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Home My WebLink About217-097C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\4MY18Q6V\2025-09-02_KRU_1H-102_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 16049 KRU 1H-102 50-029-23580-00 Caliper Survey w/ Data 02-Sep-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 217-097 T40855 9/5/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.09.05 14:45:10 -08'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\2SR1PWCY\2025-06-29_23083_KRU_1H-102_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 23083 KRU 1H-102 50-029-23580-00 Caliper Survey w/ Log Data 29-Jun-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 217-097 T40635 7/8/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.08 12:40:20 -08'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2025-02-07_24004_KRU_1H-102_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 24004 KRU 1H-102 50-029-23580-00 Caliper Survey w/ Log Data 07-Feb-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 217-097 T40079 2/18/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.18 12:41:08 -09'00' Originated: Delivered to:2ͲMayͲ24Halliburton Alaska Oil and Gas Conservation Comm.Wireline & PerforatingAttn.:Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska99501Anchorage, Alaska 99518Office: 907Ͳ275Ͳ2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#11DͲ117 50Ͳ029Ͳ22844Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 21ͲAprͲ24 0 121EͲ05A 50Ͳ029Ͳ20479Ͳ01 n/a Kuparuk River Plug Setting Record FieldͲFinal 2ͲAprͲ24 0 131HͲ102 50Ͳ029Ͳ23580Ͳ00 909266407 Kuparuk River Multi Finger Caliper Field & Processed 22ͲAprͲ24 0 142BͲ03B 50Ͳ029Ͳ21151Ͳ02 909270379 Kuparuk River Perforation Record FieldͲFinal 11ͲAprͲ24 0 152CͲ12 50Ͳ029Ͳ21222Ͳ00 n/a Kuparuk River Leak Detect Log FieldͲFinal 29ͲAprͲ24 0 162DͲ13 50Ͳ029Ͳ21070Ͳ00 909258948 Kuparuk River Leak Detect Log FieldͲFinal 11ͲAprͲ24 0 172DͲ13 50Ͳ029Ͳ21070Ͳ00 909258948 Kuparuk River Multi Finger Caliper Field & Processed 9ͲAprͲ24 0 183GͲ24 50Ͳ103Ͳ20145Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 8ͲAprͲ24 0 193JͲ14 50Ͳ029Ͳ21496Ͳ00 909238639 Kuparuk River Leak Detect Log FieldͲFinal 7ͲAprͲ24 0 110 3JͲ14 50Ͳ029Ͳ21496Ͳ00 909238639 Kuparuk River Multi Finger Caliper Field & Processed 6ͲAprͲ24 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T38757T38758T38759T38760T38761T38762T38762T38763T38764T3876431HͲ10250Ͳ029Ͳ23580Ͳ00 909266407KuparukRiverMultiFingerCaliperField&Processed22ͲAprͲ2401 Or i g i n a t e d : D e l i v e r e d t o : 1ͲMa r Ͳ24 Ha l l i b u r t o n A l a s k a O i l a n d G a s C o n s e r v a t i o n C o m m . Wi r e l i n e & P e r f o r a t i n g At t n . : Na t u r a l R e s o u r c e T e c h n i c i a n At t n : F a n n y H a r o u n 3 3 3 W e s t 7 t h A v e n u e , S u i t e 1 0 0 69 0 0 A r c t i c B l v d . A n c h o r a g e , A l a s k a 99 5 0 1 An c h o r a g e , A l a s k a 9 9 5 1 8 Of f i c e : 9 0 7 Ͳ27 5 Ͳ26 0 5 FR S _ A N C @ h a l l i b u r t o n . c o m Th e t e c h n i c a l d a t a l i s t e d b e l o w i s b e i n g s u b m i t t e d h e r e w i t h . P l e a s e a d d r e s s a n y p r o b l e m s o r co n c e r n s t o t h e a t t e n t i o n o f t h e s e n d e r a b o v e WE L L N A M E A P I # S E R V I C E O R D E R # F I E L D N A M E J O B T Y P E D A T A T Y P E L O G G I N G D A T E P R I N T S # D I G I T A L # E S E T # 11 B Ͳ16 A 5 0 Ͳ02 9 Ͳ22 4 5 7 Ͳ01 n / a K u p a r u k R i v e r L e a k D e t e c t L o g F i e l d Ͳ Fi n a l 2 7 ͲDe c Ͳ23 0 1 21 D Ͳ13 0 5 0 Ͳ02 9 Ͳ22 8 1 5 Ͳ00 n / a K u p a r u k R i v e r P a t c h S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 4 ͲDe c Ͳ23 0 1 31 D Ͳ14 1 A 5 0 Ͳ02 9 Ͳ22 9 6 7 Ͳ01 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 2 5 ͲDe c Ͳ23 0 1 41 H Ͳ10 2 5 0 Ͳ02 9 Ͳ23 5 8 0 Ͳ00 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 2 4 ͲJa n Ͳ24 0 1 51 Y Ͳ06 A 5 0 Ͳ02 9 Ͳ20 9 5 8 Ͳ01 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 2 0 ͲFe b Ͳ24 0 1 62 A Ͳ10 A 5 0 Ͳ10 3 Ͳ20 0 5 6 Ͳ01 9 0 9 1 7 6 6 9 3 K u p a r u k R i v e r P e r f o r a t i o n R e c o r d F i e l d Ͳ Fi n a l 2 6 ͲFe b Ͳ24 0 1 72 C Ͳ12 5 0 Ͳ02 9 Ͳ21 2 2 2 Ͳ00 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 3 0 ͲDe c Ͳ23 0 1 82 F Ͳ15 5 0 Ͳ02 9 Ͳ21 0 4 8 Ͳ00 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 2 5 ͲFe b Ͳ24 0 1 92 U Ͳ05 5 0 Ͳ02 9 Ͳ21 2 8 1 Ͳ00 n / a K u p a r u k R i v e r P l u g S e t t i n g R e c o r d F i e l d & P r o c e s s e d 8 ͲDe c Ͳ23 0 1 10 2 W Ͳ01 5 0 Ͳ02 9 Ͳ21 2 7 3 Ͳ00 n / a K u p a r u k R i v e r P a t c h S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 6 ͲDe c Ͳ23 0 1 PL E A S E A C K N O W L E D G E R E C E I P T B Y S I G N I N G A N D R E T U R N I N G A C O P Y O F T H E T R A N S M I T T A L L E T T E R T O T H E A T T E N T I O N O F : Fa n n y H a r o u n , H a l l i b u r t o n W i r e l i n e & P e r f o r a t i n g , 6 9 0 0 A r c t i c B l v d . , A n c h o r a g e , A K 9 9 5 1 8 FR S _ A N C @ h a l l i b u r t o n . c o m Da t e : Si g n e d : Tr a n s m i t t a l D a t e : T3 8 5 7 5 T3 8 5 7 6 T3 8 5 7 7 T3 8 5 7 8 T3 8 5 7 9 T3 8 5 8 0 T3 8 5 8 1 T3 8 2 8 2 T3 8 5 8 3 T3 8 5 8 4 21 8 - 1 5 5 19 7 - 1 8 3 20 8 - 0 1 6 21 7 - 0 9 7 19 7 - 1 3 4 22 3 - 0 9 2 18 4 - 2 0 6 18 3 - 1 7 2 18 5 - 0 1 8 18 5 - 0 1 0 Me r e d i t h G u h l Di g i t a l l y s i g n e d b y M e r e d i t h G u h l Da t e : 2 0 2 4 . 0 3 . 0 4 1 5 : 1 9 : 5 8 - 0 9 ' 0 0 ' 21 7 - 09 7 1H Ͳ10 2 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop _1E-17 50-029-20793-00 182116_1E-17_IPROF_16Jan2023 _1E-20 50-029-20895-00 183005_1E-20_LDL_10Jan2023 183005_1E- 20_PlugSettingRecord_20Aug2023 183005_1E-20_PPROF_29Sep2022 183008_1E-20_RBP_25Feb2023 1F-06 50-029-20820-00 182145_1F-06_Perf_11Jul2022 182145_1F-06_TubingCut_20Feb2022 1G-09 50-029-21001-00 183124_1G-09_IPROF_01Jun2022 1G-103 50-029-20824-00 219110_1G-103_RSTWFL_09Nov2022 1G-11 50-029-21008-00 183131_1G-11_LDL_31May2022 1G-13 50-029-21016-00 183140_1G-13_LDL_09Jul2022 1H-102 50-029-23580-00 217097_1H-102_PPROF_02May2022 1H-103 50-029-23593-00 218003_1H-103_PPROF_06May2022 1H-109 50-029-23595-00 218013_1H-119_IPROF_02JUL2023 3of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38329 T38330 T38331 T38332 T38333 T38334 T38335 T38336 T38337 T38338 2/29/2024 1H-102 50-029-23580-00 217097_1H-102_PPROF_02May2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:29:27 -09'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\KRU_1H-102_16-Jan-24_ProductionProfile_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15965 KRU 1H-102 50-029-23580-00 Production Profile 16-Jan-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 217-097 T38445 1/29/2024 Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.29 15:05:09 -09'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2024-01-14_15965_KRU_1H-102_JewelryLog_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15965 KRU 1H-102 50-029-23580-00 Jewelry Log 14-Jan-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 217-097 T38313 1/18/2024 Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.18 13:22:39 -09'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\023-08-25_22117_KRU_1H-102_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22117 KRU 1H-102 50-029-23580-00 Caliper Survey w/ Log Data 25-Aug-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 8/31/2023 PTD: 217-097 T37969 Kayla Junke Digitally signed by Kayla Junke Date: 2023.08.31 13:49:12 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-06-28_21147_KRU_1H-102_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21147 KRU 1H-102 50-029-23580-00 Caliper Survey w/ Log Data 28-Jun-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 217-097 T37799 Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.30 13:06:46 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-05-28_22097_KRU_1H-102_CaliperSurvey_LogData_Transmittal.docx 22097 DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22097 KRU 1H-102 50-029-23580-00 Caliper Survey w/ Log Data 28-May-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 217-097 T37683 Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.02 09:08:19 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 12960'feet None feet true vertical 4022'feet None feet Effective Depth measured 12960'feet 8227'feet true vertical 4022'feet 3963'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 7289' MD 3714' TVD Packers and SSSV (type, measured and true vertical depth) 8228' MD N/A 3963' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: West Sak Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 1771' 1691' Burst Collapse Production Liner 8554' 4562' Casing 3991' 4-1/2" 8591' 12790' 4020' 1731' 119'Conductor Surface Intermediate 20" 10-3/4" 78' measured TVD 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 217-097 50-029-23580-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025639 Kuparuk River Field/ West Sak Oil Pool KRU 1H-102 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 1800 Gas-Mcf MD 1350 Size 119' 2300 1350350 2100 3902700 380 323-126 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 475 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker HRD-E ZXP LTPacker SSSV: None Dusty Ward dusty.ward@conocophillips.com (907) 265-6531Senior Workover Engineer Slotted Liner: 8745-10977', 11314-12746' Slotted Liner: 3991-4013', 4034-4020' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Kayla Junke at 1:09 pm, May 08, 2023 Page 1/8 1H-102 Report Printed: 4/26/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/28/2023 00:00 3/28/2023 01:00 1.00 MIRU, MOVE FRZP P Complete pumping 75 bbls diesel let u- tube 0.0 0.0 3/28/2023 01:00 3/28/2023 02:30 1.50 MIRU, MOVE RURD P PJSM // Jack pits up pull away from rig // Transport to 1H pad 0.0 0.0 3/28/2023 02:30 3/28/2023 06:00 3.50 MIRU, MOVE RURD P Prep rig for pulling off well // PJSM // Pull rig off well 34 position by shop for maintenance 0.0 0.0 3/28/2023 06:00 3/28/2023 18:00 12.00 MIRU, MOVE RURD P Move off rig, Spot sub if front of shop for maintenance. 0.0 0.0 3/28/2023 18:00 3/29/2023 00:00 6.00 MIRU, MOVE RURD P Continue maintenance. on stack Rig down berming around camp and prep for rig move Load out KDTH trucks to 1H-pad Straighten up and organize pad for rig move 0.0 0.0 3/29/2023 00:00 3/29/2023 06:00 6.00 MIRU, MOVE RURD P Continue putting BOP Bonnet back together, w/spreader plate. 0.0 0.0 3/29/2023 06:00 3/29/2023 18:00 12.00 MIRU, MOVE WAIT P Continue workjing BOP's while waiting on 1H-102 inner annulas valve removal 0.0 0.0 3/29/2023 18:00 3/29/2023 20:00 2.00 MIRU, MOVE WAIT P Continue working on BOP's 1H-102 inner annulas valve removed DHD pumped 480 bbls of 12.0 ppg NaCI down the IA Final pressures T=60 psi, IA=2 psi 0.0 0.0 3/29/2023 20:00 3/29/2023 23:00 3.00 MIRU, MOVE RURD T Repair tools stuck behind Hilcorp Rig move Send pusher to get tools around rig Thread chaser on location Unable to repair threads on double gate Locate replacement double gate from Deadhorse. 0.0 0.0 3/29/2023 23:00 3/30/2023 00:00 1.00 MIRU, MOVE RURD T Brake apart stack in cellar, prepair for replacment Service Top Drive and Iron Roughnecks ** Hot shot truck sent to Yellow Jacket for replacement ** 0.0 0.0 3/30/2023 00:00 3/30/2023 12:00 12.00 MIRU, MOVE RURD T Continue prep for replacement double gate. Brake apart annular and mudcross. Service pipe skate, redress tongs 0.0 0.0 3/30/2023 12:00 3/30/2023 13:30 1.50 MIRU, MOVE MOB P Move rig to spione and 1R intersection. 0.0 0.0 3/30/2023 13:30 3/30/2023 19:30 6.00 MIRU, MOVE WAIT T Delayed at the spine road for aircraft and then additional 3 hour wait for crane to pass followed by field change out. 0.0 3/30/2023 19:30 3/30/2023 22:00 2.50 MIRU, MOVE MOB P Continue to move to 1H-102 3/30/2023 22:00 3/30/2023 23:00 1.00 MIRU, MOVE RURD P Spot rig over well with pad operator. 3/30/2023 23:00 3/31/2023 00:00 1.00 MIRU, MOVE RURD P Back pits into position marry up to rig. berm in rig, 3/31/2023 00:00 3/31/2023 04:00 4.00 MIRU, MOVE RURD P Continue to RU to well and complete pre -acceptance checklist. set cuttings tank, spot in camps and shop, establish communications. 3/31/2023 04:00 3/31/2023 07:30 3.50 MIRU, WELCTL RURD P Loading KWF in the pits accepted rig at 4:00 AM. pre-acceptance checklist completed. RU hardline to Tbg and IA to cement manifold in cellar. Rig: NABORS 7ES RIG RELEASE DATE 4/9/2023 Page 2/8 1H-102 Report Printed: 4/26/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/31/2023 07:30 3/31/2023 09:00 1.50 MIRU, WELCTL RURD P Seawater loaded in pits to start initial loading of well. flood lines from rig to kill tank. pressure test hardline to 2500 PSI. blow down lines and bleed gas off tubing and IA. Initial pressures. T/I/O=115/125/0. 3/31/2023 09:00 3/31/2023 12:00 3.00 MIRU, WELCTL KLWL P Start loading well with 50 bbl deep clean pill down IA followed with seawater at 5BPM down IA taking returns up the tubing. PR= 5 BPM. @ 200PSI. 50% returns at tank. Swap over attempt to circulate down tubing taking returns up the IA. No returns at tiger tank. Shut in return line to tiger tank and blow down line Continue Bullheading 201 BBL's down TBG at PR=5 BPM @ 194 PSI. Shut down pump. T/I/O=0/0/0 3/31/2023 12:00 3/31/2023 14:00 2.00 MIRU, WELCTL OWFF P OWFF 30 minutes 0 pressure increase. 15 minutes: Fill IA with 2 BBL's seawater, caught pressure. shut down pump 0 psi build up on TBG and IA in 15 minutes 30 Minutes: Fill TBG W/2 BBL Observe for 15 minutes TBG=Vac. IA=0 PSI 45 Minutes: Fill TBG W/2 BBL's seawater. Observe well for 45 minutes TBG= 0 PSI IA=0 PSI Load TBG with 2 BBL's seawater 3/31/2023 14:00 3/31/2023 15:00 1.00 MIRU, WELCTL RURD P Blow down surface lines secure well Shoot F/L in TBG and IA TBG F/L=402' IA F/L=336' 3/31/2023 15:00 3/31/2023 17:30 2.50 MIRU, WELCTL SLKL P RU Slickline, Pressure test lubricator to 2500 PSI RIH to 200' W/3.77' OD. POOH L/D gauge ring M.U. TS to DPU and 3.76" Paragon packer RIH and set packer at 40' (7ES RKB) 3/31/2023 17:30 3/31/2023 20:30 3.00 MIRU, WELCTL PRTS P R/U recorder. Pumping down secondary kill . Unable to get pressure test. R/U to S/L lubricator to pump directly to plug with master and swab open. No test. Shut tree valves to test. Get test from above. Open tree valves.Will not test 3/31/2023 20:30 3/31/2023 22:42 2.20 MIRU, WELCTL SLKL P Consult with town, Plan to stack in second PIIP packer. Redress running equipment, Bring new packer to flow and assemble 3/31/2023 22:42 3/31/2023 23:12 0.50 MIRU, WELCTL SLKL P PT SL lubricator to 2500 PSI, RIH, Set down lo lower plug pull up 2 feet 3/31/2023 23:12 4/1/2023 00:00 0.80 MIRU, WELCTL SLKL P Tool timed out, Pull to surface. Break off lubricator. Install tree cap Rig up PT. Test IBP 2500PSI/30Minutes 4/1/2023 00:00 4/1/2023 01:00 1.00 MIRU, WHDBOP MPSP P Pressure test RBP to 2500 PSI for 30 minutes. 4/1/2023 01:00 4/1/2023 01:30 0.50 MIRU, WHDBOP SLKL P RD Slick line standback lubricator on floor. 4/1/2023 01:30 4/1/2023 03:00 1.50 MIRU, WHDBOP NUND P Nipple down tree and adapter, HES here to unwire bulkhead. Vault here to nipple down tree. Rig: NABORS 7ES RIG RELEASE DATE 4/9/2023 Page 3/8 1H-102 Report Printed: 4/26/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/1/2023 03:00 4/1/2023 05:00 2.00 MIRU, WHDBOP NUND P NU BOP's 4/1/2023 05:00 4/1/2023 07:00 2.00 MIRU, WHDBOP RURD P RU to test BOP's PU test tools, MU test joints mark ram bodies RU test pump to fill BOP's, purge air out of system fill stack. Shell test stack kill line leak. Torqued bolts at kill line. shell tested stack to 2500 PSI. 4/1/2023 07:00 4/1/2023 14:00 7.00 MIRU, WHDBOP BOPE P Start testing BOPE. Initial BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested annular on 3-1/2" test joint, UVBR's, LVBR's w/3-1/2" and 4 1/2" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, FOSV, and IBOP. Tested 4 -1/2" EUE FOSV Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=2950 PSI, after closure=1500 PSI, 200 PSI attained =20 sec, full recovery attained = 185 sec. UVBR's= 5 sec, Annular= 30 sec. Simulated blinds= 5 sec. LVBRs=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 1970 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Kam StJohn. 4/1/2023 14:00 4/1/2023 14:30 0.50 MIRU, WHDBOP SVRG P Service rig 4/1/2023 14:30 4/1/2023 16:00 1.50 MIRU, WHDBOP RURD P Lay down test tools, P/U Dutch Riser and install in BOP to pull RBP's on slickline. 4/1/2023 16:00 4/1/2023 16:45 0.75 MIRU, WHDBOP RURD P RU slickline and pressure test Lubricator and dutch riser to 2500 PSI. 4/1/2023 16:45 4/1/2023 19:30 2.75 MIRU, WHDBOP SLKL P RIH with slickline and pull RBP's . Both RBP retrieved. No obvious marks on packing for PT failure 4/1/2023 19:30 4/1/2023 20:00 0.50 MIRU, WHDBOP SVRG P R/D slickline. Load out PCE / Service Rig Draw works 4/1/2023 20:00 4/1/2023 21:00 1.00 MIRU, WHDBOP CIRC P Bullhead 200 BBLs seawater down tubing. Initial pump pressure 300 PSI. Zero upon completion, Start 30 Min No Flow. R/D dutch riser 4/1/2023 21:00 4/1/2023 21:42 0.70 MIRU, WHDBOP RURD P R/U tongs, Bring tech wire spooler to floor and rig up. Make up BHA #1 Spear 4/1/2023 21:42 4/1/2023 22:00 0.30 MIRU, WHDBOP SFTY P PJSM to set spear, Back out LDS 4/1/2023 22:00 4/1/2023 22:30 0.50 MIRU, WHDBOP PULL P Set spear in hanger, Back out LDS, Pull to 155K. Unseat tubing hanger to rig floor. 110K dragging weight. 4/1/2023 22:30 4/1/2023 23:30 1.00 MIRU, WHDBOP RURD P Back out spear from hanger. Change out elevators. Lay down hangerRig up rig tongs 4/1/2023 23:30 4/2/2023 00:00 0.50 MIRU, WHDBOP PULL P Start pulling old 4 1/2" completion 0.0 70,000.0 Rig: NABORS 7ES RIG RELEASE DATE 4/9/2023 Page 4/8 1H-102 Report Printed: 4/26/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/2/2023 00:00 4/2/2023 06:00 6.00 COMPZN, RPCOMP PULL P Laying down tubing 4.5" BTC pull to 2150' PUW 87K 7,000.0 2,150.0 4/2/2023 06:00 4/2/2023 07:00 1.00 COMPZN, RPCOMP CLEN P Send 100 cannon clamps off floor, Empty spooler unit and send Tec line off floor 2,150.0 2,150.0 4/2/2023 07:00 4/2/2023 10:30 3.50 COMPZN, RPCOMP PULL P LD 4.5" Completion Total cannon clamps= 180 TOT Pins = 360 Total single clamps = 7 Rig down spooling units 2,150.0 0.0 4/2/2023 10:30 4/2/2023 11:30 1.00 COMPZN, RPCOMP OTHR P Corrosion tech inspect holes in tubing in pipe shed misc clean up on rig 0.0 0.0 4/2/2023 11:30 4/2/2023 12:00 0.50 COMPZN, RPCOMP SVRG P Service topdrive, blocks, and crown 0.0 0.0 4/2/2023 12:00 4/2/2023 12:30 0.50 COMPZN, RPCOMP OTHR P Empty shed of old completion 0.0 0.0 4/2/2023 12:30 4/2/2023 14:00 1.50 COMPZN, RPCOMP BHAH P Pick up clean out assembly 0.0 230.0 4/2/2023 14:00 4/2/2023 20:00 6.00 COMPZN, RPCOMP PUTB P Pick up singles drill pipe T/ 7230' 230.0 7,230.0 4/2/2023 20:00 4/2/2023 20:30 0.50 COMPZN, RPCOMP CIRC P Pump 100 bbls @ 4 bpm 7,230.0 7,230.0 4/2/2023 20:30 4/2/2023 21:00 0.50 COMPZN, RPCOMP TRIP P TOOH T/ 6495' Recip clean casing 7,230.0 6,495.0 4/2/2023 21:00 4/2/2023 21:30 0.50 COMPZN, RPCOMP PUTB P Pick up DP T/ 7031' 6,495.0 7,031.0 4/2/2023 21:30 4/3/2023 00:00 2.50 COMPZN, RPCOMP TRIP P TOOH 7,031.0 1,364.0 4/3/2023 00:00 4/3/2023 00:30 0.50 COMPZN, RPCOMP TRIP P Continue out or well with BHA #2 scraper. 1,364.0 230.0 4/3/2023 00:30 4/3/2023 01:30 1.00 COMPZN, RPCOMP BHAH P Lay down drill collars / BHA scraper 230.0 0.0 4/3/2023 01:30 4/3/2023 02:00 0.50 COMPZN, RPCOMP BHAH P PJSM, M/U BHA #3 G plug and test packer 0.0 50.0 4/3/2023 02:00 4/3/2023 02:30 0.50 COMPZN, RPCOMP SVRG P Service Rig, Iron Roughneck 50.0 50.0 4/3/2023 02:30 4/3/2023 06:00 3.50 COMPZN, RPCOMP TRIP P Trip in well, BHA #3 G Plug on DP F/50' T/7000' COE 50.0 7,000.0 4/3/2023 06:00 4/3/2023 06:30 0.50 COMPZN, RPCOMP MPSP P Set G-plug at 7000' fill hole with 20 BBL's seawater. RU to test 7,000.0 7,000.0 4/3/2023 06:30 4/3/2023 07:15 0.75 COMPZN, RPCOMP PRTS P Test 7-5/8" casing against G-plug at 6989' to 2500 PSI for 30 minutes. 7,000.0 7,000.0 4/3/2023 07:15 4/3/2023 07:45 0.50 COMPZN, RPCOMP TRIP P Rack back 3 stands crude in DP at floor. 7,000.0 6,700.0 4/3/2023 07:45 4/3/2023 08:30 0.75 COMPZN, RPCOMP CIRC P Circulate seawater SxS at 6 BPM 6,700.0 6,700.0 4/3/2023 08:30 4/3/2023 09:45 1.25 COMPZN, RPCOMP TRIP P TOOH F/6700' T/3586' 6,700.0 3,500.0 4/3/2023 09:45 4/3/2023 10:45 1.00 COMPZN, RPCOMP MPSP P MU 7-5/8" Storm packer set packer COE 68' below well head. 3,500.0 3,568.0 4/3/2023 10:45 4/3/2023 11:30 0.75 COMPZN, RPCOMP PRTS P Pressure test strom packer and casing to 2500 PSI for 30 minutes. 3,568.0 3,568.0 4/3/2023 11:30 4/3/2023 12:30 1.00 COMPZN, RPCOMP RURD P Lay down 2 singles. R/D testing eq. blow down lines empty stack and prepare to ND BOP's 3,568.0 3,568.0 4/3/2023 12:30 4/3/2023 16:00 3.50 COMPZN, RPCOMP NUND P ND BOP stack. and well head. 3,568.0 3,568.0 4/3/2023 16:00 4/3/2023 19:00 3.00 COMPZN, RPCOMP NUND P NU New TBG spool. Test Pack off void to 5000 PSI for 10 minutes. 3,568.0 3,568.0 4/3/2023 19:00 4/3/2023 20:30 1.50 COMPZN, RPCOMP NUND P Nipple up BOPE, Install flow riser, P/U test tools, R/U test equipment 3,568.0 3,568.0 Rig: NABORS 7ES RIG RELEASE DATE 4/9/2023 Page 5/8 1H-102 Report Printed: 4/26/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/3/2023 20:30 4/3/2023 20:48 0.30 COMPZN, RPCOMP BOPE P Perform shell test 250/2500PSI Good test 3,568.0 3,568.0 4/3/2023 20:48 4/3/2023 21:30 0.70 COMPZN, RPCOMP RURD P Install wear ring bushing, RI two LDS 3,568.0 3,568.0 4/3/2023 21:30 4/3/2023 22:00 0.50 COMPZN, RPCOMP SVRG P Service rig, Draworks, Top Drive, and crown 3,568.0 3,568.0 4/3/2023 22:00 4/3/2023 23:30 1.50 COMPZN, RPCOMP MPSP P M/U retrieval tool, Trip in 68'. Close annular, Check for pressure. Release storm packer. OWFF. Allow element to relax. POOH lay down storm packer at surface. 3,568.0 3,568.0 4/3/2023 23:30 4/4/2023 00:00 0.50 COMPZN, RPCOMP TRIP P Trip in stands to retrieve G plug 3,568.0 4,942.0 4/4/2023 00:00 4/4/2023 00:30 0.50 COMPZN, RPCOMP TRIP P Continue Tripping in stands 4,942.0 6,996.0 4/4/2023 00:30 4/4/2023 01:15 0.75 COMPZN, RPCOMP MPSP P Set down on G plug. Latched up, PUW=97K. Saw fluid bypass. Let elements relax. Pump 60 BBls down tubing 4 BPM @ 150 PSI 6,996.0 6,990.0 4/4/2023 01:15 4/4/2023 04:00 2.75 COMPZN, RPCOMP PULD P POOH laying down DP T/ 4750', PUW=97K 6,990.0 4,750.0 4/4/2023 04:00 4/4/2023 05:00 1.00 COMPZN, RPCOMP SLPC P Slip and cut 97' of drilling line. 4,750.0 4,750.0 4/4/2023 05:00 4/4/2023 08:30 3.50 COMPZN, RPCOMP PULD P LDDP F/ 4750' T/ 24', POW=40K. 4,750.0 24.0 4/4/2023 08:30 4/4/2023 09:00 0.50 COMPZN, RPCOMP BHAH P L/D BHA #3 G plug 24.0 0.0 4/4/2023 09:00 4/4/2023 09:30 0.50 COMPZN, RPCOMP RURD P Pull wear bushing 0.0 0.0 4/4/2023 09:30 4/4/2023 10:00 0.50 COMPZN, RPCOMP SVRG P Service rig 0.0 0.0 4/4/2023 10:00 4/4/2023 12:00 2.00 COMPZN, RPCOMP RURD P Mobilize HES sheaves, clamps and hand tools T/ RF. Hang sheaves. Feed control lines through sheaves and secure at RF. 0.0 0.0 4/4/2023 12:00 4/4/2023 13:00 1.00 COMPZN, RPCOMP RURD P R/U GBR tubing handling equipment and torque turn. Dead test tubing tongs. Verily Joint count and jewelry running order. 0.0 0.0 4/4/2023 13:00 4/4/2023 13:30 0.50 COMPZN, RPCOMP SFTY P PJSM with Halliburton, GBR and Rig Crew on running 4.5" Completion. 0.0 0.0 4/4/2023 13:30 4/4/2023 14:45 1.25 COMPZN, RPCOMP RCST P PU and RIH with Seal Assy X-Nipple and Tubing. 0.0 243.0 4/4/2023 14:45 4/4/2023 15:00 0.25 COMPZN, RPCOMP RCST P RU and Install Control Line to Injection Mandrel. 243.0 243.0 4/4/2023 15:00 4/4/2023 16:00 1.00 COMPZN, RPCOMP RCST P MU OPSIS Halliburton Gauge Assy, Tec- Wire and Test Same. Good Test. 243.0 308.0 4/4/2023 16:00 4/5/2023 00:00 8.00 COMPZN, RPCOMP RCST P Continue Running 4.5" Completion Per- Tally starting Tec-Wire every 1000' Test @ 1000' 348.72 psi 54.35° 3000' 963 psi 53.29° 4000' 1103 psi 55.5° 308.0 4,845.0 4/5/2023 00:00 4/5/2023 01:30 1.50 COMPZN, RPCOMP PUTB P Continue Running 4.5" Completion Per- Tally starting Tec-Wire every 1000' Test @ 1000' 348.72 psi 54.35° 3000' 963 psi 53.29° 4000' 1103 psi 55.5° 5000' 1244.29 psi 58.28° 6000' 4,845.0 6,000.0 Rig: NABORS 7ES RIG RELEASE DATE 4/9/2023 Page 6/8 1H-102 Report Printed: 4/26/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/5/2023 01:30 4/5/2023 02:00 0.50 COMPZN, RPCOMP SVRG P Service rig // Service Blocks and DW 6,000.0 6,000.0 4/5/2023 02:00 4/5/2023 05:00 3.00 COMPZN, RPCOMP PUTB P Continue Running 4.5" Completion Per- Tally starting Tec-Wire every 1000' Test @ 1000' 348.72 psi 54.35° 3000' 963 psi 53.29° 4000' 1103 psi 55.5° 5000' 1244.29 psi 58.28 Tag PBR @ 7267' / NG @ 7280' 6,000.0 7,289.1 4/5/2023 05:00 4/5/2023 08:00 3.00 COMPZN, RPCOMP HOSO P P/U and lay down Joint 171,172. Space out with 26.73' of Pup's. Use time collars to get the alignment for the Hanger correct. 7,289.1 7,289.1 4/5/2023 08:00 4/5/2023 09:00 1.00 COMPZN, RPCOMP CIRC P Circulate 200 bbls of CI Seawater @ 4 bpm, 150 psi. 7,289.1 7,289.1 4/5/2023 09:00 4/5/2023 12:00 3.00 COMPZN, RPCOMP THGR P Terminate Control line and Tec-Wire through hanger. 7,289.1 7,289.1 4/5/2023 12:00 4/5/2023 16:00 4.00 COMPZN, RPCOMP THGR T Having issue getting 13-3/8" OD Hanger through BOP Stack. 7,289.1 7,289.1 4/5/2023 16:00 4/5/2023 18:00 2.00 COMPZN, RPCOMP THGR T Confirmed No-Go steps again. Good Tag depth. POOH and L/D Hanger, Space out Pup's and Joints 170 and 169. Terminate Control line and Tec- Wire. Prep to Run Storm Packer. 7,289.1 7,106.0 4/5/2023 18:00 4/6/2023 00:00 6.00 COMPZN, RPCOMP PACK T Pick up storm packer and set on 2 jts drill pipe ~ 50' // Test packer to 2500 psi 15 min packer not testing pull to rebuild valve 21:00 to 24:00 7,106.0 0.0 4/6/2023 00:00 4/6/2023 01:00 1.00 COMPZN, RPCOMP PACK T Set storm packer hanging off completion // Pressure test 2500 psi 15 min good test // lay down retrieval tools 0.0 0.0 4/6/2023 01:00 4/6/2023 02:15 1.25 COMPZN, RPCOMP NUND T Nipple down stack for install of false bowl 0.0 0.0 4/6/2023 02:15 4/6/2023 05:00 2.75 COMPZN, RPCOMP OTHR T Install false bowl in WH // OD 13.51" ID 11" Length 22" 0.0 0.0 4/6/2023 05:00 4/6/2023 05:30 0.50 COMPZN, RPCOMP NUND T Nipple up BOP test break 250/2500 - Good test 0.0 0.0 4/6/2023 05:30 4/6/2023 06:00 0.50 COMPZN, RPCOMP RURD T B/D, R/D testing equipment. 