4.00 -85.07 3R -B12 TOO WSD 04263MA0110.90 hold at 5761.73 MD 5962.63 84.00 301.00 3647.90 0.00 0.00 Start 20.00 hold at 5962.63 MD 5982.63 84.00 301.00 3649.99 0.00 0.00 Start DLS 5.00 TFO -77.78 6589.11 90.92 271.43 3677.45 5.00 -77.78 Start 55.69'/100' DLS, 0' TF, for 126.83- 6715.94 90.92 271.43 3675.41 0.00 0.00 Start 91.83"/100' DLS, 4' TF, for 36.14' 6752.08 90.70 270.00 3674.90 4.00 -98.82 3R -B12 T03 042618 M%fart 226.37°/100' DLS, 4- TF, for 134.83' 6886.91 96.00 269.00 3667.02 4.00 -10.64 Start 378.1'/100' DLS, 4' TF, for 152.06' 7038.97 90.00 268.00 3659.07 4.00-170.52 Start 392.25'/100' DLS, 4.6° TF, for 14.16' 7053.13 90.15 267.37 3659.05 4.60 -76.39 Start 595.81`/100' DLS, 0' TF, for 203.78' 7256.91 90.15 267.37 3658.51 7317.06 91.00 270.00 3657.90 7481.80 97.58 270.33 3645.58 0.00 0.00 4.60 72.16 4.00 2.86 Start 655.93°/100' DLS, 4.6° TF, for 60.14' 3R -B12 T05 042618 M@fart 820.12'/100' DLS, 4. TF, for 164.74' Start 1055.85'/100' DLS, 0' TF, for 237.81' CASING DETAILS TVD MD Name 7719.61 97.58 270.333614.21 0.00 0.00 Start 1219.86"/100' DLS, 4- TF, for 164.57 2237.80494.81&1/2" x 10-3/4" 7884.18 91.00 270.20 3601.90 4.00-178.86 3R-1312 T07 050318 M%fart 1226.07/100' DLS, 4- TF, for 6.21' 3647.9M62.63 9 7/8" x 7-5/8" 7890.39 90.76 270.15 3601.80 4.00-168.30 Start 1654.19'/100' DLS, 0' TF, for 428.16 3463.1 59.18 6-31W'x 4-1/2" 8318.54 90.76 270.15 3596.15 0.00 0.00 Start 1692.03°/100' DLS, 2- TF, for 37.84' 8356.38 90.00 270.16 3595.90 2.00 179.21 3R -B12 T08 042618 M@fart 1717.99°/100' DLS, 2' TF, for 25.96' 8382.34 89.48 270.16 3596.02 2.00-179.58 Start 2023.1 °/100' DLS, 0° TF, for 305.13' 8687.47 89.48 270.16 3598.78 0.00 0.00 Start 2049.06°/100' DLS, 2- TF, for 25.96- 8713.43 90.00 270A6 3598.90 2.00 0.42 3R-1312 T09 042618 M%lart 2119.65°/100' DLS, 2- TF, for 70.6' 8784.03 91.41 270.16 3598.03 2.00 -0.19 Start 2292.5.1100' DLS, 0' TF, for 172.91' 8956.93 91.41 270.16 3593.77 0.00 0.00 Start 2363.09'/100' DLS, 2' TF, for 70.6 9027.53 90.00 270.16 3592.90 2.00179.81 3R -B12 T10 042618 MWart 2372.42°/100' DLS, 2° TF, for 9.33' 9036.86 89.81 270.16 3592.92 2.00-178.88 Start 2672.46°/100' DLS, 0° TF, for 300.03' 9336.90 89.81 270.16 3593.89 0.00 0.00 Start 2677.12.1100' DLS, 4' TF, for 4.67' 9341.56 90.00 270.16 3593.90 4.00 1.12 3R -B12 Tit 042618 MWart 2854.94°/100' DLS, 4' TF, for 178.28' 3. 3573.76 0.00 0.00 Start 3080.,6°/100' DLS. - TF, for 153.28' 3562.90 4.00 179.94 3R -B12 T12 042618 MWart 3126.97°/100' DLS, - TF, for 46.81' 3R -105L1 wp01 .00 If ok 7 6 .85 4.00-179.87 Start 3305.56°/109 DLS, ° TF, for 178.61' R-101 L1 P 3 .57 -0.00 0.00 Start 3349.19°/100' DLS, ° TF, for 43.63' 1" a0,y0.16 35 0 7413- 2.0 0. pgB12 T13 042618 MWart 3433.9°/100' DLS, Start 3822.09°/100' DLS, TF, for 84.73' - TF, for 388.36' 3R -106w 03 To Update P P - 1 11.69 _ 3 1 1.60, .16 3553.1 - 13 1 2.00,270.16 3552.90 .0 g Start 3830.23°/100' DLS, P17T14 042618 Mtfart 4010.02'/100' DLS, .75° T for 8.14' .75' or 180.69'250 i 8.711,270.15 3535.94 3. - . 6 3/613 Start 4032.86'/100' DLS, TF 23 075'GdQfOr74.0T 9 38,37 15 3532.42 0.0 Start 4106.26'/100' DLS, 440 - D 1 69&47 1 90 1 5}10'270.153521. 3.75 86, .75-17 . 1 1 18 Mvfart 4120.56°/100' DLS, Start 4234.52°/100' DLS, .75' TF for 143 ° Ti144bi933g'- ` TF, for 182.04' 640 5.II6. 270.15 3510.57 -.50 O.d0 7Start 4416.29"/100' IDLE, "TfEj/aQ024- $30 270.163501.90 .99- 63501.90 3.00 9.95 3.00-14 . 93�pq 3R -B72 6 b�1�FA1Lfart 4476.53'/100' DLS, 4416.53'/100' DLS, ' TF, for 0.24' 3R -3R-107 - 9.99 0.1 .92 0.00 0.0 `M; DLS2.00TF0179. 4 830 - 6 1020 ' 11 8.50 270:16 3502. 113 7.40 270.16 3504.88 2.00 179.84 00-179.76 R-131 17 DL TFO -179 old at 113 .31 6120 - 1220 1 407 7.40 271. 63510.65 0. 0.00 TFO 0.10 0.00 6 3511.90 4.7 0.10 3R- 2T18 Btad DLS 4.75 TFO -0.0 Ja20 - 1410 3R-11 D _ 7.09 0.1 02.68 4.75 0.05 Start 9.53 hold at 11721. 7.09 270.1535 51 0.00 00 n DLS 4.75 TFO 179. 4 1410 - 1600 6.00 270.163498. 4.75179 3R-812 19042618 rt DLS 4.75 TFO -179 34 1.37 270.163492.6 4.75-179. SWW��tt 137.01 hold at 1185 .4 - 2OSO 1.37 27 .16 3489.36 1.37 0.00 0.0 SlarhDLS 4.00 TFO 0.42 3R-14 21 2 0;, 485.90 0 7U 3R-8127 042618 ®tan 29964 hod at 1205 (1 00 2500 12 12 59.18 94.1 270.16 463.90 00 0 0 00 3R -1312T2 042618M at 12359.18 .S 2500 - 2950 3 270 90 3 2950 - 3400 3400 3850 f 1 3 3850 - 4300 4300 - 4750 60 - 197!' 4750 5200 7f!. 5200 - 6100 240 120 6100 - 6990 1 1 6990 - 7890 3R-25 2 f'4i0!7i3 7890 - 8780 51 < 6273633 3R-26PE1 31<r 7i . 8780 - 9680 75 t 9680 10570 210 '61, 150 10570 11470 3R-1 11470 - 12359 180 N O 9 3 g M a a 3 N J O M m 3 a J d CL _I M M M O N O 3 g0 co 09 O LO O M M N ° 09 o S2 S C m o M T c ¢? ° Oy n c O a M � cc 0£. O 9 g 0f_ O 0 V/ O T d N M o N N Q N O M O O (p M Wj M � O J R Cl) m �P9g 9� M a CL 3 N r J 0 M � M N O T Y 17 (w/ysn 0096 Bui41JaN AC Flipbook O O rn O c D O O O o 0 0 0 0 O O o 0 0 r r- m O O O O N N O M O LO O M O M u 0 M M M W M V M LO It Iq M O N V M O LO O It w M1�- N= O M ti O O N i N V CO M .- N N N M M T V In O Mr-- M O •- O O O O O O O O O O O O O O O O O O O O O O O O O M Ln V V M N N � O M O LO O LO O M O O O O M W rl- r� Yi N19 O O O N It 0 O to O V w M r- N= M M r� CO LO V' .- N N N M M 14- V LO M M r- O M 0 .� V o rn ao C) O Oa o a O 3 N r a O � JL: M O r c0 �M (0 O O Q M O oc- r _ a M M ` F R N O M N O j � M M O CL 3 d 3 3 M � n � .O 0 N M O\' Cj N � N O M M M O M N Cl) TOM Cl) TOM C5 0 C7 Q Q Q T �MilJ� No iD`+a+' cG Of Cf LL' > N oOOoOewnrmm OmOO mN00M4Om0 ero 8OO $OOron ewOo0mw0 N.mO wOoOomnOoNmPmNmwMOo mmmOmmmrOMmOo'�' mwWOOo M QK oLL +i O> XXOLL DNP QwOOmOg�mmmmnOOm O0 o QU} »> > Qo$$$$$OoNOon OO..N.000MMO00nnOMMOm mmmm.NmmmmmhHmOmmmmmNhNhhm mrprr000PP 000. MOMm N-----�-� a Hc������� o M m m ,, rr...:.owm.n66dcoddooa6ddod66006ododdaadcod m000rrmm000rnr rrrn nnnnrrrrnnrnrrrnr mMMmmNNNNNNNNNNNNNNNN[r-I IrV (nVNNNNNNNNNNNNNNNNNNN } w OmWmwwoor— H (J Z (pc �d'Nm 00$$N�OnNOMMM�Pm�nM�mO�mw mMC)p �wO�enMn mmm mmwnmm�wOww�wOmm�M �ty te+IC eowmm$bmmOwN�mNm$��hOCwi ry LL LOV VCNNma) a�C'COO>CM 55 ¢ O(O t0 pM m0p, �^, 4m0N �N0w�YN10�Numjr'� MYO� wNmN�u)$m�IM1OVOCJm mrv�$$�ry�mn$wumirnmooNfe`r mwm�nm�mmNt�o+in e4i�nn��ooeen�nn$o � N d N N M NIS �SoonrM�i U m0]WWW ��N Pemmmmmmmrnnnrnrn`a'`r�m`�mmm$wmwwwwwwoo0oa0000.- �rri LLMOOOOmm F'NMM O w 15 q* O CL 3 N r r M Q �a v c -j w O O . 0 0 0 0 0 0 0 0 O O O O O ti tl- (f) O O O O N N O (t) O M O LO O (C) 0 0 M M 00 00 M "t M In 'tet qj- M O N V (D O (f) (T 00 M r N = CA 00 r- (O O (V N V (9 00 N N N M M q V (n CO (O rl- CO O I m O O O O O O O O O O O O O O O O O O O O O O O M LO IT V M N N= O M O LO O (t) O M 0 0 (A O 00 00 r -- N V (O 00 O N V M O LO (T 191- 00 M ti N= O 00 r- (D LO V r= N N N M M V V LO (.O (D I-- 00 0 0 0 0 r N 0 00 O+ O+ O+ J X X xW m Q�OOOO V Lm n �Oa%OJ N(O (Om 0 Z_ LOO)O)O�(D VNO] poo �D �f tO �O N V6J Mq�Mq �6m]p] m d�NN Mil1rM�y tQ boom M(v iJ r mmmmmmmmmm mm .