0.0 4/6/2023 06:00 4/6/2023 06:45 0.75 COMPZN, RPCOMP PACK T Engage stomp packer. Open isolation valve. Verify no PSI on tubing. Close annular. P/U 5' releasing storm packer. Check IA for PSI - On a vac. 7,167.0 7,162.0 4/6/2023 06:45 4/6/2023 07:00 0.25 COMPZN, RPCOMP CIRC T Pump 75 Bbls sea water down IA @ 3 BPM, 100 PSI. 7,162.0 7,162.0 4/6/2023 07:00 4/6/2023 07:15 0.25 COMPZN, RPCOMP OWFF T OWFF - Well on a vac. Open annular. 7,162.0 7,162.0 4/6/2023 07:15 4/6/2023 07:45 0.50 COMPZN, RPCOMP PULD T L/D 2 joints of DP and storm packer. Install TIW valve in top of joint #168. 7,162.0 7,106.0 4/6/2023 07:45 4/6/2023 08:00 0.25 COMPZN, RPCOMP RURD T Change out elevators. P/U /U T/ top of joint# 167 7,106.0 7,066.0 4/6/2023 08:00 4/6/2023 10:45 2.75 COMPZN, RPCOMP OTHR T P/U T/ top of joint# 167. Halliburton perform OHM check on gauge tec wire. Splice control line and tec wire and PT lines. Splice is below collar on Joint 167. 7,066.0 7,066.0 4/6/2023 10:45 4/6/2023 11:00 0.25 COMPZN, RPCOMP SFTY P PJSM with Crew Members involved in Landing Completion. 7,066.0 7,066.0 Rig: NABORS 7ES RIG RELEASE DATE 4/9/2023 Page 7/8 1H-102 Report Printed: 4/26/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/6/2023 11:00 4/6/2023 14:15 3.25 COMPZN, RPCOMP PULD P RIH w/ joint #168 . Pick up Jts 169 & 170 along with space out pups and hanger // Terminate lines through hanger // Orient hanger for WH. Pump 200 bbls of CI into IA 7,066.0 7,066.0 4/6/2023 14:15 4/6/2023 15:30 1.25 COMPZN, RPCOMP THGR P Land hanger and completion // RILDS and test void to 5000 psi for 15 mins. Good Test. Check Ohm's on Cable. Good Test. 7,066.0 7,289.0 4/6/2023 15:30 4/6/2023 17:00 1.50 COMPZN, RPCOMP PRTS P PT 4.5" Completion to 3000 psi for 30 min's. Good Test. PT IA to 2500 psi for 30 min's. Good Test. Dumped Pressure and Shear the SOV. Pump 5 bbls down IA to Confirm Valve is Sheared. 7,289.0 7,289.0 4/6/2023 17:00 4/6/2023 18:00 1.00 COMPZN, RPCOMP MPSP P Set Type "H" BPV and PT same to 1000 psi for 10 mins. 0.0 0.0 4/6/2023 18:00 4/6/2023 20:00 2.00 COMPZN, RPCOMP NUND P Flush stack prep for nipple down stack // nipple down stack // halliburton deal with control lines in cellar 0.0 0.0 4/6/2023 20:00 4/6/2023 23:30 3.50 COMPZN, RPCOMP NUND P Install tree and pressure test // terminate control line and tec wire 0.0 0.0 4/6/2023 23:30 4/7/2023 00:00 0.50 COMPZN, RPCOMP NUND T Halliburton cross thread penetrator hole nipple down tree to chase threads 0.0 0.0 4/7/2023 00:00 4/7/2023 02:00 2.00 COMPZN, RPCOMP NUND T Fix port on tubing adapter // NU tree test pack offs dummy penetrator leaking // found dummy penetrator to be wrong size for tubing adapter 0.0 0.0 4/7/2023 02:00 4/7/2023 05:00 3.00 COMPZN, RPCOMP WAIT T Vault rep looking in inventory for correct tubing adapter 0.0 0.0 4/7/2023 05:00 4/7/2023 08:00 3.00 COMPZN, RPCOMP NUND T Terminate Cables. ND Wellhead and NU BOPE. 0.0 0.0 4/7/2023 08:00 4/7/2023 08:15 0.25 COMPZN, RPCOMP PRTS T Pressure Test Break to 250/2500 psi and chart same. 0.0 0.0 4/7/2023 08:15 4/7/2023 09:15 1.00 COMPZN, RPCOMP SLKL T MIRU Slickline Unit and Equipment. RIH and set catcher Sub. Pull and Replace SOV at 6805'. Unable to get Slickline tools down. Wait on Dutch Riser. 0.0 0.0 4/7/2023 09:15 4/7/2023 15:30 6.25 COMPZN, RPCOMP SLKL T MIRU Slickline Unit and Equipment. RIH and set catcher Sub. Pull and Replace SOV at 6805'. Unable to get Slickline tools down. Wait on Dutch Riser. 0.0 0.0 4/7/2023 15:30 4/7/2023 17:00 1.50 COMPZN, RPCOMP WAIT T Wait on Dutch Riser from 3S-Pad. 0.0 0.0 4/7/2023 17:00 4/7/2023 17:30 0.50 COMPZN, RPCOMP SVRG T Service rig 4/7/2023 17:30 4/7/2023 18:45 1.25 COMPZN, RPCOMP RURD T Rig up dutch riser and lubricator for pumping down slick line 0.0 0.0 4/7/2023 18:45 4/7/2023 23:00 4.25 COMPZN, RPCOMP SLKL T Pull SOV and install new SOV // Pump 1 bbl/min pump slick line down no movement // add 1.75% lubes pump 6 bbls per min moving again // slick line stop moving 1000' above SOV pull out of hole with slick line rig down slick line // 0.0 0.0 4/7/2023 23:00 4/8/2023 00:00 1.00 COMPZN, RPCOMP CIRC T Line up to circulate down tubing up IA un-able to circulate // test port leaking on WH fixed // Line up reverse circulate down IA up tubing // 0.0 4/8/2023 00:00 4/8/2023 00:30 0.50 COMPZN, RPCOMP CIRC T Circulate clean fluid into pipe // 8.6 in and out // Flow check 20 min no flow 0.0 0.0 4/8/2023 00:30 4/8/2023 02:00 1.50 COMPZN, RPCOMP HOSO T Rig up landing jt // suck out stack // make up landing jt to hanger // BOLDS pull hanger fo floor 90K PUW // 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 4/9/2023 Page 8/8 1H-102 Report Printed: 4/26/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/8/2023 02:00 4/8/2023 02:30 0.50 COMPZN, RPCOMP OTHR T Change penetrator // Halliburton check cont. in controll lines 0.0 0.0 4/8/2023 02:30 4/8/2023 04:00 1.50 COMPZN, RPCOMP CRIH T Pump CI down IA 240 bbls // SO on pipe 10K dwn to engage seals // ensure hole full prior to landing 0.0 0.0 4/8/2023 04:00 4/8/2023 06:30 2.50 COMPZN, RPCOMP HOSO T Land hanger // RILDS // Test Void to 5000 psi for 15 mins. Test IA 2500 for 15 min // Pull Landing Joint. Drain Stack. 0.0 0.0 4/8/2023 06:30 4/8/2023 08:45 2.25 COMPZN, WHDBOP MPSP T Install BPV and PT from below to 1000 psi. Blow Stack and choke manifold to tiger tank. 0.0 0.0 4/8/2023 08:45 4/8/2023 13:00 4.25 COMPZN, WHDBOP NUND T ND BOPE and NU Wellhead. Terminate Tec-Wire and Control Line through TBG head. PT Void to 5000 psi for 15 mins. Good Test. Final Tec-Wire Reading: PSI 1646 / Temp 68.45* 0.0 0.0 4/8/2023 13:00 4/8/2023 13:15 0.25 COMPZN, WHDBOP PRTS P PT Wellhead 250/5000 psi. 0.0 0.0 4/8/2023 13:15 4/8/2023 14:15 1.00 COMPZN, WHDBOP RURD P RD Testing Maninfold. MIRU LRS to pump Diesel. Pull Test Dart and BPV. 0.0 0.0 4/8/2023 14:15 4/8/2023 15:15 1.00 COMPZN, WHDBOP FRZP P Circulate 85 bbls of Diesel down IA @ 2 bpm, 700 psi. RDMO LRS. Allow Well to U-Tupe. 0.0 0.0 4/8/2023 15:15 4/9/2023 00:00 8.75 DEMOB, MOVE MOB P Secure Well & Cellar. Bridal up. Lay derrick over. Pull sub off of well. Clean up around well. Load shop, office and pits and transport to 3S pad. Move sub T/ 3S. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 4/9/2023 DTTMSTART JOBTYP SUMMARYOPS 3/2/2023 REPAIR WELL BRUSH n' FLUSH TBG W/ 3.58" GAUGE RING WHILE PUMPING 127 BBLS OF DIESEL (776) DOWN TO 7150' RKB; DRIFT W/ 5' X 3" BAILER DOWN TO 7468' RKB; RAN READ CASED HOLE 40 ARM CALIPER FROM 7397' RKB TO SURFACE. JOB COMPLETE. 3/27/2023 SUPPORT OTHER OPERATIONS PRESSURE TEST TBG TO 1000 HOLE FINDER SET @ 150' RKB(PASS),DISPLACE TBG W/DIESEL(776),BRUSH & FLUSH 3.75'' DBNIPPLE @ 7308'RKB. ATTEMPT TO SET 3.75'' DB-P PLUG BODY(UNSUCCESSFUL) STALLS OUT @7114'RKB . READY FOR LRS TO PUMP SEA WATER. 3/27/2023 SUPPORT OTHER OPERATIONS LOAD WELL PUMPED 10 BBLS DIESEL FOLLOWED BY 200 BBLS OF SEAWATER TO LOAD THE IA AND FREEZE PROTECTED WITH 58 BBLS OF DIESEL PUMPED 90 BBLS OF SEAWATER DOWN TBG AND FREEZE PROTECTED WITH 34 BBLS DIESEL TO FREEZE PROTECT PUMPED 10 BBLS OF 180* DIESEL DOWN FL PER DSO (JOB COMPLETE) 3/28/2023 RECOMPLETION Complete pumping 75 bbls diesel let u-tube, Jack pits up pull away from rig, Transport to 1H pad, Pull rig off well 34 & position by shop for maintenance, Rig down berming around camp and prep for rig move, Load out KDTH trucks to 1H-pad 3/29/2023 RECOMPLETION Continue working on & re-installing BOP Bonnet, damaged threads on double gate, chase down and attempt to chase threads, unable to repair, locate replacement double gates. 3/29/2023 SUPPORT OTHER OPERATIONS (PRE-RWO) BLEED IA UNTIL FLUID TO SURFACE, COMPLETE, LRS PUMPED TWO 240 BBL LOADS OF 12 PPG KWF, COMPLETE, VALVE CREW INSTALLED IA VR PLUG, COMPLETE, TEST TO 1500 PSI, PASSED, REMOVE IA CASING VALVE AND INSTALL BLIND FLANGE, COMPLETE, TEST IA VR PLUG AND BLIND FLANGE TO 2500 PSI, NO EXTERNAL LEAK. 3/29/2023 REPAIR WELL KILL WELL BY PUMPING 240BBLS 12PPG KILL WEIGHT BRINE DWN IA PRE RWO, TURN WELL BACK OVER TO DHD CHANGE OF SCOPE, PUMP ADDITIONAL 242 BBLS 12PPG KILL WEIGHT BRINE DWN IA, TURN OVER TO DHD/VALVE CREW TO INSTALL VR PLUG IN IA COMPANION VALVE. 3/30/2023 RECOMPLETION Break down BOP stack, replace double gate with rental. move to 1H-102. MIRU on well. Lower Derrick, Mobilize sub module and support equipment to location, Hang tree, stage wellhead equipment in cellar. Spot rig over well 102. Spot pits to rig. Spot auxiliary equipment. Cuttings tank, flow back tank, choke and flow back iron. Hook up steam and air to pits. Berm in rig. Raise derrick. Bridal down. Complete acceptance checklist. Get measurements for riser height from tubing spool height. Rig up circ manifold in cellar. Take on 9.3 PPG NaCl in pits. Take initial pressures T/IA/OA. Pressure test circ manifold & tiger tank T/ 2500 PSI. Kill well with 9.3 PPG NaCI. 3/30/2023 REPAIR WELL PUMP 40 BBLS DSL DOWN TBG PUMP 40 BBLS DSL DOWN IA 3/31/2023 RECOMPLETION Complete Rig up checklist. Accept rig 0400. Load well with seawater 5 BPM. Unable to estblish circulation down IA with 50% returns to tank. . Swap over to tubing. No returns from annulas. Bullhead 200 BBls down tubing. R/U HES set test RBP on relay. 40'. No test M/U second RBP set @ 33'. Test 2500PSI/30 Min. Good test. Start ND tree and adpapter, NU BOP and test per sundry. Pull RBP with relay unit and LD. Start pulling 4.5" completion. 1H-102 RWO Summary of Operations 3/31/2023 SUPPORT OTHER OPERATIONS SET 3.76" RBP @ 40' RKB (CE) (OAL 6.87' / SN:CPP45019) MIT TBG 2500 (FAILED), SET 3.76" RBP @ 33' RKB (CE) (OAL 5.56' / SN:CPP45021) MIT TBG 2500 PSI (PASS). RIG PULLED TREE INSTALLED BOP'S & PREFORMED TESTING. PULLED 3.76" RBP'S @ 33' & 40' RKB. JOB COMPLETE. 4/1/2023 RECOMPLETION Set RBP, PT 2500PSI/30Min. Nipple down tree, Nipple up BOPE. Perform full test. Witness waived by Kam StJohn, AOGCC. Slickline out to pull RBP. Bullhead 200 BBls seawater down tubing. M/U BHA #1 spear. Spear tubing hanger. Back out LDS. Pull hanger free @ 155K. Dragging 107K. Pull hanger to floor. Disengage spear. Rig up to lay down 4 1/2" completion 4/2/2023 RECOMPLETION Finish laying down tubing pick up scraper and run in on DP 4/3/2023 RECOMPLETION Complete scraper run to 7240. POOH, P/U BHA #3 G plug. Trip in hole, Set @ 7000' center element. PUH to 3568', 42K. M/U 7 5/8" storm packer. RIH 68'. Set packer. Test. Release packer, trip out. Nipple down stack and wellhead. Nipple up new tubing spool, PT void to 5K. Nipple up BOPE. PT break. RIH. Retrieve storm packer - lay down. Trip in to retrieve G Plug 4/4/2023 RECOMPLETION Run in and retrieve G plug, lay down drill pipe, Pick up and run completion with guage and chem inj port, clamping lines every collar 4/5/2023 RECOMPLETION Complete picking up completion, NG out on lower completion @ 7280' Pick up space out pump CI, clock hanger for install, lower into stack unable to pass false bowl through stack, make multiple attempts including re-confirm space out, found false bowl would not pass through double gate, pull install storm packer, valve failed on first storm packer, wait for second storm packer install and pressure test 4/6/2023 RECOMPLETION Set storm packer, Nipple down stack and install false bowl, nipple stack up test break 250/2500 good test pull storm packer and retrieve completion, splice control line and tec wire, land completion and test shear out valve and set BPV, nipple down stack set tree in place start terminating lines, halliburton cross thread penetrator, nipple down tree to chase threads 4/7/2023 RECOMPLETION Completed fixing threads on control line port on well head, stab well head pressure test, dummy penetrator not holding pressure, nipple down tree found wrong dummy penetrator installed, nipple up stack and test break, rig up slick line to change out SOV, unable to get sl down to SOV, rig down SL circ B/U , sov plugged reverse circ good fluid down IA 4/7/2023 SUPPORT OTHER OPERATIONS SHAKE OFF 4-1/2 BAIT-SUB, 3.50" BELL GUIDE, 2" RB W/ BELL GUIDE (OAL 59") TO SET ON BALL & ROD @ 7202' RKB. MAKE SEVERAL ATTEMPTS TO MAKE IT TO SOV @ 6805' RKB, DEEPEST DEPTH MADE 5900' RKB. DUE TO THICK FLUID IN TUBING 4/8/2023 RECOMPLETION Pull hanger to floor change out dummy penetrator, test control lines test good, pump CI 240 bbls engage seals to catch on IA side of well, land completion and test, end of well ops and RDMO 4/10/2023 REPAIR WELL DRIFT & CHASE 4 1/2" BAIT SUB PULLING TOOL ASSEMBLY DOWN TO BALL & ROD @ 7185' RKB; PULLED SOV (SHEARED) & ATTEMPT TO SET DV @ 6805' RKB (DROPPED VALVE); CONFIRM POCKET IS OPEN W/ IMPRESSION BLOCK & SET DV @ 6805' RKB (OBTAIN TBG TEST); ATTEMPT TO PULL DV @ 5505' RKB. IN PROGRESS. 4/11/2023 REPAIR WELL PULLED BK-DGLV FROM 5505' RKB & 2678' RKB. SET BK-OGLV @ 5505' RKB (7/16" PORT), SET BK-LGLV @ 2678' RKB (1/4" PORT, 1556psi TRO), PULLED BAITED BALL & ROD & 3.81" RHC FROM 7203' RKB. RAN 3.70" DRIFT TO DEVIATION @ 7282' SLM, NO SAMPLE RECOVERED, JOB COMPLETE. NOTE: RECOVERED DV IN CATCHER THAT WAS LOST 4/10/23. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By LAST TAG: 1H-102 jennalt Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Installed post rig GLD. Pulled RHC equip. 1H-102 4/11/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: jennalt Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread Conductor 20 19.12 40.3 118.6 118.6 78.67 B Surface 10 3/4 9.95 40.2 1,771.0 1,690.9 45.50 L-80 Hydril 563 Intermediate 7 5/8 6.88 37.4 8,591.1 3,991.2 29.70 L-80 Hyd 563 LINER 4 1/2 4.00 8,227.6 12,790.1 4,020.4 11.60 L-80 IBT-m Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 0.0 Set Depth 7,289.1 Set Depth 3,714.0 String Ma 4 1/2 Tubing Description Tubing Production Wt (lb/ft) 12.60 Grade L-80 Top Connection Hyd 563 ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 515.1 514.5 5.46 Nipple - X 4.500 3.81 X Nipple S# 004855432-1 Halliburt on 3.813" X Nipple 3.958 2,678.2 2,295.3 58.94 Mandrel 4.500 Camco 4-1/2" x1" KBMG Mandrel, Hyd 563 DMY S# 23061-14 SLB KBMG 3.900 5,505.2 3,197.7 72.30 Mandrel 4.500 Camco 4-1/2" x1" KBMG Mandrel, Hyd 563 DMY S#23061-03 SLB KBMG 3.890 6,805.2 3,573.6 72.50 Mandrel 4.500 Camco 4-1/2" x1" KBMG Mandrel, Hyd 563 SOV S# 23061-02 SLB KBMG 3.890 6,990.0 3,628.6 72.57 Other 4.500 OPSIS Halliburton Gauge assembly S# MX M18767-03 Halliburt on OPSIS Single Ended Gauge 3.920 7,055.4 3,648.0 73.16 Mandrel INJ 4.500 Halliburton Chemical injection mandrel S# 050622384 Halliburt on CIV 3.949 7,202.7 3,689.7 73.30 Nipple - X 5.030 3.813" Halliburton "X" nipple W/RHC plug S# 0004855432-6 Halliburt on X Landing Nipple. RHC-M 3.813 7,260.6 3,706.2 73.80 Locator 5.400 Baker locator Baker GBH-22. 192-47 Locator 3.870 7,262.1 3,706.6 73.81 Seal Assembly 4.620 Baker GBH-22 192-47 locating seal assembly Baker 192-47 3.880 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,678.2 2,295.3 58.94 1 GAS LIFT GLV BK 6.38 1,556.0 4/11/2023 Schlumb erger BK 0.250 5,505.2 3,197.7 72.30 2 GAS LIFT OV BK 6.36 0.0 4/11/2023 Schlumb erger KBMG 0.438 6,805.2 3,573.6 72.50 3 GAS LIFT DMY BK 6.38 0.0 4/10/2023 Schlumb erger KBMG 0.000 7,055.4 3,648.0 73.16 4 CHEM CIV 5.49 2 4/6/2023 Halliburt on DD Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,227.6 3,962.6 78.67 PACKER 5.500 Baker HRD-E ZXP 5.5" x 7.63" Flex-Lock Liner top packer L-80 Hyd 563 pin Baker PN: H296- 45-0131, Control # 106140598 5.750 8,247.5 3,966.4 79.55 NIPPLE 5.500 Baker 5.5" "RS" Packoff Seal Nipple 17# L-80 Hyd 563 box x box Baker PN: H294- 01-0656, Control # 106022610- 02 4.890 8,279.9 3,971.9 80.89 XO Reducing 5.500 5.5" Hyd 563 15.5 # box x 4.5" 12.6# IBT- pin Crossover 3.950 8,713.5 3,991.0 90.51 Swell Packer 6.380 Baker 6-3/8" OD Swell Packer #3 "F" SN: 049169-001-12 Baker 920 Compound 1834, PN H301-87- 0397, SN: 049169-001 3.970 10,967.6 4,013.2 88.23 Swell Packer 6.380 Baker 6-3/8" OD Swell Packer #2 "E" SN: 049169-001-20 Baker 920 Compound 1834, PN H301-87- 0397, SN 049169-001 - 3.970 11,282.2 4,031.4 85.88 Swell Packer 6.380 Baker 6-3/8" OD Swell Packer #1 "D" SN: 049169-001-7 Baker 920 Compound 1834, PN H301-87- 0397, SN 049169-001 3.970 12,768.3 4,020.1 89.23 stand 4" DP = 0.000 stand 4" DP 0.000 1H-102, 5/5/2023 8:34:36 AM Vertical schematic (actual) LINER; 8,227.6-12,790.1 SLOTS; 11,314.1-12,746.4 SLOTS; 8,745.4-10,977.5 Intermediate; 37.4-8,591.1 L1 - Lower Completion; 7,973.4- 13,097.3 Packer; 7,912.5 L2 - Lower Completion; 7,840.0- 13,204.2 L3 - Lower Completion; 7,644.6- 14,667.7 Packer; 7,460.4 NIPPLE; 7,308.2 Mandrel INJ; 7,055.4 Other; 6,990.0 Mandrel; 6,805.2 Mandrel; 5,505.2 Mandrel; 2,678.2 Surface; 40.2-1,771.0 Conductor; 40.2-118.6 Tubing hanger; 0.0 KUP PROD KB-Grd (ft) 38.62 RR Date 10/20/201 7 Other Elev 1H-102 ... TD Act Btm (ftKB) 12,960.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292358000 Wellbore Status PROD Max Angle & MD Incl (°) 92.45 MD (ftKB) 11,741.17 WELLNAME WELLBORE1H-102 Annotation LAST WO: End Date 4/8/2023 H2S (ppm) 20 Date 11/20/2017 Comment SSSV: NONE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,745.4 10,977.5 3,990.7 4,013.5 WS A2, 1H-102 9/8/2017 32.0 SLOTS 4 x rows per foot w/ 8 slots per row - each slot is 3" long x 1/8" wide 11,314.1 12,746.4 4,033.6 4,019.9 WS A2, 1H-102 9/8/2017 32.0 SLOTS 4 x rows per foot w/ 8 slots per row - each slot is 3" long x 1/8" wide 1H-102, 5/5/2023 8:34:37 AM Vertical schematic (actual) LINER; 8,227.6-12,790.1 SLOTS; 11,314.1-12,746.4 SLOTS; 8,745.4-10,977.5 Intermediate; 37.4-8,591.1 L1 - Lower Completion; 7,973.4- 13,097.3 Packer; 7,912.5 L2 - Lower Completion; 7,840.0- 13,204.2 L3 - Lower Completion; 7,644.6- 14,667.7 Packer; 7,460.4 NIPPLE; 7,308.2 Mandrel INJ; 7,055.4 Other; 6,990.0 Mandrel; 6,805.2 Mandrel; 5,505.2 Mandrel; 2,678.2 Surface; 40.2-1,771.0 Conductor; 40.2-118.6 Tubing hanger; 0.0 KUP PROD 1H-102 ... WELLNAME WELLBORE1H-102 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By LAST TAG: 1H-102L1 jennalt Last Rev Reason Annotation Wellbore End Date Last Mod By REV REASON: H2S 1H-102L1 1/8/2018 pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: jennalt Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1 - Lower Completion 4 1/2 4.00 7,973.4 13,097.3 3,986.2 11.60 L-80 IBTM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 7,912.5 Set Depth 8,298.6 Set Depth 3,934.8 String Ma 4 1/2 Tubing Description Tubing Production Wt (lb/ft) 12.60 Grade L-80 Top Connection TXP BTC ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,912.5 3,881.7 74.47 Packer 6.560 Baker ZXP Liner Top Packer 5.5" x 7.63", 5-1/2" H563 Baker Baker ZXP Liner top packer 4.920 7,932.4 3,887.0 74.41 SBE (Seal Bore Extension) 6.240 Baker 190-47 Seal Bore Extension, 5-1/2" Baker Baker Seal Bore Extensio n 4.750 7,952.2 3,892.3 74.36 Crossover (XO) Bushing 5.500 Reducing Crossover sub 5½" Hyd 563 X 4-1/2" TXP 3.940 7,970.1 3,897.1 75.03 Triple connect bushing 5.570 Baker 4.5" x 7.63"LEM #1 (Above Hook hanger) SN # 106041637-02 Baker L1 LEM: Above Hook 3.710 7,973.4 3,898.0 75.20 Triple connect bushing 6.610 Baker 4.5" x 7.63" LEM #1 (Below Hook Hanger) Baker L1 LEM: Below Hook 3.688 8,244.3 3,935.4 90.34 Nipple - DB, XN, DS, D 4.500 Camco 4-1/2" x 3.562" DB-6 Nipple SN# W04883-3 Camco DB 6 Camco DB 6 3.562 8,295.3 3,934.8 90.48 SEAL ASSY 4.760 Baker 190-47 GBH-22, 4-1/2", L-80 Stright Non-Locating Seal Assy Baker Baker Seal Assy 3.890 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,180.5 3,933.8 86.72 Swell Packer 6.040 Baker 6.0" OD Swell Packer #3 "C" SN: 054007-010-14 ( 8165' ) Baker SN: 054007 -010-14 3.950 10,993.2 3,966.3 85.84 Swell Packer 6.000 Baker 6.0" OD Swell Packer #3 "B" SN: 54007-010-11 ( 10990') Baker SN: 54007- 010-11 3.950 11,179.5 3,983.4 84.52 Swell Packer 6.000 Baker 6.0" OD Swell Packer #3 "A" SN: 54007-010-20 ( 11162') Baker SN: 54007- 010-20 3.950 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,186.3 10,979.4 3,934.1 3,965.3 WS A3, 1H- 102L1 9/17/2017 32.0 SLOTS 4 x rows per foot w/ 8 slots per row - each slot is 3" long x 1/8" wide 11,185.3 13,053.7 3,983.9 3,983.6 WS A3, 1H- 102L1 9/17/2017 32.0 SLOTS 4 x rows per foot w/ 8 slots per row - each slot is 3" long x 1/8" wide 1H-102L1, 5/5/2023 8:34:38 AM Vertical schematic (actual) L1 - Lower Completion; 7,973.4- 13,097.3 SLOTS; 11,185.3-13,053.7 SLOTS; 8,186.3-10,979.3 Nipple - DB, XN, DS, D; 8,244.3 Intermediate; 37.4-8,591.1 Packer; 7,912.5 L2 - Lower Completion; 7,840.0- 13,204.2 L3 - Lower Completion; 7,644.6- 14,667.7 Packer; 7,460.4 NIPPLE; 7,308.2 Mandrel INJ; 7,055.4 Other; 6,990.0 Mandrel; 6,805.2 Mandrel; 5,505.2 Mandrel; 2,678.2 Surface; 40.2-1,771.0 Conductor; 40.2-118.6 Tubing hanger; 0.0 KUP PROD KB-Grd (ft) 38.62 RR Date 10/20/201 7 Other Elev 1H-102L1 ... TD Act Btm (ftKB) 13,127.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292358060 Wellbore Status PROD Max Angle & MD Incl (°) 91.86 MD (ftKB) 12,024.44 WELLNAME WELLBORE1H-102 Annotation LAST WO: End DateH2S (ppm) 20 Date 11/20/2017 Comment Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By LAST TAG: 1H-102L2 jennalt Last Rev Reason Annotation Wellbore End Date Last Mod By REV REASON: H2S 1H-102L2 1/8/2018 pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: jennalt Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L2 - Lower Completion 4 1/2 4.00 7,840.0 13,204.2 3,933.1 11.60 L-80 IBT-m Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,295.4 3,878.0 93.12 Swell Packer 6.000 Baker 6.0" OD Swell Packer #3 "F" SN: 54007-010-13 ( < 8295') Baker PN: H301- 87-0450, SN: 54007- 010-13 3.950 10,929.3 3,902.0 87.97 Swell Packer 6.030 Baker 6.0" OD Swell Packer #2 "E" SN: 54007-010-15 ( > 10950') Baker PN: H301- 87-0450, SN: 54007- 010-15 3.950 11,174.6 3,921.1 85.97 Swell Packer 6.010 Baker 6.0" OD Swell Packer #1 "D" SN: 54007-010-10 (< 11144') Baker PN: H301- 87-0450, SN: 54007- 010-10 3.950 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,301.2 10,915.5 3,877.7 3,901.5 WS A4, 1H- 102L2 9/27/2017 32.0 SLOTS 4 x rows per foot w/ 8 slots per row - each slot is 3" long x 1/8" wide 11,180.3 13,160.6 3,921.5 3,931.4 WS A4, 1H- 102L2 9/27/2017 32.0 SLOTS 4 x rows per foot w/ 8 slots per row - each slot is 3" long x 1/8" wide 1H-102L2, 5/5/2023 8:34:39 AM Vertical schematic (actual) L2 - Lower Completion; 7,840.0- 13,204.2 SLOTS; 11,180.3-13,160.6 SLOTS; 8,301.2-10,915.5 Intermediate; 37.4-8,591.1 L3 - Lower Completion; 7,644.6- 14,667.7 Packer; 7,460.4 NIPPLE; 7,308.2 Mandrel INJ; 7,055.4 Other; 6,990.0 Mandrel; 6,805.2 Mandrel; 5,505.2 Mandrel; 2,678.2 Surface; 40.2-1,771.0 Conductor; 40.2-118.6 Tubing hanger; 0.0 KUP PROD KB-Grd (ft) 38.62 RR Date 10/20/201 7 Other Elev 1H-102L2 ... TD Act Btm (ftKB) 13,435.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292358061 Wellbore Status PROD Max Angle & MD Incl (°) 95.05 MD (ftKB) 8,202.23 WELLNAME WELLBORE1H-102 Annotation LAST WO: End DateH2S (ppm) 20 Date 11/20/2017 Comment Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By LAST TAG: 1H-102L3 jennalt Last Rev Reason Annotation Wellbore End Date Last Mod By REV REASON: H2S 1H-102L3 1/8/2018 pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: jennalt Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L3 - Lower Completion 4 1/2 4.00 7,644.6 14,667.7 3,843.9 11.60 L-80 IBT-m Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 7,460.4 Set Depth 7,753.1 Set Depth 3,827.1 String Ma 4 1/2 Tubing Description Tubing Production Wt (lb/ft) 12.60 Grade L-80 Top Connection TXP-m ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,460.4 3,760.3 74.26 Packer 6.550 Baker ZXP Liner Top Packer 5.5" x 7.63", 5-1/2" H563 Baker Baker ZXP Liner top packer 4.910 7,480.3 3,765.7 74.19 SBE (Seal Bore Extension) 6.270 Baker 190-47 Seal Bore Extension, 5-1/2" Baker Seal Bore Extensio n 4.750 7,500.1 3,771.1 74.21 Crossover (XO) Bushing 5.500 Reducing Crossover sub 5½" Hyd 563 X 4-1/2" TXP 3.940 7,641.4 3,808.5 75.88 Triple connect bushing 5.590 Baker 4.5" x 7.63"LEM # 3 (Above Hook hanger) SN #106042200-01 Baker L3 LEM: Above Hook 3.800 7,644.6 3,809.3 75.96 Triple connect bushing 6.640 Baker 4.5" x 7.63" LEM #3 (Below Hook Hanger) Baker L3 LEM: Below Hook 3.688 7,749.8 3,826.9 85.50 SEAL ASSY 4.750 Baker 190-47 GBH-22, 4-1/2", L-80 Straight Non-Locating Seal Assy Baker Baker Seal Assy 3.870 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,777.1 3,828.4 88.14 Swell Packer 6.010 Baker 6.0" OD Swell Packer #1 "G" SN: 54007-010-25 Baker PN: H301- 87-0450, SN: 54007- 010-25 3.970 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,782.8 10,901.0 3,828.5 3,852.5 WS B, 1H-102L3 10/6/2017 32.0 SLOTS 4 x rows per foot w/ 8 slots per row - each slot is 3" long x 1/8" wide 11,043.4 14,624.1 3,868.1 3,843.2 WS B, 1H-102L3 10/6/2017 32.0 SLOTS 4 x rows per foot w/ 8 slots per row - each slot is 3" long x 1/8" wide 1H-102L3, 5/5/2023 8:34:39 AM Vertical schematic (actual) L3 - Lower Completion; 7,644.6- 14,667.7 SLOTS; 11,043.4-14,624.1 SLOTS; 7,782.8-10,901.0 Intermediate; 37.4-8,591.1 Packer; 7,460.4 NIPPLE; 7,308.2 Mandrel INJ; 7,055.4 Other; 6,990.0 Mandrel; 6,805.2 Mandrel; 5,505.2 Mandrel; 2,678.2 Surface; 40.2-1,771.0 Conductor; 40.2-118.6 Tubing hanger; 0.0 KUP PROD KB-Grd (ft) 38.62 RR Date 10/20/201 7 Other Elev 1H-102L3 ... TD Act Btm (ftKB) 14,686.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292358062 Wellbore Status PROD Max Angle & MD Incl (°) 93.55 MD (ftKB) 11,613.52 WELLNAME WELLBORE1H-102 Annotation LAST WO: End DateH2S (ppm) 20 Date 11/20/2017 Comment Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By LAST TAG: 1H-102L4 jennalt Last Rev Reason Annotation Wellbore End Date Last Mod By REV REASON: H2S 1H-102L4 1/8/2018 pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: jennalt Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L-4 - Lower completion 4 1/2 4.00 7,391.7 14,670.0 3,780.4 11.60 L-80 IBT-m Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 7,252.2 Set Depth 7,494.5 Set Depth 3,763.3 String Ma 4 1/2 Tubing Description Tubing Production Wt (lb/ft) 11.60 Grade L-80 Top Connection TXP BTC ID (in) 3.89 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,252.2 3,703.8 73.73 PACKER 6.530 Baker ZXP Liner Top Packer 5.5" x 7.63", 5-1/2" H563 Baker ZXP Liner top packer PN# H296-45 -0131 4.920 7,272.2 3,709.4 73.90 SBE (Seal Bore Extension) 6.260 Baker 190-47 Seal Bore Extension, 5-1/2" Baker PN# H02 -43317- a1 4.750 7,291.9 3,714.8 74.07 Crossover (XO) Bushing 5.500 Reducing Crossover sub 5½" Hyd 563 X 4-1/2" TXP Baker 3.930 7,308.3 3,719.3 74.15 NIPPLE 4.500 Camco 4-1/2" x 3.750" OS DB-6 Nipple SN# 4239-5 Camco DB 6 SN#423 9-5 3.750 7,371.0 3,736.3 74.44 Triple connect bushing 5.590 Baker 4.5" x 7.63"LEM #1 (Above Hook hanger) SN # Baker PN# H289-18 -0039 3.800 7,374.2 3,737.1 74.46 Triple connect bushing 6.630 Baker 4.5" x 7.63" LEM #1 (Below Hook Hanger) Hook @ 7,393.56' Baker 3.688 7,491.2 3,762.8 79.82 Seal Assembly 4.750 Baker 190-47 GBH-22, 4-1/2", L-80 Stright Non-Locating Seal Assy Baker PN# H453-01 -0033 3.880 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,525.0 3,768.1 81.83 Swell Packer 6.010 Baker 6.0" OD Swell Packer #1 "H" SN: 054007-010-12 Baker PN: H301- 87-0450, SN: 54007- 010-12 3.970 1H-102L4, 5/5/2023 8:34:40 AM Vertical schematic (actual) L-4 - Lower completion; 7,391.7- 14,670.0 Intermediate; 37.4-8,591.1 NIPPLE; 7,308.2 Mandrel INJ; 7,055.4 Other; 6,990.0 Mandrel; 6,805.2 Mandrel; 5,505.2 Mandrel; 2,678.2 Surface; 40.2-1,771.0 Conductor; 40.2-118.6 Tubing hanger; 0.0 KUP PROD KB-Grd (ft) 38.62 RR Date 10/20/201 7 Other Elev 1H-102L4 ... TD Act Btm (ftKB) 14,670.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292358063 Wellbore Status PROD Max Angle & MD Incl (°) 93.64 MD (ftKB) 13,360.42 WELLNAME WELLBORE1H-102 Annotation LAST WO: End Date 4/8/2023 H2S (ppm) 20 Date 11/20/2017 Comment C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-03-02_22082_KRU_1H-102_02-Mar-23_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API # Log Description Log Date 22082 KRU 1H-102 50-029-23580-00 Caliper Survey w/ Log Data 02-Mar-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12960'None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Slotted Liner: 8745-10977', 11314-12746' 4-1/2" Slotted Liner: 3991-4013', 4034-4020' 12790'4562' 4-1/2" 4020' 20" 10-3/4" 78' 1731' Perforation Depth MD (ft): 7-5/8"8554' MD 119' 1691' 3991' 119' 1771' 8591' Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 4022' 12960' 4022' 1224 psi None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025639 217-097 P.O. Box 100360, Anchorage, AK 99510 50-029-23580-00-00 ConocoPhillips Alaska, Inc. KRU 1H-102 West Sak Oil PoolWest Sak Oil PoolKuparuk River Field N/A Tubing Grade: Tubing MD (ft): 8228' MD and 3963' TVD N/A Perforation Depth TVD (ft): Tubing Size: L-80 7289' 3/20/2023 Packer: Baker HRD-E ZXP Flex-Lock LTP SSSV: None 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Dusty Ward dusty.ward@conocophillips.com (907) 265-6531 Senior Workover Engineer Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Carlisle at 2:18 pm, Feb 28, 2023 323-126 SFD 3/1/2023 DSR-2/28/23 10-404 X X VTL 03/08/2023 BOP test to 2500 psig Annular preventer test to 2500 psig GCW 03/08/23JLC 3/8/2023 3/9/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.03.09 10:17:26 -09'00' RBDMS JSB 030923 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 27, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Dusty K Ward Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over West Sak Producer 1H- 102 (PTD# 217-097-0). Well 1H-102 was drilled in 2017 as a gas lift producer of the West Sak. Holes were discovered in the tubing in 2023 after failing a TIFL and it has become a RWO candidate. If you have any questions or require any further information, please contact me at +1503-476-2519. The tubing will be pulled from seals in the liner top packer and a new 4.5" completion will be ran. 1H-102 RWO Procedure West Sak Producer Pull and Replace Tubing PTD #217-097 Page 1 of 2 Remaining Pre-Rig Work 1. T-PPPOT and T-POT tests. 2. Set plug below tubing seals if possible. 3. CMIT-TxIA 4. Prepare well for rig arrival within 48-72 hours of rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 1H-102. (No BPV will be installed pre-rig due to internal risk assessment for N7ES.) 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 4-1/2” tubing down to seals (6778’). a. If holes appear to be from External corrosion, then consult with town engineer and discuss possible Eline caliper of 7-5/8”. If not, then move to re-complete. Install new 4-½” Tubing 6. MU 4 ½” completion with muleshoe, 4.5” x 7-5/8” packer, gauge, CMU, nipples, Chem Injection, and GLMs. a. Note: “Alt1” completion schematic would use seals instead of muleshoe and sting back into SBE rather than stacking a 4.5” x 7-5/8” packer. If seals arrive in time, this is preferred option. Also, the Chemical Injection mandrel and line may or may not be ran in either of these scenarios. 7. RIH with completion. Once on depth, sting into SBE. 8. Space out as needed. Circulate CI brine at opportune time. Land tubing and RILDS. Test packoffs. Set packer. 9. Pressure test tubing to 3000 psi for 30 minutes and chart. 10. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ND BOP, NU Tree 11. Confirm pressure tests, then shear out SOV with pressure differential. 12. Install BPV. Test BPV as needed. 13. ND BOPE. NU tree. 14. Pull BPV, freeze protect well if necessary. 15. RDMO. Post-Rig Work 16. Pull all plugs from tubing string and install GLD. 17. Turn over to operations. 1H-102 RWO Procedure West Sak Producer Pull and Replace Tubing PTD #217-097 Page 2 of 2 General Well info: Wellhead type/pressure rating: Vetco Gray MB222A, 5M psi top flange Production Engineer: Will Parker Reservoir Development Engineer: Sayeed Abbas Estimated Start Date: 3/20/2023 Workover Engineer: Dusty Ward (265-6531/ dusty.ward@conocophillips.com) Current Operations: This well is currently online, but will be SI after 28 day clock expires from failed TIFL. Well Type: Producer Scope of Work: Pull the existing 4-1/2” completion from seals. Run new 4-1/2” completion and stab back into PBR with seals with muleshoe and stacked packer. (*Note: If seals arrive in time, will run new seals and eliminate stacked packer. Want AOGCC to be aware of both options for lower seal so we don’t need to revise. Thanks.) BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T Failed TIFL 2/25/2023 CMIT-TxIA 7-5/8” casing passed initial drill tests. Expected to pass in upcoming diagnostics once plug can get set. MIT-OA N/A IC POT &PPPOT PASSED – 2/26/2023 TBG POT &PPPOT PASSED – 2/26/2023 MPSP: 1224 psi using 0.1 psi/ft gradient Static BHP: 1724 psi / 3687’ TVD measured on 10/30/2017 1H-102 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 119 119 20 19.12 78.7 B Welded Welded Surface 1771 1691 10.75 9.95 45.5 L80 HYD563 HYD563 Production 8591 3991 7.625 6.88 29.7 L80 HYD563 HYD563 Laterals 12790 4020 4.5 4 11.6 L80 IBTM IBTM Tubing 7289 3714 4.5 3.96 12.6 L80 TXPM TXPM PROPOSED COMPLETION 4-1/2" 12.6# L-80 HYD563 Tubing to surface 3.813" X-Nipple 4-1/2" Camco KBMG gas lift mandrels @ TBD CMU Gauge Mandrel (TEC wire with Clamps to Surface) Chem Injection Mandrel (1/4" Line to Surface) 4-1/2" x 7-5/8" Packer 3.813" X-Nipple 4-1/2" Muleshoe (Non-Sealing) REMAINING COMPLETION LEFT IN HOLE ZXPN Liner Top Packer (8228' RKB) Seal Bore Extension. 4.750" ID (8260' RKB) West Sak Laterals Production Casing Conductor West Sak Liners/Laterals Surface Casing 1H-102 Proposed RWO Completion_Alt1 COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 119 119 20 19.12 78.7 B Welded Welded Surface 1771 1691 10.75 9.95 45.5 L80 HYD563 HYD563 Production 8591 3991 7.625 6.88 29.7 L80 HYD563 HYD563 Laterals 12790 4020 4.5 4 11.6 L80 IBTM IBTM Tubing 7289 3714 4.5 3.96 12.6 L80 TXPM TXPM PROPOSED COMPLETION 4-1/2" 12.6# L-80 HYD563 Tubing to surface 3.813" X-Nipple 4-1/2" Camco KBMG gas lift mandrels @ TBD CMU Gauge Mandrel (TEC wire with Clamps to Surface) Chem Injection Mandrel (1/4" Line to Surface) 3.813" X-Nipple 4-1/2" Seals REMAINING COMPLETION LEFT IN HOLE ZXPN Liner Top Packer (8228' RKB) Seal Bore Extension. 4.750" ID (8260' RKB) West Sak Laterals Production Casing Conductor West Sak Liners/Laterals Surface Casing Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By LAST TAG:1H-102 jennalt Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Install new GLD, Set CSV 6/3/2020 1H-102 fergusp Casing Strings Casing Description Conductor OD (in) 20 ID (in) 19.12 Top (ftKB) 40.3 Set Depth (ftKB) 118.6 Set Depth (TVD) … 118.6 Wt/Len (l… 78.67 Grade B Top Thread Casing Description Surface OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 40.2 Set Depth (ftKB) 1,771.0 Set Depth (TVD) … 1,690.9 Wt/Len (l… 45.50 Grade L-80 Top Thread Hydril 563 Casing Description Intermediate OD (in) 7 5/8 ID (in) 6.88 Top (ftKB) 37.4 Set Depth (ftKB) 8,591.1 Set Depth (TVD) … 3,991.2 Wt/Len (l… 29.70 Grade L-80 Top Thread Hyd 563 Casing Description LINER OD (in) 4 1/2 ID (in) 4.00 Top (ftKB) 8,227.6 Set Depth (ftKB) 12,790.1 Set Depth (TVD) … 4,020.4 Wt/Len (l… 11.60 Grade L-80 Top Thread IBT-m Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 8,227.6 3,962.6 78.67 PACKER Baker HRD-E ZXP 5.5" x 7.63" Flex-Lock Liner top packer L-80 Hyd 563 pin 5.750 8,247.5 3,966.4 79.55 NIPPLE Baker 5.5" "RS" Packoff Seal Nipple 17# L-80 Hyd 563 box x box 4.890 8,250.4 3,966.9 79.67 HANGER Baker 5.5" x 7.63" Flex-Lock Liner hanger 17# L-80 Hyd 563 pin x pin 4.810 8,260.2 3,968.6 80.07 Seal Bore Extension Baker 190-47,4.75" ID Seal Bore Extension, 5 1/2" Hyd 563 box x pin 4.750 8,279.9 3,971.9 80.89 XO Reducing 5.5" Hyd 563 15.5 # box x 4.5" 12.6# IBT- pin Crossover 3.950 8,713.5 3,991.0 90.51 Swell Packer Baker 6-3/8" OD Swell Packer #3 "F" SN: 049169- 001-12 3.970 10,967.6 4,013.2 88.23 Swell Packer Baker 6-3/8" OD Swell Packer #2 "E" SN: 049169- 001-20 3.970 11,282.2 4,031.4 85.88 Swell Packer Baker 6-3/8" OD Swell Packer #1 "D" SN: 049169- 001-7 3.970 12,768.3 4,020.1 89.23 stand 4" DP = stand 4" DP 0.000 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 32.7 Set Depth (ft… 7,289.0 Set Depth (TVD) (… 3,714.0 Wt (lb/ft) 12.60 Grade L-80 Top Connection TXP-m Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 32.7 32.7 0.00 HANGER Vetco Grey MB222A offset hanger w/ false bowl 7,126.8 3,668.2 73.75 SLIDING SLV Camco 4-1/2" Sliding Sleeve, TXP-m, 3.812 CMU 3.812 7,193.2 3,687.0 73.31 GAUGE Camco 4-1/2" Solid gauge Mandrel, NDPG, single gauge, TXP-m 3.879 7,259.9 3,706.0 73.79 LOCATOR Baker 192-47 locator seal assembly(OD 5.19") Larger OD above located 7,260.3 3,706.1 73.80 SEAL ASSY Baker 192-47 locator seal assembly w/mule shoe---below located 3.860 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,127.0 3,668.2 73.75 Cat Standing Valve Set 3.81" DB Cat standing valve. (oal 27" 3.13" G F/N) 5/29/2020 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,745.4 10,977.5 3,990.7 4,013.5 WS A2, 1H-102 9/8/2017 32.0 SLOTS 4 x rows per foot w/ 8 slots per row - each slot is 3" long x 1/8" wide 11,314.1 12,746.4 4,033.6 4,019.9 WS A2, 1H-102 9/8/2017 32.0 SLOTS 4 x rows per foot w/ 8 slots per row - each slot is 3" long x 1/8" wide Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,668.5 2,290.3 Camco KBMG 1 GAS LIFT GLV BK 0.156 1,480.0 5/30/2020 2 5,515.1 3,200.7 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,546.0 6/2/2020 3 7,057.4 3,648.6 Camco KBMG 1 GAS LIFT OV BK 0.438 0.0 5/30/2020 Notes: General & Safety End Date Annotation NOTE: 1H-102, 6/4/2020 8:22:38 AM Vertical schematic (actual) LINER; 8,227.6-12,790.1 SLOTS; 11,314.1-12,746.4 SLOTS; 8,745.4-10,977.5 Intermediate; 37.4-8,591.1 L1 - Lower Completion; 7,973.4- 13,097.3 Triple connect bushing; 7,973.4 Triple connect bushing; 7,970.1 Crossover (XO) Bushing; 7,952.2 SBE (Seal Bore Extension); 7,932.4 Packer; 7,912.5 L2 - Lower Completion; 7,840.0- 13,204.2 L3 - Lower Completion; 7,644.6- 14,667.7 Triple connect bushing; 7,644.6 Triple connect bushing; 7,641.4 Crossover (XO) Bushing; 7,500.1 SBE (Seal Bore Extension); 7,480.3 Packer; 7,460.4 Triple connect bushing; 7,374.2 Triple connect bushing; 7,370.9 Crossover (XO) Bushing; 7,291.9 SBE (Seal Bore Extension); 7,272.2 SEAL ASSY; 7,260.3 PACKER; 7,252.2 LOCATOR; 7,259.9 GAUGE; 7,193.2 SLIDING SLV; 7,126.8 Cat Standing Valve; 7,127.0 GAS LIFT; 7,057.4 GAS LIFT; 5,515.1 GAS LIFT; 2,668.5 Surface; 40.2-1,771.0 Conductor; 40.2-118.6 HANGER; 32.7 KUP PROD KB-Grd (ft) 38.62 Rig Release Date 10/20/2017 1H-102 ... TD Act Btm (ftKB) 12,960.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292358000 Wellbore Status PROD Max Angle & MD Incl (°) 92.45 MD (ftKB) 11,741.17 WELLNAME WELLBORE1H-102 Annotation LAST WO: End DateH2S (ppm) 20 Date 11/20/2017 Comment SSSV: NONE ISSUED AS:PRELIMINARYDATE:ISSUED BY:AS BUILTFOR:APPROVALMARK-UPQUOTEREVIEW07-JUN-21PKMXX17'-314"[5261]3'-912"[1156]4'-734"[1418]2'-0"[610]2'-934"[859]2'-0"[610]2'-0"[610]BY NABORSBY OPERATORPIPE RAMCL WELLCHOKE LINE7BILL OF MATERIALS413121NOQTY DESCRIPTIONBOP, RAM 1358" 5M CAMERON "U" (DOUBLE)1DRILL SPOOL 1358" 5M w/ (2) 318" 5M OUTLETS.BOP, RAM 1358" 5M CAMERON "U" (SINGLE)36GATE VALVE, MANUAL 318" 5MGATE VALVE, HYDRAULIC 318" 5M22BOP, ANNULAR 1358" 5M CAMERON T-9012434455556724" HEIGHT.678KILL LINE5API TARGET BLIND FLANGE 318" 5M48DSA 318"5M x 2116" 5M1FF-TICKET #:THIS DRAWING IS SHOWN TRUE SCALE ONLY WHEN PRINTED ON THIS SIZE PAPERTHIS DOCUMENT AND THE INFORMATION CONTAINED HEREIN IS A CONFIDENTIAL DISCLOSURE. IT IS SHOWN TO YOUR COMPANY WITH THE UNDERSTANDING IT IS NOT TO BEREVEALED TO OTHERS OR USED FOR ANY PURPOSE WITHOUT THE WRITTEN CONSENT OF NABORS INDUSTRIES.REV.XREFDESCRIPTION APP.DATEBYTITLE COPYRIGHTED©DATE:DRN BY:ER:BDWG:APP:RIG:SCALE:NABORSSHT NO. OFNABORS RIG 7ES13 5/8" 5M BOP STACK LAYOUT14002 7ESPKM NTS27-MAY-21 SMB7ES-0008-01B REVISED AND ISSUED FOR INFORMATION 07-JUN-21 PKM3470945 01 01DRILLER SIDEOFF DRILLER SIDE ConocoPho ips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 6, 2019 Commissioner Hollis French Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Hollis French: c� / 7— O '�7 MAY 0 8 2019 lyOGCC 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 Winter ConocoPhillips Well Integrity Field Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) Kuparuk Field Date 6/6/2019 1J & 1H Well Name API # PTD # Initial top of cement Vol. of cement purr ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al U-180 50029233290000 2061500 20'9" 2.80 115" 5/4/2019 5 5/5/2019 1H-101 50029235850000 2171380 2'10" 0.70 9" 5/4/2019 2.2 5/5/2019 11-1-102 50029235800000 2170970 2'9" 0.65 8" 5/4/2019 1.7 5/5/2019 1H-103 1 50029235930000 2180030 2'2.5" 0.45 9" 5/4/2019 2.2 5/5/2019 50029236100000 2180840 2'.5" 0.40 9" 5/4/2019 2.2 5/5/2019 50029236080200 2180820 3'8" 0.80 10" 5/4/2019 2.5 5/5/2019 50029235950000 2180130 2'3" 0.40 9" 5/4/2019 2.2 5/5/2019 P1JH-1 50029236010000 2180310 2'6.5" 0.65 85" 5/4/2019 2 5/5/2019 50029235810000 2171330 2' 035 9" 5/4/2019 2.2 5/5/2019 50029235880000 2171680 2'1" 0.40 8" 5/4/2019 1.7 5/5/2019 50029235840000 2171360 1'11" 0.25 7.5" 5/4/2019 1.8 5/5/2019 1H-115 50029236050000 2180530 2'2.5" 0.35 8.5" 5/4/2019 2 5/5/2019 1H-116 50029235940000 2180120 17" 0.25 7" 5/4/2019 1.7 5/5/2019 1H-117 50029236020000 2180320 1'11" 0.35 7" 5/4/2019 1.7 5/5/2019 11-1-118 50029235780000 2170840 2'4" 0.50 8.5" 5/4/2019 2 5/5/2019 11-1-119 50029235910000 2171780 3' 0.80 8" 5/4/2019 1.8 5/5/2019 DATA SUBMITTAL COMPLIANCE REPORT 1/22/2018 Permit to Drill 2170970 Well Name/No. KUPARUK RIV UNIT 111-102 MD 12960 TVD 4022 Completion Date 10/20/2017 REQUIRED INFORMATION Mud Log No✓ Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23580-00-00 Completion Status 1-0I1 Current Status 1 -OIL UIC No Samples No t/ Directional Survey Yes/ DATA INFORMATION List of Logs Obtained: GR/Res (from Master Well Data/Logs) Well Log Information: Logi Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 28575 Digital Data -35 7471 9/7/2017 _ Electronic Data Set, Filename: CPAI_1H- 102_USIT_03Sep17_ConCu_R03_L007Up.las- ED C 28575 Digital Data 9/7/2017 Electronic File: CPAI_11-1- 102_U S IT_03S ep 17_ConCu_R03_L007 Up.dlis ED C 28575 Digital Data 9/7/2017 Electronic File: CPAI_1H- o 1 102 USIT_03Sep17_Fieldprint.Pdf Log C 28575 Log Header Scans 0 0 2170970 KUPARUK RIV UNIT 1H-102 LOG HEADERS ED C 28722 Digital Data 6958 7938 10/20/2017 Electronic Data Set, Filename: CPAI_1H- 118_W FL_16Oct17_Depth_Confirmation_Log_5_ Up.las ED C 28722 Digital Data 43025 43025 10/20/2017 Electronic Data Set, Filename: CPAI_1H- 118_W FL_ 160ct17_Station_1460BW PD_7512ft_ Slow_Log_1g.las ED C 28722 Digital Data 43025 43025 10/20/2017 Electronic Data Set, Filename: CPAI_1H- 118_WFL 160ct17_Station_1460BWPD_7525ft_ Siow_Log_18.las ED C 28722 Digital Data 43025 43025 10/20/2017 Electronic Data Set, Filename: CPAI 1H- 118_WFL_ 16Oct17_Station_14608WPD_7535ft_ - Slow_Log_17.1as ED C 28722 Digital Data 43025 43025 10/20/2017 Electronic Data Set, Filename: CPAI_1H- 118_W FL_16Oct17_Station_1460B W PD_7592ft_- Normal_Log_16.1as ED C 28722 Digital Data 43025 43025 10/20/2017 Electronic Data Set, Filename: CPAI_1H- 118_WFL_16Oct17_Station_1460BWPD_7592ft_ - Slow_Log_15.las AOGCC Page 1 of 6 Monday, January 22, 2018 DATA SUBMITTAL COMPLIANCE REPORT 1/22/2018 Permit to Drill 2170970 Well Name/No. KUPARUK RIV UNIT 11-1-1102 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23580-00-00 MD 12960 TVD 4022 Completion Date 10/20/2017 Completion Status 1-0IL Current Status 1-0I1- UIC No ED C 28722 Digital Data 43025 43025 10/20/2017 Electronic Data Set, Filename: CPAI 1H - 118_W FL_ 160ct17_Station_77OB W PD_7196ft_ Slow_Log_14,1as ED C 28722 Digital Data 43025 43025 10/20/2017 Electronic Data Set, Filename: CPAI_1H- 118 WFL 160ct17_Station_770BWPD_7375ft_ Slow_Log_13.las ED C 28722 Digital Data 43025 43025 10/20/2017 Electronic Data Set, Filename: CPAI - _1H 118_W FL_160ct17_Station_770B W PD_7403ft_ Slow_Log_12.1as ED C 28722 Digital Data 43025 43025 10/20/2017 Electronic Data Set, Filename: CPAI_1H- 118_WFL 160ct17_Station_77OBWPD_7418ft_ Slow_Log_11.1as ED C 28722 Digital Data 43025 43025 10/20/2017 Electronic Data Set, Filename: CPAI_1H- 118 WFL_160ct17_Station_770BWPD_7512ft_ Slow_Log_10.las ED C 28722 Digital Data 43025 43025 10/20/2017 Electronic Data Set, Filename: CPAI 1H- 118_WFL 160ct17_Station_77OBWPD_7525ft_ Slow_Log_9.las ED C 28722 Digital Data 43025 43025 10/20/2017 Electronic Data Set, Filename: CPAI_1H- 118_W FL_160ct17_Station_770B W PD_7535ft_ Slow_Log_8.las ED C 28722 Digital Data 43024 43025 10/20/2017 Electronic Data Set, Filename: CPAI - _1H 118_W FL_ 160ct17_Station_7706 W PD_7592ft_ Slow_Log_7.las ED C 28722 Digital Data 43024 43024 10/20/2017 Electronic Data Set, Filename: CPAI_1H- 118_WFL 160ct17_Station_770BWPD_7650ft_ Slow_Log_Was ED C 28722 Digital Data 43024 43024 10/20/2017 Electronic Data Set, Filename: CPAI_1H- 118_WFL 160ct17_Station_77OBWPD_7900ft_ ast_Log_4.las ED C 28722 Digital Data 43024 43024 10/20/2017 Electronic Data Set, Filename: CPAI 1H - 118_W FL_16Oct17_Station_770BW PD_7900ft_ Normal_Log_3.las ED C 28722 Digital Data 43024 43024 10/20/2017 Electronic Data Set, Filename: CPAI1H- 118_W FL_ 160ct17_Station_77OB W_PD_7900ft Slow_Log_5.las ED C 28722 Digital Data 10/20/2017 Electronic File: CPAI_1H- 118_W FL_160ct17_Depth_Confirmation_ConC _RO1 _LO05Up_RST_PSTP.dlis AO(;( C Page 2 of 6 Monday, January 22, 2018 DATA SUBMITTAL COMPLIANCE REPORT 1/22/2018 Permitto Drill 2170970 Well Name/No. KUPARUK RIV UNIT 1H-102 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23580-00-00 MD 12960 TVD 4022 Completion Date 10/20/2017 Completion Status 1-0IL Current Status 1 -OIL UIC No ED C 28722 Digital Data 1 012 0/2 01 7 Electronic File: CPAI_1H- 118_WFL_l60ctl7_Station_146OBWPD 7512ft Slow_ConCu_R01 _Sta019_RST_PSTP.dlis ED C 28722 Digital Data 10/20/2017 Electronic File: CPAI_1H- 118_WFL_ 160ctl7_Station_1460BWPD 7525ft_ Slow_ConCu_R01 ED C 28722 Digital Data 10/20/2017 _Sta018_RST_PSTP.dlis Electronic File: CPAI_1H- 118_W FL_160ctl7_Station_1460BW PD_7535ft_ Slow_ConCu_R01 ED C 28722 Digital Data 10/20/2017 _Sta017_RST_PSTP.dlis Electronic File: CPAI_1H- 118_WFL_160ctl7_Station_1460BWPD 7592ft_ Normal_ConCu_R01 ED C 28722 Digital Data 10/20/2017 _Sta016_RST_PSTP.dlis Electronic File: CPAI_1H- 118_WFL l60ctl7_Station_146OBWPD 7592ft_ Slow_ConCu_R01 ED C 28722 Digital Data 10/20/2017 _Sta015_RST_PSTP.dlis Electronic File: CPAI_1H- 118_W FL_160ctl7_Station_77OBW PD_7196ft Slow_ConCu_R01 dlis _ ED C 28722 Digital Data 10/20/2017 _Sta014_RST_PSTP. Electronic File: CPAI_1H- 118_WFL_l6Octl7_Station_770BWPD 7375ft Slow_ConCu_R01_Sta013_RST ED C 28722 Digital Data 10/20/2017 _PSTP.dlis Electronic File: CPAI_1H- 118_WFL_160ctl7_Station_770BWPD 7403ft Slow_ConCu_R0 t_Sta012_RST_PSTP. dlis ED C 28722 Digital Data 10/20/2017 Electronic File: CPAI_1H- 118_WFL_l60ctl7_Station 77OBWPD 7418ft Slow_ConCu_R01_Sta011 ED C 28722 Digital Data 10/20/2017 _RST_PSTP.dlis Electronic File: CPAI_iH- 118_WFL_16Oct17_Station_770BWPD 7512ft_ Slow_ConCu_R01_Sta010_RST_PSTP.dlis ED C 28722 Digital Data 10/20/2017 Electronic File: CPAI_1H- 118_WFL_160ctl7_Station_770BWPD 7525ft_ Slow_ConCu_R01 _Sta009_RST_PSTP.dlis ED C 28722 Digital Data 10/20/2017 Electronic File: CPA[ 1H - 118_W FL_16Oct17_Station_7706 W PD_7535ft_ Slow _ConCu_R01_Sta008_RST_PSTP.dlis ED C 28722 Digital Data 10/20/2017 Electronic File: CPAI 1H - 118_W FL_ 16Oct17_Stal ion_770B W PD_7592ft Slow_ConCu_R01 _Sta007_RST_PSTP.dlis AOGCC Page 3 of 6 Monday, January 22, 2018 DATA SUBMITTAL COMPLIANCE REPORT 1/22/2018 Permit to Drill 2170970 Well Name/No. KUPARUK RIV UNIT 11-1-102 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029.23580.00-00 MD 12960 TVD 4022 Completion Date 10/20/2017 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 28722 Digital Data 10/20/2017 Electronic File: CPAI _1H- 118_WFL_160ct17_Station 77OBWPD 7650ft Slow_ConCu_R01_Sta006_RST_PSTP.dlis ED C 28722 Digital Data 10/20/2017 Electronic File: CPAI _1H- 118 WFL_160007_Station 770BWPD 7900ft F eat _ConCu_R01_Sta004_RST_PSTP. dl is ED C 28722 Digital Data 10/20/2017 Electronic File: CPAI_1H- 118_W FL_160ct17_Station_770B W PD_7900ft_ . Normal _ConCu_R01 _Sta003_RST_PSTP.d I is ED C 28722 Digital Data 10/20/2017 Electronic File: CPAI _1H- 118_WFL_i60ct17_Station_770BWPD 7900ft S low_ConCu_R01 _Sta005_RST_PSTP.dI is ED C 28722 Digital Data 10/20/2017 Electronic File: CPAI n _1H- 118_WFL 160ct17 FieIdPrint.Pdf - Log C 28722 Log Header Scans 0 0 2170970 KUPARUK RIV UNIT 11-1-102 LOG HEADERS ED C 28748 Digital Data 32 1776 10/26/2017 Electronic Data Set, Filename: CPAI 11-1-102 Scope Resistivity_RM_LW0001.1as ED C 28748 Digital Data 1740 8598 10/26/2017 Electronic Data Set, Filename: CPAI 1H-102 Scope Resistivity_RM_LW D002.las ED C 28748 Digital Data 8551 12960 10/26/2017 Electronic Data Set, Filename: CPAI 11-1-102 Scope Resistivity_RM_LW D003.las ED C 28748 Digital Data 32 12960 10/26/2017 Electronic Data Set, Filename! CPAI 11-1-102 Scope Resistivity RM.las ED C 28748 Digital Data 32 12960 10/26/2017 Electronic Data Set, Filename: CPAI 1H-102 Scope Resistivity Customer Channel LAS.Ias ED C 28748 Digital Data 10/26/2017 Electronic File: CPAI 1H-102 Scope Resistivity RM LWD001 DLIS.dlis ED C 28748 Digital Data 10/26/2017 Electronic File: CPAI 1 H-102 Scope Resistivity - RM LW D001 DLIS.html ED C 28748 Digital Data 10/26/2017 Electronic File: CPAI 1H-102 Scope Resistivity RM LWD002 DLIS.dlis ED C 28748 Digital Data 10/26/2017 Electronic File: CPAI 1H-102 Scope Resistivity RM LWD002 DLIS.html ED C 28748 Digital Data 10/26/2017 Electronic File: CPAI 1H-102 Scope Resistivity , RM LWD003 DLIS.dlis AOGCC Page 4 of Monday. January 22, 2018 DATA SUBMITTAL COMPLIANCE REPORT 1/22/2018 Permit to Drill 2170970 Well Name/No. KUPARUK RIV UNIT 1H-102 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50.029-23580-00-00 MD 12960 TVD 4022 Completion Date 10/20/2017 Completion Status 1-0I1. Current Status 1 -OIL UIC No ED C 28748 Digital Data 10/26/2017 Electronic File: CPAI 1H-102 Scope Resistivity, RM LWD003 DLIS.html ED C 28748 Digital Data 10/26/2017 Electronic File: CPAI 1H-102 Scope Resistivity. RMDLIS.dlis ED C 28748 Digital Data 10/26/2017 Electronic File: CPAI 1H-102 Scope Resistivity ' RM DLIS.html ED C 28748 Digital Data /210/26/2017 Electronic File: CPAI 1H - Y 102_Scope_Resistivity_RM_2MD.pdf , ED C 28748 Digital Data 10/26/2017 Electronic File: CPAI 1H- 110/26/2017 102_Scope_Resistivity_RM_2TVD.pdf ' ED ED C 28748 Digital Data Electronic File: CPAI - P _1H 102_ Scope_Resistivity_RM_5MD.pdf ED C 28748 Digital Data 10/26/2017 Electronic File: CPAI 1H- -P 102_ Scope_Resistivity_RM_5TVD.pdf " ED C 28748 Digital Data 10/26/2017 Electronic File: 1H-102 NAD27 EOW Compass Survey.pdf ED C 28748 Digital Data 10/26/2017 Electronic File: 1H-102 NAD83 EOW Compass Survey.pdf ED C 28748 Digital Data 10/26/2017 Electronic File: 11-1-102 [Canvas] NAD27.txt' ED C 28748 Digital Data 10/26/2017 Electronic File: 1H-102 [Canvas] NAD83.txt ' ED C 28748 Digital Data 10/26/2017 Electronic File: 1 H-102 [Macro] NAD27.txt - ED C 28748 Digital Data 10/26/2017 Electronic File: 1 H-102 [Macro] NAD83.txt ED C 28748 Digital Data 10/26/2017 Electronic File: 11-1-102 [Petrel] NAD27.bd ED C 28748 Digital Data 10/26/2017 Electronic File: 1 H-102 [Petrel] NAD83.txt . ED C 28748 Digital Data 10/26/2017 Electronic File: 1H-102 [Surveys] NAD27.txt ' ED C 28748 Digital Data 10/26/2017 Electronic File: 1H-102 [Surveys] NAD83.txt ' ED C 28748 Digital Data 10/26/2017 Electronic File: CPAI 1H-102 Survey List.csv . Log C 28748 Log Header Scans 0 0 2170970 KUPARUK RIV UNIT 1H-102 LOG HEADERS Well Cores/Samples Information: Interval Sample NameSet Start Stop Sent Received Number Comments AOGCC Page 5 of Monday, January 22, 2018 DATA SUBMITTAL COMPLIANCE REPORT 1/22/2018 Permit to Drill 2170970 Well Name/No. KUPARUK RIV UNIT 1H-102 MD 12960 TVD 4022 INFORMATION RECEIVED Completion Report RYNA Production Test Information Geologic Markers/Tops ( COMPLIANCE HISTORY Completion Date: 10/20/2017 Release Date: 7/18/2017 Description Completion Date 10/20/2017 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23580-00-00 Completion Status 1-0I1 Current Status 1 -OIL UIC No Directional / Inclination Data OY Mud Logs, Image Files, Digital Data Y /lam' Core Chips Y NA Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files2 Core Photographs Y NA Daily Operations Summary 0Y Cuttings Samples Y &A Laboratory Analyses Y NA Date Comments Comments: Compliance Reviewed By: — -- Date: V AOGCC Page 6 of 6 Monday, January 22, 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION t'iCVG1 • w NOV 2 0 2017 FTATONTON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑� , Gas El SPLUG ❑ Other ❑ Abandoned ❑ SuspendedE]1b. 20AAC25L105 21mc25.111 GINJ❑ WINJ❑ WAG ❑ WDSPL❑ No. of Completions: Well Class: Development E Exploratory ❑ Service Stratigraphic Test❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 1012011-4 14. Permit to Drill Number/ Sundry: 217-097 ' 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: « 0""or 41204'^^4%Jz3Jl? 15. API Number: 50-029-23580-00-00 ' 4a. Location of Well (Governmental Section): Surface: 40.52' FNL, 764.65' FEL, Sec 33, T12N, R1 OE, UM Top of Productive Interval: 4730' FNL, 1647' FEL, Sec 27, T12N, R10E, UM Total Depth: 383' FNL, 1806' FEL, Sec 27, T12N, R10E, UM 8. Date TD Reached: 9/7/2017 16. Well Name and Number: KRU 1H-102 9. Ref Elevations: KB:92.6 GL: 54 � BF: 17. Field / Pool(s): Kuparuk River FieldNVest Bak Oil Pool 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 25639 - 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 549577.46 y- 5980662.56 Zone- 4 TPI: x- 553969 y- 5981281 Zone- 4 Total Depth: x- 553772 y- 5985629 Zone- 4 11. Total Depth MD/TVD: 12960/4022 19. DNR Approval Number: LO/NS 80-261 12. SSSV Depth MD1 VD: N/A 20. Thickness of Permafrost MD/TVD: 1699/1630 5. Directional or Inclination Survey: Yes ❑Z - (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 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 lags 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 23. CASING, LINER AND CEMENTING RECORD WT. PER CASING FT GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 78.67 B 40 119 40 119 42 Existing Cement to Surface 103/4 45.5 L-80 40 1771 40 1691 13.5 876 sx 11.0 ppg Lead Cement 211 sx 12.0 ppg Tail Cement 75/8 29.7 L-80 37 8593 37 3991 9.875 1155 sx 15.8 ppg, Class G 4112 11.6 L-80 8249 12790 3967 4020 6.75 Uncemented Slotted Liner 24. Open to production or injection? Yes 0 No ❑ If Yes, list each interval open (MDlf VD of Top and Bottom; Perforation Size and Number; Date Perfd): SLOTTED @: 8745 - 12746 MD and 3991 -4020 TVD COMPLETION DAJE o I-} VERIFIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/f VD) 41/2 7289 n/a 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑Q Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 11/4/2017 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 11/15/2017 Hours Tested: 13 hrs, 7 min Production for Test Period Oil -Bbl: 3058 bbls Gas -MCF: 1154 MSCF Water -Bbl: 11 bbl Choke Size: 62% Gas -Oil Ratio: 416 SCFISTB Flow Tubing Press. 