-���e>�Hmmmmmn n n mm O�OOWOJ (O (O �MV<D LLMOOmO)(O (O F-NMM d ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit -2 Kuparuk 3R Pad Plan: 3R-112 50029xxxxx00 Plan: 3R-112 Plan: 3R-112wp04 Error Ellipse Survey Report 29 May, 2019 Company: ConocoPhillips Alaska lnc Kupawk Project: Kuparuk River Unit_2 Site: Kupamk 3R Pad Well: Plan: 3R-112 Wellbore: Plan: 3R-112 Design: 3R-112wp04 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference TVD Reference: MO Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 3R-112 Plan D142: 39.1 + 9.8 (off 48.90usft (Doyon 142) Plan D142: 39.1 + 9.8 @ 48.90usft (Doyon 142) True Minimum Curvature 2.00 sigma OAKEDMPI Project Kupamk River Unit -2, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kupamk 3R Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.16 ° well Plan: 3R-112 From Well Position +NIS 0.00 usft Northing: Latitude: Tool Name +EAW 0.00 usft Easting: Longitude: Position Uncertainty 1,100.00 0.00 usft Wellhead Elevation: Ground Level: 9.80 usft Wellbore Plan: 3R-112 Magnetics Model Name BGGM2018 Design 3R-112wp04 Audit Notes: Sample Date Declination Dip Angie (1 (1) 7/30/2019 16.50 Version: Phase: Vertical Section: Depth From (TVD) (usft) 39.10 Field Strength (nT) 80.95 57,417 PLAN Tie On Depth: 39.10 +N/S +EI -W Direction (usft) (usft) (°) 0.00 0.00 270.00 Survey Tool Program Date 5/29/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description 39.10 1,100.00 3R-112wp04 (Plan: 3R-112) GYD-GC-SS Gyrodata gyro single shots 1,100.00 2,494.87 3R-112wp04(Plan: 3R-112) MWD OWSG OWSG MWD - Standard 1,100.00 2,494.87 3R-112wp04(Plan: 3R-112) MWD+IFR2+SAG+MS OWSG MWD +IFR2+Sag +Multi -Station Correction 2,494.87 3,994.87 3R-112wp04(Plan: 3R-112) MWD OWSG OWSG MWO- Standard 2,494.87 5,962.63 3R-112wp04(Plan: 3R-112) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correction 5,962.63 7,462.63 3R-112wp04(Plan: 3R-112) MWDOWSG OWSG MWD - Standard 5,962.63 12,359.18 3R-112wp04(Plan: 3R-112) MWD+IFR2+SAG+MS OWSG MWD +IFR2+Sag +Multi -Station Correction 5292019 11:19:O0AM Page 2 COMPASS 5000.14 Build 850 ConocoPhillips Error Ellipse Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well Plan: 3R-112 Project: Kupauk River Unit -2 TVD Reference: Plan D142: 39.1 +9.8 @ 48.90usft (Doyon 142) Site: Kupawk 3R Pad MD Reference: Plan D142: 39.1 +9.8 @ 48.90usft (Doyon lalaral 142) Well: Plan: 3R-112 North Reference: True Wellbore: Plan: 3R-112 Survey Calculation Method: Minimum Curvature Design: 3R-112wp04 Output errors are at 2.00 sigma Bias E., Database: OAKEDMPI Plan Survey Tool Program Date 5/29/2019 Error A ir,wh T.0 Depth From Depth To fl (11 (usft) (usft) Survey (Wellbore) Tool Name Remarks (..ft) 1 39.10 1,100.00 3R-112wpO4 (Plan: 3R-112) GYD-GGSS (UM) (usft) luau) Gyrodata gyro single shots 2 1,100.00 2,494.87 3R-112wpO4 (Plan: 3R-112) MWD OWSG 39.10 0.00 0.00 OWSG MWD - Standard 0,00 3 1,100.00 2,494.87 3R-112wp04 (Plan: 3R-112) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + 4 2,494.87 3,994.87 3R-112Wp04 (Plan: 3R-112) MWD OWSG OWSG MWD - Standard 5 2,494.87 5,962.63 3R-112wp04 (Plan: 3R-112) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + 6 5,962.63 7,462.63 3R-112Wp04 (Plan: 3R-112) MWD OWSG OWSG MWD -Standard 7 5,962.63 12,359,18 3R-112Wp04 (Plan: 3R-112) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Position uncertainty and bias at survey station M.a.uraa mdinaaon Amumh va,ur.l wgnsmo lalaral wninal M.9afton4 5.m ,lpr Semi.minor mpm Depth Error Bias E. Bias E., Bus aeiaa Emar Error A ir,wh T.0 lase) fl (11 (Deal fusel lush) (..ft) (use) (use) fuss/ (UM) (usft) luau) (°) 39.10 0,00 0.00 39.10 0.00 0.00 0.00 0,00 000 0.00 0.00 000 0.00 0,00 UNDEFINED 10000 0.00 0.00 $00.0 0.09 0.00 0.09 000 2.30 0.00 0.00 0.09 0.09 0.00 GYD-GGW(1, 1) 200.00 0.00 0,00 200.00 0.38 0.00 0.38 0.00 2.30 0.00 0.00 030 0.38 0.00 GYD-GO-SS(1. 1) 250.00 0,00 0.00 250.00 0.52 0.00 0.52 0.00 230 0.01 0.01 0.52 0.52 0,00 GYD-GGSS(1, 1) 300.00 0.75 105.00 300.00 ass 0.00 0.63 0.00 2.30 0.01 0.01 0.63 0.63 45.00 GYDGGSS(1, 1) 400.00 2.25 105,00 asses 0.81 0.00 0.81 0.00 230 0.02 0.02 0.81 0.81 15.43 GYD�GC-S$(1, 1) 450.00 3.00 105.00 449.91 0.93 0.00 0.93 0.00 2.30 0.02 0.02 0.93 0.93 15,38 GYDGDSS(1. 1) 500.0 4.25 105.00 499.81 1,05 0.00 1.05 000 2.30 0.03 0.03 1.06 1.05 1550 GYD-GGSs(1, 1) 600.00 6.75 105,00 599.34 IM 0.00 1.32 0.00 2.30 0.04 0.04 1.33 1.32 16.57 GYDGGSS(1, 1) 700.00 9.25 105.00 690.36 1,58 0.00 1.62 0.00 2.30 0.06 0.06 1.62 1.62 45.00 GYD-GGSS (1, 1) 000.00 1135 105.00 798.86 1.86 -0.01 1.94 0.00 2.29 0.07 0.00 1.94 1.92 103.55 GYDGGSS(1, 1) 900.00 14.25 105.00 894.11 2.15 .0.a1 2.30 0.00 2.29 0.10 0.10 2.30 2.23 101.23 GYD-GGSS(1, 1) 1,00a.00 18,75 105.00 990.46 2,46 -0.02 2.70 0.00 2.28 0.12 0,12 2.70 2.55 104.46 GYDGDSS(1, 1) 1,100.00 19.25 105.0 I,a85.56 2.77 -0.02 3.14 0.00 2.20 0,14 0.15 3.14 2.88 104.58 GYDGOSS(1, 1) 1,200.00 21.75 105.00 1,179.22 2,93 .0.02 3.44 0.00 2.52 0.01 0,03 3.44 3.10 101.77 MWD OW5G(1, 2) 1,300.00 24.25 105.00 1,271.28 2.97 -0.02 4.01 0.00 2.56 0.01 0.03 601 3.19 105.30 MWD OWSG(1, 2) 1.400.0 26.75 105.00 1,361.51 3.08 -0.2 5.08 0.00 2.81 0.01 0.03 5.08 3.33 105.45 MWD OW5G(1, 2) 11500.00 29.25 105.00 1,449.00 3.26 0.02 6.56 0.00 2.68 0.01 0,03 6.55 3.53 105.48 MWD OWSG(1, 2) 1,600.00 31,75 105.00 1.535.98 3,50 -0.02 6,37 0.0 2.78 0,01 0,03 0.37 3,77 105.47 MWD OMG(1, 2) 1.700.00 34.25 105.00 1,619.02 3.80 -a.a2 10.46 0.00 2.91 0.01 0.03 10.48 4,04 105.44 MWD OW5G (1, 2) 1.769.1D 35.98 105.00 1.676.34 4.16 -0.02 12,82 0.00 3.09 0,01 0.03 12.82 4,35 105.41 MWD OWGG(1, 2) 1.000.00 36.75 105.00 1,701.22 4.16 -0.02 12.82 0.00 3.09 0.01 0.03 12.02 4.35 105.41 MWD OMG (1, 2) 1,808.22 36,98 105.00 1,707.00 4.19 -0.02 13,02 0.00 3.10 0.01 0.3 13.02 4.38 105.41 MWD OW5G(1. 2) W92019 11:19:00AM Page 3 COMPASS 5000.14 BUIId 86D ConocoPhillips Error Ellipse Report Company: ConocoPhillips Alaska Inc_Kupawk Local Co-ordinate Reference: Well Plan: 3R-112 Project: Kuparuk River Unit -2 TVD Reference: Plan D142: 39.1 + 9.8 @ 48.90usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: Plan 0142: 39.1 +9.8 ® 48.90usft (Doyon Lateral Wrdcal 142) Well: Plan: 3R-112 North Reference: True Wellbore: Plan: 3R-112 Survey Calculation Method: Minimum Curvature Design: 3R-112wp04 Output errors are at 2.00 sigma Error Bias Database: OAKEDMP7 Position uncertainty and blas at survey station MeaSums Inclination Asimath Ventral Highslde Lateral Wrdcal Ma9nituds seminals, semiminur Depth Depth Eno, alas Ensr Bias Error Bias of Bias Error Error AalmNh Tool (usft) r) /°1 (rift) (usn) (ush) (uaft) loan) (usft) (us") loan) (usft) (oan) (°) 1,83)23 sees 105.00 1]30.98 4.58 -002 15.32 0.00 330 0.01 0.03 15.32 467 105.39 MWO OW9G(1, 2) 1,900.00 36.96 105.00 1.78114 4.58 -0.02 15.32 0.00 3.30 0.01 0.03 15.32 4.67 105.39 MWD 0WSG(1, 2) 1,933.36 36.96 105.00 1&17.80 4.23 -0.02 16.16 0.00 3.38 0.01 0.03 16.16 4.28 105.39 MWD OMG (1. 2) 2,000.00 32.42 10112 1,850.90 5.13 -0.02 12.82 0.00 3.55 0.01 0.03 19.86 5.00 105.20 MWD OMG (1, 2) 2,100.00 38.34 95.22 1,939.85 5.96 4.02 20.24 0.00 3.82 0.01 0.03 20.46 5.35 104.38 MWD OMG (1, 2) 2,108.31 38.43 95.27 1948.36 7.07 -0.02 22.58 -001 4.10 0.01 0.03 23.10 5.71 103.5 MWD OMG (1, 2) 2,200.00 3960 90.46 2,017.67 7.07 -0.02 22.56 -0.01 4.10 0.01 0.03 23.10 5.71 103.05 MWD 0WSG(1, 2) 2,300.00 40.89 85.48 2,094.07 8.30 -0.02 24.84 41.01 491 0.01 0.03 25.28 6.08 101.44 MWD OMG (1, 2) 2,400.0 42.48 80.79 2.16817 9.59 -0.02 27.04 -0.01 4.73 0.01 0.03 28AS 6.47 99.62 MWD OMG (1. 2) 2,494.87 44.16 76.61 2,237.80 10.81 -0.02 29.09 -0.01 5.06 0.01 0.03 31.08 683 97.77 MWD 0WSG(2, 3) 2,500.00 44.16 76.61 2,241.40 6.93 -0.02 13.86 -0.01 6.03 0.01 0.03 14.87 5.77 99.72 MWD OMG (2, 3) 2,514.87 44.16 76.61 2.252.15 6.93 4.02 13.95 41.01 4.04 0.01 0.03 14.95 5.78 99.54 MWD OMG (2, 3) 2,600.00 43.94 71.72 2,313.35 7.42 4).02 14.29 -0.01 4.11 0.01 0.03 15.63 5.85 97.74 MWD OMG (2. 3) 2,700.00 43.96 65.96 2,385.37 8.09 -0.02 15.04 -0.02 4.22 0.01 0.03 16.75 6.36 94.41 MWD OMG (2, 3) 2.800.00 44.27 60.23 2.457.19 8.83 4).02 16.05 -0.02 4.37 0.01 0.03 18.11 6.92 90.36 MWD OMG (2, 3) 2,900.00 44.86 54.69 2,528.47 9.60 -0.02 1720 -0.02 4.56 0.01 0.03 19.63 7.58 86.05 MWD OMG (Z 3) 3,000.00 45.72 49.09 2,598.05 10.40 4.01 18.42 -0.02 4.78 0.01 0.03 2134 8.22 81.77 MWD OMG (2, 3) 3,100.00 46.84 43.77 2,667.99 11.19 4).01 19.65 .0.02 5.03 0.01 0.03 22.91 8.87 77.65 MWD OMG (2.3) 3,200.00 48.19 36.67 2,735.55 11.94 -0,01 2085 -0.02 5.32 0.01 0.03 24.58 9.50 73.75 MWD OMG (2, 3) 3,300.00 49.76 33.79 2,801.21 12.84 4.1 21.99 -0.02 5.64 0.01 0.03 25.26 10.11 70.07 MVA OMG (2, 3) 3.400.00 51.52 29.15 2,864.65 13.27 -0.01 23.08 -0.02 5.99 0.01 0.03 27.90 10.69 65.50 MWD OMG (2. 