334 PSI1 JCasinq Press: 1391 PSI Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: 2273 MSCT/d Water -Bbl 1 2.21 QTMIA20.7 I Oil Gravity- API (corr): API Form 10 e�s`�/5/22017 V-fL '112 f t &'�� T}NUED ON PAGE 2 RB®iMS L4 N10V 2 27017 Submit ORIGINIAL grtf 128. CORE DATA Conventional Corals): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No ❑� ormations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages 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 ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1699 1630 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 8593 3991 information, including reports, per 20 AAC 25.071. Formaflon @ TPI -West Salk A2 UGNU C 5083 3066 WEST SAK D 7367 3735 WEST SAX C 7563 3788 - WEST SAK B 7644 3810 WEST SAK A4 7785 3848 WEST SAK A3 7941 3889 WEST SAK A2 8272 3970 TO 12960 4022 Formation at total depth: West Sak A2 List or Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematics Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontoloaical report, productionor well 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: G. L. Alvord Contact Name: Kelsey Hallford Authorized Title— Alaska Drilling Mana erI� Contact Email: kelse .hallford co .00m Authorized /�- �, �_ n L—VV ar' Contact Phone: Signature: C� L Date: > 1, loia 265-1577 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item Is: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 41b: 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 10-407 Revised 512017 Submit ORIGINAL Only -�� LI "A3"Send Window @ 79)g MD/BOW )993'MD Ldcrd ally Module 0.1/2°Slolled Lincr, IL61IBTM L80;4H"BIaJ; pipe 1261 480 TXP A y�r__..___.___.................................... ..................... Tubing Sed AssanMY • N 3.562" DP Nipple Profile@@ 8244.36' h>D 3 LO ZXP pocket@8249.5' • 0.1/2"Slaved Lircr mW Blade Pipe, 11Wl 1BTM L80 -5/8", 2911, 480, HYd5e, Csg _ - ___--_ ••�•_•••__. •__ 6314" D sell lahnl 1467O MD/ 378V TVD Limr TD ®14652.5' MD ------------------ &NW'B sand lawml 14686 MD /38" TVD Liner TD@ 14668' MD 6314"A3 sandlawrd 1312CMD/3%8'TVD unm ImeM Wellhead/Tubing Head/Tree, CadnB. `Muck mC-I C2Muuor 13-3/e"x0.'h'l$,OBOkai 1H-102 Producer Schematic 0312" Tubin81 hing: 4-11",12.61, 480 TXP Final Ru WTD -As Localar Seal Asswnbly Q]25998'MD ,Bollwn of Mule Shin@@ 728908' MD Z g`6 $ Vs Gas Lift Mendml, 4 -IX x 1" w/dummy valve 2668.56' MD/2288' TVD Gas Lift Mandiel, 4-Ifi" x 1" w/dmnmy valve 5515.1' MD/ 319V T 10-314", 455q Gas Lift Mardiel, 4-1/2"xl"w/ SOV 115149' MD -T 480, Hyd%3—�� ❑11' MD/ 1691' TVD 13M7 D 0.W'SSD wilh 3,812" DB Ni pile profile )12686' MD Permanent Down Hole Gauge ]193.23' MD LO Z%P Pac4r®125213' MD Tubing SIM Asmmbly S s 3,75" DP Nipple Profile (a -J ]308.25'MD 4�L4"D"Sand Wirdow®]3]T MD/BOW; ]39060'MD ,_�„ S •. Swell Packers =s •, .......611BTM Le0,SIohML........"BJsnk ...............TXP v = _ O 4 4SLenkM Baker llnok Hangs ................. L3"B"Sand Willow@ 7W MD/BOW: ]660.1 Level J Junction Systems MD 1•" `. 4-IQ"Slollcd Lmeq I I a ]BTM L80, 4-W .................................._Blmlk 12.61 L-80 TXP . RP ........... ........................... , ZXPPackerDepW: a=e=__- .. .....................••____...__...._._...._..._...._.._..._. L2"AO"SeM WiMow ]MS'MD/BOW: 7859'MD •••__""•_•_"...__..6: U@7719.30'MD LI ®]912M'MD 75.5]°inc 1343 `•� _ 0.12'Sb Liner, 116q IBTM L80; 0.'/."BIvJ:Pi 1261480 TXP Lirei - ................. ......... R:.________ -�� LI "A3"Send Window @ 79)g MD/BOW )993'MD Ldcrd ally Module 0.1/2°Slolled Lincr, IL61IBTM L80;4H"BIaJ; pipe 1261 480 TXP A y�r__..___.___.................................... ..................... Tubing Sed AssanMY • N 3.562" DP Nipple Profile@@ 8244.36' h>D 3 LO ZXP pocket@8249.5' • 0.1/2"Slaved Lircr mW Blade Pipe, 11Wl 1BTM L80 -5/8", 2911, 480, HYd5e, Csg _ - ___--_ ••�•_•••__. •__ 6314" D sell lahnl 1467O MD/ 378V TVD Limr TD ®14652.5' MD ------------------ &NW'B sand lawml 14686 MD /38" TVD Liner TD@ 14668' MD 6314"A3 sandlawrd 1312CMD/3%8'TVD unm ImeM - Operations Summary (with Timelog Depths) r'Pti� 1 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Cade Activity Code Time P -T -X Operation (MB) Entl Depth (ftKa) 8/2212017 8/23/2017 6.00 MIRU MOVE MOB P Move ri f/ 1H-118 to 1H-102 ('417). 18:00 00:00 At 2300 spot over conductor. 8/23/2017 8/23/2017 0.75 MIRU MOVE MOB P Spot Pits 00:00 00:45 8/23/2017 8/23/2017 0.75 MIRU MOVE MOB P Spot pump Mod 00:45 01:30 8/23/2017 8/23/2017 0.50 MIRU MOVE MOB P Spot motor complex 01:30 02:00 8/23/2017 8/23/2017 0.50 MIRU MOVE MOB P Spot Rock washer 02:00 02:30 8/23/2017 8/23/2017 1.25 MIRU MOVE MOB P Spot pipe shed and drop landings. 02:30 03:45 8/23/2017 8/23/2017 5.25 MIRU MOVE RURD P Hook up all service connections and 03:45 09:00 comms. Continue with derrick board installation. 8/23/2017 8/23/2017 3.00 MIRU MOVE NUND P NU Annular/ Diverter, install pitchin 09:00 12:00 nipple,and riser, take on water to pits and build spud mud. Load 10 3/4" casing into pipe shed. Rig ACCEPTED at 0900. 8/23/2017 8/23/2017 6.00 MIRU MOVE NUND P Install mouse hole, NU surface ann / 12:00 18:00 Divert. & GE starting head. build spud mud, C/O saver sub. Install bushings / and elevators to rig floor. Swap to high line power at 1730 HRS. 8/23/2017 8/23/2017 0.75 MIRU MOVE BOPE P PU stand of 5" DP and perform 18:00 18:45 diverter test. Ann close time 26 sec. Knife valve opening time = 8 sec. 3000 PSI on koomy. 1,500 PSI on manifold, 1,950 after function with 7 sec to build 200 PSI, 44 sec full recovery. with two electric pumps and 2 air pumps. average 2,004 PSI on 6 N2 bottles. Jeff Jones waived witness of diverter test. 8/23/2017 8/23/2017 2.25 MIRU MOVE RURD P Send BHA componets to rig floor while 18:45 21:00 working smart tools in the pipe shed. Work and inspect 5" DP on sills outside. load 5" DP in shed. 8/23/2017 8/23/2017 2.00 MIRU MOVE BHAH P MU surface BHA. RIH with same to 105.0 21:00 23:00 tag at 105' 8/23/2017 8/2412017 1.00 MIRU MOVE SEOP P Make up top drive and surface test to 105.0 105.0 23:00 00:00 3,500 PSI for 15 min. Shallow hole test GPM 450 GPM @ 424 PSI, NO = 32%. 8/24/2017 8/24/2017 6.00 SURFAC DRILL DDRL P Drill 13 1/2" surface hole from 105' - 105.0 491.0 00:00 06:00 491' MD 491' TVD. 500 GPM, 800 PSI DPP. 44% F/O 40 RPM, 3K To with 20K WOB. UP WT = 74K. DWN WT = 79K. 5K To, off BTM pressure = 730 PSI. Maz gas units = 35. AST .66 , ART = 2. ADT = 2.66// Total bit hours = 13.3. Total jar hrs = 92.98 Page 1179 Report Printed: 10130/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start oelem Smit Time End Time Our (fir) Phase Op Code Activity Code Tene P -T -X Operation (@Ka) End Non (Me) 8/24/2017 8/24/2017 6.00 SURFAC DRILL DDRL P Drill 13 1/2" surface hole from 491- 491.0 1,008.0 06:00 12:00 1,008' MD 1,006' TVD. 500 GPM, 1,090 PSI DPP. 44% Flo 60 RPM, 5K TO with 27K WOB. UP WT = 93K. OWN WT = 94K. 1 K TQ, off BTM pressure = 875 PSI. Max gas units = 160. AST 1.43 , ART = 3.21. ADT = 4.6411 Total bit hours = 17.94. Total jar hrs = 97.62 8/24/2017 8/24/2017 6.00 SURFAC DRILL DDRL P Drill 131/2" surface hole from 1,008' 1,008.0 1,558.0 12:00 18:00 MD - 1,558' MD 1,506' TVD. 500 GPM, 1,121 PSI DPP. 44% F/O 60 RPM, 5K TQ with 28K WOB. UP WT = 100K. OWN WT = 99K. 1 K TO, off BTM pressure = 943 PSI. Max gas units = 8658. AST 2.21 , ART = 2.11. ADT = 4.32// Total bit hours = 22.26. Total jar hrs = 101.94 8/24/2017 8/24/2017 3.25 SURFAC DRILL DDRL P Drill 13112" surface hole froml,558' 1,558.0 1,777.0 18:00 21:15 MD - 1,777' MD 1,694' TVD. 500 GPM, 982 PSI DPP. 41% F/O 60 RPM, 4K TO with 15K WOB. UP WT = 105K. OWN WT = 100K. 2K TQ, off BTM pressure = 950 PSI. Max gas units= 827. AST 1.59 , ART= .44. ADT = 2.03// Total bit hours = 24.29. Total jar hrs = 103.97 8/24/2017 8/24/2017 0.75 SURFAC CASING CIRC P Rotate and circulate from 1,775' MD to 1,777.0 1,777.0 21:15 22:00 1,718' MD with 500 GPM, 960 PSI DPP. 40% F/O. 60 RPM, 2K Q UP WT= 105K. OWN WT= 100K. ROT = 103K 2K TQ total stks pumped 2,872. 8/24/2017 8/24/2017 0.50 SURFAC CASING OWFF P OWFF. Hydrates noted breaking out. 1,777.0 1,777.0 22:00 22:30 slowed down significantly. Continue to POOH as planned. 8/24/2017 8/25/2017 1.50 SURFAC CASING BKRM P BKRM OOH from 1,777'to 1,292' MD. 1,777.0 1,292.0 22:30 00:00 550 GPM @ 1,128 PSI DPP. RPM =- 60. 2K TQ. UP WT = 95K. DWN WT = 92K. ROT = 95K. 8/25/2017 8125/2017 2.25 SURFAC CASING BKRM P Continue to BKRM OOH from 1,292'- 1,292.0 398.0 00:00 02:15 398' MD. 500 GPM @ 730 PSI DPP. 33% F/O. 60 RPM, 2K TQ. 8/25/2017 8/25/2017 0.75 SURFAC CASING BKRM P BKRM with CBU from 398' to 305' MD 398.0 305.0 02:15 03:00 500 GPM @ 680 PSI DPP. 33% F10. 40 RPM, 1 K TQ, total strokes pumped = 2,200. BD top drive. monitor well for 10 min. static with slight gas breakout. UP WT=68K. OWN WT=71K. 8/25/2017 8/25/2017 2.00 SURFAC CASING BHAH P RS stand 1 and break / LD 305.0 0.0 03:00 05:00 Schlumberger directional tools as per DD. 8125/2017 8/25/2017 0.75 SURFAC CASING BHAH P Clean and Gear rig floor of all handling 0.0 0.0 05:00 05:45 equip etc. 8/25/2017 8/25/2017 2.00 SURFAC CASING RURD P RU all 10 3/4" handding equipment for 0.0 0.0 05:45 07:45 10 314" casing. slips / Volant / elevators and empty pipeshed of BHA, and load shoe track. 8/25/2017 8/25/2017 0.25 SURFAC CASING SFTY P Pre -job safety meet for running 10 3/4" 0.0 0.0 07:45 08:00 I HYD 563. Page 2179 ReportPrinted: 1 0/3 012 01 7 Operations Summary (with Timelog Depths) IH-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dw ihri Phew Cotle Adrvny Code Time P-T-X operation Start (rt Ka) End Depth (flx8) 8/25/2017 8/2512017 1.00 SURFAC CASING PUTB P RIH with 10 3/4" shoe track to 105' 0.0 105.0 08:00 09:00 MD. Baker lock shoe track and install cent / stop rings as per pipe detail. Check floats & pump through at 8 BPM = 24% F/O. 4 BPM = 17% F/O. 2 BPM =11%F/O. 8/25/2017 8/25/2017 5.25 SURFAC CASING PUTB P RIH from 106- 1,725' MD. monitor 105.0 1,725.0 09:00 14:15 disp via pits 3-6. Fill on the fly every 5 joints. TO all conn to 23K FT/LBS. install cent on all connections. 8/25/2017 8/25/2017 0.50 SURFAC CASING HOSO P MU rasing hanger and land joint. 1,725.0 1,771.0 14:15 14:45 Remove slips and wash down to landing ring with 4 BPM @ 215 PSI DPP. Set on hngr with 103K UP WT - 114K. A # 41 last joint with a centralizer, 43 centralizers and 4 stop rings were run. 8/25/2017 8/25/2017 0.50 SURFAC CEMENT SFTY P PJSM with all crews on cement 1,771.0 1,771.0 14:45 15:15 program. RU on cement hose B/D top drive. 8/25/2017 8/25/2017 7.00 SURFAC CEMENT CMNT P Stage pumps up to 8 BPM 290 PSI 1,771.0 1,771.0 15:15 22:15 DPP with 268 PSI FDPP. 23% F/O. While recip from 1,740-1770' MD. Pump maker sweep and observe back at 3,650 STKS. 12,000 Total silks pumped @ 8 BPM. UP WT = 117K DWN WT = 109K. Line up SLB pump 5 BBLS CWto PT lines & chart 3,500 PSI test. Pump remainder CW for total BBLS of 40 @ 3.1 BPM 75 PSI DPP. 15% F/O. Batch up and pump 77.4 BBLS 10.5 PPG Mud Push. @ 3.5 BPM 115 PSI DPP. 19% F/O. Drop BTM plug. Balch and pump 298 BBLS of 11# cement @ 5.6 BPM 180 PSI DPP, 21 % FIC. Batch and pump 61.9 BBLS 12# tail cement and pump at 4 BPM 164 PSI DPP with 19% F/O. Drop top jug and pump with 10 BBLS H2O, UP WT = 11 K-DWN WT = 95K. Chase cement with rig pumps utilizing 9.6# mud @ 5 BPM 330 PSI 31-55% F/O. from 1356 STKS reduce rate to 3 BPM 300 PSI FCP 56% F/O. Bump plug at 1,502 STKS at 2207. increase pressure to 1,082 PSI and hold for 5 min. Bleed off pressure and check floats. GOOD. Cement in place at 2207 hrs. Recip until last 30 bbls pumped. Circulated contaminated cement to surface 67.7 bbls prior to bumping the plug, circulated 9 bbls of good 11. ppg cement to surface. CIP 2207 his 8/25/2017. 8/25/2017 8/26/2017 1.75 SURFAC CEMENT RURD P RD cement equipment B/D cement 1,771.0 0.0 22:15 00:00 lines. B/0 landing joint and lay down. Clean pits and flow box. Drain stack, PU 5" test joint to wash stack. Page 3179 ReportPrinted: 10130/2017 Operations Summary (with Timelog Depths) 16 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Siert Time I End Time Our (hr) PhaseOp Cotle AcfivRy Code Tome P -T -X Operation Sten Depth (RKB) End Oepm (XKB) 8/26/2017 8/26/2017 1.50 SURFAC CEMENT WWWH P Clean dg floor of casing equipment. 0.0 0.0 00:00 01:30 Flush stack and set black water pill in place. Rinse out same. Suck out cellar and UD test jt. 8/26/2017 8/26/2017 4.00 SURFAC CEMENT NUND P NO surface annular, Tee / starting 0.0 0.0 01:30 05:30 head. Remove riser and flange. PUII back diverter line. Measured cement in conductor, 2' below starting head at the 4" drain outlets. 8/26/2017 8/26/2017 1.75 SURFAC WHDBOP NUND P Clean hanger neck, install Vetco grey 0.0 0.0 05:30 07:15 MB222 wellhead. Test seal sub to 2000 psi f/ 10 min (good). Test witnessed by Granville Rizek. 8/26/2017 8/26/2017 4.75 SURFAC WHDBOP NUND P NU hi pressure riser and BOPE stack. 0.0 0.0 07:15 12:00 Install choke and kill lines. Install riser/ flange install 1502 unionson tbg. IA/OA valves. Install test plug and MU dart / TIW valves, RU test pump. 8/26/2017 8/26/2017 1.25 SURFAC WHDBOP NUND P DNL valve IA & OA, Plug seocndary 0.0 0.0 12:00 13:15 IA, insstall safety slings on choke & kill, air up boots. 6/26/2017 8/26/2017 8.75 SURFAC WHDBOP BOPE P Flush and fill stack and choke. TEst 0.0 0.0 13:15 22:00 BOPE all test to 250 low/ 3,500 PSI high for 5 min each with exception of man operated and super chokes to 25/2000 TSI for 5 min. Tested with 4 1/2" - 5"- 7 5/8". Tested LPR's, 1-12S, and combustible gas alarms. Test witness waived by Chuck Scheve. Drawdown initial = 1,550 man, 3,000 ACC. 800 Ann. 1850 PSI after function of Ann, 3 rams. & 2 HCR's. 200 PSI build = 11 sec. Full press = 51 sec. 6 BTL average = 1,925 PSI. BD and RD test equipment. Pull test plug set wear bushing. 8/26/2017 8/27/2017 2.00 SURFAC CEMENT SLPC P Hang blocks cut 59' DL. Slip on 0.0 0.0 22:00 00:00 ssame. 8/27/2017 8/27/2017 1.00 SURFAC CEMENT SLPC P Unhang blocks and recalibrate 0.0 0.0 00:00 01:00 totco/amphion system for block height. 8/27/2017 8/27/2017 1.00 SURFAC CEMENT SVRG P Service topdnve. 0.0 01:00 02:00 8/27/2017 8/27/2017 2.50 SURFAC CEMENT BHAH P MU BHA #2. as per DD. RIH to 829' 0.0 829.0 02:00 04:30 MD. Monitor displacement via pill. 8/27/2017 8/27/2017 0.75 SURFAC CEMENT PULD P RIH to 1,583' MD. Monitor DISP via 829.0 1,583.0 04:30 05:15 pit 1. Change out joint number 20 and kick out as it is bent. 8127/2017 8/27/2017 0.50 SURFAC CEMENT DHEQ P Circulate at 500 GPM / 915 PSI DPP. 1,583.0 1,583.0 05:15 05:45 32% F/O. Shallow hole test MWD (GOOD) total stks pumped = 1,400. MW - in = 9.5, MW -out = 9.6.. UP WT =104K DWN WT=99K. ROT - 101k. 8/27/2017 8/27/2017 1.25 SURFAC CEMENT PRTS P RU test OA valve and casing to 3,DOD 1,583.0 1,583.0 05:45 07:00 PSI charted (GOOD) RD test equip. 26 slks t / pressure up. 2.7 BBLS bleed back. Page 4179 Repoli Printed: 1 013 01201 7 DOYON 142 07:00 07:30 Operations Summary (with Timelog Depths) IH -102 Tme Job: DRILLING nRIGtNer 400 GPM @ 600 PSI, 26% F/O. UP WT=106K. DWN WT=98K. ROT= 100K. with 380 GPM 555 PSI DPP. 25% F/O. 60-70 RPM 2-6K TO. 3-18K WOB. Continue to drill cement & shoe with 500 GPM 890 PSI DPP. 33% F/O. 3K WOB, 60 RPM. 2-5K TO. TOC @ 1,670' MD. TOP plugs @ 1,683.4 TOP FIC @ 1,683'. Top F/C@ 1,685.5' BTM F/C, 1,686.7'. Top shoe @ 1,768.84' BTM Shoe @ 1,770.12 MD. Drill rathole out to 1777- 09:45 10:00 - """' """` r Drill 20' of new hole from 1777' - 1,797' MD W/500 GPM w 500 GPM 910 PSI 33% F/O. 60 RPM. 4K TO. 3K WOB. ADT .26 total bit hours 017 8/27/2017 1.00 SURFAC CEMENT CIRC =.26 Total jar hours = 50.81 10:00 10:00 11:00 P Circulate bottoms up while rotating and recip from 1,796 - 1,713' MD with 500 GPM @ 900 PSI. 32% F/O 60 RPM 3.5K TQ.. Total STKS pumped = 5,824. 9.6 MW IN/OUT. 10 min gel 8/27/ 017 8/27/2017 1.00 SURFAC CEMENT FIT = 14. 11:00 12:00 P R/U fiootl lines for FIT/LOT to 12.5 PPG. 40 STKS pumped. 0 BBLS 8/27/20178/27/2017 1.00 SURFAC CEMENT WAIT bleed back. STBY for orders. 12:00 13:00 T Wait on orders from town for plan 8/27/2017 8/27/2017forwar 1.00 SURFAC CEMENT FIT tl. 13:00 14:00 T RU for FIT. Obtained LOT 12.6 PPGEMW w/ 9.6 ppg mud weight, 262 psi and 1691.1 TVD. 24 STKS were pumped (2.4 bbls) 0 BBLS 8/27/2017 8/27/2017 3.75 SURFAC CEMENT COND returned. RD. 14:00 17:45 T Begin making up LCM pill as per Program. Mix up number 2 FINE 10 PBL, #2 MED 20# PBL, Nut plug fine 5 PBL, Nut Plug Med 5# PBL. mix 50 BBLS to pump 35. perform rig 8/27/2017 8/27/2017 0.25 SURFAC CEMENT CIRC maintenance during mixing. 17:45 18:00 T Pump 35 BBLS of 40# LCM at max rate displacing with 34 bbls 9# LSND. 8/27/2017 18:00 8/27/2017 19:15 1.25 SURFAC CEMENT TRIP T Trip OOH from 1779'-1397' MD to begin squeeze LCM operations. 8/27/2017 8/28/2017 4.75 SURFAC CEMENT SQEZ Monitor disp via TT. 19:15 00:00 T Circulate 8 BBLS at 2 BPM to Pn�,re no LCM left in DP. RU are equipment with ANN closed to SQZ LCM @ .6 BPM. 264 PSI, Shut in and monitor/bleed off. Repeat 1 OX with gradual increasing pressure to 320 PSI. SQZ total of 4 BBLS into formation. Ending pressure of SQZ sessions = 1. 144 PSI 2. 206 PSI, 3. 278 PSI, 4. 286 PSI 5. 270 PSI, 6. 292 PSI, 7. 305 PSI, 8. 316 PSI, 9. 326 PSI, 10. 324 PSI. Operations Summary (with Timelog Depths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time ErMTune Ow(hr) Phaeaop Code Aciiviy Code Time P-T-X Operation Start Depth (mKB) Entl Depth (ftKB) 8/28/2017 8/28/2017 0.50 SURFAC CEMENT SQEZ T Perfom SQZ push #11 to 306 PSI. 1,397.0 1,397.0 00:00 00:30 hold for tem min. 8/28/2017 8/28/2017 0.50 SURFAC CEMENT SVRG P Service rig. 1,397.0 1,397.0 00:30 01:00 8/28/2017 8/28/2017 1.00 SURFAC CEMENT WASH T Wash down to 1,770' MD. @ 5 BPM 1,397.0 1,770.0 01:00 02:00 140 PSI, 18% F/O UP WT = 11 OK, DWN WT= 102K. 8/28/2017 8/28/2017 0.50 SURFAC CEMENT CIRC T Circulate bottoms up while rotating / 1,770.0 1,770.0 02:00 02:30 circulating from 1,276'- 1,680' MD. With 500 GPM, 545 PSI, 31 % F/O. 60 RPM, 31K TQ. 9.0 MW in/out. total STKS pumped = 2,260. UP WT = 110K. DWN WT = 106K. 8/28/2017 8/28/2017 1.00 SURFAC CEMENT LOT T Perform last FIT to 12.6 PPG EMW 1,770.0 1,770.0 02:30 03:30 and call town. 10 stks to 320 PSI. 10 min bleed off 320 - 245 PSI. 12.6 PPG pic. Discussed pressures, LCM squeezed away and timing. 8/28/2017 8/28/2017 2.50 INTRMt DRILL DDRL P Make connection and downlink to 1,770.0 1,961.0 03:30 06:00 EXCEED. Dtill 9 7/8" hole from 1,770' - 1,961" MD 1,847" TVD. 550 GPM 665 PSI DPP. 35% F/O, 60 RPM 3.61K TO, 1K WOB. ECD's 9.8 PPG. Off bottom 665 PSI DPP. UP WT = 11 OK DWN WT = 102K. ROT = 106K. 21K TO. ADT- 1.67, Bit his 1.93, Jar hrs 52.48. 8/2812017 8/28/2017 6.00 INTRMI DRILL DDRL P Dtill 9 7/8" hole from 1,961" MD - 1,961.0 2,594.0 06:00 12:00 2,594' MD 2,253' TVD. 550 GPM 735 PSI DPP. 34% F/O, 120 RPM 4K TQ, 4.51K WOB. ECD's 9.86 PPG. Off bottom 730 PSI DPP. UP WT = 119K DWN WT = 105K. ROT= 112K. 3.5K TO. ADT- 4.6, Bit his 6.27, Jar hrs 56.82. MAx gas 220 units. SPR's 2,245' MD 2,050 TVD MW = 9.1 PPG @ 0900 his MP1) 30 SPM 120 PSI 40 SPM 140 PSI MP2) 30 SPM 120 PSI 40 SPM 140 PSI 8/28/2017 8/28/2017 6.00 INTRM1 DRILL DDRL P Dill 97/8" hole from 2,594'MD- 2,594.0 3,193.0 12:00 18:00 3,193' MD 2,510' TVD. 595 GPM 890 PSI DPP. 34% F/O, 100 RPM 6- 9K TQ, 1 OK WOB. ECD's 9.86 PPG. Off bottom 885 PSI DPP. UP WT = 131KDWNWT=91K. ROT= 110K. 41K TO. Max gas 220 units. SPR's 2,813' MD 2,363 TVD MW = 9.0 PPG 1400 hrs MP1) 30 SPM 140 PSI 40 SPM 160 PSI MP2) 30 SPM 130 PSI 40 SPM 150 PSI Page 6/79 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sten Depth Siert Time End rm Dur (hr) Phase Op Code Acbvdy Code Time P -T -x Opembon (WO) End Depth ^13) 8/28/2017 8/29/2017 6.00 INTRMI DRILL DDRL P Dtill97/8" hole from 3,193' MD- 3,193.0 3,750.0 18:00 00:00 3,750' MD 2,672' TVD. 650 GPM @ 1135 PSI DPP. 35% F/O, 100 RPM 6- 9K TO, 8K WOB. ECD's 10.04 PPG. Off bottom 1135 PSI DPP. UP WT = 125K DWN WT=96K. ROT =11 OK. 6K TO. Max gas 96 units. ADT 8.92, Bit hrs 15.19, Jar hrs 65.74 SPR's 3,571' MD 2,620' TVD MW = 9.0 PPG @ 2200 hrs MPI) 30 SPM 160 PSI 40 SPM 180 PSI MP2) 30 SPM 150 PSI 40 SPM 180 PSI 8/29/2017 8/29/2017 6.00 INTRMI DRILL DDRL P Directionally drill 9-7/8" intermediate 3,750.0 4,424.0 00:00 06:00 hole from 3750' to 4424' MD, 2867' TVD. Pump at 700 gpm, 1430 psi on - trim, 1430 psi off-btm, 36% F/O, ECD 10.36 ppg. Rotate at 120 rpm with 5- 13k Tq on-btm, 7k off-btm. 9k WOB. PUW 132k, SOW 92k, ROT 111 it. Max gas of 122 units. ADT 4.93 hrs, Bit 20.12 hrs, Jars 70.67 hrs. Pump hi - vis sweep with 4 ppb Nut Plug Medium every 4 x stands. SPRs @ 4045' MD 2757' TVD, MW=9.0 ppg, 02:30 hours MP#1: 30 spm=160 psi, 40 spm=200 psi. MP #2: 30 spm=160 psi, 40 spm=200 psi. 8/29/2017 8/29/2017 6.00 INTRMI DRILL DDRL P Directionally drill 9-7/8" intermediate 4,424.0 5,010.0 06:00 12:00 hole from 4424' to 5010' MD, 3042' TVD. Pump at 675 gpm, 1410 psi on- btm, 1405 psi off -trim, 35% F/O, ECD 10.22 ppg. Rotate at 150 rpm with 10k Tq on-btm, 7.5k Tq off -trim. 11k WOB. PUW 139k, SOW 96k, ROT 113k. Max gas of 146 units. ADT 4.31 hrs, Bit 24.43 hrs, Jars 74.98 hrs. Continued seeing high stick slip, increased lubes by 0.5% Lo-Torq, total concentration in mud at 1.5% Lo-Torq. Pump hi -vis sweep with 4 ppb Nut Plug Medium every 4-5 stands. SPRs @ 4610' MD 2921' TVD, MW=9.05 ppg, 07:58 hours MP#1: 30 spm=180 psi, 40 spm=220 psi. MP #2: 30 spm=180 psi, 40 spm=220 psi. Page 7179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Toe EM Toe Dur (hr) Phase Op Code A ty C.de Toe P -T -x Operation Sl Dapth rftK8) EM Depth {ftK6) 8/29/2017 6129/2017 6.00 INTRM1 DRILL DDRL P Directionally drill 9-7/8" intermediate 5,010.0 5,384.0 12:00 18:00 hole from 5010'to 5384' MD, 3160' TVD. Pump at 603 gpm, 1200 psi on- btm, 1200 psi off-btm, 34% F/O, ECD 10.07 ppg. Rotate at 100 rpm with 9- 11 k Tq on-btm, 7.5k Tq off-btm. 6k WOB. PUW 139k, SOW 99k, ROT 117k. Max gas of 132 units. ADT 4.5 hrs, Bit 28.93 hrs, Jars 79.48 hrs. Pump hi -vis sweep with 4 ppb Nut Plug Medium every 5 x stands. SPRs @ 5084' MD 3065' TVD, MW=9.05 ppg, 12:40 hours MP#1: 30 spm=190 psi, 40 spm=230 psi. MP #2: 30 spm=190 psi, 40 spm=230 psi. 8/29/2017 8/30/2017 6.00 INTRMI DRILL DDRL P Directionally drill 9-7/8" intermediate 5,384.0 5,835.0 18:00 00:00 hole from 5384'to 5835' MD, 3297' TVD. Pump at 603 gpm, 1295 psi on- btm, 1295 psi off-btm, 35% F/O, ECD 10.24 ppg. Rotate at 130 rpm with 11- 13k Tq on-btm, 9k Tq off-btm. 11 k WOB. PUW 147k, SOW 95k, ROT 121k. Max gas of 327 units. ADT 4.42 hrs, Bit 33.35 hrs, Jars 83.9 hrs. Encountered hard spot at 5455' - 5460' MD. SPRs @ 5655' MD 3065' TVD, MW=9.05 ppg, 12:40 hours MP#1: 30 spm=190 psi, 40 spm=230 psi. MP #2: 30 spm=190 psi, 40 spm=230 psi. Total downhole losses for past 24 hours = 68 bbls. 8/30/2017 8/30/2017 6.00 INTRMI DRILL DDRL P Directionally drill 9-7/8" intermediate 5,835.0 6,339.0 00:00 06:00 hole from 5835' to 6339' MD, 3433' TVD. Pump at 600 gpm, 1335 psi on- btm, 1330 psi off-btm, 35% F/O, ECD 10.23 ppg. Rotate at 140 rpm with 11- 12k Tq on-btm, 9k Tq off-btm. 4k WOB. PUW 152k, SOW 98k, ROT 121 k. Max gas of 590 units. ADT 4.76 hrs, Bit 38.11 hrs, Jars 88.68 hrs. Pump 50 bbl hi -vis sweep at -6000' MD and observe -20% increase in cuttings, it Came back -600 strokes early. Drill through hard spots @ 5861' - 5867',6081- - 6087', and 6161'- 6164'. SPRs @ 6313' MD 3424' TVD, MW=9.10 ppg, 05:35 hours MP#1: 30 spm=220 psi, 40 spm=260 psi. MP #2: 30 spm=220 psi, 40 spm=260 psi. Page 8179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start TimEnd Time Dur(hn Phase Op Code Admry Cade Tune P-T-X Opeolon SiertO wth (MO)) End oepm (face) 8/30/2017 8/30/2017 6.00 INTRMI DRILL DDRL P Directionally drill 9-7/8" intermediate 6,339.0 6,837.0 06:00 12:00 hole from 6339' to 6837' MD, 3585' TVD. Pump at 550 gpm, 1150 psi on- btm, 1145 psi off-btm, 34% NO, ECD 10.16 ppg. Rotate at 120 rpm with 7- 16k Tq on-btm, 10k Tq off-btm. 3k WOB. PUW 167k, SOW 93k, ROT 126k. Max gas of 250 units. ADT 4.98 hrs, Bit 43.09 hrs, Jars 93.64 hrs. Increase lubes to 2.0% Lo-Torq to try and help with continued high stick-slip. Drill hard spot @ 6483'. Pump hi-vis sweep at 6600' and observe -10% increase in cuttings, it came back -800 strokes early. 