3) 3,439.69 52.27 27.37 2,989.14 13.80 -0.01 24.12 -0.02 6.38 0.01 0.03 29.52 11.25 6392 MWD OMG (2, 3) 3.500.00 5346 24.73 2.925.55 43.80 -0.01 24.12 -002 6.38 0.01 0.03 29.52 11.25 63.32 MVA OMG (2.3) 3.600.00 55.55 20,85 2,993.63 14.23 -0.01 25.10 -0.02 6.79 0.01 0.03 31.10 11.81 60.19 MM OMG (2,3) 3.700.00 57.78 16.57 3,038.59 14.55 4),01 26.06 -0.02 735 0.01 0.03 32.65 12.37 57.19 MVA OMG (2, 3) 3,scool 60.13 12.79 3,090.17 14.77 0.00 2200 -0.02 7.73 0.01 0.03 34.17 12.97 54,26 MWD OMG (2, 3) 3,900.00 62.58 9,18 3,138.12 14.87 0.00 27.98 -002 8.25 0.01 0.3 35.67 13.61 51.36 MWD OMG (2, 3) 3.903.40 62.88 9.07 3,139.68 10.42 0.00 13.76 -0.02 6.65 0.01 0.03 2021 11.59 69.13 Mt /IFR2+SAG+MS(3, 3) 4,000.00 65.12 5.74 3,18210 10.42 O.0 13.76 -0.02 6.65 0.01 043 20.21 11.59 89.13 MM-IFR2+SAG+M8(3.3) 4,100.00 67,73 2.44 3,222.20 10.19 0.00 14.18 -0.02 6.95 0.01 0.03 20.52 12.16 66.25 MVA+IFR2+SAG+MS(3,3) 4.200.00 7041 359.25 3.257.93 9.95 0.00 14.68 -0.02 7.26 0.01 0.03 2083 1277 63.16 MWD+IFR2+SAG+MS(3,3) 4237.31 71.42 358.09 3,270.13 9.84 0.00 14.95 .0.02 7.42 0.01 0,03 20.99 13.08 61.57 MVA+IFR2+SAG+MS(3, 3) 4,248.52 71+73 357.75 3,273.68 9.84 0.00 14.95 -0.02 742 0.01 0.03 was 1306 61,57 MWD+IFR2+SAG+MS(3,3) 4.30000 71,73 357.75 3,289.81 9.99 0.00 1545 -0.02 7.59 0.01 0,03 21.16 13.42 59.79 MWD+IFR2+SAG+MS (3,3) 4,346.90 71.73 357.75 3,304.52 10.13 0.00 15.93 -0.02 7.75 0.01 0,03 21.33 13.73 58.06 MVA+IFR2+SAG+MS(3,3) 4,400.00 71.92 355.52 3,321.09 10.27 0.00 16,20 -0.02 7.93 0.01 0.03 21.53 14.08 56.04 MVA+IFR2+SAG+MS (3.3) 4.9OO.00 72,36 351.35 3,351.76 10.53 0.00 16.77 -0.02 828 0.01 0.03 2191 14.78 51.99 MWD+IFR2+SAG+MS(3,3) 4,600.00 72.88 347.19 3,381.64 10.76 0.00 17.42 -0.02 063 0.01 0.03 22.31 15.50 0.55 MWD+IFR2+SAG+MS(3,3) 4.700.00 73.49 343.06 3410.57 10,98 0.00 18.15 -0.02 8.99 0.01 0.03 22.74 16.26 42.61 MWD+IFR2+SAG+MS(3,3) 4,70425 73.52 342.89 3,411.78 11.19 0.00 18.98 .0.02 9.36 0.01 0.03 23.21 17.05 37,03 MWD+IFR2+SAG+MS(3, 3) 4,800.00 74.18 336.96 3,438.42 11.19 0.00 Mel -0.02 9.36 0.01 0.03 23.21 17.05 37.03 MWD+11'R2+SAG+MS (3, 3) 4,900.00 74.95 334.88 3,465.05 11.39 0.00 19.91 -0.02 9.72 0.01 0.03 23.75 17.66 30.69 MWD+IFR2+SAG+MS(3, 3) 5,(100.00 75.78 330.84 3.490.32 11.58 0.00 20.94 -0.02 10.10 0.01 0.03 24.40 18.64 23.57 MWD+IFR2+6AG+MS(3, 3) 5,100.00 76.69 326.83 3,514.12 11.77 0.00 22.06 -0.02 10,48 0.01 0.03 25.17 19.38 15.84 MWD+IFR2+SAG+MS(3, 3) 5120000 77.66 322.85 3,536.33 11.96 0.00 23.27 .0.01 10.86 0.01 0.03 26.11 20.05 7,92 MWD+IFR2+SAG+MS(3, 3) 5.300.00 78.68 31090 3,556.85 12.17 0.00 24,55 -0.01 11.25 0.01 0.03 27.21 20.63 0.30 MWD+IFR2+SAG+MS(3, 3) 5,400.00 79.76 314.98 3.575.56 12ail 0.00 25.89 -0.01 11.64 0.01 0.03 28,48 21.12 173.36 MWD+IFR2+SAG+MS(3, 3) 5,500.00 80.88 311.08 3,592.36 12.60 0.00 27.28 -0.01 12.03 0.01 0.03 29.09 21.54 167.22 MWD+IFR2+6AG+MS(3, 3) 5.600.0 8204 307.21 3,607.23 12.85 0.00 28.69 -0.01 12.43 0.01 0.03 31,42 21.90 161.85 MWD+IFR2+SAG+MS(3, 3) 5,700.00 83.24 303.37 3,620.04 13.11 0.00 30.11 -0.01 12.83 0.01 0.03 33.04 22.21 157,14 MWD+IFR2+SAG+MS(3. 3) 5,739.47 83.73 301.85 3.624.52 13.29 0.00 3099 -0.01 13.8 0.01 0.03 34.00 22.39 154.51 MWD+IFR2+6AG+M9(3, 3) 5,761,73 04.00 301.00 3,626.90 13,29 0.00 30.99 -0.01 13.08 0.01 0.03 34.08 22.39 154.51 MWD+IFR2+SAG+MS (3, 3) 5292019 11:19:00AM Page 4 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit -2 Site: Kupamk 3R Pad well: Plan: 3R-112 Wellborn: Plan: 3R-112 Design: 3R-112wpO4 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Co -Ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 3R-112 Plan D142: 39.1 + 9.8 @ 48.90usft (Doyon 142) Plan D142: 39.1 +9.8 @ 48.90usft (Doyon 142) True Minimum Curvature 2.00 sigma OAKEDMPI Measured Inclination Azimuth vertical Hlghalde tate2l Vettical Magnitude Smofl n.ter Semi+ninar Now aepm Error Bias Ertor Blas Eoor Bks or Bias Ertor Error Azimtah now (usn) (°I r) (uoe) (coal, (9m) (..ft) haat (uaft) (usftl (test (usft) (usn) CI 5,800.00 94.00 301.00 3,63090 1344 000 31.78 -0.01 13.23 0,01 0.03 U.74 22.49 152.99 MA0+1FR2+5AG+MS(3, 3) 5.900.00 84.00 301.00 3,641.35 13.84 0.00 33.90 -0.01 13.64 0.01 0.03 36.55 n.72 149.50 MWD+IFR2+SPG+MS(3. 3) 5.982.63 84.00 301.00 3,647al) 14.09 0.00 35.24 -0.01 13.99 0.01 0.03 37.73 22.83 147.65 MWD OMG (3, 4) 5,992.63 84.00 301.00 3,849.99 14.13 0.00 35.50 -0.01 13.79 0.01 0.03 38.48 23.79 150.42 MWD OMG (3,4) 5000.00 84.18 300.15 3,651.78 14.11 0.00 35.42 4).01 13.79 0.01 0.03 38.81 23.71 150AB MWD OMG (3.4) 6,020.33 84.40 299.15 3,653.80 14.03 0.00 35.32 000 13.83 0.01 0.03 39.67 23.44 149.62 MWD OMG (3+ 4) 6,100.00 85.27 295.25 3,86ew 14.03 0.00 35.32 0.00 13.03 0.01 0.03 39.67 23.44 149.62 MWD OWSG(3,4) Q200.00 96.39 290.36 3,668.25 14.01 0.00 35.84 0.00 13.91 0.01 0.03 4118 23.53 147.24 MWD OWSG(3,4) 6,300.00 87.54 285.49 3,673.55 14.06 0.00 36.95 0.00 14.03 0.01 0.03 43.08 Mae 143.73 MWD OMG (3.4) 8,400.00 80.70 280.62 3,676.83 14.19 -0.01 36.56 0.00 14.19 0.01 0.03 45.33 24.75 139.48 MWD OWSG (3.4) 6,500.00 89.88 275.76 3,678.07 14.39 -aul 40.55 0.00 14.40 0.01 0.03 47.89 25.69 134.84 MWD OMG (3.4) 6,589.11 90.92 271.43 3,677.45 14.65 -0.01 42.52 0.01 last 001 0.03 50.38 26.81 130.81 MWD OMG (3. 4) 6,600.00 90.92 271.43 3,64.20 14.68 -0.01 42.95 0.01 14.64 0.01 0.03 50.70 26]2 130.10 MWD OMG (3, 4) 6,700.00 WW2 271.43 3,675.67 14.96 -0.al 47.21 0.01 14.92 0.01 0.03 53.86 27.72 125.50 MWD 0VJ5G(3,4) 8,715.94 90.92 271.43 3,675.41 15.01 -0.01 47.91 0.01 14.97 0.01 0.03 5140 27.87 124.0 MWD OWSG(3,4) 6,752.08 90.70 270.00 3.674.90 15.11 -0.01 40.98 0.01 15.08 0.01 0.03 55.64 28.20 123.40 MWD OWS3(3, 4) 6,900.00 92.59 269.65 3,873.53 15.41 -0.01 $1.00 0.01 15.24 0.01 0.03 57.35 28.62 121.49 MWD OMG (3.4) 6.886.91 96.00 26900 3,657.02 16.16 -0.01 54.75 0.01 15.54 0.01 0.03 80.60 29.31 118.32 MWD OMG (3,4) 6,900.00 95.48 288.91 3,655.71 16.14 -0.01 55.33 0.01 15.59 0.01 0.03 61.10 29.40 117.88 MWD OMG (3.4) 7,000.00 91.54 268.26 3,659.59 16.05 -0.01 69.81 0.01 1598 0.01 0.03 65.12 30.09 114.73 MWD OMG (3,4) 7.038.97 Wee 260.00 3,659.07 16.12 -0.01 61.59 0.01 18.12 0.01 0.03 86]4 30.33 113.63 MWD OMG (3 4) 7,053.13 WAS 267.37 3.659.05 16.18 -0.01 62.03 0.01 16.18 0.01 0.03 67.34 30.41 113.24 MWD OWSG(3, 4) 7,10000 90.15 267.37 3,658.92 16.38 -0.01 64.31 0.01 16.37 0.01 0.03 89.33 30.60 112.00 MWD OMG (3,4) 7.200.00 90.15 267.37 3,659.66 16.81 -0.01 69.24 0.01 16.81 0.01 0.03 73.73 31.19 109.65 MWD OMG (3,4) 7,256.91 90.15 267.37 3.658.51 17.07 -0.01 72.08 0.01 17.07 0.01 0.03 76.30 31.44 109.47 MWD OMG (3, 4) 7,364.00 90.76 269.25 3,658.16 17.30 -0.01 7495 0.01 17.27 0.01 0.03 7829 31.62 107.67 MWD OMG (3, 4) 7,317.06 91.00 270.00 3.657.90 17.39 -0.01 76.08 0.01 17.35 0.01 0.03 79.10 31.68 107.38 MWD OMG (3.4) 7,400.00 94.31 270.17 3,656.06 1806 -0.01 sow 001 17]5 0.01 003 03.00 31.95 106.12 MM GW5G (3.4) 7481.80 97.58 270.33 3,645.59 16.25 -0.01 45.16 001 15.40 0.01 0.03 49.62 30.00 121.67 MVA)AFR SAG+MS(4,4) 71500.00 97.50 270.33 3,643.18 16.28 -0.01 45.51 0.01 15.43 0.01 0.03 49.89 30.09 121.23 MWD+IFR2+SAG+10S(4,4) 7,600.00 97.58 270.33 3,629.99 16.48 -0.01 4743 0.01 15.64 0.01 0.03 51.40 Sam 1111.94 MW1)+1FR2+SAG+MS(4,4) 7,700.00 97.50 270.33 3,618]9 16.68 -0.01 49.40 0.01 15.65 0.01 0.03 52.99 30.96 116.82 1JWD+1FR2+SAG+MS(4, 4) 7,719.61 97.58 270.33 3,614.1 16.72 -0.01 49.79 0.01 15.90 0.01 0.03 53.32 3104 116.42 MWD+1FR2+SAG+MS(4,4) 7,900.00 94.37 270.27 3,605.84 16.42 -0.01 51.40 0.01 16.08 0.01 0.03 54.68 31.33 114.87 MM+IFR2+SAG+MS(4,4) 7,884.10 91.00 270.20 3,601.90 16.32 -0.01 53.12 0.01 16.28 0.01 0.03 56.17 31.62 113.36 1,W0+IFR2+SAG+MS(4,4) 7,690.39 90.76 270.15 3,601.80 16.32 -0.01 53.24 0.01 16.29 0.01 0.03 56.20 31.64 113.25 MVA+IFR2+SAG+MS(4.4) 7,900.00 9036 270.15 3,601.66 16.35 -0.01 53.44 0.01 16.32 0.01 0.03 56.46 31.67 113.09 MA0AFR2+SAG+1JS(4,4) 8,000.00 90+76 270.15 3,600.36 16.59 -0.01 5554 0.01 16.56 0.01 0.03 56.3) 31.98 111.47 MWD+IFR2+SAG+MS(4,4) 8,10000 90.76 270.15 3,599.04 18.85 -0.01 57.67 0.01 16.82 0.01 0.03 60.20 32.26 110.01 MWWIFR2+SAG+MS(4,4) 8,20000 90.76 270.15 3,597.72 17.11 4).01 59.83 0.01 Wes 0.01 0.03 62.16 32.51 108.70 1AVJD+1R SAG+1AS(4,4) 8,300.00 00]6 270.15 3,596.39 17.39 -0.01 62.01 0.01 17.35 0.01 0.03 64.16 32]3 107.51 MWD+1FR2+SAG+MS(4,4) 0,310.54 90.76 270.15 3,596.15 17.44 -0.01 62.41 0.01 17.40 0.01 043 64.53 32.77 107.31 MWD+IFR2+SAG+MS(4.4) 8,356.38 90.00 270.16 3,595.90 17.51 -0.01 63.25 0.01 17.51 0.01 0.03 65.30 32.85 106.90 MWD+IFR2+SAG+MS(4,4) 8,382.34 89.4a 270.16 3,596.02 17.57 -0.01 63.82 0.01 17.58 0.01 0.03 65.84 32.90 106.63 MWD+IFR2+SAG+MS(4, 4) 8,400.00 89.48 270.16 3,596.16 17.62 -0.01 64.21 0.01 17.63 0.01 0.03 66.20 32.94 106.45 MWD+IFR2+SAG+MS(4,4) 9,500.00 89.48 270.16 9,597.08 17.911 -0.01 66.42 0.01 17.92 0.01 0.03 60.27 33.12 105.49 MPID+1FR2+SAG+MS(4.4) 8.80000 89.48 270.16 3,597.99 18.20 -0.01 66.66 0.01 18.21 0.01 0.03 70.36 33.30 104.62 MMA+IFR2+SAG+MS(4,4) 8,667.47 09.40 270.16 3,598.78 18.46 -0.01 70.62 0.01 18.48 0.01 0.03 72.25 33.44 103.92 MWD+IFR2+SAG+MS(4,4) 8,700.00 69.73 270.16 3,598.87 18.50 -0.01 70.91 0.01 18.51 0.01 0.03 n.52 33.46 103.82 MWWIFR2+SAG+MS(4,4) 8,713.43 Bow 270.16 3,599.90 18.55 -0.01 71.21 0.111 16.55 0.01 0.03 72.80 33.48 10312 MWD+IFR2+SAG+1AS(4,41 8,784.03 91.41 270.16 3,599.03 18.83 -0.01 72.80 001 18.n 0.01 0.03 74.33 33.58 103.22 MW ffn+SAG+MS(4,4) 8.800.00 91.41 270.16 3,597.64 18.88 -0.01 73.17 0.01 16.02 0.01 0.03 74.68 33.80 103.11 1AWD+IFR2+8AG+1JS(4.4) 0,900.00 91.41 270.16 3,595.17 19.19 -0.01 75.44 0.01 19.13 0.01 0.03 76.86 33.74 102.45 MWD+1FR2+SAG+MS(4,4) 5292019 11:19.00AM Page 5 COMPASS 5000.14 Build 85D Company: ConaccPhillips Alaska lnc_Kuparuk Project: Kuparuk River Unit -2 Site: Kuparuk 3R Pad ConocoPhillips Error Ellipse Report Local Coordinate Reference: TVD Reference: MO Reference: Well: Plan: 3R-112 North Reference: Wellbore: Plan: 3R-112 Survey Calculation Method: Design: 3R-112wp04 Output errors are at Database: Well Plan: 3R-112 Plan D142: 39.1 + 9.8 @ 48.90usft (Doyan 142) Plan D142: 39.1 + 9.8 @ 48.90usft (Doyon 142) True Minimum Curvature 2.00 sigma OAKEDMPI Position uncertainty and bias at survey station Measured Inclination Azimuth varietal Rl9hside lateral vertical Ma9nhade Semimgpr scsh mita Depth Depth Ems Bias Empr Bias E. Blas ofBase Enor Eea Azlmeth Tad (ea") (I (°I (usn) (u31) (rift) (earn (usn) (us6) ft an) (earn I -aft) (uaB) (°) 8,956.93 91.41 270.16 3,593.77 19.37 -0.01 76.74 0.01 1931 0.01 0.03 78.11 33.81 102.10 MWD+IFR2+SAG+MS (4,4) 9,000.00 90.55 270.16 3,593.03 19.47 -0.01 77.72 0.01 19.45 0.01 0.03 79.06 33.87 101.85 MWD+IFR2+SAG+MS (4,4) 9,027.53 9000 270.16 3592.90 19.54 -0.01 78.38 0.01 lass 0.01 0.03 79.67 33.90 1D1.70 MW 1FR2+SAG+MS(4,4) 9,036.86 89.81 270.16 3,592.92 law -0.01 78.57 0.01 19.57 0.01 0.03 79.00 33.91 101.64 MW IFR2+SAG+MS(4,4) 9,100.00 89.81 270.16 3,593.12 19.77 -0.01 80.02 0.01 19.77 0.01 0.03 81.20 33.99 101.30 MWD+IFR2+SAG+MS(4, 4) 9,200.00 89.81 270.16 3,59345 20.09 -0.01 8232 001 20.10 0.01 0.03 03.52 34.10 100.80 MWD+IFR2+8AG+MS(4, 4) 9.300.00 89.81 270.16 ],593]7 20.43 4).01 84.84 0.01 20.43 0.01 0.03 85.77 34.21 10D.33 MWD+IFR2+SAG+MS(4,4) 9,336.90 89.81 270.16 3,59189 n.55 4.01 85.49 0.01 20.55 0.01 0.03 86.60 34.25 100.17 MWD+IFR2+SAG+MS(4. 4) 9,341.56 90.00 270.16 3,593.90 20.57 -0.01 85.60 0.01 20.57 0.01 0.03 0.71 34.25 100.15 MWD+IFR2+SAG+MS(4,4) 9,400.00 92.34 270.16 3,592.71 20.0 -0.01 06.96 0.01 20.T7 0.01 0.03 88.03 3431 99.90 MVVD+IFR2+SAG+MS(4,4) 9,600.00 96.34 270.15 3,585.15 21.0 -0.01 89.27 0.01 21.11 0.01 0.03 90.30 34.41 99,51 MWD+IFR2+SAG+MS(4,4) 9,519.04 97.13 270.15 3,582.82 2174 .0.01 89.73 0.01 21.19 0.01 0.03 90.74 3643 99.43 MWD+IFR2+SAG+MS(4,4) 9.592.81 97.13 270.15 3573.76 21.98 -0.01 91.41 0.01 21.43 0.01 003 9239 34.49 99.17 MWD+IFR2+SAG+MS(4,4) 9800.00 98.84 00.15 3,572.89 21.97 .0.01 91.50 0.01 21.45 0.01 0.03 92.56 00.50 99.14 MWD+(FR2+SAG+MS(4,4) 9,7M.OD 92.84 270.16 3,564.45 21.94 -0.01 93.90 0.01 21.80 0.01 0.03 94.84 34.59 98.80 MWD+IFR2+SAG+MS(4.4) 9,746.09 91.00 270.16 3,582.90 22.00 -0.01 84.99 0.01 21.0 0.01 0103 95.90 34.63 98,65 MWD+IFR2+SAG+MS(4,4) 9,792.90 89.13 270.16 3,02.05 22.10 -0.01 06.08 0.01 22.13 0.01 0.03 96.98 34.67 98.50 MWD+IFR2+SAG+MS(4,4) 9,800.00 89.13 00.16 3,562.96 22.13 -0.01 0.25 0.01 22.15 0.01 0.03 97.14 34.67 98.48 MWD+IFR2+SAO+MS(4,4) 9,90.00 89.13 270.16 3,564.40 22.49 -0.01 98.60 0.01 2251 0.01 0.03 99.46 U.76 98.18 MWD+IFR2+$AG+MS(4,4) 9,971.51 89.13 270.16 3,565.57 22.74 -001 100.28 0.01 22.77 0.01 0.03 101.11 %.81 97.98 MWD+IFR2+SAG+MS(4,4) 10,000.00 89.70 270.16 3.05.0 22.66 -0.01 Mills 0.01 22.87 0.01 0.03 101.70 34.84 97.90 MWD+IFR2+8AG+MS(4,4) 10,015.14 90.00 270.16 9,565.90 22.93 -0.01 101.31 0.01 22.93 0.01 0.03 102.13 34.85 97.86 MWD+IFR2+SAG+MS(4,4) 10,099.87 91.69 270.16 3.564.65 23.31 -0.01 103.32 0.01 23.23 0.01 003 104.10 34.91 97.64 MWD+IFR2+SAG+MS(4,4) 10.100.00 91.69 270.16 3,564.0 2131 -0.01 10.32 0.01 23.23 0.01 0.03 104.10 34.91 97.64 MWD+IFR2+SAG+MS(4,4) 10.200.00 91.60 270.16 3,561.69 23.67 -0.01 105.68 0.01 23.60 0.01 0.03 106.04 34.99 97.40 MW0+IFR4+SAG+MS (4,4) 10,300.00 91.69 270.16 3,558.73 24.04 -0.01 108.05 0.01 23.97 0.01 0.03 108.70 35.06 97.16 MVJD+IFR2+SAG+M8 (4, 4) 10,400.00 91.69 270.16 3,555,71 24.41 -0.01 110.43 0.01 24.34 0.01 0.03 111.13 35.13 %.95 MWD+IFR2+SAG+MS(4,4) 10,08833 91.69 270.16 3,553.16 24.74 -0.01 11252 0.01 24.68 0.01 0.03 113.20 35.20 0.77 MVJD+lFR2+SAG+M8 (4,4) 10,496.37 9200 270.16 3552.90 2A.79 -0.01 112.72 0.01 24.71 0.01 0.03 113.40 M,m 0.75 MM+IFR2+SAG+MS(4,4) 10,500.00 92.14 270.16 3,552.7] 24,81 -0.01 112.90 0.01 24.72 0.01 0.03 113.40 35.20 96.74 MWD+IFR2+SAG+MS (4,4) 10,600.00 95.89 270.16 3,545.78 25.0 -0.01 115.17 0.01 25.10 0.01 0.03 115.83 35.2 96.55 MVJD+IFR2+6AG+MS (4,4) 10,677.06 98.78 270.15 3,53594 26.01 -0.01 116.99 0.01 25.39 0.01 0.03 117.62 35.32 0.41 MM+IFR2+SAG+MS (4,4) 10,700.00 98.78 270.15 3,53244 26.09 -0.01 117.52 0.01 25.47 0.01 0.03 110.16 35.34 WX MWD+IFR2+SAG+MS(4,4) 10,700.17 98.78 270.15 3,53242 Mrs -0.01 117.52 0.01 25.47 0.01 0.03 110.16 35.34 0.37 MWD+IFR2+SAG+MS(4,4) 10,774.19 SaW 270.16 3,522.00 28.10 -0.01 119.0 0.01 25.75 0.01 0.03 119.89 MM 0.24 MM+IFR2+SAG+MS (4,4) 10,788.56 9546 270.15 3,521-47 MAl 401 119.81 0.01 25.81 0.01 0.03 120.0 35.39 9812 MNLI+IFR2+8AG+MS(4,4) 10,800.00 95.46 270.15 3,520.38 28.18 4.01 119.88 0.01 25.85 Dot 0.03 120.49 MAO 0.20 MWD+IFR2+SAG+MS(4,4) 10,900.00 95.48 270.15 3,510.86 20.54 4.01 12226 001 26.23 0.01 0.03 122.85 35.47 0.04 MNAHFR2+SAG+MS (4,4) 10,903.05 95A6 270.15 3,510.57 28.55 -0.01 122.33 0.01 26.24 0.01 0.03 122.92 35.47 98.03 MWD+IFR4+SAG+MS (4,4) 11.000.00 92.55 270.16 3,503.80 26.73 4.01 124.64 0.01 28.62 0.01 0.03 125.21 35.53 95.08 MWD+lFR2+SAO+MS (4,4) 11,085.09 90.00 270.16 3501.90 26.95 4.01 126.68 0.01 26.95 0.01 0.03 127.23 35.0 95,75 MMID+IFR2+SAG+MS (4,4) 11,085.34 89.99 270.16 3501.90 28.95 -0.01 126.68 0.01 Wes 0.01 0.03 1033 35.0 95.75 MWD+IFR2+SAG+MS(4,4) 11,100.00 89.99 270.16 3501.90 27.01 -0.01 127.03 0.01 27.01 0.01 0.03 127.59 35.59 95.73 MWD+lFR2+SAG+MS(4,4) 11,200.00 89.99 270.16 3.501.91 27.40 4.01 129.43 0.01 240 0.01 0.03 129.97 35.66 95.59 MWD+IFR2+SAG+MS(4,4) 11,260.43 89.99 270.16 3,501.92 27.61 -0.01 130.08 0.01 2.64 0.01 0.03 131.41 35.69 95.51 MM+IFR2+SAG+MS (4,4) 11,300.00 8920 270.16 350220 27.77 -0.01 131.83 0.01 27.79 0.01 0.03 132.35 35.72 95.45 MWD+IFR2+SAG+MS(4,4) 11,335.13 88.50 270.16 3,502.90 27,89 4.01 132.67 0.01 27.93 0.01 0.03 133.19 35.74 95.41 MWD+IFR2+SAG+MS(4,4) 11.390.31 87AO 270.16 3,504.88 28.00 0.00 133.99 0.01 28.15 0.01 0.03 134.50 35.77 95.34 MMID+IFR2+SAG+MS (4,4) 11,400.00 87.40 270.16 3,505.32 28.12 0.00 134.23 0.01 28.19 0.01 0.03 134.73 35.78 95.32 MWD+IFR2+SAG+MS(4. 