8/30/2017 8/30/2017 6.00 INTRMI DRILL DDRL P Directionally drill 9-7/8" intermediate 6,837.0 7,176.0 12:00 18:00 hole from 6837'to 7176' MD, 3682' TVD. Pump at 510 gpm, 1055 psi on- btm, 1055 psi off-trim, 31% Flo, ECD 10.09 ppg. Rotate at 100 rpm with 10- 15k Tq on-btm, 9.5k Tq off-btm. 18k WOB. PUW 164k, SOW 99k, ROT 126k. Max gas of 737 units. ADT 3.73 hrs, Bit 46.82 hrs, Jars 97.37 hrs. Drill hard spots at 6929' - 6931', 7173'- 7176'. SPRs @ 6885' MD 3598' TVD, MW=9.10 ppg, 12:30 hours MP#1: 30 spm=230 psi, 40 spm=280 psi. MP #2: 30 spm=230 psi, 40 spm=280 PSL 8/30/2017 8/31/2017 6.00 INTRMI DRILL DDRL P Directionally drill 9-7/8" intermediate 7,176.0 7,421.0 18:00 00:00 hole from 7176' to 7421' MD, 3750' TVD. Pump at 697 gpm, 1800 psi on- btm, 1800 psi off-btm, 35% NO, ECD 10.19 ppg. Rotate at 120 rpm with 13k Tq on-btm, 9.5k Tq off-btm. IOk WOB. PUW 164k, SOW 99k, ROT 126k. Max gas of 161 units. ADT 5.26 hrs, Bit 52.08 hrs, Jars 102.63 hrs. Observe fault at 7211' MD with -50' down-to-south throw. Drill hard spots from 7176'- 7180' and 7404'- 7415'. Pump 50 bbis hi-vis sweep at 7260' and observe -10% increase in cuttings, it came back -900 strokes early. Downhole losses for past 24 hours = 21 bbis. Page 9179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stmt Time End Tme Div (N) Phase op code Activity Code Time P-T-X Qpe�ation SUrt OepN (ftDe End DepU (tIKB) 8/31/2017 8/31/2017 6.00 INTRMI DRILL DDRL P Directionally drill 9-7/8" intermediate 7,421.0 7,673.0 00:00 06:00 hole from 7421'- 7673' MD, 3817' TVD. Pump at 700 gpm, 1860 psi on- trim, 1855 psi off-btm, 35% F/O, ECD 10.39 ppg. Rotate at 110 rpm with 14k Tq on-blm, 11 k Tq off-btm. 10k WOB. PUW 164k, SOW 97k, ROT 128k. Max gas of 480 units. ADT 3.97 his. Bit 56.05 his. Jars 106.6 hrs. Drill through concretions at 7427' - 7436', 7467'- 7469', 7657'- 7561', and 7664'- 7673' MD. SPRs @ 7450' MD 3758' TVD, MW=9.10 ppg, 01:00 hours MP#1: 30 spm=230 psi, 40 spm=260 psi. MP #2: 30 spm=230 psi, 40 spm=260 psi. 8/31/2017 8/31/2017 6.00 INTRM1 DRILL DDRL P Directionally drill 9-7/8" intermediate 7,673.0 8,142.0 06:00 12:00 hole from 7673'- 8142' MD, 3943' TVD. Pump at 700 gpm, 1990 psi on- blm, 1985 psi off-btm, 35% F/O, ECD 10.62 ppg. Rotate at 150 rpm with 14k Tq on-btm, 11k Tq off-trim. 7k WOB. PUW 171 k, SOW 99k, ROT 129k. Max gas of 620 units. ADT 4.84 hrs, Bit 60.89 hrs, Jars 111.44 hrs. Drill through concretions at 7673' - 7677', 7771'- 7773', 7809'- 7813', and 7963'- 7967', 8/31/2017 8/31/2017 6.75 INTRMI DRILL DDRL P Directionally drill 9-7/8" intermediate 8,142.0 8,598.0 12:00 18:45 hole from 8142' to TD of 8598' MD, 3991' ND. Pump at 697 gpm, 2015 psi on-trim, 2010 psi off-blm, 36% F/O, ECD 10.65 ppg. Rotate at 130 rpm with 12-16k Tq on-blm, 12.4k Tq off-btm. 10k WOB. PUW 173k, SOW 92k, ROT 131 k. Max gas of 1048 units. ADT 4.43 hrs. Bit 65.32 hrs. Jars 115.87 hrs. Pump 70 bbl hi-vis sweep just prior to TO and observe it bring back -10% increase in cuttings, at surface -900 strokes early. Drill through concretion at 8342' - 8344' MD. SPRs @ 8211' MD 3961' TVD, MW=9.30 ppg, 12:55 hours MP#1: 30 spm=300 psi, 40 spm=360 psi. MP #2: 30 spm=300 psi, 40 spm=360 psi. Downhole losses for past 18:45 hrs = 39 bbls Total downhole losses while drilling interval = 128 bbls. Page 10179 Report Printed: 1013012017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start lime End Tima Dur thrl Phase Op GD& Aclrvity Code Time P -T -X O ration Pe SIeM1 Depth jn De Eritl Depth (MKB). 8/31/2017 8/31/2017 1.00 INTRMI CASING BKRM P Obtain final T&D paramters, SPR's, 8,598.0 8,500.0 18:45 19:45 and survey at TD, Downlink Xceed to neutral. PUW 1731k, SOW 92k, ROT 131k w/ 12.4k Tq. Backream out stand to 8500' MD with 697 gpm, 2030 psi, 35% F/O, 120 rpm, 11-16k Tq, ECD 10.62 ppg SPRs @ 8598' MD 3991' TVD, MW=9.25 ppg, 19:05 hours MP#1: 30 spm=310 psi, 40 spm=360 psi. MP #2: 30 spm=310 psi, 40 spm=360 psi. 8/31/2017 8/31/2017 0.50 INTRMI CASING OWFF P Monitor well for flow for 30 minutes- 8,500.0 8,500.0 19:45 20:15 observe fluid level drop -1 ft in riser over 30 minutes, calculated to -0.5 bbl/hr static loss rate. 8/31/2017 9/1/2017 3.75 INTRMI CASING BKRM P Backream OOH from 8500'to 7362' 8,500.0 7,362.0 20:15 00:00 MD with 697 gpm, 1905 psi, 35% F/O, ECD 10.45 ppg. Rotate at 120 rpm with 11-16k Tq, ROT 123k. Monitor displacement via pits #1-5. Lay down 5" DP via mousehole. Calculated displacement = 8.4 bbls. Actual displacement = 23 bbls. 9/1/2017 9/1/2017 6.00 INTRMI CASING BKRM P Backream OOH from 7362'- 4849' 7,362.0 4,849.0 00:00 06:00 MD with 700 gpm, ICP 1910 psi, FCP 1660 psi, 36% F/O, Initial ECD 10.45 ppg, Final ECD 10.48 ppg. Rotate at 120 rpm with 7k Tq. PUW 135k, SOW 92k. Monitor displacement via pits #1- 5. Increase pulling speed up to 1000 fl/hr. MW 9.3 ppg. SIMOPS: Floorhands lay out 5" DP stands using mousehole while backreaming out. At 1000 ft/hr pulling speed, floorhands finish laying out stand by the time driller reaches top of next stand. 9/1/2017 9/1/2017 6.00 INTRMI CASING BKRM P Backream OOH from 4849'-3010' 4,849.0 3,010.0 06:00 1200 MD with 698 gpm, ICP 1660 psi, FCP 1470 psi, 35% F/O, Initial ECD 10.48 ppg, Final ECD 10.30 ppg. Rotate at 120 rpm with 5k Tq. Pull at -700 ft/hr from 4849'to 3120'then drop pulling speed to 200 fl/hr as ECD increased, up to a 10.70 ppg highest seen @ -3240' MD. MW 9.3 ppg. SIMOPS: Floorhands lay out 5" DP stands using mousehole while backreaming out. Page 11179 Report Printed: 1 013 0/2 01 7 ® Operations Summary (with Timelog Depths) 1 H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Stan Time End Lune our (hr) Phase op Code Activity Code Tune P -T -X ope2 n (Id(B) End Depth (ffKB) 9/1/2017 9/1/2017 5.50 INTRM1 CASING BKRM P Backream OOH from 3010'- 1771' 3,010.0 1,771.0 12:00 17:30 MD with 697 gpm, ICP 1470 psi, FCP 1290 psi, 36% FIC, Initial ECD 10.30 ppg, Final ECD 9.96 ppg. Rotate at 120 rpm with 2.5k Tq. Pull at 200-500 It/hr with max ECD of 10.88 ppg seen at -2350' MD. MW 9.3 ppg. Observed ECD drop -0.3 ppg as we pulled the BHA into rasing. SIMOPS: Floorhands lay out 5" DP stands using mousehole while backreaming out. 9/1/2017 9/1/2017 0.25 INTRMI CASING OWFF P Monitor well for flow at the shoe - well 1,771.0 1,771.0 17:30 17:45 static. 9/1/2017 9/1/2017 1.25 INTRMI CASING BKRM P Backream OOH from 1771'- 1397' 1,771.0 1,397.0 17:45 19:00 MD with 697 gpm, 1215 psi, 34% F/O, ECD 9.83 ppg. Rotate at 100 rpm, 2k Tq. Observe hole unload at -1550' MD and then shakers cleaned up. SIMOPS: Floorhands lay out 5" DP stands using mousehole while backreaming out. 9/1/2017 9/1/2017 1.00 INTRMI CASING PULD P Pull OOH on elevators from 1397'- 1,397.0 829.0 19:00 20:00 829' MD, laying out 5" DP sideways and monitoring displacement via trip tank. 9/1/2017 9/1/2017 0.25 INTRMI CASING OWFF P Monitor well for flow at top of BHA- 829.0 829.0 20:00 20:15 well static. 9/1/2017 9/1/2017 2.50 INTRMI CASING BHAH P Pull OOH on elevators from 829'to 829.0 0.0 20:15 22:45 surface, laying out BHA #2 per DD. Observe large amount of wear on upper NM integral blade stabilizer with unusual wear pattern, significant wear on 8-3/8" sleeve stabilizer with only -2" of blades remaining and stabilizer loose from original position, and minimal wear on the two NM slabs on the Xceed. The bit had multiple broken teeth and chipped teeth but was in - gauge. 9-7/8" Smith MSi516 PDC Bit grade: 2 -3 -BT -A -X -0 -CT -TD Upper 9-3/4" NM Integral Blade Stabilizer: 1-5116" undergauge 8-3/8" NM Straight -blade sleeve stabilizer: minimal amount of stabilizer remaining Upper Xceed 9-3/4" NM Integral Blade Stabilizer: In -gauge Lower Xceed 9-3/4" NM Integeral Blade Stabilizer: 1/16" undergauge Calculated displacement for trip = 90.9 bbls Actual displacement for trip = 126.0 WE 9/1/2017 9/1/2017 0.50 INTRMI CASING BHAH P I Clean and clear floor of BHA 0.0 0.0 22:45 23:15 equipment. Page 12179 Report Printed: 1013012017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time Our (hr) phase Op Code AcW Code aY Time P-T-X O ration pa St(ftent wpm (nK a End Depth (ftKe) 9/1/2017 9/1/2017 0.50 INTRMI CASING WWWH P Make up 2 x 5" DP singles, XO, and 0.0 0.0 23:15 23:45 stack washer. Jet stack and wellhead with 819 gpm. 9/1/2017 9/2/2017 0.25 INTRMI CASING RURD P Lay out stack washer and make up 0.0 0.0 23:45 00:00 wearbushing retrieval tool. 9/2/2017 9/2/2017 0.50 INTRMI CASING RURD P Pull Vetco Grey wearbushing with 0.0 0.0 00:00 00:30 retrieval tool. Lay down both. 9/2/2017 9/2/2017 1.50 INTRMI CASING RURD P Rig up Volant casing running tool. Pick 0.0 0.0 00:30 02:00 up spiders and side door elevators. Install bail extensions. Stage 7-5/8" casing pups on the rig floor. Load lop row of casing in the shed (16 its). 9/2/2017 9/2/2017 4.50 INTRMI CASING PUTB P Make up it# l with the Weatherford 0.0 1,771.0 02:00 06:30 float shoe ((2) 7-5/8" x 9-3/8" OD centralizers & total of 4 stop rings. Centralizer 10' f/ each end). Jt # 2 centralzied the same as above, and jt 3 with the Davis Lynch double valve - float collar (no centralizers on jt #3). MU joint #4 (pin end of #4 and all below are baker locked).Check floats, OK. Continue to run 7-5/8" 29.7# L-80 Hydril 563 dopeless casing per tally to it # 41. PU wt 86k, SO wl 88k. Fill pipe on the fly and top off every 10 its. Install centralizers per tally. Install pups per tally. Make up with 14k Tq to make-up mark. NO CENTRALIZERS ON THE WINDOW JOINTS, OR JOINT ABOVE AND BELOW. 912/2017 9/2/2017 0.50 INTRMI CASING CIRC P Circulate at the 10-3/4" shoe. Stage 1,771.0 1,771.0 06:30 07:00 pumps up to 6 bpm w/ 110 psi. Circulate bottoms up @ 1771'. 9/2/2017 9/2/2017 3.75 INTRMI CASING PUTB P Contiinue to run in w/ 7-5/8" 29.7 ppf L 1,771.0 3,780.0 07:00 10:45 -80 Hyd 563 dopeless casing f/ 1771' to 3780' installing 7-5/8" x 9-3/8" Volant centralizers floating on its up to it 105. 90 joints in the hole at this depth. Average MU torque 14k ft lbs. Fill pipe on the fly and top off every 10 its. Install centralizers per tally.. 9/2/2017 9/2/2017 0.75 INTRMI CASING CIRC P Stage pumps up to 6 bpm w/ 200 psi. 3,780.0 3,780.0 10:45 11:30 Once at full rate, circulate bottoms up at 3780'. 9/2/2017 9/2/2017 0.50 INTRMI CASING PUTB P Contiinue to run in w/ 7-5/8" 29.7 ppf L 3,780.0 4,024.0 11:30 12:00 -80 Hyd 563 dopeless casing f/ 3780' to 4024' installing 7-5/8" x 9-3/8" Volant centralizers floating on its up to jt 105. 96 joints in the hole at this depth. Average MU torque 14k ft lbs. PU wt 120k, SO wt 96k. Fill pipe on the fly and top off every 10 its. Install centralizers per tally.. Calculated mud losses —17-19 bbls. Page 13/79 Report Printed: 10130/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log a oepm Start Sten Time End Time our(hr) Phase op Code Aa code M Time P-T-x Cpeaeon B) E� neem (ItK6) 9/212017 9/2/2017 2.75 INTRM1 CASING PUTB P Contiinue to run in w/ 7-5/8" 29.7 ppf L 4,024.0 5,429.0 12:00 14:45 -80 Hyd 563 dopeless casing f/ 4024' to 5429' installing 7-5/8" x 9-3/8" Volant centralizers floating on jts up to jt 105. 130 joints in the hole at this depth. Average MU torque 14k R lbs. Fill pipe on the fly and top off every 10 jts. Install centralizers per tally.. 9/2/2017 9/2/2017 1.25 INTRMI CASING CIRC P Circulate, reciprocate from 5429'to 5,429.0 5,480.0 14:45 16:00 5480', Stage pumps up to 9 bpm w/ 395 psi 27% flow out. After circulating PU wt 155k, SO wt took. 9/2/2017 9/2/2017 2.75 INTRMI CASING PUTB P Contiinue to run in w/ 7-5/8" 29.7 ppf L 5,480.0 6,873.0 16:00 18:45 -80 Hyd 563 dopeless casing f/ 5480' to 6873'. 165 joints in the hole at this depth. SOW = 75k Average MU torque 14k ft Itis. Fill pipe on the fly and top off every 10 jts. 9/2/2017 9/2/2017 0.25 INTRMI CASING RURD T Change out cup on volant tool. 6,873.0 6,873.0 18:45 19:00 9/2/2017 9/2/2017 1.25 INTRMI CASING CIRC P Circulate/ reciprocate from 6873'to 6,873.0 6,908.0 19:00 20:15 6908', Stage pumps up to 8 bpm w/ ICP 530 psi, FCP 440 psi, 24% F/O and circulate 1 x bottoms up. After circulating, observe 9.2ppg MW Vis 43 going in, 9.35 ppg MW Vis 59 coming out, PUW 178k, SOW 101 k. 9/2/2017 9/2/2017 3.50 INTRMI CASING PUTB P RIH w/7-5/8" 29.7# L-80 Hyd 563 6,908.0 8,550.0 20:15 23:45 dopepless casing per tally from 6908' to 8550' MD. MUT 14k Calculated displacement = 90.72 bbis Actual displacement = 63.50 bbls 9/2/2017 9/3/2017 0.25 INTRMI CASING HOSO P Make up Vetco 7-5/8" casing hanger 8,550.0 8,550.0 23:45 00:00 using single-stack tongs. Pick up and make up landing joint to hanger. 9/3/2017 9/3/2017 0.50 INTRMI CASING HOSO P Finish making up landing joint, run in 8,550.0 8,591.0 00:00 00:30 hole and land off hanger. 9/3/2017 9/3/2017 1.00 INTRMI CEMENT CIRC P Stage up to 342 gpm and circulate / 8,591.0 8,591.0 00:30 01:30 condition mud with reciprocation, 470 psi, 24% F/O, PUW 184k, SOW 82k. MW in 9.3ppg Vis 50, MW out 9.35ppg Vis 63. 9/3/2017 9/3/2017 1.50 INTRMI CEMENT CIRC P Rig up cement hose and continue 8,591.0 8,591.0 01:30 03:00 circulating / conditioning mud at 254 gpm, 480 psi. Hold PJSM for cement job and rig up cementers. Page 14179 Report Printed: 1013012017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time Fnd Tme our (hr) Plica® op cme Activity Code Time P -T -X Om,r n start D.Pm (flKB) EM Cepm(ftKB) 9/3/2017 9/3/2017 2.00 INTRMI CEMENT CMNT P Pump cement job as follows: SLB 8,591.0 8,591.0 0300 05:00 pump 5 bbls freshwater and pressure test lines to 400 / 3500 psi - good test. Pump 50 bbls 12.5ppg Mudpush at 3 bpm, ICP 450 psi, FCP 210 psi. Drop Davis Lynch anti -rotational bottom plug. Batch mix cement, cement wet at 03:46 hrs. SLB pump total of 239.3 bbls 15.8ppg Class G cement. Pumped 170 bbls at 6 bpm, ICP 459 psi, FCP 315 psi. Then observe "H" pump fail so swap to "G" pump which has slightly lower rate capacity. Did not have to stop pumping but rate briefly dropped to -3 bpm. Continue pumping additional cement at -4.5 bpm, ICP 230 psi, FCP 190 psi. Drop Davis Lynch anti -rotational top plug. SLB pump 10 bbls freshwater at 4 bpm, 120 psi. Reciprocate pipe -15 ft, PUW 220k, SOW 95k. 9/3/2017 9/3/2017 1.25 INTRMI CEMENT CMNT P Swap to rig mud pump #1 and 8,591.0 8,591.0 05:00 06:15 displace cement with 9.3ppg LSND at 8 bpm for 3250 strokes, ICP 242 psi, FCP 1587 psi. Drop rate to 3 bpm and continue displacing cement, ICP 1120 psi. Bump plug at 3797 strokes, FCP 1423 psi. Pressure up to 2000 psi and hold for 5 minutes. Bleed off and check floats - floats holding. Cement in place @ 06:10 hrs. Calculated TOC @ 4250' MD. Note: Total downhole losses throughout cement job = 11 bbls 9/3/2017 9/3/2017 0.75 INTRMI CEMENT PRTS P Pressure up to 3500 psi and hold for 8,591.0 0.0 06:15 07:00 30 minutes to test 7-5/8" casing - good test. Pump 5.6 bbls, returned 5.6 bbls. 9/3/2017 9/3/2017 1.50 INTRMI CEMENT RURD P Rig down and blow down cement line 0.0 0.0 07:00 08:30 and test equipment. Lay down Volant tool and casing handling equipment. 9/3/2017 9/312017 1.50 INTRMI CEMENT W WSP P Make up packoff running tool and 0.0 0.0 08:30 10:00 install packoff. Run in lock down screws and lay down running assembly. Inject packoff with packing and pressure test to 5000 psi / 10 min, witnessed by CPAI - good test. SIMOPS: Start rigging in E -line. 9/3/2017 9/3/2017 2.00 INTRMI EVALWB ELDG P Rig up SLB E -line. Pick up Welltec 0.0 0.0 10:00 12:00 tractor and USIT logging tools and function test at surface. 9/3/2017 9/3/2017 2.50 INTRMI EVALWB ELOG P RIH on E -line from surface to 3000' 0.0 0.0 1200 14:30 MD and then utilize tractor to run in from 3000' to 7500', average of 57 ft/min with tractor. Page 15179 Report Printed: 10/3012017 Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sbrl 11me End Time Our (tin Phe% Op Cotle Activity Cotle Time P -T -X Operation stem (rt De End Depth (flKB) 9/3/2017 9/3/2017 8.00 INTRMI EVALWB ELOG P Pull up and get stretch out of string 0.0 0.0 14:30 22:30 and confirm tool working. Pull OOH on E -line, logging from top of D -sand at 7450' MD to surface at 15 R/min pulling speed for high-definition resolution. 9/3/2017 9/3/2017 0.75 INTRMI EVALWB ELOG P Rig down E -line equipment. 0.0 0.0 22:30 23:15 913/2017 9/4/2017 0.75 INTRMI CEMENT RURD P Change out saver sub to XT39. 0.0 0.0 23:15 00:00 9/4/2017 9/4/2017 1.00 INTRMI CEMENT RURD P Change out saver sub to XT39. 0.0 0.0 00:00 01:00 Change out die blocks and install bell guide. 9/4/2017 9/4/2017 1.50 TNTRM1 WHDBOP RURD P Rig up to test BOPE. Assemble floor 0.0 0.0 01:00 02:30 valves and install ported sub on top drive. Make up 4-1/2" test joint and test plug. Troubleshoot inability to suck out stack through IA. Page 16/79 Report Printed: 1 013 012 01 7 Operations Summary (with Timelog Depths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time Dur(fin Phase OpCotle Activity Cotle Time P -T -X Opennon Sart Depth (fiIQ3) Entl Depth (WS) 9/4/2017 9/4/2017 5.50 INTRMI WHDBOP BOPE P Test ROPE with 4" and 4-1/2" test joint 0.0 0.0 02:30 08:00 to 250/3500 psi 5/5 min, witness waived by AOGCC rep Bob Noble. Test Sequence as follows: 1) 4" XT39 Dart valve and Upper IBOP 2) 4" XT39 FOSV and Lower IBOP 3) Choke valves #12, 13, R 14 4) Choke valves # 9 and 11 5) Choke valves #8 and 10 6) Super and manual chokes Install 4-1/2" test joint 7) Annular, Floor Kill, Choke valves #1, 2, and 5 8) HCR choke and Mezzanine Kill 9) Lower 3-1/2" x 6" pipe rams Install 4" test joint 10) Annular, Manual choke, Manual Kill, and HCR 11) Lower 3-1/2" x 6" pipe rams Pull test joint 12) Blinds, Manual Kill, Choke valves #6 and 7 13) Choke valves #3 and 4. Perform koomey drawdown test: System Pressure = 3,000 psi PSI after closure = 1,900 psi 200 psi Attained with 2 x electric pumps = 8 seconds Full Pressure attained with 2 x electric and 2 x air pumps = 47 seconds N2 = 6 each @ 2,033 psi Tested all gas and H2S sensors, PVT and flow alarms both audio and visual, and functioned primary and remote BOP controls - all good. Upper 7-518" casing rams not tested, Note: Started testing surface equipment while finishing up troubleshooting difficulty draining stack through IA valve. Drain stack through the production wing port and observe muddy material around top of packoff. Close blind rams, hook up air to one side of IA and blow air through and out the other IA port and clear out packoff ports. Fill stack up with water and confirm no issues draining out through both IA ports. Move forward with installing test plug. 9/4/2017 9/4/2017 1.00 INRMI WHDBOP RURD P Blow down and rig down test 0.0 0.0 08:00 09:00 equipment. Pull test plug and install Vetco short wearbushing with 9" ID. Page 17179 Report Printed: 1 013 0/2 01 7 Operations Summary (with Timelog Depths) 0 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time Eno Time Our (hr) Phew Op CoCe Activity Code lime P -T-% operation Start Depth (WS) End Depth (RKB) 9/4/2017 9/4/2017 1.25 INTRMI CEMENT LOT P Rig up to perform OA leak off test prior 0.0 0.0 09:00 10:15 to freeze protecting. Using mud pump #1, pressure up OA to 740 psi at 7 spm with no indication of leak -off. Kill pump and shut in. Observe pressure drop to 282 psi after 10 minutes and 210 psi after 45 minutes. Discuss path forward with town. 9/4/2017 9/4/2017 1.25 INTRMI CEMENT BHAH P Make up 6-3/4" production "A2" drilling 0.0 118.0 10:15 11:30 BHA to 118' MD per DD, monitoring displacement via trip tank. SIMOPS: Pressure up on OA with mud pump #1 to 700 psi at 7 spm - . observe erratic pressure buildup. Swap to mud pump #2 and continue pressuring up to 960 psi at 7 spm with no indication of leak off. Kill pump and shut in. Observe pressure fall to 300 psi after 40 minutes. Discuss path forward with town. 9/4/2017 9/4/2017 1.00 INTRMI CEMENT LOT P Pressure up on OA with mud pump #2 118.0 118.0 11:30 12:30 to 1460 psi at 7 spm and observe pressure break over and drop to -800 psi. Bullhead total of 80 bbls freshwater, increasing rale to 3 bpm and observe injection pressure stabilize - 470 psi. 9/4/2017 9/4/2017 1.50 INTRMI CEMENT FRZP P Rig up Little Red and pressure test 118.0 118.0 12:30 14:00 lines to 2000 psi. Little Red freeze protect OA with 82 bbls IsoTherm at -1.5 bpm, ICP 335 psi, FCP 1050 psi. Rig down Little Red. After shut in for 10 minutes, OA pressure = 550 psi. SIMOPS: Service lopdrive and blocks. 9/4/2017 9/4/2017 0.75 INTRMI CEMENT BHAH P Continue making up 6-3/4" drilling 118.0 302.0 14:00 14:45 BHA from 118'to 302' MD per DD, monitoring displacement via trip tank. 9/4/2017 9/4/2017 2.50 INTRM1 CEMENT PULD P Single in hole on 4" DP singles from 302.0 2,196.0 14:45 17:15 302'- 2196' MD, monitoring displacement via trip tank. 9/4/2017 9/4/2017 0.50 INTRMI CEMENT DHEQ P Fill pipe and shallow hole test MWD 2,196.0 2,196.0 17:15 17:45 tools at 240 gpm, 1100 psi, 19% F/O - good test. 9/4/2017 9/4/2017 3.50 INTRMI CEMENT PULD P Single in hole on 4" DP singles from 2,196.0 5,797.0 17:45 21:15 2196'- 5797' MD, monitoring displacement via trip tank and filling pipe every 20 x stands. Page 18179 ReportPrinted: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tune End Time Ow (hr) Phew Op Cotle ActivityCoca Time P -T -X Operation Siert Depth (ftKB) End Depth (WS) 9/4/2017 9/5/2017 2.75 INTRM7 CEMENT PULD P Single in hole on 4" DP with super 5,797.0 7,881.0 21:15 00:00 sliders pre-installed from 5797' - 7881' MD, monitoring displacement via trip tank and filling pipe every 20 x stands. Note: Super sliders installed 58" above pin -end on each joint. OA pressure at midnight = 330 psi 9/5/2017 9/5/2017 1.00 INTRMI CEMENT PULD P Single in hole on 4" DP with super 7,881.0 8,433.0 00:00 01:00 sliders pre-installed from 7881' - 8433' MD, monitoring displacement via trip tank. 9/5/2017 9/5/2017 0.25 INTRMI CEMENT WASH P Make up stand in mousehole and 8,433.0 8,451.0 01:00 01:15 wash down on stand #90 with 221 gpm, 1550 psi, 23% F/O. Tag up on cement stringer at 8451' MD with -4k weight. 9/5/2017 9/5!2017 0.50 INTRMI CEMENT COCF P Ream down from 8451'to 8501' MD 8,451.0 8,501.0 01:15 01:45 and tag top of plugs with 235 gpm, 1850 psi, 24% F/O, 40 rpm, 8-10k Tq, idk WOB. 9/5/2017 9/5/2017 2.75 INTRMI CEMENT DRLG P Drill out plugs, float collar, shoetrack 8,501.0 8,598.0 01:45 04:30 cement, shoe, and rathole from 8501' - 8598' MD with 222 gpm, 1760 psi, 24% F/O, 40-60 rpm, 8-10k Tq, 2-14k WOB. 9/5/2017 9/5/2017 0.25 INTRMI CEMENT DDRL P Drill 20' of new formation from 8598'to 8,598.0 8,618.0 04:30 04:45 8618' MD with 270 gpm, 2280 psi, 26% F/O, 60 rpm with 9k Tq on tom, 6k Tq off btm. 2k WOB. PUW 145k, SOW 62k, ROT 94k. MW 9.3ppg. ADT 0.33 hrs, Bit 0.33 hrs, Jar 0.33 hrs. 9/5/2017 9/5/2017 0.75 INTRMI CEMENT CIRC P Pull up inside shoe to 8588' MD and 8,618.0 8,588.0 04:45 05:30 circulate / condition mud with 240 gpm, 1916 psi, 22% F/O, 60 rpm, 8.5k Tq until even in/out 9.3ppg MW observed. 9/5/2017 9/5/2017 0.75 INTRMI CEMENT FIT P Rig up and perform FIT to 13.0 ppg 8,588.0 8,588.0 05:30 06:15 EMW. Pump down drill pipe and annulus with mud pump #1 to 768 psi with 9.3ppg LSND at 3991' TVD. Shut in and monitor, observe pressure drop to 635 psi after 10 minutes. Pump 1.8 bbls, Return 1.7 bbls. 9/5/2017 9/5/2017 0.25 PRODI DRILL WASH P Wash down to bottom from 8588'to 8,566.0 8,618.0 06:15 06:30 8618' MD with 276 gpm, 2430 psi, 80 rpm, 9k Tq. 9/5/2017 9/5/2017 0.25 PRODI DRILL DDRL P Drill 6-3/4" production "A2" lateral from 8,618.0 8,636.0 06:30 06:45 8618'to 8636' MD with 276 gpm, 2100 psi, 80 rpm, 9k Tq, 2K WOB. ADT 0.2 hrs, Bit 0.53 hrs, Jar 0.53 hrs. Pump 30 bbl hi -vis spacer and start displacing to 9.2ppg FloPro on the fly. Page 19179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) F&MW IH-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Cede ACM1vity Code Time P-T-X operaYon Stan Depth (flKS) End Depth(ttKa) 9/5/2017 9/5/2017 1.00 PROD1 DRILL DISP P Circulate / reciprocate from 8636' to 8,636.0 8,636.0 06:45 0745 8607' MD with 276 gpm, 2050 psi, 24% F/O, 80 rpm, 7k Tq and finish displacing well to new 9.2ppg FloPro WBM. Obtain new SPR's. SPRs @ 8631' MD 3992' TVD, MW=9.20 ppg, 07:30 hours MP#1: 20 spm=520 psi, 30 spm=720 psi. MP #2: 20 spm=520 psi, 30 spm=700 psi. 9/5/2017 9/5/2077 4.25 PR0D1 DRILL DDRL P Directionally drill 6-3/4" production 8,636.0 9,011.0 07:45 1200 "A2" lateral from 8636' to 9011' MD, 3990' TVD. Pump at 271 gpm, 1906 psi, 23% F/O, ECD 10.95 ppg, MW 9.2 ppg. Rotate at 140 rpm with 8k Tq on-btm, 61k Tq off-bim. 3k WOB. PUN 140k, SOW 70k, ROT 961k. ADT 3.61 hrs, Bit 4.14 hrs, 4.14 hrs. Observe shakers start blinding off throughout section. Quadco troubleshoot gaswatch system. 9/5/2017 9/5/2017 6.00 PROD1 DRILL DDRL P Directionally drill6-3/4" production 9,011.0 9,554.0 12:00 1800 "A2" lateral from 9011' to 9554' MD, 3986' TVD. Pump at 280 gpm, 1950 psi, 23% F/O, ECD 11.18 ppg, MW 9.2 ppg. Rotate at 150 rpm with 8k Tq on-btm, 8k Tq off-btm. 5k WOB. PUW 143k, SOW 65k, ROT 95k. Max gas of 277 units. ADT 4.56 hrs, Bit 8.7 hrs, Jar 8.7 hrs. Continue controlling ROP at —100 ft/hr from 9113'- 9304' MD due to shakers blinding off and then from 9304'- 9554' MD for directional work. Did not see first fault that was prognosed at —9000' MD. SPRs @ 9206' MD 3993' TVD, MW=9.20 ppg, 14:00 hours MP#1: 20 spm=560 psi, 30 spm=740 psi. MP #2: 20 spm=540 psi, 30 spm=730 psi. Page 20179 ReportPrinted: 10/30/2017 Operations Summary (with Timelog Depths) 1 H-102 r. Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Time End Tn. Our{hr) Phase opowe Activity Cotle Time P -T -X Operation StartDepth (rt K6) d End Depth (ftKa) 9/5/2017 9/6/2017 6.00 PROD1 DRILL DDRL P Directionally drill 6-3/4" production 9,554.0 9,960.0 18:00 00:00 "A2" lateral from 9,554' to 9960' MD, 3999' TVD. Pump at 275 gpm, 2000 psi on-blm, 1990 psi off-bim, 22% F/O, ECD 11.43 ppg. MW 9.2 ppg. Rotate at 170 rpm with 8.5k Tq on- btm, 8k Tq off-btm. 5k WOB. PUW 148k. SOW - Lose ability to obtain slackoff weight at 9945' MD. ROT 92k. Max gas of 177 units. ADT 4.34 hrs, Bit 13.04 hrs, Jars 13.04 his. Change out all 24 x shaker screens prior to midnight due to wear. Observe '.greasing" of sand/safecarb coming out over shakers throughout the day, partial blinding off 170 mesh screens. Lubes have not been increased, kept at initial 1% concentration of Lo -Torg. OA pressure at midnight = 460 psi Downhole losses over past 24 hours = 31 bbis. 9/6/2017 9/6/2017 6.00 PROD1 DRILL DDRL P Directionally drill 6-3/4" production 9,960.0 10,512.0 00:00 06:00 "A2" lateral from 9960' MD to 10512' MD, 4005' TVD. Pump at 275 gpm, 2140 psi, 23% F/O, ECD 11.48 ppg, MW 9.2 ppg. Rotate at 170 rpm with 9k Tq on-btm, 8k Tq off-btm. 3-6k WOB. PUW 160k, unable to slack off, ROT 107k. Max gas of 30 units. ADT 4.68 his, Bit 17.72hrs, Jar 17.72 his. Observe slightly less "greasing" at shakers and less blinding off of shaker screens. SPRs @ 10051' MD 4005' TVD, MW=9.20 ppg, 01:00 hours MP#1: 20 spm=640 psi, 30 spm=860 psi. MP #2: 20 spm=640 psi, 30 spm=860 psi. 9/6/2017 9/6/2017 6.00 PRODi DRILL DDRL P Directionally drill 6-3/4" production 10,512.0 11,225.0 06:00 12:00 "A2" lateral from 10512' MD to 11225' MD, 4026' TVD. Pump at 275 gpm, 2350 psi, 23% F/O, ECD 11.91 ppg, MW 9.2 ppg. Rotate at 170 rpm with 9k Tq on-btm, 8k Tq off-btm. 3-6k WOB. PUW 170k, unable to slack off, ROT 99k. Max gas of 577 units. ADT 4.5 his, Bit 22.22 hrs, Jar 22.22 hrs. Control drilled as needed for directional control. No further "greasing" observed at shakers. Changed 4 x 170 mesh screens over past 12 hours due to wear. Faulted out of zone at 11,047' and observed 27' DTN throw. Total of 221' out of zone. Page 21179 Report Printed: 10/30/2017 DOYON 142 Operations Summary (with Timelog Depths) 1H-102 Job: DRILLING ORIGINAL Stan Time 9/6/2017 End Time 9/6/2017 Dur (hr) 6.00 Phase PROD1 Op Code Acbvity Code Time P -T -x Operation Sid �pN (hK End Depth fl 12:00 1800 DRILL DDRL P Directionally drill 6-3/4"protluction 11,22 25.0 11,81'8 000.00 "A2" lateral from 11,225' to 11,800' MD, 4,033' TVD. Pump at 275 gpm, 2530 psi, 22% F/O, ECD 12.17 ppg, MW 9.2 ppg. Rotate at 170 rpm with 9k Tq on-btm, 8.5k Tq off-btm. 5k WOB, PUW 172k, unable to slack off, ROT 106k. Max gas of 177 units. ADT 3.95 hrs, Bit 26.17 hrs, Jars 26.17 hrs. SPRs @ 11340' MD 4033' TVD, MW=9.20 ppg, 12:45 hours MP#1: 20 spm=780 psi, 30 spm=980 psi. MP #2: 20 spm=780 psi, 30 spm=980 psi. 9/6/2017 18:00 9/7/2017 00:00 6.00 PROD1 DRILL DDRL P Directionally drill 6-3/4" production 11,800.0 12,260.0 "A2" lateral from 11800'to 12260' MD, 4020' TVD. Pump at 275 gpm, 2535 psi, 22% F/O, ECD 11.96 ppg, MW 9.2 ppg. Rotate at 170 rpm, 9k Tq on- btm, 9k Tq off-btm. 3k WOB, PUW 186k, unable to slack off, ROT 110k. Max gas of 226 units. ADT 4.01 hrs, Bit 30.18 hrs, Jars 30.18 hrs. Perform 290 bbl dump/dilute at 12,170' MD. OA pressure at midnight = 400 psi Downhole losses for past 24 hours = 8 bbls 9/7/2017 00:00 9/7/2017 06:00 6.00 PROD1 DRILL DDRL P Directionally drill 6-3/4" production 12,260.0 12,814.0 "A2" lateral from 12260'to 12814' MD, 4020' TVD. Pump at 275 gpm, 2646 psi, 22% f/O, ECD 12.04 ppg, MW 9.2 ppg. Rotate at 170 rpm with 10k Tq on -btm, 9k Tq off him, 3k WOB. PUW 190k, unable to slackoff, ROT 11 Ok. Max gas of 300 units. ADT 4.49 hrs, Bit 34.67 hrs, Jars 34.67 hrs. 9/7/2017 06:00 9/7/2017 07:00 1.00 PROD1 DRILL DDRL P Directionally drill 6-3/4" -production 12,814.0 12,960.0 "A2" lateral from 12814' to TD of 12960' MD, 4022' TVD. Pump at 275 gpm, 2720 psi, 22% F/O, ECD 12.04 ppg, MW 9.2 ppg. Rotate at 170 rpm with 10k Tq on-btm, 9k Tq off-btm. 3k WOB. PUW 190k, Unable to slackoff, ROT 110k. ADT 0.88 hrs, Bit 35.55 hrs, Jars 35.55 hrs. Did not see at 12,845' MD. Page 22/79 ReportPrinted: 10130/2017 Summary (with Timelog Depths) 1H-102 Fi6Operations DOYON 142 Job: DRILLING ORIGINAL Time LogRig: Start Time EM Time Dw hr ( ) Phase Op Code ACYvity Coo'e Time P -T -X Operation s�DepM 0810) EM Depth (f1Ka) 9/7/2017 9/7/2017 1.75 PROD1 CASING CIRC P Circulate bottoms up at TO with 275 12,960.0 12,960.0 07:00 08:45 gpm, 2686 psi, 170 rpm, 9k Tq. Obtain final surveys, parameters, and SPR's. PUW 190k, Unable to slack off, ROT 110k. SPRs @ 12960' MD 4022' TVD, MW=9.20 ppg, 07:00 hours MP#1: 20 spm=810 psi, 30 spm=1020 psi. MP #2:20 spm=810 psi, 30 spm=980 psi. 9!7/2017 9/7/2017 0.50 PROD1 CASING OWFF P Monitor well forflow-well static. 12,960.0 12,960.0 08:45 09:15 Service top drive and traveling equipment. 17 09:15 09:15 9/7/2017 2.75 PRODt CASING BKRM P Backream out of hole from 12960' to 12,960.0 11,987.0 12:00 11987' MD with 275 gpm, ICP 2700 psi, FCP 2500 psi, ECD 11.63 ppg, 170 rpm, 6k Tq, monitoring displacement via pits 1-5. Note: Regained slackoff weight @ 11,986' MD, PUW 170k, SOW 82k 9/7/2017 9/7/2017 6.00 PROD1 CASING BKRM P Backream out of hole from 11987' to 11,987.0 10,055.0 12:00 18:00 10055' MO with 277 gpm, 1995 psi, 20% F/0, ECD 10.98 ppg, 170 rpm, 4- Sk Tq, PUW 145k, SOW 83k, ROT 100k, monitoring displacement via pits 1-5. Ream stand #109 twice through 5.64° DLS at 10543' MD and re- survey. 9/7/2017 18:00 9/7/2017 4.00 PROD1 CASING BKRM P Backream out of hole -from 10055to 10,055.0 8,546.0 22:00 8546' MD with 277 gpm, 1845 psi, 21 % F/O, ECD 10.8 ppg, 170 rpm, 4- 5k Tq. monitoring displacement via pits 1-5. Decrease rotary to 120 rpm as BHA entered shoe. 9/7/2017 22:00 9/7/2017 1.00 PRODi CASING CIRC P Circulate hole clean inside casing with 8,546.0 8,546.0 23:00 2 x bottoms up at 277 gpm, 1800 psi, 21 % F/0, 120 rpm, 4-5k Tq, ECD 10.66 ppg. Drop 2.12" OD hollow rabbit with 102' of wire on stand #87. PUW 117k, SOW 80k, ROT 100k. 9/7/2017 23:00 9/7/2017 0.25 PRODt CASING OWFF P Monitor well for flow -well static. 8,546.0 8,546.0 23:15 9/7/2017 9/7/2017 0.50 PROD1 CASING SVRG P Service topdrive and blocks. 8,546.0 8,546.0 23:15 23:45 Electrician inspect MCWS and change out encoder. 9/7/2017 9/812017 0.25 PROD1 -CASING RURD P Blow down topdrive and line up for 8,546.0 8,546.0 23:45 00:00 pulling out of hole on elevators. - Downhole losses for past 24 hours = 41 bbls OA pressure at midnight = 380 psi 9/8/2017 9/8/2017 4.00 PROD1 CASING TRIP P POOH on elevators f/ 8540' MD to 8,546.0 123.0 00:00 04:00 123' MD standing back 4" DP and 4" HWDP in derrick. Actual displacement= 60.4 bbls, Calculated displacement= 55.2 bbls. 5.2 bbls lost to formation. Page 23179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Siert Time Ertl Imre Dur (ht) Phew Op Catle AdiviH Cotle Time P -T -X Opereeon Sten Depth (tea) End Deptlr (RKB) 9/8/2017 9/8/2017 1.50 PROD1 CASING BHAH P UD BHA as per SLB DD. Bit was in 123.0 0.0 04:00 05:30 good shape with only 1 x broken cutter. Smith 6-3/4" X516 bit grade= 0- 1 -BT -G -X -0 -NO -TD. All stabilizers came out of hole in -gauge. 9/8/2017 9/8/2017 1.00 COMPZI CASING KURD P Rig up GBR casing equipement, 0.0 0.0 05:30 06:30 power tongs and make up XO on floor valve. 9/8/2017 9/8/2017 6.00 COMPZI CASING PUTS P Make up 4-1/2" Ray Oil tools float 0.0 4,483.0 06:30 12:30 shoe and run in hole with 4-1/2" slotted liner per tally to 4483' MD, monitoring displacement via trip tank. Use JetLube Run -n -Seal dope and torque to -4000 ft -lbs. Install 4-1/2" x 6-1/8" Tesco thin-walled centralizers every joint free floating. Run total of 3 x 6-3/8" swell packers, 87 x joints 4-1/2" 11.6# L-80 IBT-m slotted liner, and 18 xjoints 4-1/2" 12.6# L-80 IBT-m blank liner, 106 x 4- 1/2" by 6-1/8" Tesco hydroform centralizers, and 1 x 4-1/2" by 6-1/2" Volant hydroform centralizer. No remakes. Rejected 1 x joint (#58 = 41.77') prior to torquing up as centralizer would not easily go onto pipe -replaced with #101 = 42.15'. 9/8/2017 12:30 918/2017 1 .00 COMPZI CASING OTHR P Make up Flex -Lock Liner hanger and 4,483.0 4,553.0 13:30 HRD-E liner top packer w/ pusher tool per Baker to 4553' MD. Fill tieback sleeve with Xan-Plex D. PUW 79k, SOW 72k. 9/8/2017 13:30 9/8/2017 0.50 COMPZI CASING CIRC P RIH with 1 x stand 4" DP to 4647' MD. 4,553.0 4,647.0 14:00 Circulate -12 bbls through liner assembly and confirm no obstructions. Blow down lop drive. 9/8/2017 9/8/2017 2.00 COMPZI CASING RUNL P Run 4-1/2" liner on 4" DP from derrick 4,647.0 8,591.0 14:00 16:00 from 4647' to 8591' MD, monitoring displacement via trip tank. Obtain parameters at shoe - PUW 112k, SOW 83k 9/8/2017 9/8/2017 3.25 COMPZI CASING RUNL P Run 4-1/2" liner on 4" DP and 4" 8,591.0 12,790.0 16:00 19:15 HWDP from derrick to 12790' MD, monitoring displacement via trip lank. PUW 174k, SOW 97k. Calculated displacement = 82.3 bbls Actual displacement = 87.8 bbls (pipe self -filling, not full) Note: 12 x stands 4" DP slick, 43 x stands 4" DP with super sliders, 30 x stands 4" HWDP with super sliders, and 3 x stands 4" HWDP slick. 9/8/2017 9/8/2017 0.50 COMPZI CASING CIRC P Circulate 1 x drill pipe volume per 12,790.0 12,790.0 19:15 19:45 Baker, staging up to 3 bpm, 544 psi, 13% F/O. Page 24179 Report Printed: 10130/20171 T Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time Entl Time Our (hr) Pham Op Code Aabiry COEe Time P-T-XStart Operation Oeplh (NCS) EM DBPM (NCB) 9/8/2017 9/8/2017 0.75 COMPZI CASING PACK P Drop 1.625" phenolic ball. Pump down 12,790.0 12,790.0 19:45 20:30 at 4 bpm, 738 psi, 15% F/O for 500 strokes. Slow rate to 2.5 bpm, 451 psi, 11 % Flo after 500 strokes. Ball on seat at 590 strokes. Pressure up to 1840 psi and hold to set liner hanger. Slack off to block weight (stacking —55k on hanger) and confirm hanger set. Pressure up to 2600 psi and hold - observe pusher tool shear at 2250 psi. Increase pressure up to 4000 psi, observing pusher tool neutralize at 3500 psi. 9/8/2017 9/8/2017 1.00 COMPZI CASING PRTS P Line up to IA, Gose annular, and 12,790.0 8,249.5 20:30 21:30 pressure test liner top packer l0 3500 psi / 30 minutes, charted - good test. Use mud pump #1. Pumped 4.0 Obis, Returned 4.0 Obis. Liner top packer set at 8249.5' MD 9/8/2017 9/8/2017 0.75 COMPZI WELLPR CIRC P Pick up and expose dogs. PUW 153k, 8,249.5 8,249.5 21:30 22:15 SOW 116k. Slack off to block weight, observing dog sub shear at 50k hookload. Pressure up to 200 psi and pull out of RS packoff. Once pressure dropped, roll pump at 1 bpm and continue pulling up into tieback sleeve. Pump 28 bbls of Corrosion -inhibited brine at 4 bpm, 620 psi, 15% F/O and spot with 67 We of 9.2ppg Flo -Pro at 4 bpm, 590 psi, 15% F/O. 9/8/2017 9/812017 0.25 COMPZ1 WELLPR TRIP P Pull OOH with running tools to 8246' 8,249.5 8,246.0 22:15 22:30 and rack back stand #88. Blow down kill line. 9/8/2017 9/8/2017 0.50 COMPZI WELLPR OWFF P Monitor well for flow - well static. 8,246.0 8,246.0 22:30 23:00 1 9/8/2017 9/9/2017 1.00 COMPZI WELLPR TRIP P Pull OOH on elevators from 8246'to 8,246.0 6,775.0 23:00 00:00 6775' MD, racking back 4" HWDP in derrick, monitoring displacement via trip tank. PUW 1261k, SOW 102k. OA pressure at midnight = 280 psi 9/9/2017 9/9/2017 3.00 COMPZI WELLPR TRIP P POOH w/ Baker liner running tools f/ 6,775.0 0.0 00:00 03:00 6775' MD to surface. Inspect running tools, oberserved dog sub sheared. Calculated displacement = 62.1 bbls Actual displacement = 71.91 bbls 9/9/2017 9/9/2017 0.75 COMPZ1 WELLPR SHAH P Service break Baker liner running 0.0 0.0 03:00 03:45 tools and L/D tools via beaver slide. 9/9/2017 9/9/2017 1.00 COMPZI WELLPR SLPC P Cut and slip 73' of drilling line. 0.0 0.0 03:45 04:45 9/912017 9/9/2017 1.00 PROD2 WHPST BHAH P Mobilize Baker BHA components to rig 0.0 0.0 04:45 05:45 floor: string mills, magnets, whip stock and misc BHA tools. Page 25179 ReportPrinted: 10130120171 Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sten Time End Time Our (hr) Phase Op Code Acwrt/ Code Time P -T -X Operation Stan Depth (W) EM Depth (tKB) 9/9/2017 9/9/2017 4.25 PROD2 WHPST BHAH P Make up milling BHA. WU MWD, 1 0.0 404.0 05:45 10:00 joint HWDP, XO, Upper mill, Flex joint, Lower mill and Window mill. Obtain tool face offset of 294.82 deg. Stand back in derrick. M/U and RIH w/ seals, unloader, 7 joints of 4" DP, string magnet and Anchor assembly. Whipstock assembly weight = 5k. M/U milling BHA stand to whip stock using 35K brass shear screw and RIH w/ 4 string magnets on top. 9/9/2017 9/9/2017 1.00 PROD2 WHPST TRIP P Run in hole on 4" DP stands from 404.0 1,533.0 10:00 11:00 derrick from 404' to 1533' MD, monitoring displacement via trip tank. 9/9/2017 9/9/2017 0.25 PROD2 WHPST DHEQ P Shallow hole test MWD at 1533' MD 1,533.0 1,533.0 11:00 11:15 with 235 gpm, 590 psi. 9/9/2017 9/9/2017 4.75 PROD2 WHPST TRIP P Trip in hole on 4" DP 14" HWDP string 1,533.0 8,189.0 11:15 16:00 with super sliders installed to 8189' MD, running speed 60 ft/min, filling pipe every 20 stands, monitoring displacement via trip tank. 9/9/2017 9/9/2017 0.25 PROD2 WHPST PULD P Pick up 1 x 4" DP single (31.63 ft) and 8,189.0 8,221.0 16:00 16:15 RIH to 8221'. 9/9/2017 9/9/2017 0.25 PROD2 WHPST WPST P Kelly up to stand # 84, establish 8,221.0 8,221.0 16:15 16:30 circulation at 230 gpm, 1278 psi, 18% Flo and orient whipstock to 22° left of highside. PUW 141k, SOW 106k. 9/9/2017 9/9/2017 0.25 PROD2 WHPST WPST P Wash down wl 233 gpm, 1300 psi, 8,221.0 8,249.5 16:30 16:45 18% Flo and tag liner top at 8249.5' MD with no-go. Confine orientation at 22" left of highside. Slack off 181k and set anchor. Pick up 7k overpull and confirm anchor set. 9/9/2017 9/9/2017 1.00 PROD2 WHPST WPST T Attempt to shear 35k window mill bolt - 8,249.5 8,249.5 16:45 17:45 unsuccessful. PUW 141k, SOW 106k. Work up and down to weaken bolt, setting down -65k weight on it and pulling 20k weight max overpull with no indication of shear. Kill pump and continue working with no success. Note: Anchor pinned to shear at 60k overpull 9/9/2017 9/9/2017 2.50 PROD2 WHPST WPST T Work down torque in 500 ft -lb 8,249.5 8,249.5 17:45 2015 increments up to max of 8000 ft -lbs (3- 1/2" REG make-up torque at 8000 ft - Itis, anchor slips good to 15000 ft -lbs) and continue working pipe up/down, setting down -65k weight on it and pulling 20k max overpull with no indication of shear. Establish circulation at 234 gpm, 1285 psi, 20% F/O and confirm orientation hasn't changed once trapped torque let out. Discuss path forward with town. Page 26/79 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time 9/9/2017 EM Time 9/9/2017 Dur (hr) 0.50 Phase PROD2 Op Code Acevity Cotle Tirtre P-T-X O �� P SiaDep n N (flKB) End Depth (flK8) 20:15 20:45 WHPST WPST T Work out all trapped torque and pull to 8,249.5 8,249.5 195k hookload (54k overpull) and observe good indication of shear. Observe new PUW -145k. Pull up, rack back stand # 84 and lay down 31.63' drill pipe single, and blow down top drive. 9/9/2017 20:45 9/10/2017 3.25 PROD2 WHPST TRIP T Pull OOH racking back 4" HWDP and 8,249.5 3,210.0 00:00 4" DP to 3210' MD, monitoring displacement via trip tank. OA pressure at midnight = 390 psi No downhole losses observed for past 24 hours. 9/10/2017 9/10/2017 1.50 PROD2 WHPST TRIP T Cont POOH f/ 3215' MD to surface. 3,210.0 0.0 00:00 01:30 Observed bolt at window mill/ whipstock sheared. The shear bolt sheared in the correct location on the bolt, no issues could be visual observed on shear bolt. The decision was made to RIH w/ retrieval hook. Caculated displacement = 57.1 bbls Actual displacement = 57.1 bbls 9/10/2017 9/10/2017 0.50 PROD2 WHPST BHAH T UD milling BHA as per Baker rep. 0.0 0.0 01:30 02:00 9/10/2017 9/10/2017 1.00 PROD2 WHPST SHAH T Make up whipstock retrieval BHA, 0.0 90.0 02:00 03:00 hook, HWDP, MWD and oil jars. Scribe MWD to jet, 171 ° toolface offset. 9/10/2017 9/10/2017 4.00 PROD2 WHPST TRIP T RI w/ whipstock retrival BHA f/ 90' 90.0 7,970.0 03:00 07:00 MD to 7970' MD. Obtain parameters , P/U= 136K, SIO= 107K, Pump @ 237 gpm= 1130 psi. 9/102017 9/10/2017 3.25 PROD2 WHPST FISH T Orient retrieval hook to 20 deg L and 7,970.0 7,986.0 07:00 10:15 hook up into retrieval slot. Set down 10K @ 7986.5' MD. Pick up and overpull 15K to confirm hook up, observed toolface @ 19 deg L. Stage up PIU to 235K (95K over) and attempt to release anchor without jarring, no success. Set down 1O to cock jars, P/U to 175K ( 40K over) and fire jars, straight pull to 235K ( 95K over) No success. Slowly stage up jar firing overpull f/ 40K over to 95K over while pulling to 235K ( 95K over) post jar fire. Able to jar free when firing jars @ 235K ( 95K overpull) Picked up 16' to stand back DP and observed 12K drag. 9/10/2017 9/10/2017 0.25 P7RO02 WHPST OWFF T OWFF, static. 7,986.0 7,970.0 10:15 10:30 9/10/2017 9/10/2017 0.50 PROD2 WHPST TRIP T POOH 5 stands f/ 7970' MD to 7602'7,970.0 7,602.0 10:30 11:00 MD, P/U= 147K, 11 K drag. 9/10/2017 9/10/2017 0.50 TROD2 SFTY Perform post jarring derrick inspection 7,602.0 7,602.0 11:00 11:30 as per DDI, all good.T 9/10/2017 9/10/2017 4.75 TIROD2 TRIP T Pull OOH on elevators from 7602' to 7,602.0 268.0 11:30 16:15 268'to bring whipstock to surface, monitoring displacement via trip tank. Page 27/79 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tama EM Toe Dur (hr) Phase op Code Activity Code Tbna P -T -X Operation Start Depth (WB) Ertl DeaN(ftKS) 9/10/2017 9/10/2017 1.75 PROD2 WHPST BHAH T Lay down whipstock retreival BHA and 268.0 0.0 16:15 18:00 whipstock assembly per Baker. The shear bolt sheared in the correct location on the bolt, no issues were visually observed on shear bolt. Overall condition of BHA was good with no wear. Observed moderate amount of metal on magent below whipstock. Lay down assembly and rack back 4" DP spaceout pipe. Calculated displacement = 58.4 bbls Actual displacement = 59.7 bbls 9/10/2017 9/10/2017 1.50 PROD2 WHPST BHAH T Clean and clear rig floor and mobilize 0.0 0.0 18:00 19:30 new whipstock components to rig floor. 9/10/2017 9/10/2017 2.50 PROD2 WHPST BHAH T Make up milling BHA. M/U MWD, 1 0.0 404.0 19:30 22:00 joint HWDP, XO, Upper mill, Flex joint, Lower mill and Window mill. Obtain tool face offset of 227° from MWD highside to jet. Stand back in derrick. M/U and RIH w/ seals, unloader, 7 joints of 4" DP, string magnet and Anchor assembly. Whipstock assembly weight= 5k. M/U milling BHA stand to whip stock using 35K brass shear screw and RIH w/ 4 string magnets on top to 404' MD. PUW 49k, SOW 55k. Note: Used prior milling BHA components that were in good condition and changed out anchor, disconnect, whipstock, and window mill. Re -confirmed correct gauges on mills. Added in a 2.05' spacer sub to ensure anchor is set above previous set point. Anchor pinned with 4 x screws, —14k shear and shipping bolt removed. Unloader re -pinned with 3 x screws, —18k shear. Length of new slide = 13.67', retrieval slot 5.25' down. Whipstock pinned with 35k brass shear screw from different batch then prior shear screw. 9/10/2017 9/10/2017 1.00 PROD WHPST TRIP T Trip in hole on 4" DP stands from 404.0 2,006.0 22:00 23:00 derrick from 404' to 2006' MD, monitoring displacement via trip tank, running speed 60 ft/min. 9/10/2017 9/10/2017 0.25 PROD2 WHPST DHEQ T Shallow hole test MWD with 235 gpm, 2,006.0 2,006.0 23:00 23:15 540 psi, 20% F/O. Blow down top drive. 9/10/2017 9/11/2017 0.75 PROD2 WHPST TRIP T Trip in hole on 4" DP stands from 2,006.0 3,144.0 23:15 00:00 derrick from 2006' to 3144' MD, monitoring displacement via trip tank, running speed 60 it/min. OA pressure at midnight = 325 psi No downhole losses for past 24 hours Page 2809 ReportPrinted: 10/30/2017 Operations Summary (with Timelog Depths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Star) Tmte Entl Time Dz hr ( ) phos¢ Op code Activity Cotle Tlme P -T -X Operation start Depth (ftKB) ad Depth (ftKB) I 9/11/2017 9/11/2017 3.25 PROD2 WHPST TRIP T Trip in hole on 4" DP / 4" HWDP with 3,144.0 8,219.0' 00:00 03:15 super sliders from 3144' to 8219' MD, confirming pipe fill at 5000' and monitoring displacement via trip tank. Make up 31.63' 4" DP single above stand #83. Calculated displacement = 56.6 bbls Actual displacement = 58.6 bbls 9/11/2017 9/11/2017 0.50 PROD2 WHPST WP -ST T Establish circulation, obtain PUW 8,219.0 8,249.5 03:15 03:45 1371k, SOW 106k with 238 gpm, 1234 psi. Orient to 22° left of highside. RIH and tag liner top at 8249.5' MD with —5k. Confirm orientation at 22° left of highside. Slack off to 92k HL (141k on it) and observe good indication of anchor shear. Pick up to 148k HL (11k overpull) and confirm anchor set. 9/11/2017 9/11/2017 1.00 PROD2 WHPST WPST T Slack off to block weight (-65k on it) to 8,249.5 8,249.5 03:45 04:45 shear 35k shear bolt - no sign of shear. Start working pipe up/down to fatigue bolt, 238 gpm, 1240 psi, 20% F/O, pulling up to 15k overpull (152k HL) and slacking off down to 75k on it (31 k HL) - no sign of shear. 9/11/2017 04:45 9/11/2017 0.25 PROD2 WHPST WPST T Slack off to block weight, kill pumps, 8,249.5 8,249.5 05:00 and start using rig's rocker system with 3-5k torque limit. Observe hookload increase from 45k to 52k. 9/11/2017 05:00 9/11/2017 0.25 PROD2 WHPST WPST T With rocker system engaged and 3k 8,249.5 7,979.1 05:15 torque limit, start working pipe up/down to fatigue bolt, no pumps. Work up to 20k overpull (157k HL) and down to 68k weight slacked off (38k HL). Observe good indication of bolt shear on downstroke and HL increase from 38k to 52k. Top of window @ 7979.13' MD Btm of window @ 7992.80' MD 9/11/2017 9/11/2017 0.25 PROD2 WHPST T7PST P Obtain parameters with 238 gpm, 7,979.1 7,979.1 05:15 05:30 1225 psi, 19% F/O, PUW 134k. Engage rotary at 80 rpm, 4k Tq, ROT 114k. 9/11/2017 9/11/2017 11.50 PROD2 WHPST MILL P Mill 6-3/4" window for L1 Latera (from 7,979.1 8,014.3 05:30 17:00 7979.1'to 8014.3' MD with 238 gpm, 1460 psi, 20% F/O, 80 rpm, 5-9k Tq, starting with 1-3k WOB and ending with 4-81k WOB. Pump super sweeps as each mill passed the slide with minimal metal shavings observed at surface. Mill out on pit #1 only, keeping other FloPro isolated. Note: 5 ft of gauge 6-3/4" hole to 7997' MD, rathole to 8014.3' MD Page 29179 ReportPrinted: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End7ime Dur (hr) Phase Op Code ACM' Gude Time P -T -x Operation Start Depm (fixe) End Depth (ftKa) 9/11/2017 9/11/2017 1.00 PROD2 WHPST REAM P Pump super sweep at TD with 238 8,014.3 7,975.0 17:00 18:00 gpm, 1464 psi, 20% VO, 80 rpm, 5-9k Tq and ream through window twice and wash down through window once. With pump on, PUW 133k, SOW 100k, ROT 122k. Once sweep turned comer, pull pipe from TO back up into cased hole and circulate sweep to surface reciprocating from 7975'to 7950' MD w/ 238 gpm, 1464 psi, 20% F/O - total strokes pumped = 3392. Minimal metal shavings observed at surface. MW in/out 9.3 ppg 9/11/2017 9/11/2017 0.25 PROD2 WHPST TRIP P Kill pumps and obtain parameters - 7,975.0 7,975.0 18:00 18:15 PUW 150k, SOW 105k. Work pipe up and down through window to TD, observing 1-3k drag - confirm window smooth and in good shape. 9/11/2017 9/11/2017 0.75 PROD2 WHPST FIT P Blow down top drive, rig up and 7,975.0 7,975.0 18:15 19:00 perform FIT for Ll lateral to 13.Oppg EMW with 9.3ppg FloPro at 3900' TVD. Close bag, pump down drillpipe and IA with mud pump #1, and pressure up to 750 psi. Shut in and monitor, observing pressure drop to 635 psi over 10 minutes. Pumped 1.4 bbls, bled back 0.5 bbls. Rig down test equipment and blow down lines. 9/11/2017 9/11/2017 4.00 PROD2 WHPST TRIP P Pull OOH on elevators from 7975'—to 7,975.0 133.0 19:00 23:00 133' MD racking back 4" DP / HWDP stands, monitoring displacement via trip tank. Note: Laid down the 31.63' DP single we installed between stand #83 & 84 that allowed us to mill window on full stand 9I11I2017 9/12/2017 1.00 PPOD2 BHAH P Lay down milling assembly per Baker. 133.0 0.0 23:00 00:00 Observe pockets full of metal shavings on all 4 x magnets. Clean off magnets and lay down MWD tool and mills. - 6-3/4" window mill was 1/4" undergauge, - 6-5/8" lower mill was 1/8" undergauge. - 6-3/4" upper mill was in -gauge Calculated displacement = 55.4 bbls Actual displacement = 55.0 bbls OA pressure at midnight = 465 psi No downhole losses observed over past 24 hours 9/12/2017 9/12/2017 1.00 PROD2 WHPST WWWH P M/U stack washing tool on stand of 0.0 0.0 00:00 01:00 HWDP, wash and flush stack/ wellhead of swarf from milling operations. 