4) 11.00.00 87AO 270.16 3,509.0 28.52 0.00 136.62 0.01 28.58 0.01 0.03 137.12 35.84 95.20 MWD+lFR2+SAG+MS(4,4) 11,517.52 87AO 270.16 3,510.65 28.59 0.00 137.04 0.01 28.65 0.01 0.03 137.53 35.85 95.16 MM+IFR2+SAG+MS (4,4) 11,572.34 90.00 270.16 3,511.90 28.87 -0.01 138.36 0.01 28.87 0.01 0.03 130.84 35.88 95.12 MVVD+1FR2+SAG+005(4,4) 5292019 11: 19:OOAM Page 6 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska Inc_Kupamk Project: Kuparuk River Unit_2 site: Kuparuk 3R Pad Well: Plan: 31R-112 Wellborn: Plan: 3R-112 Design: 3R-1 l2MIp04 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Coordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 3R-112 Plan D142: 39.1 + 9.8 @ 48.90usft (Doyon 142) Plan D142: 39.1 + 9.8 @ 48.90usft (Doyon 142) True Minimum Curvature 2.00 sigma OAKEDMPt el.suaW Inclination AvmuW wrvm., Higlnilb Labral vertical MagniW6e Semimalor Seml+nlnw U;Ah Dean Error aias Error Bias Emr Bias ofs,.s Error Emr Anima Tod (usm (1 r) (usft) (nsft) (usn) (usft) (..ft) (usm (usnl (waft) (ush) (rift) (9 11,600.00 91.31 270.16 3.511.58 29.03 -001 139.02 0.01 2898 0.01 0.03 139.51 35.90 95.08 MVrDNFR2+SAG+M5(4,4) 11,70000 95.08 270.15 3.505.15 29.68 -0.01 141.42 0.01 29.36 001 0.03 141.89 35.96 94.97 MV .IFR2+SAG+MS(4,4) 11721.54 97.09 270.15 3,502.68 29.84 -0.01 141.93 0.01 29.47 0.01 0.03 142.40 35.97 WaS MVrt1+1FR2+SAG+MS(4,4) 11,731.07 97.09 270.15 3,501.51 29.00 -0.01 142.16 0.01 29.51 0.01 0.03 142.63 35.97 94.94 MND+IFR2+SAG+MS(4,4) 11,75396 96.00 270.16 3,498.90 29.89 -0.01 142.71 0.01 29.60 0.01 003 143.17 35.99 94.92 MV IFR2+SAG+MS(4,4) 11,800,00 93.81 270,16 3,494.96 29.95 -0.01 143.81 001 29.79 0.01 0.03 144.27 36.01 94.87 MWD+IFR2+SAG+MS(4,4) 11.851.46 91.37 270.16 3,492.64 30.04 -0.01 145,05 0.01 29.99 0.01 0.03 145.50 36.04 94.81 MWD+IFR2+SAG+MS (4,4) 11,900.00 91.37 270.16 3.49148 30.23 .0.01 146.22 0.01 30.18 0.01 0.03 145,86 36.07 94.76 MVd3+lFR2+5AG+M8 (4.4) 11,900.47 91.37 270.15 3,489.36 30.59 -0.01 148.35 0.01 30.51 0.01 0.03 148.79 36.12 94.68 MM.11W+SAG+MS(4,4) 12.00.00 91.83 270.16 3,489.04 30.66 -0A1 140.63 0.01 30.59 0.01 0.03 149.06 36.13 94.67 MWD+1FR2+SAG+MS(4,4) 12,004.26 92.00 270.16 3,488.90 30,68 -0,01 148.73 0.01 30.61 0.01 0.03 149.17 36.13 94.66 MM+IFR2+SAG+M8 (4, 4) 12059.54 94.21 270.16 3,485,90 31.01 -0.01 150.06 0.01 30.83 0,01 0,03 150.49 36.17 9181 MVA+1FR2+SAG+MS(4,4) 12,10,00 94,21 270.16 3,482.93 31.19 -0.01 151.04 0.01 30.99 0.01 0.03 151.46 36.19 W,57 MVrt1+1FR2+SAG+MS(4,4) 12,200.00 94.21 270.16 3,475.59 3158 -0.01 153.44 0.01 31.40 0.01 003 153.86 36.24 94.40 MWD+1FR2+8AG+M6(4, 4) 12,30.00 94.21 27016 3,468.25 31.99 -0.01 155.115 0.01 31.91 0.01 0,03 156.25 36.30 9439 MV.0+1FR2+SAG+MS(4, 4) 12,359.16 94.21 270.16 3,463.90 32.23 -0.01 157.28 0.01 32.05 0.01 0.03 157.67 36.33 94.34 MV IFR2+SAG+MS(4,4) 512912019 11 19 00AM Page 7 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska lnc Kupamk Project: Kuparuk River Unit -2 Site: Kuparuk 3R Pad ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: Well: Plan: 3R-112 North Reference: Wellbore: Plan: 3R-112 Survey Calculation Method: Design: 3R-112wp04 Output errors are at Database: Design Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +N/S +E/ -W -Shape (1) C) (usft) (usft) (usft) 3R.B12 T21 042618 MVA 0.00 0.00 3,463.90 2,467.54 -5,688.41 - plan hits target center - Circle (radius 100.00) 3R -B12 T20042618 MN 0.00 0.00 3,488.90 2,466.57 -5,334.38 - plan hits target center - Circle (radius 100.00) 3R -B12 T19 042618 MN 0.00 0.00 3,498.90 2,465.89 -5,084.35 - plan hits target center -Circle (radius 100.00) 3R -B72 T16042618 MN 0.00 0.00 3,501.90 2,464.07 -4,416.29 - plan hits target center - Circle (radius 100.00) 3R -B12 T17 042618 MN 0.00 0.00 3,502.90 2,464.75 4,666.31 - plan hits target center - Circle (radius 100.00) 3R-Bi2 Tl8042618 MN 0.00 0.00 3,511.90 2,465.40 -4,903.34 - plan hits target center - Circle (radius 100.00) 3R -B12 T15042618 MN 0.00 0.00 3,522.90 2,463.22 4,106.26 - plan hits target center - Circle (radius 100.00) 3R-1312714042618 MN 0.00 0.00 3,552.90 2,462.47 -3,830.23 - plan hits target center - Circle (radius 100.00) 3R -B12 T12 042618 MN 0.00 0.00 3,562.90 2,460.42 -3,080.16 - plan hits target center - Circle (radius 100.00) 3R -B72 T13042618 MVA 0.00 0.00 3,565.90 2,461.15 -3,349.19 - plan hits target center - Circle (radius 100.00) 3R-812 77 0 042618 MN 0.00 0.00 3,592.90 2,458.46 -2,363.09 - plan hits target center - Circle (radius 100.00) 3R -B72 T11042618 MN 0.00 0.00 3,593.90 2,459.32 -2,677.12 - plan hits target center - Circle (radius 100.00) 3R -B12 T08 042618 MN 0.00 0.00 3,595.90 2,456.63 -1,692.03 - plan hits target center - Circle (radius 100.00) 3R -B12 T09042618 MN 0.00 0.00 3,598.90 2,457.60 -2,049.06 - plan hits target center - Circle (radius 100.00) 3R -B12 T07 050318 MN 0.00 0.00 3,601.90 2,455.39 -1,219.86 - plan hits target center - Circle (radius 100.00) 3R -B12 T07 042618 MN 0.00 0.00 3,607.90 2,454.54 -925.95 - plan misses target center _ Ii -1e i..,wa...on nm by 23.40usft at 7591.68usft MD (3631.08 TVD, 2453.90 N. -929.04 E) Well Plan: 3R-112 Plan D142: 39.1 +9.8 @ 48.90usft (Doyon 142) Plan 0142: 39.1 + 9.8 @ 48.90usft (Doyon 142) True Minimum Curvature 2.00 sigma OAKEDMPI 5292019 11: 19:OOAM Page 8 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska Inc_Kupamk Project: Kuparuk River Unit_2 Site: Kupamk 3R Pad ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: Well: Plan: 31 North Reference: Wellbore: Plan: 3R-112 Survey Calculation Method: Design: 3R-112Wp04 Output errors are at (usft) Name (in) Database: 3R -B12 T00 WSD 04261 0.00 0.00 3,626.90 2,185.70 834.49 - plan hits target center - Circle (radius 100.00) 312 TO6 042618 MN 0.00 0.00 3,642.90 2,453.08 -757.94 - plan misses target center by 9.54usft at 7420.22usft MD (3652.39 TVD, 2452.99 N, -758.93 E) - Circle (radius 100.00) 3R-B12T01 Csg04261£ 0.00 0.00 3,647.90 2,268.06 707.71 - plan misses target center by 7.34usft at 5914.19usft MD (3642.84 TVD, 2263.80 N, 704.52 E) - Circle (radius 100.00) 3R-812 T05 042618 MN 0.00 0.00 3,657.90 2,452.80 -655.93 - plan hits target center -Circle (radius 100.00) 3R -B12 T04 042618 MO 0.00 0.00 3,662.90 2,459.71 -255.87 - plan misses target center by 7.92usft at 6916.82usft MD (3664.20 TVD, 2467.52 N. -256.14 E) - Circle (radius 100,00) 3R -B12 T02042618W 0.00 0.00 3,664.90 2,360.59 514.94 - plan misses target center by 5.88usft at 6128.83usft MD (3663.27 TVD, 2365.84 N, 517.02 E) - Circle (radius 100.00) 31 T03 042618 MN 0.00 0.00 3,674.90 2,469.26 -91.83 - plan hits target center - Circle (radius 100.00) Casing Points Well Plan: 31 Plan D142: 39.1 + 9.8 @ 48.90usft (Doyon 142) Plan D142: 39.1 + 9.6 @ 48.90usft (Doyon 142) True Minimum Curvature 2.00 sigma OAKEDMPI Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 2,494.87 2,237.80 13-1/2"x 10-3/4" 10.750 13.500 5,962.63 3,647.90 9 7/8" x 7-5/8" 7.625 9.875 12,359.18 3,463.90 6-3/4" x 4-1/2' 4.500 6.750 Formations 2,889.14 Top Ugnu C 0.00 Measured Vertical Dip Depth Depth Dip Direction (usft) (usft( Name Lithology (°) (1) 1,769.10 1,676.34 T3 0.00 1,837.23 1,730.98 Base Permafrost 0.00 2,108.31 1,946.36 K15 0.00 3,439.69 2,889.14 Top Ugnu C 0.00 3,903.40 3,139.68 Top Ugnu B 0.00 4,237.31 3,270.13 Top Ugnu A 0.00 4,704.25 3,411.78 Tap N Sands 0.00 5,739.47 3,624.52 Top West Sak D 0.00 6,020.33 3,653.80 Top WS -C 0,00 5/2912019 11: 19: OOAM Page 9 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska lnc_Kupamk Project: Kupawk River Unit -2 Site: Kuparuk 3R Pad ConocoPhillips Error Ellipse Report Local Coordinate Reference: TVD Reference: MD Reference: Well: Plan: 3R-112 North Reference: Wellbore: Plan: 3R-112 Survey Calculation Method: Design: 3R-112wp04 Output errors are at (usft) (usft) Database: Plan Annotations Well Plan: 3R-112 Plan D142: 39.1 + 9.8 @ 48,90usft (Doyon 142) Plan D142: 39.1 + 9.8 @ 48.90usft (Doyon 142) True Minimum Curvature 2.00 sigma OAKEDMPI Measured Vertical Local Coordinates Depth Depth +N/ -S +EJw (usft) (usft) (usft( (usft) comment 250.00 250.00 0.00 0.00 KOP: Start -5.06°/100' DLS, 1.5° TF, for 200' 450.00 449.91 -1.35 5.06 Start Build 2.50 1,808.22 1,707.80 -119.71 446.76 Start 125.14 hold at 1808.22 MD 1,933.36 1,807.80 -139.18 519.43 Start DLS 3.50 TFO-80.00 2,494.87 2,237.80 -137.56 876.23 Start 20.00 hold at 2494.87 MD 2,514.87 2,252.15 -134.34 889.78 Start DLS 4.00 TFO -95.32 4,248.52 3,273.68 965.66 1,524.31 Start 98.37 hold at 4248.52 MD 4,346.90 3,304.52 1,059.00 1,520.64 Start DLS 4.00 TFO-85.07 5,761.73 3,626.90 2,185.70 834.49 Start 200.90 hold at 5761.73 MD 5,962.63 3,647.90 2,288.61 663.23 Start 20.00 hold at 5962.63 MD 5,982.63 3,649.99 2,298.85 646.18 Start DLS 5.00 TFO-77.78 6,589.11 3,677.45 2,465.65 71.08 Start 55.69°/100' DLS, 0° TF, for 126.83' 6,715.94 3,675.41 2,468.81 -55,69 Start 91.834/100' DLS, 4° TF, for 36.14' 6,752.08 3,674.90 2,469.26 -91.83 Start 226.37°/100' DLS, 4° TF, for 134.83' 6,886.91 3,667.02 2,468.09 -226.37 Start 378.1'1100' DLS, 4" TF, for 152.06' 7,038.97 3,659.07 2,464.11 -378.10 Start 392.25°/100' DLS, 4.6' TF, for 14.16' 7,053.13 3,659.05 2,463.54 -392.25 Start 595.81 °/100' DLS, 0' TF, for 203.78' 7,256.91 3,658.51 2,454.18 -595.81 Start 655.93°/100' DLS, 4.6' TF, for 60.14' 7,317.06 3,657.90 2,452.80 -655.93 Start 820.12°/100' DLS, 4' TF, for 164.74' 7,481.80 3,645.58 2,453.27 -820.12 Start 1055.85'/100' DLS, 0" TF, for 237.81' 7,719.61 3,614.21 2,454.63 -1,055.85 Start 1219.86'/100' DLS, 4' TF, for 164.57' 7,884.18 3,601.90 2,455.39 -1,219.86 Start 1226.07'/100' DLS, 4' TF, for 6.21' 7,890.39 3,601.80 2,455.41 -1,226.07 Start 1654.19'/100' DLS, 0° TF, for 428.15' 8,318.54 3,596.15 2,456.53 -1,654.19 Start 1692.03°/100' DLS, 2° TF, for 37.84' 8,356.38 3,595.90 2,456.63 -1,692.03 Start 1717.99°/100' DLS, 2' TF, for 25.96' 8,382.34 3,596.02 2,456.70 -1,717.99 Start 2023.1'/100' DLS, 0' TF, for 305.13' 8,687.47 3,598.78 2,457.53 -2,023.10 Start 2049.06°/100' OLS, 2° TF, for 25.96' 8,713.43 3,598.90 2,457.60 -2,049.06 Start 2119.65'/100' DLS, 2' TF, for 70.6- 8,784.03 3,598.03 2,457.80 -2,119.65 Start 2292.5"/100' DLS, 0° TF, for 172.91' 8,956.93 3,593.77 2,458.27 -2,292.50 Start 2363.09'/100' DLS, 2' TF, for 70.6' 9,027.53 3,592.90 2,458.46 -2,363.09 Start 2372.42'/100' DLS, 2° TF, for 9.33' 9,036.86 3,592.92 2,458.49 -2,372.42 Start 2672.46°/100' DLS, 0' TF, for 300.03' 9,336.90 3,593.89 2,459.31 -2,672.46 Start 2677.12°/100' DLS, 4' TF, for 4.67' 9,341.56 3,593.90 2,459.32 -2,677.12 Start 2854.94°/100' DLS, 4' TF, for 178.28' 9,519.84 3,582.82 2,459.81 -2,854.94 Start 2927.34°/100' DLS, 0' TF, for 72.97' 9,592.81 3,573.76 2,460.00 -2,927.34 Start 3080.16°/100' DLS, 4' TF, for 153.28' 9,746.09 3,562.90 2,460.42 -3,080.16 Start 3126.97°/100' DLS, 4' TF, for 46.81' 9,792.90 3,562.85 2,460.55 -3,126.97 Start 3305.56°/100' DLS, 0' TF, for 178.61' 8,971.51 3,565.57 2,461.03 -3,305.56 Start 3349.19°/100' DLS, 2' TF, for 43.63' 10,015.14 3,565.90 2,461.15 -3,349.19 Start 3433.9°/100' DLS, 2° TF, for 84.73' 10,099.87 3,564.65 2,461.39 -3,433.90 Start 3822.09°/100' DLS, 0' TF, for 388.36' 10,488.23 3,553.16 2,462.44 -3,822.09 Start 3830.23°/100' DLS, 3.75" TF, for 8.14' 10,496.37 3,552.90 2,462.47 -3,830.23 Start 4010.02°/100' DLS, 3.75' TF, for 180.69' 10,677.06 3,535.94 2,462.96 -4,010.02 Start 4032.86°/100' DLS, 0' TF, for 23.11' 10,700.17 3,532.42 2,463.02 -4,032.86 Start 4106.26"/100' DLS, 3.75' TF, for 74.02' 10,774.19 3,522.90 2,463.22 -4,106.26 Start 4120.56'/100' DLS, 3.75° TF, for 14.37' 10,788.56 3,521.47 2,463.26 -4,120.56 Start 4234.52'/100' DLS, 0° TF, for 114.49' 10,903.05 3,510.57 2,463.57 -4,234.52 Start 4416.29'/100' DLS, 3° TF, for 182.04' 11,085.34 3,501.90 2,464.07 -4,416.53 Start 4416.53°/100' DLS, 3° TF, for 0.24' 11,260.43 3,501.92 2,464.54 -4,591.62 Start DLS 2.00 TFO 179.84 11,335.13 3,502.90 2,464.75 -4,666.31 Start DLS 2.00 TFO -179.76 11,390.31 3,504.88 2,464.90 -4,721.46 Start 127.21 hold at 11390.31 MO 11,517.52 3,510.65 2,465.25 -4,848.54 Start DLS 4.75 TFO 0.10 11,572.34 3,511.90 2,465.40 -4,903.34 Start DLS 4.75 TFO-0.05 11,721.54 3,502.68 2,465.80 -5,052.16 Start 9.53 hold at 11721.54 MD 11,731.07 3,501.51 2,465.83 -5,061.61 Start DLS 4.75 TFO 179.64 11,753.96 _ _3498.90 _ 2,465.89 -5,084.35 Start DLS 4.75 TFO-179.94 5/292019 11:19.00AM Page 10 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska lnc_Kuparuk Project: Kupamk River Unit -2 Site: Kupamk 3R Pad ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MO Reference: Well: Plan: 3R-112 North Reference: Wellbore: Plan: 3R-112 Survey Calculation Method: Design: 3R-ll2wp04 Output errors are at Start DLS 4.00 TFO 0.42 12,004.26 Database: Well Plan: 3R-112 Plan D142: 39.1 +9.8 @ 48.90usft (Doyon 142) Plan D142: 39.1 +9.8 @ 48.90usft (Doyon 142) True Minimum Curvature 2.00 sigma OAKEDMPI 11,851.46 3,492.64 2,466.16 -5,181.63 Start 137.01 hold at 11851.46 MD 11,988.47 3,489.36 2,466.53 -5,318.60 Start DLS 4.00 TFO 0.42 12,004.26 3,488.90 2,466.57 -5,334.38 Start DLS 4.00 TFO-0.10 12,059.54 3,485.90 2,466.73 -5,389.58 Start 299.64 hold at 12059.54 MD 12,359.18 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Datum: NAD83 Region: alaska C Latitude/Longitude IDecimalDegrees C UTM Zone: I— r South G State Plane Zone: Units: us -ft C Legal Description (NAD27 only) -Starting Coordinates: X: 1661586.08 Y: 6031198.09 i - ❑ x To. Datum: NAD27 Region: alaska C Latitude/Longitude IDecimalDegrees C UTM Zone: True (- South C•' State Plane Zone: F7-1 Units: us -ft C Legal Description (NAD27 only) Ending Coordinates: -- X: Y: ;! 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BASIS OF LOCATION AND ELEVATION IS DS3R MONUMENTATION PER LOUNSBURY & ASSOC. 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES ARE N.A.D. 27. 3. ELEVATIONS ARE B.P.M.S.L. 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 9, TOWNSHIP 13 NORTH, RANGE 9 EAST, UMIAT MERIDIAN, ALASKA. 5. DATES OF SURVEY: 5/03/19 - 5/05/19. 6. ALL DISTANCES SHOWN ARE GROUND. 5 4 COME M. 6 1� PER K160005ACS ind M-1ild 16 k 5 VICINITY MAP 101 1 6 1"= 1 MILE 102 k 7 106 40 9 • 10 AT 10 = 11 co 112012 • 26 • 14 • 15 • 25 • 17 • 18 • 19 1 FQEyg • 21 • EXISTING CONDUCTOR LOCATION • 22 0 AS—BUILT CONDUCTOR LOCATION x PLUGGED AND ABANDONED GRAPHIC SCALE o 75 150 �� o I inch = 150 ft. LOUNSBURY SEE SHEET 2 AND 3 FOR LOCATION INFORMATION I A s ��TBg• INC. 9 YOBS SNGIN86R3 PWNNE39 V AREA: 3R MODULE: XXXX UNIT: D3 ConocoPhillips DS3R WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CAIWrFILEAl NO.dIR 17/9q/Dq DRAWING No. CEA—D3RX-6318D18 (PART: 1 OF3 IREV:3 ' 11 15/5/19 CC I JLS I APER K190005ACS muni IeTnwc APP I nreT'Fn IN PROTRACTED SECTION 9. T. 13 N.. R. 9 E.. UMIAT MERIDIAN Well No. NAD 27 ASP Coordinates NAD 27 Geographic Coordinates Section Offset. Elev. Y X Lot. Long. F.N.Lj F.W.L O.G. PAD *105 6031685.03 520642.40 70' 29' 51.808" 149' 49' 52.295" 1678' 2337' 4.8' 9.8' *106 6031666.09 520649.00 70. 29' 51.621" 149' 49' 52.102" 1697' 2343' 4.9' 9.8' *107 6031633.15 520660.18 70' 29' 51.297" 149' 49' 51.776" 1730' 2354' 5.0' 9.8' *111 6031614.47 520666.78 70' 29' 51.113" 149' 49' 51.583" 1749' 2361' 5.1' 9.8' *112 6031581.19 520678.16 70' 29' 50.785" 149' 49' 51.251" 1782' 2372' 5.2' 9.8' * CONDUCTOR ASBUILT THIS SURVEY .............. A•�P•.• t� SURVEYORS CERTIFICATE . �.. {s , s}�y I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND AV AV �........... 49 h ♦ LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF .... ...... ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY •............• ••••••..•......•:••••. DONE BY ME OR UNDER MY DIRECT SUPERVISION AND �' , !.JEREMIAH F. coRNELL,-'L i THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION �� J'� •.• Ls -12/663 ARE CORRECT AS OF MAY 5, 2019. LOUNSBURY ���`ca'' • f{�fif 'o �•�/Z\� & ASSOCIATES. INC. �� �FESSIONAI-�" ��� ,q aws 6NG1Ne6Re euxwens AREA: 3R MODULE: XXXX UNIT: D3 ConocoPhillips DS3R WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE N0. DRAWING N0. PART: REV: LK6318d18 12/29 os 1 CEA-D3RX-6318D18 1 3 OF 3 1 Appendix U a) C tlA m E O 0 O m C N c s o a-+ u � U O O c - L s Q a3 Z O Q O 0 o o _ � L C: t U i o c (6 N E c O N aj LX O N s O 0 } O O � •E LE co •� N v b C � L cn LU ■ ■ ■ Y c E aJ aJ 3 a v E N a) Y O Q c c c y� u v w E aJ N 6 N CL N O w N CL C w aJ L -0 O Y _ c � N 0 3 = �o v vu N_I_- 0 LaJ o m GA L a m a) a) t L Q Y Y o O cu O C Y U U v ai E v a bA y aJ C C L L � � = N �v L v L w c0 N N 2 F- N pA c aJ s U m i 41 F- c (6 N L au F- s O c 4� C: O U C: _O AU W Ln ai Eb L Q� w 0 IF ON Wo v a ao m � N O '— a+ N m > C i v 3 O u Y U y� U N Q. U a IA L O U c 'u v � c S m v c m "- > > Q0_ _ m aO i C r 4J Z3 N m co a _ m u v N Q Ecli t ar .3 - + m y u_ u u O N C C m it u `^ O O *•+ i m d bA N NU o m -0 m' > . E U > U c m v -O s U ++ T C N C O m O m _ cy i -0 Q a) N N N UJ CL 7@ 7 - Y N ra L mCT N C N O G7 .0 L U C i C O IA? O u N Q Laj A Li = f�6 m y O1 C N O U .2 + m Y H m vOi m 0 O o � c U U Y i N C C C ON Wo 3R-112 Drilling Hazards Summary 13-1/2" Open Hole / 10-3/4" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low Control drill, Reduced pump rates, Reduced drilling Abnormal Reservoir Pressure Low fluid temperatures, Additions of ScreenKleen. Running Sands and Gravels Low Maintain planned mud parameters, increase mud weight, Anti -Collision Low use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), Differential Sticking Moderate pumping out Washouts / Hole Sloughing Low Cool mud temperatures, minimize circulating times when possible Anti -Collision Low Follow real time surveys very closely, shut in nearby wells that have collision concerns, utilize gyro survey to Fault Crossings and Moderate ensure survey accuracy through zone with magnetic Concretions interference. 9-7/8" Open Hole / 7-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Gravels Low Maintain planned mud parameters, increase mud weight, use weighted sweeps. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Pressure Low BOP training and drills, increased mud weight. Lost circulation Moderate Reduced pump rates, mud rheology, LCM Anti -Collision Low Follow real time surveys very closely. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud weight. Pressure Stuck Pipe Low Good hole cleaning, PWD tools monitoring and analysis, decreased mud weight Lost Circulation Moderate Reduced pump rates, mud rheology, LCM program, additional fluid stored on location during completion run. Differential Sticking Moderate Follow mud program, keep pipe moving when able Anti -Collision Low Follow real time surveys very closely, shut in nearby wells that are of concern for collision. Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out or backreamin Fault Crossings and Moderate Use developed best practices for concretion drilling: 1-2klbs Concretions WOB, 80-100 rpm with RS in neutral. Getting Liner to Bottom Moderate Properly clean hole on trip out with BHA, add lubes prior to tripping out to aid in torque and drag, and keep DLS to a minimum. Utilize Su erSliders if necessary. 3R-112 Drilling Hazards Summary.doc 6/4201911:16:36 AM ,1,11 I�III ,I,II I,II e L O y . � N i o F ILII . VIII j VIII - VIII M ILII c Ohl - - JmX S I III 4hl Idn - C hW hhl C U u 8 � z f c — 1 V v U O 'e F � F � H �o 3h J N c " U - d ConocoPhillips Draft Schematic Injector .,,ry aallf(a Attachment 5 BOP Configuration The following ram configuration will be utilized for the West Sak wells. Further details regarding the BOPE specifications can be found with the Doyon 142 documentation on file with the State. Loepp, Victoria T (CED) From: Woodard, Madeline E <Madeline.E.Woodard@conocophillips.com> Sent: Friday, June 14, 2019 9:33 AM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]RE: 3R-112 PTD Application Attachments: 311-112 PTD updated BHP.pdf Victoria, See attached. The section highlighted in yellow is all that has changed. Please let me know if you need more information. Madeline From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Friday, June 14, 2019 8:27 AM To: Woodard, Madeline E <Madeline.E.Woodard@conocophillips.com> Subject: [EXTERNAL]RE: 311-112 PTD Application Madeline, Please email me the corrected section of the application. I will hand change the 10-401 form. Thanx, Victoria From: Woodard, Madeline E <Madeline.E.Woodard@conocophillips.com> Sent: Friday, June 14, 2019 8:20 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: 311-112 PTD Application Victoria, I received some more information on bottom hole pressure from our reservoir group this week and need to update the MPSP on the 311-112 PTD application. What is the best way to do this? I can re -fill out the 10-401 and the requirements for 20 AAC 25.005 (c)(4) section on the application and deliver to AOGCC today. Please let me know what I can do. Thanks, Madeline Woodard Drilling Engineer ConocoPhillips Alaska, Inc Office: 907-265-6086 Mobile: 907-764-8095 Drilling Hazards Information Reauirements of 20 AAC 25.005 (c)(4) :In apphcauon far a Permu to Orvll nuust he aecampamed by each of the folloving items, except forat, item alreadv on f le midi the commission and identified in the application: (4) information on drilling hacards. including (4) the maximum downhole pressure that may be encountered criteria used to determine a. and maximum potential surface pressure based on a methane gradient: The maximum potential surface pressure (MPSP) while drilling 3R-112 is calculated using an estimated maximum reservoir pressure of 1,640 psi (based on 3R-102 downhole gauge data and reservoir modeling), a gas gradient of 0.10 psi/ft, and the estimated depth of the West Sak D sand at 3,625' TVD: D Sand Estimated. BHP = 1,640 psi D Sand estimated depth = 3,625' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 362 psi (3,625 TVD * 0.10 psi/ft) MPSP = BHP — gas column =1,278 psi (1,640 psi — 362 psi) +81 clan an potential gas -one,. The well bore is not expected to penetrate any shallow gas zones. ,ind (( ) dam concerning potential causes q` hole problems such as abnormally geo-pressured strata. lost circulation cones, and=ones that have a propensiq, for differential sticking: See attached 311-112 Drilling Hazards Summary Requirements of 20 AAC 25.005 (e)(5) hr nppl c au,nr , :r i'e,mu m Onll nurst be accompanied by each of the following items, except for an item alreadv on, file with the commission and identified in the application: (5) a description urthe procedure fur c ondw ling formation integriry tests, as required under 20 AAC 25.030(Q: A procedure is on file with the commission for performing LOT'S. Casing and Cementing Program Requirements of 20 AAC 25.005(OM Ju uppliranoo for a Pe. aid nr Lr Ji rnuu be accompanied by each of die following items, except far an item already on file wah the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20AAC 25.930, and a description of an, slotted liner. pre-perleraled lineror C' 11 m he mcr'dh d Casing and Cement Program Casin and Cementin Pro ram Csg/Tbg OD Hole Weight Grade Conn. Length Top MD/TVD Btm MD/TVD Cement Program (in) One (1b/f) (ft) (ft) 20 42 94 H-40 Welded 80 Surf 1 I9 / 119 Existing Cement to Surface with 10-3/4 13-1/2 45.5 L-80 HYD563 2,495 Surf 2,495 / 2,238 1275 sx LiteCRETE Lead 1 LO ppg, 192 sx Dee CRETE Tail 12,0 PPQ . 