9/12/2017 9/12/2017 1.50 PROD2 WHPST BHAH P Make up clean out BHA, Mud motor, 0.0 639.0 01:00 02:30 impulse w/ 4 Baker string magnets to 639' MD as per SLB. Page 30179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X O rahon pe Start Depth (fdfB) End Depth (flK8) 9112/2017 9/1212017 4.00 PROD2 WHPST TRIP P RIH w/ clean out BHA f/ 639' MD to 639.0 7,845.0 02:30 06:30 7845' MD. Shallow hole test MWD @ 1500' MD, good. 9/12/2017 9/12/2017 1.00 PROD2 WHPST TRIP P Establish circulation @ 7845' MD, 7,845.0 8,014.0 06:30 07:30 pump @ 253 gpm= 1920 psi. P/U= 128K, S/O= 96K. Orient motor to 20 deg L. Trip down thought window with no pumps, TOW @ 7979' MD, BOW @ 7993' MD. Observed small 4K bobble @ 7992' MD. Trip down to bottom of rat hole @ 8014' MD and set 5K down. 9/12/2017 9/12/2017 4.50 PROD2 DRILL DDRL P DDrill 6-3/4" L1 hole f/ 8014' MD to 8,014.0 8,299.0 07:30 12:00 8299' MD, TVD= 3934'. Pump @ 234 gpm= 1650 psi. on, 1600 psi off 19% FO. Rotate @ 40 rpm's w/ 6K Tq on, 5K Tq off. WOB= 2-14K. P/U= 133K, S/O= 99K, ROT= 106K. 9.2 ppg MW. AST= 2.0, ART= 1.47. ADT= 3.47, Bit hours= 3.47, Total jar hours= 39.02. At 8299' MD 33' of separation from 1H -102 main bore. Displace out milling fluid on the fly to new/used 9.2 ppg Flo-Pro NT @ 8110' MD Obtain SPRs @ 8299' MD, 3944' TVD w/ 9.2 ppg mud MP #1: 20 spm= 480 psi, 30 spm= 660 psi MP#2: 20 spm- 480 psi, 30 spm= 660 psi 9/12/2017 9/12/2017 0.50 PROD2 DRILL OWFF P OWFF- Static 8,299.0 8,299.0 12:00 12:30 9/12/2017 9/12/2017 0.75 PROD2 DRILL TRIP P POOH on elevators from 8,299'- 8,299.0 7,935.0 12:30 13:15 8,121' MD then orient to 20 DEG left high side from 8,121'- 8,029'- 7,935' MD UP WT 135-150K off BTM antl through window. DWN WT=99K. 9/12/2017 9/12/2017 4.25 PROD2 DRILL TRIP P Pump heavy sweep and POOH to 101' 7,935.0 101.0 13:15 17:30 MD monitoring displacement via TT. Prep to lay down BHA. 9/12/2017 9/12/2017 1.00 PROD2 DRILL I BHAH P LD BHA. Monitor disp via TT. 101.0 0.0 17:30 16:30 9/12/2017 9/12/2017 1.50 PROD2 WHDBOP RURD P Clean dg floor and wash out stack. 0.0 0.0 18:30 20:00 Set test plug and pull wear bushing. Page 31179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stag Time 9/12/2017 End Time 9/13/2017 Our hr ( ) 4.00 Prises PROD2 D Code WHDBOP Aawiry Cafe BOPS Tlme P -i -X P tlPaand Test BOPE with 4" and 4-1/2" test joint Sfert Depth (ftKBj 0.0 Entl OapN (ft 0.0 20:00 00:00 to 250/3500 psi 515 min, witness .0) waived by AOGCC rep Jeff Jones. Test Sequence as follows: 1) 4" XT39 Dart valve and Upper IBOP 2) 4" XT39 FOSV and Lower SOP 3) Choke valves #12,13, & 14 4) Choke valves # 9 and 11 5) Choke valves #8 and 10 6) Super and manual chokes Install 4" test joint 7) Annular, Floor Kill, Choke valves #1, 2, and 5 8) HCR choke and Mezzanine Kill 9) Lower 3-1/2" x 6" pipe rams Install 4 1/2" testjoint 10) Annular, Manual choke, Manual Kill, and HCR 11) Lower 3-1/2" x 6" pipe rams Pull test joint 12) Blinds, Manual Kill, Choke valves #6 and 7 13) Choke valves #3 and 4. Perform koomey drawdown test: System Pressure = 3,000 psi PSI after closure = 1,800 psi 200 psi Attained with 2 x electric pumps = 9 seconds Full Pressure attained with 2 x electric and 2 x air pumps = 47 seconds N2 = 6 each @ 2,033 psi Tested all gas and H2S sensors, PVT and flow alarms both audio and visual, and functioned primary and remote BOP controls - all good. Upper 7-5/8" casing rams not tested. Note: While installing test plug first PT failed. Pulled test plug seal missing, Replace test plug seal and retest _ GOOD 9/13/2017 9/13/2017 0.50 PROD2 WHDBOP BOPE P Cont to test BOPE w/ 4-1/2" TJ to 0.0 0.0 00:00 00:30 250/3500 psi. Test pit level sensors and flow out alarm. Test 1-12S and combustible gas alarms. Witness of BOP test waived by Jeff Jones of the AOGCC. 9/13/2017 9/13/2017 1.00 PROD2 WHDBOP KURD P Rig down testing equipment, remove 0.0 0.0 00:30 01:30 test plug; blow down choke/kill lines, top drive and choke manifold. RID floor valves from testing equipment. Install wear bushing. 9/13/2017 9/13/2017 1.00 PROD2 DRILL BHAH P M!U BHA as per SLB, X516 PDC bit, 0.0 302.0 01:30 02:30 PowefDrIve, PeriScope, Impulse, NMFC, Jars and 4" HWDP to 302' MD. Page 32179 Report Printed: 1 013 012 01 7 Operations Summary (with Timelog Depths) IH-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Active Code Time P-T- X Operation Start Depth (ftKB) End Depth(flKB) 9/13/2017 9/13/2017 4.25 PROD2 DRILL TRIP P RIH w/ clrilling BHA f/ 302' MD to TOW 302.0 8,093.0 02:30 0645 @ 7979' MD. Shallow hole test tools @ 1500, tools in neutral. Slowly trip down thought window @ 7979' MD to 7993' MD. Cont RIH U 8093' MD. P/U= 117K. S/0= 82K. 9/13/2017 9/13/2017 0.75 PROD2 DRILL DLOG P MAD pass down f/ 8093 MD to 8300 8,093.0 8,300.0 06:45 07:30 MD. Pump @ 236 gpm= 1460 psi, Rotate @ 40 rpms w/ 4K Tq. 9/13/2017 9/13/2017 4.50 PROD2 DRILL DDRL P DDRL from 8,300' MD - 8,636' MD 8,300.0 8,636.0 07:30 12:00 3,929' TVD. 271 GPM 1,844 PSI DPP. 21 % F/0. 120 RPM with 5K TO. 2-5K WOB along with ECD's of 10.64 EMW. Off BTM 1,830 PSI DPP, UP WT = 114K, DWN WT = 79K. ROT = 94K. 4K TQ. MW = 9.2 PPG. Max gas = 50 units. ADT-3 Bit hrs - 3 Jar his - 42.02 SPR 7,870' MD 2,930' TVD @ 0600 hrs MP 1) 20 SPM - 440 PSI 30 SPM - 620 PSI MP 2) 20 SPM - 420 PSI 30 SPM - 600 PSI 9/13/2017 9/13/2017 6.00 PROD2 DRILL DDRL P DDRL from 8,636' MD 3,929' TVD - 8,636.0 9,430.0 12:00 1800 9,430' MD 3,948' TVD. 271 GPM 1,947 PSI DPP. 23% F/O. 120 RPM with 6K TQ. 4-5K WOB along with ECD's of 10.82 EMW, Off BTM 1,931 PSI DPP, UP WT = 121 K, DWN WT = 70K. ROT = 94K. 6K TO. MW = 9.2 PPG. Max gas = 171 units- ADT-4.25 Bit his - 7.24 Jar hrs - 45.79 SPR 8,825' MD 3,941' TVD @ 1330 his MP 1) 20 SPM - 420 PSI 30 SPM - 600 PSI MP 2) 20 SPM - 420 PSI 30 SPM - 620 PSI 9/13/2017 9/14/2017 6.00 PROD2 DRILL DDRL P DDRL from 9,430' MD 3,948' TVD - 9,430.0 10,215.0 18:00 00:00 10,215' MD 3,957' TVD. 271 GPM 2,090 PSI DPP. 22°% F/0. 120 RPM with 6K TO. 2-5K WOB along with ECU's of 11.16 EMW. Off BTM 2,064 PSI DPP, UP WT= 125K, DWN WT= 68K. ROT = 92K. 6K TO. MW = 9.2 PPG. Max gas = 222 units. ADT-4.18 Bit hrs - 11.42 Jar hrs - 49.97 9/14/2017 9/14/2017 6.00 PROD2 DRILL DDRL P DDRL from 10,215' MD 3,957' TVD - 10,215.0 11,070.0 00:00 0600 11,070' MD 3,970' TVD. 271 GPM 2,300 PSI DPP. 22% F/O. 120-135 RPM with 8K TO. 2-5K WOB along with ECD's of 11.5 EMW. Off BTM 2,264 PSI DPP, UP WT = 136K, DWN WT = 73K. ROT = 101K 6K TQ. MW = 9.2 PPG. Max gas = 60 units. ADT-4.72 Bit his - 16.14 Jar his - 54.69 Page 33179 Report Printed: 10/3012017 = Operations Summary (with Timelog Depths) y ` 1H-102 art. Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op Code Acwity Code O m6on ce Start Depth (fiKB) End Depth (fiKa) 9/14/2017 9/14/2017 6.00 PROD2 DRILL DDRL rom 11,070' MD 3,970' TVD - 11,070.0 11,716.0 06:00 12:00 MD 3,986' TVD. 271 GPM SI DPP. 22% F/O. 120 - 135 VMVV ith 8K TO. 2-6K WOB along D's of 12.05 EMW. Off BTM SI DPP, UP WT = 125K, DWN 6K. ROT= 117K. 7K TO, .2 PPG. Max gas = 65 units. ADT -4.16 Bit hrs - 20.3 Jar hrs - 58.85 SPR 10,333" MD 3,955' TVD @ 00:30 hrs MP 1) 20 SPM - 550 PSI 30 SPM - 760 PSI MP 2) 20 SPM - 540 PSI 30 SPM - 740 PSI 9/14/2017 9/14/2017 6.00 PROD2 DRILL DDRL P DDRL from 11,716' MD 3,986' TVD - 11,716.0 12,362.0 12:00 1800 12,362' MD 3,974' TVD. 272 GPM 2,601 PSI DPP. 22% F/O, 110-120 RPM with 9K TO. 2-6K WOB along with ECD's of 11.76 EMW. Off BTM 2,590 PSI DPP, UP WT = 164K, OWN WT = 63K. ROT = 108K. 8K TO, MW = 9.2 PPG. Max gas = 150 units. ADT -4.6 Bit hrs - 24.63 Jar hrs - 63.18 SPR 11,803" MD 3,985' TVD @ 13:33 hrs MP 1) 20 SPM - 750 PSI 30 SPM - 960 PSI MP 2) 20 SPM - 740 PSI 30 SPM - 950 PSI 017 9/1512017 -6 00 PROD2 DRILL DDRL P DDRL from 12,362' MD 3,974' TVD - --T2- 12,719.0 18:003620 00:00 12,719 MD 3,970' TVD. 271 GPM 2,653 PSI DPP. 22% F/O. 110-120 RPM with 9K TO. 2-5K WOB along with ECD's of 11.82 EMW, Off BTM 2,644 PSI DPP, UP WT = 173K, OWN WT=63K. ROT =11 OK. 8K TO. MW = 9.2 PPG. Max gas = 150 units. ADT -3.75 Bit hrs - 28.38 Jar hrs - 66.93 9/15/2017 00:00 9/15/2017 3.25 PROD2 DRILL DDRL P DDRL from 12,719 MD 3,970TVD - 12,719.0 13,126.0 03:15 13,126' MD 3,988' TVD. 271 GPM 2,653 PSI DPP. 22% F/O. 110-135 RPM with 9K TO. 2-5K WOB along with ECD's of 11.95 EMW, Off BTM 2,700 PSI DPP, UP WT = 175K, OWN WT = 63K. ROT = 106K. 8K TQ. MW = 9.2 PPG. Max gas = 150 units. ADT -2.7 Bit hrs - 31.08 Jar hrs - 69.63 Page 34/79 Report Printed: 10/30/2017 DOYON 142 Operations Summary (with Timelog Depths) IH -102 Job: DRILLING ORIGINAL SW Time 9/15/2017 End Time 9/15/2017 Dur(hr) 1.75 Phew PROD2 Do Corte Activity Code Time P -T -X CASING Start Depth Ehd IWAI 03:15 05:00 CIRC P TD called by Anch Geo /Rack bait 13, 26.0 103 126.0 stand and pump BU. rotate 140 RPM, 8K TO. Reap 13126-13030' MD 270 9/15/2017 9/15/2017 0.50 PROD2 GPM 2,668 DPP. CASING OWFF P 05:00 05:30 OWFF. (STATIC) 13,126.0 13,126.0 9/15/2017 9/15/2017 08:30 3.00 PROD2 CASING BKRM P BKRM OOH from 13,126' - 12,086' 13,126.0 9/15/ 9/15/2017 9/15/2017 0.50 PROD2 MD. 130 RPM 270 GPM. CASING 12,086.0 08:30 09:00 SVRG P Inspect top drive and service same. 12,086.0 12,086.0 9/15/2017 09:00 9/15/2017 18:45 9.75 PROD2 CASING BKRM P BKRM OOH from 12,086' - 8,356' MD 12,086.0 8,356.0 272 GPM @ 2310-1,950 PSI DPP. RPM 130-80 wRh UP WT 145K. DWN WT=69K. ROT= 101 K. 9/15/2017 18:45 9/15/2017 19:15 0.50 PROD2 CASING TRIP P POOH on elevators from 8,356' 7,882.0 - 7,882' MD with Baker rep on site 8,356.0 through window. - 10K bobble. UP 9/15/2017 9/15/2017 1.50 PROD2 WT=128K. DWN WT=80K. CASING CIRC 19:15 20:45 P Rotate and circulate from 7,882' - 7,882.0 7,882.0 7,785' MD total of 5,003 STKS. 240 GPM @ 1,450 PSI DPP. RPM @ 60. 4.5 TO. UP WT= 120K. DWN WT= 9/15/2017 9/15/2017 0.50 PROD2 80K. RT = 93K. CASING OWFF P 20:45 21:15 OWFF (Static) Pump slug and install 7,882.0 7,882.0 9/15/20179/16/2017 2.75 PROD2 CASING TRIP P wiper rubber. 21:15 00:00 POOH on elevators from 7,882'-1,155' 7,882.0 1,155.0 MD. Monitor disp via TT. UP WT = - 9/16/2017 9/16/2017 0.75 PROD2 118K. DWN WT = 80K. CASING TRIP 00:00 00:45 P Continue to POOH from 1, 155'-302' 1,155.0 302.0 MD monitoring disp via TT. REmove 017 9/1612017 0.25 PROD2 strippin rubber. CASING OWFF P 00:45 00:45 01:00 OWFF. PJSM for laying down BHA. 302.0 302.0 9/16/2017 01:00 9/16/2017 02:15 1.25 PROD2 CASING BHAH P Lay down BHA #9 as per DD from 302.0 0.0 302' MD to surface. Monitor disp via 9/16/2017 02:15 9/16/2017 0.25 PROD2 TT. CASING BHAH P Clean dg Floor. 0.0 0.0 02:30 9/16/2017 02:30 9/16/2017 1.25 PROD2 CASING SLPC P SLPC 73' drill line. 0.0 0.0 03:45 9/16/2017 03:45 9/16/2017 0.50 PROD2 CASING SVRG -P7- Service top drive and blocks. 0.0 0.0 04:15 017 04:15 9/16/2017 06:00 1.75 COMP72 FISH BHAH P MU BHA # 10 and scdb as per BOT 0.0 230.0 9/16/ 017 9/16/2017 1.25 50MP22 rep to 230' MD FISH 06:00 06:00 07:15 TRIP P RIH from 230' - 2,209' MD monitoring 230.0 2,209.0 Disp via TT. UP WT = 70K DWN 9/18/2017 9/16/2017 0.25 COMPZ2 WT= 70K FISH DHEO P 07:15 07:30 Shallow test MWD (PASSED). 2,209.0 2,209.0 07:30 017 9/16/2017 07:30 10:30 3.00 COMPZ2 FISH TRIP P Continue to Tdp in hole from 2,209' - 2,209.0 7,904' MD. Fill pipe every 30 stnds. 7,904.0 Paae 35/]9 _ rceport Printed: 10/30/201 Operations Summary (with Timelog Depths) AL 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Steri Time End Imre our (hr) Phase Op Cade AiAmty Code Time P -T -X Operation (WS) End Deper (W13) 9/16/2017 9/16/2017 1.50 COMPZ2 FISH JAR P Wash down from 7,904'- 7,991' MD 7,904.0 7,991.0 10:30 12:00 @ 5.5 BPM 1,650 PSI DPP. 20% F/O. Up WT=120K, OWN WT=77K. Orient 22 DEG. Latch into whipstock and work up to 100K overpull with no success with straight overpull. Jar 3X at 40K / 4X at 60K, Whipstock free after 2 80K hits with straight pulls to 100K. 127K UP WT with 1 OK drag. 9/16/2017 9/16/2017 1.50 COMPZ2 FISH CIRC P Circulate bottoms up X2 @ 268 GPM, 7,991.0 7,960.0 12:00 13:30 1,284 PSI DPP. 21 % F/O. 4,862 STKS pumped. 9/16/2017 9/16/2017 0.50 COMPZ2 FISH OWFF P OWFF. (STATIC). PUH to 7,904' MD. 7,960.0 7,904.0 13:30 14:00 UP WT = 125K. Blow down top drive. 9/1612017 9/1612017 5.00 COMPZ2 FISH TRIP P POOH with Whipstock assym on 7,904.0 230.0 14:00 19:00 elevators. from 7,960'- 230' MD. UP WT = 125K. Monitor disp via TT. Drop 2.115 OD rabbit. 9/16/2017 9/1612017 2.00 COMPZ2 FISH BHAH P Lay down BHA #10 and whipstock as 230.0 0.0 19:00 21:00 per Baker rep. Monitor disp via TT. 9/1612017 9116/2017 1.00 COMPZ2 FISH BHAH P Clean dg Floor and LD running tools. 0.0 0.0 21:00 22:00 9/1612017 9116/2017 1.50 COMPZ2 CASING RURD P Rig up to run liner., Bring GBR 0.0 0.0 22:00 23:30 equipment to rig floor, centrilizers, etc. 9/16/2017 9/17/2017 0.50 COMPZ2 CASING PUTB P PJSM / pick up 4 1/2" 11.6# IBTM 0.0 290.0 23:30 00:00 slotted liner as per tally to 290' MD. UP WT = 47K, OWN WT = 47K. 9/17/2017 9/17/2017 7.25 COMPZ2 CASING PUTB P RIH with 4 1/2" 11.6# L-80 IBTM 290.0 5,097.0 00:00 07:15 slotted liner as per tally from 290' - 5,097' MD. Monitor disp via TT. Install centralizer on every joint. TO connections to 5K FT/LB. 9/17/2017 9/17/2017 1.00 COMPZ2 CASING OTHR P Change out elevators and make up 5,097.0 5,130.0 07:15 08:15 hook hanger assym + Impulse and scribe. UP WT=82K. DWN WT= 69K. 9/17/2017 9/17/2017 0.50 COMPZ2 CASING RUNL P RIH with DP fro 5,130' - 5,687' MD. 5,130.0 5,687.0 08:15 08:45 Monitor Disp via TT. 9/17/2017 9117/2017 0.25 COMPZ2 CASING DHEQ P Shallow hole test MWD with 100 GPM 5,687.0 5,687.0 08:45 09:00 320 PSI DPP, 10% F/O (PASSED) Blow down top drive. 9/17/2017 9/17/2017 4.50 COMPZ2 CASING RUNL P RIH with 4" DP from 5,687'- 10,431' 5,687.0 13,040.0 09:00 13:30 MD then HWDP to 13,040' MD UP WT 168K, OWN WT 91 K. 9/17/2017 9/17/2017 1.25 COMPZ2 CASING RUNL P Kelly up and wash down from 13,040 - 13,040.0 13,110.0 13:30 14:45 13,090' MD. Stage pumps up to 3 1/2 BPM ICP -920 PSI, FCP-1, 134 PSI with 14% F/O. Tool face 150 DEG left on high side wash down to 13,110' MD PIU orient 22 DEG left highside to set hood hanger on depth with 30K dwn wt. Page 36179 Report Printed: 1 0/3 012 01 7 = Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Tore End Time Der(hr) Phase Op Code Activdy Code Tune P -T -X Operabon (ttKe) End Depth ptKB) 9/17/2017 9/17/2017 0.75 COMPZ2 CASING CIRC P Drop 29/32" ball and pump down @ 4 13,110.0 13,110.0 14:45 15:30 BPM 170 GPM, 1,350 PSI DPP. 14% F/O. Decrease rate to 42 GPM - 350 PSI DPP. 5% F/O. Ball on seat at 667 STKS. Pressure up to 3,300 PSI. Pick up to confirm release observe 145K UP WT. Pressure up to 4,362 PSI to shear out ball seat. 9/17/2017 9/17/2017 0.50 COMPZ2 WELLPR OWFF P OWFF (Static) 13,110.0 13,110.0 1530 16:00 9/17/2017 9/17/2017 3.50 COMPZ2 WELLPR TRIP P POOH on elevators from 7,952 to 75' 7,952.0 75.0 16:00 19:30 MD. 9/17/2017 9/17/2017 0.50 COMPZ2 WELLPR SHAH P LD liner running BHA from 75'-45' MD 75.0 45.0 19:30 20:00 9/17/2017 9/17/2017 1.00 COMPZ2 WELLPR SHAH P Lay down and flush SLB MWD tools. 45.0 0.0 20:00 21:00 9/17/2017 9/17/2017 1.00 COMPZ2 WELLPR SHAH P Clean rig floor and remove BHA from 0.0 0.0 21:00 22:00 floor. Service TO. 9/17/2017 9/1812017 2.00 COMPZ2 WELLPR RGRP T Begin traction motor replacement on 0.0 0.0 22:00 00:00 top drive. 9/18/2017 9/18/2017 15.00 COMPZ2 WELLPR RGRP T Continue to change out top drive 0.0 0.0 00:00 15:00 motors 9/18/2017 9/18/2017 0.50 COMP7-2 WELLPR SFTY T Perform DROPS inspection. 0.0 0.0 15:00 15:30 9/18/2017 9/18/2017 1.00 COMPZ2 RWRID RURD P Bring tools to rig floor to run LEM / 0.0 0.0 15:30 16:30 ZXP. GBR set to Torque tum TXP treads. 9/18/2017 9/18/2017 2.50 COMPZ2 RWRID PUTS P MU and RIH with LEM /ZXP assym to 0.0 399.0 16:30 19:00 399'MD. Up WT=47K OWN WT= 53K. Monitor disp via TT. Utilizing GBR to make up torque on TXP threads. 9/18/2017 9/19/2017 5.00 COMPZ2 RWRID RCST P RIH with LEM / ZXP ASSYM from 399' 399.0 5,645.0 19:00 00:00 - 5,645' MD. Monitor disp via TT. UP WT=107K OWN WT=87K. Shallow hole test MWD at 870' MD with 80 GPM 210 PSI 8% F/O (PASSED). 9/19/2017 9/19/2017 2.00 COMPZ2 RWRID RCST P Continue to RIH from 5,645 - 8,270' 5,645.0 8,270.0 00:00 02:00 MD. Monitor disp via TT 9/19/2017 9/19/2017 1.75 COMPZ2 RWRID PACK P Bring on pumps and orient to 90 DEG 8,270.0 8,299.0 02:00 03:45 L. Set LEM with 15K OWN and confine latched with 5K overpull. Work pipe to turn to 28 DEG left and drop 1 3/4" ball. Bring pumps on line at 80 GPM with ball going on seat at 558 STKS. Pressure up to 2,800 PSlfor 5 min. Increase pressure to 3,700 PSI to set isolation tool and PKR. Bleed off pressure. Pressure lest PKR for 10 min at 3,500 PSI. (PASSED). UP WT= 145K. OWN WT = 106K 9/19/2017 9/19/2017 1.00 COMPZ2 RWRID CIRC P PUH to 7,907' MD and circulate in 28 8,299.0 7,907.0 03:45 04:45 BELS of 9.3 PPG Cl pill with 140 GPM at 440 PSI DPP. 12% F/O. UP WT = 147K. 9/19/2017 9/19/2017 0.75 COMPZ2 RWRID OWFF P PUH to 7,849'MD OWFF. Blow down 7,907.0 7,849.0 04:45 05:30 top drive. Fluid level dropped 2" Page 37179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depth Step Time End Time Our (hr) Phase Op Code Ae6vdy Code Time P -T -X Operation (IB(B) End Depth (ftKB) 9/19/2017 9/1912017 4.50 COMPZ2 RWRID TRIP P POOH from 7,849'- 74' MD 7,849.0 74.0 05:30 10:00 monitoring disp via TT. Up WT = 145K 9/19/2017 9/19/2017 0.75 COMPZ2 RWRID SHAH P LD LEM assym BHA 74.0 0.0 10:00 10:45 9/19/2017 9/1912017 0.50 COMPZ2 RWRID SHAH P Clean rig floor and perp for next run. 0.0 0.0 10:45 11:15 9/19/2017 9/19/2017 2.75 PROD3 WHPST SHAH P PU Baker Whipstock BHA as per 0.0 305.0 11:15 14:00 Baker rep. Monitor Disp via TT. Dwn WT = 53K 9/19/2017 9/19/2017 5.25 PROD3 WHPST TRIP P RIH with BHA #12 on 4" DP and 305.0 7,511.0 14:00 19:15 HWDP from 305'-7,811' MD. Monitor disp via TT. UP WT = 137K. OWN WT = 105K. Shallow hole test of MWD at 2,192' MD with 220 GPM 688 PSI DPP with 17% F/O. 9/19/2017 9/19/2017 1.25 PROD3 WHPST WPST P Kelly up and fill pipe @ 7,811' MD. 7,511.0 7,915.0 19:15 20:30 Wash DWN and orient 125 DEG Left high side @ 220 GPM, 1,177 PSI DPP. 16% F/O. 7,915' MD UP WT = 137K. DWN WT = 105K. 9/19/2017 9/19/2017 0.75 PROD3 WHPST WPST P Locate liner top @ 7,915'MD with 7,915.0 7,831.8 20:30 21:15 5KDWN and set ancot with 15K DWN. PUI 10K over to check set. Shear off and slide with 40K DWN WT. 9/19/2017 9/20/2017 2.75 PROD3 WHPST MILL P Mill window as per BOT 7,831.8 7,848.0 21:15 00:00 recomendations with 300 GPM, 1,906 PSI DPP with 20% F/O. 80 RPM with 4K TO. UP WT=137K. DW WT= 105K. ROT= 120K. to 7,848' MD. 9/20/2017 9/20/2017 6.00 PROD3 WHPST MILL P Mill Window and new hole as per 7,848.0 7,865.9 00:00 06:00 Baker rep. From 7,848' MD - 7,865.87' MD. At 296 GPM, 2,050 PSI DPP, F/O = 22%4K WOB with 3-7K TO. PUUmp 25 BBLS high vis super sweeps at 7,852', 7,855', 7,866' MD. 9/20/2017 9/20/2017 3.50 PROD3 WHPST MILL P Continue to mill from 7,865'- 7,865.9 7,880.0 06:00 09:30 7,880'MD. 296 GPM @ 2,260 PSI DPP, 21% F/O, 8K WOB, 120 RPM, 4K TO and pumped 21 BBLS high vis at 7,880' MD. Work through window 2X w/ pump and rotary (GOOD) 2X w/o pump and rotary (GOOD) UP WT = 148K, DWN WT = 106K. 9/20/2017 9/20/2017 0.25 PROD3 WHPST CIRC P Circulate BU at 200 GPM. 7,880.0 7,880.0 09:30 09:45 9/20/2017 9/20/2017 1.25 PROD3 WHPST FIT P Perform FIT Tto 12.9 EMW. 8 STKS 7,880.0 7,880.0 09:45 11:00 to pressure up to 720 PSI. .8 BBLS bled back. RD and BD test equip. 9/20/2017 9/20/2017 0.25 PROD3 WHPST OWFF P OWFF(GOOD). 7,880.0 7,880.0 11:00 11:15 9/20/2017 9/20/2017 4.75 PROD3 WHPST TRIP P POOH monitoring disp via TT. Strap 7,880.0 231.0 11:15 16:00 OOH and inspect all SS. No correction. 9120/2017 9/20/2017 1.25 PROD3 WHPST BHAH P LD Milling BHA as per Baker Rep from 231.0 0.0 16:00 1715 231'to Surface. Upper mill was full guage. Page 38179 Report Printed: 1 013 0/2 01 7 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sten Time End Time Dur (hr) Phase Op Code Activity Cade Time P -T -X Operation Depthity ptl(8) EM pepllr (tlKB) 9/20/2017 9/20/2017 1.75 PRODS WHPST WWWH P MU/ BOP stack washer and cycle 0.0 0.0 17:15 19:00 rams. 470 GPM with 20 RPM. F/O 20 %. BD top drive. SIMOPS with I/S Mill BHA via Beaver Slide clean and wash Floor. 9/20/2017 9/20/2017 1.00 PROD3 WHPST RGRP T Change out lights of derrick. 0.0 0.0 19:00 20:00 9/20/2017 9/20/2017 0.50 PROD3 WHPST EQRP P Change out SLB stand pipe 0.0 0.0 20:00 20:30 transducer. 9/20/2017 9/20/2017 1.75 PROD3 WHPST SHAH P PU/MU clean out BHA as per SLB DD. 0.0 887.0 20:30 22:15 to 887' MD //UP WT = 53K, DWN WT = 58K. Monitor disp via TT. 9/20/2017 9/20/2017 1.00 PRODS WHPST TRIP P Trip in hole with 4" DP form 887'- 887.0 1,558.0 22:15 23:15 1,558' MD. UP WT 67K, DWN WT= 71K. Perform shallow test @ 250 GPM 1,048 PSI DPP 20% F/O. (FAILED) 9/20/2017 9/2112017 0.75 PRODS WHPST EQRP T Troubleshoot Faulty SLB pressure 1,558.0 1,558.0 23:15 00:00 transducer equip. Replace transducer wire system and re -test @ 220 GPM 831 PSI DPP. 18% F/O (PASSED) 9/21/2017 9/21/2017 4.00 PROD3 WHPST TRIP P Comtinue to trip in hole from 1,558'- 1,558.0 7,718.0 00:00 04:00 7,718' MD. Change out Super Sliders as per W WT rep. Fill pipe every 20 Stands. UP WT = 125K, DWN WT = 78K. 9/21/2017 9/21/2017 0.75 PRODS WHPST TRIP P Orient to 18 DEG L and RIH from 7,718.0 7,874.0 04:00 04:45 7,718'- 7,874' MD with 230 GPM. 1,560 PSI DPP. 20% F/O. 9/21/2017 9/21/2017 7.25 PRODS DRILL DDRL P DDRL 6 3/4" hole from 7,880'- 8,283' 7,874.0 8,283.0 04:45 12:00 MD 3,878' TVD. 230 GPM 1,560 PSI DPP. 18% F/O. 40 RPM, 8K TQ, 17K WOB. Off BTTM - 1,300 PSI, UP WT =124K, DWN WT=74K. Max gas= 40 Units. ADT 4.24, AST -2.17, ART, 2.07, Bit hrs 7.71, Jar HR 4.24 1 SPR's @ 7,997' MD 3,916 TVD - MW 9.2 PPG Time 07:45 MP 1) 20 SPM = 430 PSI 30 SPM = 590 PSI MP 2) 20 SPM = 400 PSI 30 SPM = 570 PSI 9/21/2017 9/2112017 1.00 PROD3 DRILL DDRL P DDRL 6 3/4" hole fro,m 8,283'- 8,331' 8,283.0 8,331.0 12:00 13:00 MD 3,877' TVD. 230 GPM, 1,370 PSI DPP, 18% F/O, 40 RPM. 71K TO, with 31K WOB. Off BTM 1,305 PSI, UP WT =127K, DWN WT=72K, ROT WT - 94K. Max gas 81 units. ADT .65, AST .20, ART .45, Bit hrs 8.36, Jar hrs. 4.89. SPR's @ 8,373' MD 3,873 TVD - MW 9.2 PPG Time 13:00 MP 1) 20 SPM = 450 PSI 30 SPM = 620 PSI MP 2) 20 SPM = 450 PSI 30 SPM = 620 PSI Page 39/79 Report Printed: 10/3012017 . Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Siert Time End Titre Our (hr) Press Op Code AcWity Code Tme PJA Operation Start Depth (fiKB) EW Depth (WB) 9/21/2017 9/21/2017 0.75 PROD3 DRILL CIRC P Rotate and reciprocate from 8,331' - 8,331.0 8,331.0 13:00 13:45 8,285' MD at 230 GPM, 1,310 PSI, 18% F/O. 40 RPM, with 6K DWN WT --UP WT=72K. ROT WT=94K, 2,580 STKS pumped. 9/21/2017 9/21/2017 0.50 PROD3 DRILL OWFF P OWFF (Static) 8,331.0 8,331.0 13:45 14:15 9/21/2017 9/21/2017 0.50 PROD3 DRILL TRIP P POOH on elevators from 8,331'- 8,331.0 7,905.0 14:15 14:45 7,905'MD. Monitor disp via TT. UP WT = 135K, DWN WT = 74K. 9/21/2017 9/21/2017 0.75 PROD3 DRILL TRIP P Kelly up and orient to 25 DEG Left 7,905.0 7,813.0 14:45 1530 highside for Whipstock pull through with Baker rep on site. UP WT 138K. 9/21/2017 9/21/2017 3.50 PROD3 DRILL TRIP P Pump heavy slug and blow down lop 7,813.0 895.0 15:30 19:00 drive. POOH on elevators from 7,813' -895'MD. UP WT=135K. DWN WT = 74K. Monitor disp via TT. 9/21/2017 9/21/2017 1.50 PROD3 DRILL SHAH P LD BHA as per SLB rep from 895' MD 895.0 0.0 19:00 20:30 to surface monitoring disp via TT. 9/21/2017 9/21/2017 0.50 PROD3 DRILL W W WH P Make up BOP stack washer tool and 0.0 0.0 20:30 21:00 jet ram cavities. 9/21/2017 9/21/2017 0.50 PROD3 WHDBOP RURD P Pull wear bushing and install test plug 0.0 0.0 21:00 21:30 9/21/2017 9/22/2017 2.50 PROD3 WHDBOP BOPE P MU BOPE test joint and dart valve. 0.0 0.0 21:30 00:00 Flush all lines, fill stack and body test. PJSM and Perform BOPE test with AOGCC rep Matt Herrera on site to witness. Low 250 High 3500 for 5 min each, Test #1-4 JNT, ANN, CV1, 12,13,14,4" Kill line on mud manifold, 4:" Dart valve. Test #2 CV 9,11 Mez Kill ine 4" FOSV. 9/22/2017 9/22/2017 3.00 PROD3 WHDBOP BOPE P Continue to test BOPE. All test to 0.0 0.0 00:00 03:00 250/ 3,500 PSI 5 min charted. Except super chokes to 1,500 PSI. Test choke valves 1-14 UPR & LWR IBOP, XT 39 dart and TIW valve. Man choke and kill valves. 4" Kill valve & Mez Kill valve. with 4" & 4 1/2" test joints. AN & 3 1/3"X6" VBR's. Blind rams Koomey draw down = 3050 PSI. 1850 after functions. 7 sec for 200 PSI, with 2 elect pumps 44 sec for total build up with 2 electric pumps and 2 air pumps. aver of 6 bill back up 2,020 PSI. Matt Herrera with AOGCC witnessed test, Perform derrick inspection. 9/22/2017 9/22/2017 1.00 PROD3 WHDBOP RURD P RID test equipment BD top drive. 0.0 0.0 03:00 04:00 Drain stack and pull test plug. Install wear bushing. grease upper IBOP. 9/22/2017 9/22/2017 0.25 PROD3 DRILL SFTY P PJSM for upcoming BHA work 0.0 0.0 04:00 04:15 9/22/2017 9/22/2017 1.50 PROD3 DRILL BHAH P PU/MU BHA # 14 as per DD / MWD. 0.0 306.0 04:15 05:45 Monitor disp via TT 9/22/2017 9/22/2017 0.75 PROD3 DRILL TRIP P RIH from 306' MD to 2,105' MD. 306.0 2,105.0 05:45 06:30 Monitor disp via TT UP WT = 75K, DWN WT = 75K. Page 40179 Report Printed: 1013012017 Summary (with Timelog Depths) 1H-102 lipOperations Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tune EM Tma our (hr) Phase Op Code Amivity CodeTime P -T -X Operation Stan OepN (M(6) End DBPM (HKB). 9/2212017 9/22/2017 0.25 PRODS DRILL DHEA PShallow hole test MWD with 220 GPM 2,105.0 2,105.0 06:30 06:45 @ 920 PSI DPP. 17% F/O 9.2 PPG (GOOD) 9/22/2017 9/22/2017 3.75 PRODS DRILL TRIP P Continue to RIH from 2,106'- 7,945' 2,105.0 7,945.0 06:45 10:30 MD. Monitor disp via TT. UP WT = 132K. DWN WT = 79K. Fill pipe every 20 stands. 