667 sx Class G at 15 8 ppg 7-5/8 9-7/8 29.7 I: 80 HVD563 5,963 Surf 5,963 / 3,648 w/ TOC at 3,403' MD 4-1/2 6-3/4 12.6 L-80 HYD563 6,547 5,812 / 3,632 12,359 / 3,464 N/A 10-3/4^ Surface casing run to 2,495' MD / 2,238' TVD From: To: Subject: Date: Hi David, Woodard Madeline E Boyer David L (CED) RE: [EXTERNAL]Digital Survey File for KRU 211-112 Well Thursday, June 6, 2019 7:29:34 AM Please replace the schematic from 6/4 with the one from 6/5. Sounds good on the H2S. Thanks, Madeline From: Boyer, David L (CED) <david.boyer2@alaska.gov> Sent: Wednesday, June 5, 2019 4:58 PM To: Woodard, Madeline E <Madeline.E.Woodard@conocophillips.com> Subject: RE: (EXTERNAL]Digital Survey File for KRU 213-112 Well Madeline, I have the PTD folder right now which will end up with Victoria after Dave Roby reviews it. Would you like me to replace the well schematic dated 6/4/19 in the package with the enclosed schematic dated 6/5/19? I will shred the original diagram to avoid any confusion here. The H2S readings for the West Salk are less than 20 ppm in the regulations. I do not think H2S measures should be required for this well, unless I am overruled by more senior staff during the review process. Thank you, Dave Boyer From: Woodard, Madeline E <M Adelina E Woodardnconocoohillips.com> Sent: Wednesday, June 5, 2019 4:33 PM To: Boyer, David L (CED) <david boyer2galaska Eov> Subject: RE: [EXTERNAL]Digital Survey File for KRU 2R-112 Well David, 3R-112 will be pre -produced for less than 3 months. That decision was just made recently and I actually have a new well schematic that needs to accompany the application. It is attached to this email, but should I also send it to Victoria? There have been two H2S samples taken from existing West Salk well 3R-101 resulting in 10 ppm (10/27/17) and 3 ppm (10/20/18). Please let me know if you need more information. Thanks, Madeline From: Boyer, David L (CED) <david boygt2@alaska gov> Sent: Wednesday, lune 5, 2019 3:39 PM To: Woodard, Madeline E <Madeline F WoQdaf(.IPcOnOCO Plill sp <on-'> Subject: RE: [EXTERNAL] Digital Survey File for KRU 2R-112 Well Hi Madeline, There were two other questions on the PTD checklist that require some clarification: 1. Since KRU 3R-112 is a water injector, will it be pre -produced? If so, for less than 3 months? 2. Since the waterflood in the West Salk D is much less mature than in the Kuparuk formation, has H2S been reported in the West Salk wells on 3R Pad? Most Kuparuk wells require 1-12S measures. Thank you, Dave Boyer From: Woodard, Madeline E <MadelinP F WoodardPconocoohilLpssom_> Sent: Wednesday, June 5, 2019 2:25 PM To: Boyer, David L (CED) <david.boKer22alaska.gov> Subject: RE: [EXTERNAL] Digital Survey File for KRU 2R-112 Well Hi Dave, See attached. Let me know if you need a different format or other information. Thanks, Madeline From: Boyer, David L (CED) <davicl.boyerIa alaska gov> Sent: Wednesday, June 5, 2019 2:18 PM To: Woodard, Madeline E <Mader,e F W�odard!'DronOCO fp iilli So com> Subject: [EXTERNAL] Digital Survey File for KRU 2R-112 Well Hi Madeline, I just began the geologic review of the KRU 3R-112 PTD application. Would it be possible to e-mail over the digital survey file for the well in ASCII or Excel format for input into our GeoGraphix database? Thank you, Dave Boyer Senior Geologist AOGCC Transform Points Source coordinate system K R u 3 R - )1 a. Target coordinate system State Plane 1927 - Alaska Zone 4 Albers Equal Area (-150) Datum: Datum: NAD 1927 - North America Datum of 1927 (Mean) NAD 1927 - North America Datum of 1927 (Mean) E a Type values into the spreadsheet or copy and paste columns of data froir, a spreadsheet using the keyboard shortcuts drl+c to copy and Ctd-V to paste. Then click on the appropn ate arrow button to transform the points to the desired coordinate system. < flack Finish Cancel Help TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: a 19. - Q$ O Development `/ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: POOL: We -5+ 50. k 6 l Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. _'API No. 50- - function (If last two digits Production should continue to be reported as a of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50-_- -_� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of J well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 PTD#: 2190850 Company ConoeoPhilliDs Alaska Inc Initial Class/Type SER Weli Name: KUPARUK RIV U WSAK 3R-112 Program SER Well bore seg ❑ / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 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 --__ -.- 5 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 Directional_ plan view -$ wellbore profile included, 9 Operator only affected party. - . . . . . . ... . . . . - . -Yes . 10 Operator has appropriate- bond in force ........... . . . . . . . . . . .. . . . . . Yes ........ _ - 11 Permit can be issued without conservation order--------- --- --------------- Yes - _-------- _---------.--.-.. Appr Date 12 Permit can be issued without administrativeapproval- - - - - - - - - - - - - - - - - - ----- - - Yes _ - - - _ - _ . _ _ _ _ _ _ - - _ ......... 13 Can permit be approved before 15-day wait, . .... . ........ . Yes - DLB 6/6/2019 14 Well located within area and strata authorized by Injection Order # (put 10# in.comments)-(For. Yes ..... AIO 213-applies in-the West Sak pool.. 15 All wells within 1[4-mile area of review identified (For service well only)............... Yes ...... - .. - - - . - ...... _ - _ - - - - . 16 Pte-produced injector; duration of pre-production less than_3 months (For service well only) - _ Yes 17 Nonconven, gas.conforrnsto AS31,05A30(il.A),0.2.A-D) - - - - - - - - - - - - - - - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - - - - - 18 Conductor string provided .... ................... - _ - - _ . Yes . - 80' conductor set. - - - - Engineering 19 Surface casingprotectsall-known USDWS -- - - - - - - - - - - - - - - - - - - - - - - -- - - Yes - - - _ Surface casing set to 2495' MD - - 20 CMT vol adequate to circulate on conductor$ surf.csg ........................ Yes ....... 204%. excess oement planned _ ................ 21 CMT. vol adequate to tie-in tong string to surf csg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ NO - - - - - - - TQC 3403'-MD 22 C.MT.will cover all known productive horizons- - - - - - - - - - - - - - - - - - - - - - No - - - - - Productiveintervalwill be completed with uncemented slotted liner - - - 23 Casing designs adequate for C..T, B R Permafrost.......... . - - - - _ - Yes 24 Adequate tankage. or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - Rig has steel tanks; all waste to approved disposal wells- - - - 25 If a-re-drill, has -a 10-403 for abandonment been approved . . . .............. . .... NA. ... I ..... ...... 26 Adequate wellbore separation proposed - - - - _ - - - .... - ...... Yes Anti-collision analysis; no major risk failures 27 If diverteir required, does it meet regulations - - - - - - - - - Yes - Diyerter variance granted per 20 AAC 25.035(h)(2) - - - - - - Appr Date 28 Drilling fluid program schematic.$ equip list adequate........... . . . . . . . . . . . . . . Yes - Max formation pressure is-1640 psig(8.7 ppg EMW ); will drill w/ 9.Q-9.5 ppg EMW.. . VTL 6/18/2019 29 POPEs,.dotheymeetregulation - - _ - - - - - - - - - - - - - - - Yes- 30 BOPE-press rating appropriate; test to-(put psig in comments)........ - _ - _ - . Yes - _ MPSP is 1278 psig; will test BOPS-to 3500 prig............. . .. . 31 Choke manifold complies w/API_ RP-53 (May 84). . . . . ............. . ...... Yes ......... - ........ - .... - ................. 32 Work will occur without operation shutdown- - - - - - - - . - Yes - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - 33 Is presence. of 112S gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No - - - - - - - 1-12S measures not required- 34 Mechanical condition of wells within AOR verified (Por service well only) - - - - - - - - --- - - Yes . _ _ ... _ 3 wells in AOR: Oliktok Pt St #1 Abd, 3R-14 cmt to surf; 3R-101 cmt 35 Pemtit. can be issued w/o. hydrogen sulfide measures - - - - - - - - - - - - - - - - - - - - - - - - - Yes - _ - - _ - - West Sak reservoir with trace H2S-<20ppm threhold in regulations. Geology 36 Data resented on potential overpressure zones .... - . Yes Aper Date 37 i l Seismic analysis of sallow gas zones ... . . . i h --------------------------- NA. . . .. . . . . . . .. . . . .... . . . . . . . . . . . -...---...... -. DLB 6/5/2019 38 Seabed condition survey-(if off-shore).................................. NA. 39 Contact name/phone for weekly progress reports [exploratory only] . . . . . . . . ........ NA - - - . - - . - - - - - - - .. - ...... - ......... - - - - Geologic Date: Engineering Date Public Date Commissioner: Commissioner: Commissioner