9/22/2017 9/22/2017 1.50 PRODS DRILL DLOG P Perform MAD PASS from 7,945'- 7,945.0 8,290.0 10:30 12:00 8,290' MD w@ 390 FPM. 250 GPM @ 1,545 PSI DPP. F/O = 19%. UP WT=130K, DWN WT 72K. ROT= 92K 6K TQ. 9/22/2017 9/22/2017 0.50 PROD3 DRILL DLOG P Continue MAD pass form 8,290'- 8,290.0 8,377.0 12:00 12:30 8,377' MD. with 250 GPM, 1,600 PSI, 20% F/O, 80 RPM, 5.5K TQ. 9/22/2017 9/22/2017 5.50 PRODS DRILL DDRL P Drill 6 3/4" hole from 8,377'- 8,926' 8,377.0 8,926.0 12:30 18:00 MD 3,878' TVD, 272 GPM at 1,880 PSI DPP. 22% F/O 150 RPM, 7K TQ, with 3-3K WOB. ECD's 10.73 PPG EMW, Off BTM 1,880 PSI DPP, UP WT=137K DWN WT=37K. ROT= 96K. 71K TO. Max gas = 80 units. ADT - 4.20, Bit HRS = 4.20 Jars = 9.09 9/22/2017 9/23/2017 6.00 PROD3 DRILL DDRL P Drill 6 3/4" hole from 8,926' MD 3,878' 8,926.0 9,780.0 18:00 00:00 TVD - 9,780' MD 3,887' TVD, 272 GPM at 2,005 PSI DPP. 22% F/O 150 RPM, 8K TO, with 4-51K WOB. ECD's 10.98 PPG EMW, Off BTM 2,000 PSI DPP, UP WT= 137K DWN WT= 63K. ROT = 98K. 7.81K TQ. Max gas = 223 units. ADT - 4.31, Bit HRS = 8.51 Jars = 13.4 9/23/2017 9/23/2017 6.00 PROD3 DRILL DDRL P Drill 6 3/4" hole from 9,780' MD 3,887' 9,780.0 10,439.0 00:00 06:00 TVD - 10,439' MD 3,893' TVD, 272 GPM at 2,185 PSI DPP. 21% F/O 150 RPM, 8K TQ, with 3K WOB. ECD's 11.52 PPG EMW, Off BTM 2,180 PSI DPP, UP WT = 125K DWN WT = 60K. ROT = 99K. 7.51K TQ. Max gas = 580 units. ADT - 4.15, Bit HRS = 12.66 Jars = 17.55 SPR's @ 9,870' MD 3,885 TVD - MW 9.2 PPG Time 00:53 MP 1) 20 SPM = 480 PSI 30 SPM = 670 PSI MP 2) 20 SPM = 470 PSI 30 SPM = 640 PSI 9/23/2017 9/23/2017 6.00 PROD3 DRILL DDRL P Drill 6 3/4" hole from 10,439' MD 10,439.0 11,188.0 06:00 12:00 3,893' MD - 11,188' MD 3,922' TVD, 270 GPM at 2,360 PSI DPP. 21% F/O 150 RPM, 8K TO, with 5K WOB. ECD's 11.8 PPG EMW, Off BTM 2,355 PSI DPP, UP WT = 143K DWN WT=61 K. ROT= 99K. 7.71K TQ. Max gas = 450 units. ADT - 4, Bit HRS = 16.66 Jars = 21.55 Begin 290 BBLS dump and dilute @ 10,987'MD Page 41/79 ReportPrinted: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time EM Time Our thr) Phase Op CodeAcuvsy Code Tune P -T -X �� start Depth (ftKB) Ertl Depth(IIKB) 9/23/2017 9/23/2017 6.00 PROD3 DRILL DDRL P Drill 6 3/4" hole from 11,188' MD 11,188.0 11,758.0 12:00 18:00 3,922' TVD- 11,758' MD 3,922' TVD, 271 GPM at 2,425 PSI DPP. 21 % F/0 150 RPM, 9K TO, with 5K WOB. ECD's 11.48 PPG EMW, Off BTM 2,420 PSI DPP, UP WT = 148K DWN WT=67K. ROT=101K. 8.3KT0. Max gas = 7,736 units. ADT - 4.41, Bit HRS = 21.07 Jars = 25.96 SPR's Q 11,266" MD 3,930' TVD - MW 9.2 PPG Time 12:30 MP 1) 20 SPM = 650 PSI 30 SPM = 860 PSI MP 2) 20 SPM = 640 PSI 30 SPM = 820 PSI 9/23/2017 9/24/2017 6.00 PROD3 DRILL DDRL P Drill 3/4" hole from 11,758' MD 11,758.0 12,003.0 18:00 00:00 3,922' TVD - 12,003' MD 3,909' TVD, 271 GPM at 2,440 PSI DPP. 21% F/O 150 RPM, 9K TO, with 5K WOB. ECD's 11.30 PPG EMW, Off BTM 2,420 PSI DPP, UP WT= 154K DWN WT=63K. ROT =101 K. 8.5K TO. Max gas = 3,458 units. ADT - 4.95, Bit HRS = 26.02 Jars = 30.91 9/24/2017 9/24/2017 6.00 PRODS DRILL DDRL P Drill 6 3/4" hole from 12,003' MD 12,003.0 12,517.0 00:00 0600 3,909' TVD - 12,517' MD 3,903' TVD, 270 GPM at 2,500 PSI DPP. 21% F/O 140 RPM, 8K TO, with 2.5K WOB. ECD's 11.43 PPG EMW, Off BTM 2,495 PSI DPP, UP WT= 160K DWN WT=74K. ROT =11OK. 8K TO. Max gas = 140 units. ADT - 4.02, Bit HRS = 30.04 Jars = 34.93 SPR's @ 12,095" MD 3,909" TVD - MW 9.2 PPG Time 00:55 MP 1) 20 SPM = 520 PSI 30 SPM = 750 PSI MP 2) 20 SPM = 520 PSI 30 SPM = 740 PSI 9/24/2017 9/24/2017 6.00 PROD3 DRILL DDRL P Drill 6 3/4" hole from'12,51T MD 3,903' 12,517.0 13,177.0 06:00 12:00 TVD - 13,177' MD 3,934' TVD, 270 GPM at 2,705 PSI DPP. 21 % F/O 120 RPM, 8.5K TO, with 5K WOB. ECD's 10.71 PPG EMW, Off BTM 2,700 PSI DPP, UP WT=175K DWN WT= 68K. ROT= 120K. 8.2K TO. Max gas = 65 units. ADT - 3.78 Bit HRS = 33.82 Jars = 38.71 Page 42179 Report Printed: 1013012017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time EMTme Dur(hr) Phase Op Code Actmty Cw Time P -T -X owaW ^S) Ehd Depth(aKSJ 9/24/2017 9/24/2017 3.00 PROD3 DRILL DDRL P Drill 63/4" hole from 13,177'MD 3,934' 13,177.0 13,435.0 12:00 15:00 TVD - 13,435' MD 3,924' TVD, 270 GPM at 2,820 PSI DPP. 21% F/O 140 RPM, 8.5K TQ, with 5K WOB. ECD's 11.81 PPG EMW, Off BTM 2,810 PSI DPP, UP WT = 177K DWN WT = 67K. ROT= 117K. 8.4K TQ. Max gas = 200 units. ADT - 1.84 Bit HRS = 35.66 Jars = 40.55 SPR's @ 13,199" MD 3,935" TVD - MW 9.2 PPG Time 12:10 MP 1) 20 SPM = 620 PSI 30 SPM = 870 PSI MP 2) 20 SPM = 620 PSI 30 SPM = 860 PSI 9/24/2017 9/24/2017 1.25 PRODS CASING CIRC P Obtain survey and SPR's. CBU and 13,435.0 13,430.0 15:00 16:15 recip from 13,430 MD - 13,379' MD. @ 270 GPM 2,790 PSI DPP, 21 % F/O, 150 RPM, 8K TQ, 4,500 STKS pumped. SPR's @ 13,435" MD 3,924" TVD - MW 9.2 PPG Time 15:00 MP 1) 20 SPM = 680 PSI 30 SPM = 920 PSI MP 2) 20 SPM = 660 PSI 30 SPM = 900 PSI 9/24/2017 9/24/2017 0.50 PROD3 CASING OWFF P OWFF 13,430.0 13,430.0 16:15 16:45 9/24/2017 9/25/2017 7.25 PRODS CASING BKRM P BROOH form 13,430' MD - 10,900' 13,430.0 10,900.0 16:45 00:00 MD at 270 GPM 2,265 PSI DPP. 20% F/O, 150 RPM, 6.5K TQ. 11.41 ECD EMW. UP WT= 137K, DWN WT = 756K Monitor disp via TT. 9/25/2017 9/25/2017 7.50 PROD3 CASING BKRM P Continue to BKRM OOH from 10,900' 10,900.0 8,169.0 00:00 07:30 MD -8,169' MD. 270 GPM @ 1,880 PSI DPP. 150 RPM with 5K TO. ECD =10.57, UP WT=130, DWN WT= 75K. 9/25/2017 9/25/2017 0.50 PRODS CASING TRIP P POOH on elevators from 8,169' MD- 8,169.0 7,788.0 07:30 08:00 7,788' MD UP WT = 126K, DWN WT = 80K 9/25/2017 9/25/2017 1.50 PRODS CASING CIRC P Circulate while rotating from 7,783' 7,788.0 7,788.0 08:00 09:30 MD - 7,700' MD. 270 GPM @ 1,850 PSI DPP. 19% F/O. 120 RPM, with 5K TQ. 9.25 PPG MW. 5,400 STKS pumped. UP WT = 118k, DWN TWT = 86K 9/25/2017 9/25/2017 0.50 PROD3 CASING OWFF P OWFF> PJSM for SLIP/CUT 7,788.0 7,788.0 09:30 10:00 9/25/2017 9/25/2017 0.75 PRODS CASING SLPC P SLPC 73' 7,788.0 7,788.0 10:00 10:45 9/25/2017 9125/2017 0.25 PROD3 CASING SVRG P Service top drive, Blocks and crown. 7,788.0 7,788.0 10:45 11:00 9/25/2017 9/25/2017 0.25 PROD3 CASING CIRC P Pump wieghted slug. 7,788.0 7,788.0 11:00 11:15 Page 43/79 ReportPrinted: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sent Time End Time Our (hr) Phase Op Code Aodvdy Code Time P -T -X Operahon Start Depth (ftKa) End Depth ntKa) 9/25/2017 9/25/2017 4.25 PROD3 CASING TRIP P Blow down top drive and POOH from 7,788.0 306.0 11:15 15:30 7,788' - 306' MD. Monitor Disp via TT. UP WT=121K OWN WT=83K. 9/25/2017 9/25/2017 1.25 PROD3 CASING SHAH P Monitor well for 10 min then lay down 306.0 0.0 15:30 16:45 BHA as per SLB rep. 9/25/2017 9/25/2017 0.50 PRODS CASING BHAH P Clean rig floor and clear all tools. 0.0 0.0 16:45 17:15 9/25/2017 9/25/2017 0.25 COMPZ3 FISH SFTY P PJSM for BHA handling. 0.0 0.0 17:15 17:30 9/25/2017 9/25/2017 1.50 COMPZ3 FISH BHAH P MU whipstock retrieving assym as per 0.0 230.0 17:30 19:00 Baker rep. 9/25/2017 9125/2017 1.00 COMPZ3 FISH TRIP P RIH with BHA # 15 to retrieve 230.0 1,638.0 19:00 20:00 whipstock. monitor disp via TT. 9125/2017 9/25/2017 0.50 COMPZ3 FISH DHEO P Shallow pulse test SLB BHA for 1,638.0 1,638.0 20:00 20:30 communications. 250 GPM Q 1,060 PSI DPP. 18% F/O. UP WT = 67K. OWN WT 70K. 9125/2017 9/25/2017 3.00 COMPZ3 FISH TRIP P Continue to RIH from 1,638' MD to 1,638.0 7,828.0 20:30 23:30 7,828' MD. Monitor disp via #5. Fill pipe every 20 STNDS. 9/25/2017 9/26/2017 0.50 COMPZ3 FISH FISH P Mousehole botm single stand 82. 7,828.0 7,848.0 23:30 00:00 obtain toolface orientation with 250 GPM 1,440 PSI, 19% F/0. wash whipstock slot then orient 180 degrees and latch hook. UP WT = 136K DWN WT = 105K 9/26/2017 9/26/2017 0.50 COMPZ3 FISH FISH P Pull whipstock free per Baker. Jar as 7,848.0 7,750.0 00:00 00:30 follows: 2 x times with 40k overpull, 4 x times with 60k overpull, 3 x times with 70k overpull, and 1 x time with 80k overpull. Observe whipstock come free when jarring with 80k overpull. Pick up to 7750' MD. PUW 147k. 9/2612017 9/26/2017 1.50 COMPZ3 FISH CIRC P Circulate 2 x bottoms up at 253 gpm, 7,750.0 7,750.0 00:30 02:00 1395 psi, 18% F/O. Observe initial loss of 40 bbls downhole and then dynamic losses of 13 bbl/hr. Total of 4700 strokes pumped. 9/26/2017 9/26/2017 0.50 COMPZ3 FISH OWFF P Monitor well for flow -observe fluid 7,750.0 7,750.0 02:00 02:30 level drop -1 ft over 30 minutes. Drop 2.1" OD hollow drift on stand #80. 9/26/2017 9126/2017 5.00 COMPZ3 FISH TRIP P Pull out of hole on elevators racking 7,750.0 231.0 02:30 07:30 back 4" DP and HWDP from 7750' to 231' MD, monitoring displacement via trip tank. 9126/2017 9/2612017 2.25 COMPZ3 FISH SHAH P Lay down whipstock retrieval BHA #15 231.0 0.0 07:30 09:45 and whipstock per Baker from 231' to surface. Observe whipstock wear pattern -33° right of center at bottom of slide. Observe small amount of gas trapped below whipstock, no issues breaking out. 9126/2017 9/26/2017 0.75 COMPZ3FISH BHAH P Clean and clear rig floor of whipstock 0.0 0.0 09:45 10:30 equipment. 9/26/2017 9/26/2017 1.50 COMPZ3 CASING KURD P Rig up casing tools to run 4-1/2" lower 0.0 0.0 10:30 12:00 completion. Page 44179 Report Printed: 1 013 0/2 01 7 FA d =M�! Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tme End Time du hr ( ) Phase op Cale Activity Code Time P -T -X OperaLon Stan Deplh (ftKB) End Deptll (WIS) 9/26/2017 9/26/2017 0.75 (OMPZ3 CASING RURD P Mobilize pups to rig floor, confirm pipe 0.0 0.0 12:00 12:45 count, and hold PJSM for running liner. 9/26/2017 9/26/2017 8.75 COMPZ3 CASING PUTB P Pickup bent shoe and run in hole with 0.0 5,338.0 12:45 21:30 4-1/2" 11.6# L-80 IBTm slotted liner with 4-1/2" 12.6# L-80 blank joints and 6" OD swell packers to 5338' MD per tally. Run total of 1 x bent shoe joint, 109 x 4-1/2" 11.6# L-80 IBTm slotted liner, 14 x 4-1/2" 12.6# L-80 TXPm blank liner, and 3 x 6" OD Baker swell packers with -2.7' long elements. Run total of 130 x 6-1/8" thick-walled Volant hydroform centralizers. Install 1 x free-floating on everyjoint and install above and below each swell packer element. MUT for 4-1/2" IBTm of -4500 ft -lbs. MUT for 4-1/2" TXPm of -7000 ft -lbs. No remakes / no rejects. Monitor displacement via trip tank. 9/26/2017 21:30 9/26/2017 1.00 COMPZ3 CASING OTHR P Change out handling equipment, rig 5,338.0 5,368.0 22:30 up false bowl, and install SLB slimpulse in string. Make up Baker "B- 3" Flanged Hook Hanger assembly and scribe. 130° toolface offset measured MWD highside to 180" off from hook. 926/2017g/26/2017 22:30 0.25 COMPZ3 CASING CIRC P Make up stand of 4" DP and -break 5,368.0 5,368.0 22:45 circulation, staging up pump to 2.5 bpm, 340 psi, 11% F/O. With pumps off, obtain PUW 87k, SOW 74k. 9/26/2017 22:45 926/2017 23:00 0.25 C0MPZ3 CASING RUNL P Run 4-1/2" lower completion in on 4" 5,368.0 5,835.0 DP from 5368' to 5835' MD 9/26/2017 23:00 9/26/2017 0.50 COMPZ3 CASING DHEO P Shallow hole test SLB Slimpulse at 90 5,835.0 5,835.0 23:30 gpm, 290 psi, 9% F/O -good test. Blow dow topdrive. 23:30 017 23:30 9272017 0.50 COMPZ3 CASING RUNL P Run 4-1/2" lower completion in on 4" 5,835.0 6,792.0 00:00 DP from 5835' to 6792' MD, monitoring displacement via trip tank. PUW 97k, SOW 77k. OA pressure at midnight = 20 psi Total downhole losses for past 24 hours= 101 bbls 9/27/2017 00:00 9/27/2077 0.50 COMPZ3 CASING RUNL P Run 4-12" lower completion in on 4" 6,792.0 7,829.0 00:30 DP from 6792'to 7829' MD, monitoring displacement via trip tank. 9127/2017 00:30 9/27/2017 0.50COMPZ3 CASING CIRC P Break circulation above window with 7,829.0 7,829.0 01:00 88 gpm, 358 psi, 9% F10, PUW 109k, SOW 82k. Blow down topdrive. 9/27/2017 01:00 9/27/2017 3.00 50MPZ3 CASING RUNL P Run 4-1/2" lower completion in on 4" 7,829.0 13153.0 04:00 DP and 4" HWDP from 7829' to , 13153' MD, monitoring displacement via trip tank. No issues running bent joint through window. Calculated displacement = 81.8 bbls, Actual displacement = 42.2 bbls. Page 45/79 Report Printed: 1 0/3 01201 7 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sfatt Titre End Time Our (hr) Phase Op Code Ac"Cotle Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 9/27/2017 9/27/2017 1.00 COMPZ3 CASING RUNL P Kelly up and pump at 90 gpm, 590 psi, 13,153.0 13,204.2 04:00 05:00 9% F/O. Orient to 154° right and run in hole Won stand #84 to 13213' MD, puffing hook 10' past window - no issues. Pick up and orient to 20° lett. Run in hole and engage hook hanger 50.5' in on stand #84. Set down 20k weight and confirm orientation 20° left. Pick up 15', run back in, see slight bobble of weight 50.5' in on stand #84 then engage hook at 52'm on stand #84. Set down 20k and confirm orientation 20° left. Total of 717 strokes pumped. 9/27/2017 9/27/2017 1.25 COMPZ3 CASING CIRC P Drop 29/32" phenolic ball and pump 13,204.2 7,835.0 05:00 06:15 down, 139 gpm, 990 psi, 12 % F/O for 350 strokes, then 85 gpm, 540 psi, 9% F/O for 150 strokes, then 66 gpm, 429 psi, 7% F/O for 100 strokes, then 44 gpm, 328 psi, 4% F/O to seat ball. Ball on seat at 645 strokes. Pressure up to 3300 psi and hold to release liner running tool. Continue pressuring up to 4450 psi with mud pump to shear ball seat - no shear observed. Bleed off pressure, line up test pump, pressure up with mud pump to 4100 psi, and continue pressuring up with test pump to shear ball seat. Observe shear at 4850 psi (pinned for 4000 psi shear). Pick up above hook hanger to 7835' MD, PUW 142k. Top of L2 hook hanger set at 7840.0' MD L2 Shoe set at 13204.2' MD 9/27/2017 9/27/2017 0.50 COMPZ3 WELLPR OWFF P Monitor well for flow -observe fluid 7,835.0 7,835.0 06:15 06:45 level drop 6 inches over 30 minutes. Blow down topdrive. 9/27/2017 9/27/2017 3.75 COMPZ3 WELLPR TRIP P Trip out of hole on elevators, racking 7,835.0 0.0 06:45 10:30 back 4" HWDP and 4" DP from 7835' to surface, monitoring displacement via trip tank. Calculated displacement = 57 bbls. Actual displacement = 69.9 bbls. 9/27/2017 9/27/2017 0.50 COMPZ3 WELLPR BHAH P Lay down Baker hook hanger running 0.0 0.0 10:30 11:00 tools and SLB SlimPulse. 9/27/2017 9/27/2017 0.25 COMPZ3 WELLPR BHAH P Clean and clear rig floor of running 0.0 0.0 11:00 11:15 tools. 9/27/2017 9/27/2017 0.50 COMPZ3 RWWRID TURD 5 Rig up to run L2 LEM / ZXP assembly 0.0 0.0 11:15 11:45 with GER torque turn and hold PJSM. Page 46179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start' me EM Tme Dur (hr) Phase op code Ac q Cmie Time P -T -X Ope"'e"m Start Depth (Wfl) End Depth (fe(9) 9/27/2017 9/27/2017 2.75 COMPZ3 RWRID PUTB P Make up LEM / ZXP assembly for L2 0.0 242.0 11:45 14:30 lateral to 242' MD with SLB SlimPulse installed. GBR utilize torque turn while making up TXP connections to 7000 It -lbs, no issues observed. Scribe MWD offset to 177.56°. Had issue stinging in seal assembly but eventually got it installed. 9/27/2017 9/27/2017 0.75 COMPZ3 RWRID CIRC P Run in hole on 1 x stand 4" DP to 337' 242.0 337.0 14:30 15:15 MD and break circulation at 2 bpm, 310 psi, 9% F/0, no issues observed. Blow down topdrive. 9/27/2017 9/27/2017 1.50 COMPZ3 RWRID RCST P Run in hole with L2 LEM / ZXP 337.0 2,137.0- 16:15 16:45 assembly on 4" DP from 337' to 2137' MD, monitoring displacement via trip tank. 9/27/2017 9/27/2017 0.25 COMPZ3 RWRID DHEQ P Shallow hole test MWD SlimPulse with 2,137.0 2,137.0 16:45 17:00 92 gpm, 320 psi, 10% F/O. PUW 73k, SOW 75k. Blow down topdrive. Note: Low end at 70 gpm, high end at 150 gpm for tool. 9/27/2017 9/27/2017 3.25 COMPZ3 RWRID RCST P Run in hole with L2 LEM /ZXP 2,137.0 7,838.0 17:00 20:15 assembly on 4" DP and 4" HWDP from 2137'to 7838' MD, monitoring displacement via trip tank. PUW 143k, SOW 109k 9/27/2017 9/27/2017 1.00 COMPZ3 RWRID PACK P Establish circulation at 90 gpm, 550 7,838.0 7,948.0 20:15 21:15 psi, 9% F/0. Wash down from 7838' and orient LEM to 80" left. No issues running muleshoe through hook hanger or entering L1 LTP. Run in and bury stand #82 to 7930.48' MD. Make up 4" DP single and continue washing in hole. Locate LEM in hook hanger 17.5' in on single. Slack off to 90k HL (19k set down) and observe toolface roll to 26° left. Confirm orientation at 26° left, Pick up to 155k (12k overpull) and confirm latched. 9/2712017 9/27/2017 1.25 COMPZ3 RWRID PACK P Drop 1.625" frac ball and pump down 7,948.0 7,948.0 21:15 22:30 at 3 bpm, 780 psi, 13% F/O for 350 strokes, then 2 bpm, 490 psi, 10% F/0 for 150 strokes, then 1.5 bpm, 385 psi, 8% F/O. Ball on seat at 558 strokes. Increase pressure to 2300 psi and hold for 1 minute, observing pusher tool shear at 2300 psi. Stage up pressure to 4000 psi, observing pusher tool neutralize at 3600 psi. Bleed off pressure and pick up to 146k. Slack off to 90k and pick up to 150k - not released. Slack off to 90k and pressure up to 4400 psi with mud pump. Slack off to 80k HL. Bleed off pressure and pick up, observing breakover at 147k - confirm released. Page 47179 Report Printed: 10/30/2017 . Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Our (hr) Phase Op Cotle Acwoy Code Time P -T -X Operation swn Depm (ftKB) End O ph (MB) 9/27/2017 9/27/2017 0.50 COMPZ3 RWRID PRTS P Close bag and pump down IA with 7,948.0 7,948.0 22:30 23:00 mud pump #1 to pressure test L2 liner top packer. Pressure up to 3500 psi and hold for 10 minutes, charted - good test. Pumped 3.6 bbls, returned 3.6 bbls. Bottom of seal assembly at 7947.98' MD - spaced out 4.24' off no-go Top of L2 Liner Top Packer at 7718.30' MD 9/27/2017 9/27/2017 0.50 COMPZ3 RWRID CIRC P Lay down single and continue pulling 7,948.0 7,718.0 23:00 23:30 up to place ports at top of liner tieback sleeve for high circulation rate. Pump 26 bbls corrosion inhibited brine and spot with 73 bbls of 9.3ppg FloPro at 213 gpm, 665 psi, 17% F/O. Note: Circulation port is above the SlimPulse 9/27/2017 9/28/2017 0.50 COMPZ3 RWRID OWFF P Rack back stand to 7642' MD, blow 7,718.0 .7,642.0 23:30 00:00 down topddve, and monitor well for 30 minutes. OA pressure at midnight = 30 psi Downhole losses for past 24 hours = 53 bbls. 9/28/2017 9/28/2017 0.25 COMPZ3 RWRID OWFF P Finish monitoring well for flow and 7,642.0 7,642.0 00:00 00:15 blow down kill line. 9/28/2017 9/28/2017 5.75 COMPZ3 RWRID TRIP P Trip out of hole on elevators from 7,642.0 87.0 00:15 06:00 7642' to 87', racking back 4" HWDP and 4" DP and adjusting supersliders per W WT as needed. 9/28/2017 9/28/2017 0.75 COMPZ3 RWRID BHAH P Lay down LEM / ZXP running tools 87.0 0.0 06:00 06:45 and SLB Slimpulse. 9/28/2017 9/28/2017 0.50 COMPZ3 RWRID SHAH P Clean and clear dg floor of running 0.0 0.0 06:45 07:15 tools. 9/28/2017 9/28/2017 1.25 PROD4 WHPST BHAH P Mobilize whipstock BHA to rig floor, 0.0 0.0 07:15 08:30 confirm spaceout, and mobilize spaceout pups to dg floor. Hold PJSM. 9/28/2017 9/28/2017 3.00 PROD4 WHPSTBHAH P Make up 6-3/4" milling assembly with 0.0 307.0 08:30 11:30 Slimpulse MWD and scribe, 242.11 ° TFO. Rack back milling assembly. Make up 7-5/8" Gen II whipstock assembly and bolt up milling assembly with 25k shear bolt. RIH to 307' MD. SOW 57.5k 9/28/2017 9/28/2017 1.50 PROD4 WHPST TRIP P Trip in hole with whipstock assembly 307.0 2,197.0 11:30 13:00 on 4" DP from 307'to 2197' MD, II monitoring displacement via trip tank. 9/28/2017 9/28/2017 0.50 PROD4 WHPST DHEQ P Shallow hole test MWD with 213 gpm, 2,197.0 2,197.0 13:00 13:30 605 psi, 16% F/O - no issues. Note: Flow range is 175 - 330 gpm 9/28/2017 9/28/2017 4.25 PROD4 WHPST TRIP P Trip in hole with whipstock assembly 2,197.0 7,625.0 13:30 17:45 on 4" DP and 4" HWDP from 2197' to 7625' MD,filling pipe every 20 x stands and monitoring displacement via pit #1. Page 48179 Report Printed: 1 0/3 012 01 7 . Operations Summary (with Timelog Depths) ,. 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Our (hr) Phase Op Code Activity Code Cotle Time P -T -X Operebon Depth (WB) Entl Depth(ftKa) 9/28/2017 9/28/2017 0.50 PROD4 WHPST WEST P Establish circulation at 200 gpm, 1000 7,625.0 7,625.0 17:45 18:15 psi, 15% F/O and orient whipstock to 22° left. PUW 142k, SOW 111k 9/28/2017 9/28/2017 0.50 PROD4 WHPST WPST P Wash in hole from 7625', SOW 110k, 7,625.0 7,647.0 18:15 1845 Observe -1k drag as seals entered top of liner. Locate top of liner at 7719.09' MD (0.79' deep, -amount that pusher tool compress LTP). Slack off to 105k HL (6k set down) and observe good indication of anchor shear. Confirm whipstock orientation at 22° left. Kill pump and pick up to 150k HL (8k overpull) - confirm anchor set. Slack off to 80k HL (30k set dawn) and observe good indication of bolt shear. Pick up and observe free travel at PUW 1421k. Top of window @ 7647.0' MD Btm of window @ 7660.7' MD 9/2812017 9128/2017 0.25 PROD4 WHPST WPST P Establish parameters with 200 gpm, 7,647.0 7,647.0 18:45 19:00 1000 psi, 16% F/O, 20 rpm, 4.5k ft -lbs off-btm torque. 9/28/2017 9129/2017 5.00 PR0D4 WHPST MILL P Mill 6-3/4" window for L3 lateral from 7,647.0 7,657.0 19:00 0000 7647' to 7657' MD per Baker with 300 gpm, 1880 psi, 21% F/O, 100 rpm, 3- 5k Tq, 3K WOB, 9.3ppg in/out MW with 65 vis in / 59 vis out. Pump 25 bbl hi -vis super sweep at 7652' MD, observe moderate increase in metal cuttings over shakers. Mill out on pit #1 only, keeping other FloPro isolated. Downhole losses for past 24 hours = 24 bbls OA pressure at midnight = 360 psi 9/29/2017 9/29/2017 7.75 PR0D4 WHPST MILL P Mill 6-3/4" window for L3 Lateral from 7,657.0 7,685.0 00:00 07:45 7657' to 7685' MD with 300 gpm, 1850 psi, 21 % F/O, 100 rpm, 3-7k Tq, 5-12k WOB. Pump super sweeps per Baker rep. Mill out on pit #1 only, keeping other FloPro isolated. Note: -7 ft of gauge 6-3/4" hole to 7668' MD, rathole to 7685' MD TOW @ 7647,0' MD BOW @ 7660.7' MD 9/29/2017 9/29/2017 0.50 PROD4 WHPST REAM P Pump super sweep at TD with 300 7,685.0 7,637.0 07:45 0815 gpm, 1850 psi, 21% f/O, 100 rpm, 3- 4k Tq and ream through window - no issues. Kill rotary, drop flow to 86 gpm, 618 psi, 11 % F/O and wash up and down through window - no issues. Pumps on PUW 140k, SOW 104k. Rack back stand to 7637' MD. Page 49/79 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) IH-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time log Siert Time EM Time Our hr ( ) Phase Op Cpr� Aprvity Cotle Time P-T-X Cperalim San Depth MKa) EM Depth (flKa) 9/29/2017 9/29/2017 0.50 PROD4 WHPST CIRC P Circulate sweep out while staying 7,637.0 7,637.0 08:15 08:45 above window with 300 gpm, 1800 psi, 21% F/O, MW in/out 9.3ppg. Moderate amount of metal cuttings observed once sweep at surface. Obtain SPR's. Total 3400 strokes pumped. SPRs @ 7633' MD 3806' TVD, MW=9.30 ppg, 08:39 hours MP#1: 20 spm=610 psi, 30 spm=780 psi. MP #2: 20 spm=600 psi, 30 spm=740 psi. 9/29/2017 9/29/2017 1.00 PROD4 WHPST FIT P Rig up and Perform FIT for L3 window 7,637.0 7,637.0 08:45 09:45 to 12.9ppg EMW. Close annular, pump down drill pipe and IA with mud pump #1. Pressure up to 715 psi and shut in, observe pressure drop to 595 Psi after 10 minutes. Pumped 0.9 bbl, returned 0.9 bbl. Rig down and blow down equipment. 9/29/2017 09:45 9/29/2017 0.50 PROD4 WHPST OWFF P Monitor well for flow - observe fluid 7,637.0 7,637.0 10:15 level drop -3 inches. 9/29/2017 9/29/2017 0.25 PROD4 WHPST TRIP T7--- Trip OOH from 7639' to 7436' MD, 7,637.0 7,436.0 10:15 10:30 racking back 4" HWDP stands, monitoring displacement via trip tank. Note: Lay down top single of stand #77 to switch breaks on the stands. 9/29/2017 10:30 9/29/2017 0.25 PROD4 WHPST CIRC P Pump dry job, install stripping rubbers, 7,436.0 7,436.0 10:45 and blow down topddve. 9/29/2017 9/29/2017 4.00 PROD4 WHPST TRIP P Tdp OOH from 7436' to 23V MD, 7,436.0 231.0 10:45 14:45 racking back 4" DP and 4" HWDP, monitoring displacement via trip tank. 9/29/2017 9/29/2017 1.00 PROD4 WHPST BHAH P Lay down milling BHA from 231' to 231.0 0.0 14:45 15:45 surface. Clean off metal from each magnet - pockets mostly full on each magnet. Lay down MWD tool and gauge mills. Upper 6-3/4" Mill - In Gauge Lower 6-5/8" Mill - 1/4" undergauge Window 6-3/4" Mill - 1/2" undergauge 9/29/2017 9/29/2017 0.50 PROD4 WHPST BHAH P Clean and clear rig floor of BHA tools. 0.0 0.0 15:45 16:15 9/29/2017 9/29/2017 0.75 PROD4 WHPST W W WH P Make up stack washer and jet stack 0.0 0.0 16:15 17:00 with 21 bpm, 150 psi. SIMOPS - mobilize motor BHA to rig floor. 9/29/2017 9/29/2017 2.00 PROD4 WHPST BHAH P Make up 6-3/4" motor BHA with 1.51 0.0 896.0 17:00 19:00 motor and run in hole to 896' MD. Monitor displacement via trip tank. Note: Re-run 6-3/4" milkooth bit and 1.5" motor as they are both in good shape and low hours. 9/29/2017 9/29/2017 1.00 PROD4 WHPSTTRIP P Trip in hole on 4" DP from 896' to=,0871D 19:00 20:00 2087' MD, monitoring displacement via trip tank. Page 50/79 Report Printed: 10130/2077 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Torre EM Imre Our (het Phase rap Cade Adrvny Code Time P -TA Opmlon Start Depb (ftKB) End Depth (AKS) 9/29/2017 9129/2017 0.50 PROD4 WHPST DHEO P Fill pipe and shallow hole test MWD 2,087.0 2,087.0 20:00 20:30 tool at 270 gpm, 1235 psi, 21 °k F/O - good test. Blow down top drive. 9/29/2017 9/29/2017 2.75 PROD4 WHPST TRIP P Trip in hole on 4" DP and 4 HWDP 2,087.0 7,556.0 20:30 23:15 from 2087'to 7556' MD, monitoring displacement via trip tank and filling pipe every 20 x stands. PUW 148k, SOW 108k. Note: Replace 4" HWDP single on top of same stand it was removed from. 9/29/2017 9129/2017 0.50 PROD4 WHPST CIRC P Kelly up and orient motor to 22° left 7,556.0 7,675.0 23:15 23:45 with 275 gpm, 2010 psi, 22% F/O. Kill pump and trip in from 7556' to 7675' MD - no drag observed tripping through window. Observed string start taking 1-2k drag at 7668' MD, end of gauge hole. Continue tripping in and observe 5-6k weight at 7675' MD. Pick up 7 ft and trip in, setting down 5-6k weight at 7675' MD. 9/29/2017 9/30/2017 0.25 PROD4 WHPST WASH P Wash down from 7675'to 7685' MD 7,675.0 7,685.0 23:45 00:00 with 250 gpm, 1760 psi, 18°k F/O, 4- 7k WOB. Observe hard spot between 7675'- 7677' MD. OA pressure at midnight = 0 psi Downhole losses for past 24 hours = 20 bbls 9/30/2017 9/3012017 3.00 PROD4 DRILL DDRL P Directionally drill 6-3/4" production L3 7,685.0 7,918.0 00:00 03:00 lateral from 7685' to TO of 7918' MD, 3882' TVD. TO called early per Geo as we obtained higher than expected motor yield (15' versus 12°) that put us in pay zone quicker. Pump at 250 gpm, 1850 psi on-btm, 1750 psi off- btm, 19% F/O. Rotate at 30 rpm, 5k Tq on-btm, 3.5k Tq off-blm. 5-8k WOB. Max gas 39 units. PUW 138k, SOW 11 ok, ROT 114k. ADT 1.43 hrs, AST 0.67 hrs, Bit 9.79 hrs, Jar 41.98 hrs. Displace wellbore to new/used 9.2ppg Flo -Pro on the fly on first full stand and put on full active system, dumping all milling fluid. Note: Observed flow -out reading drop & gas unit reading rise once started dumping milling fluid returns to rockwasher. Actual flow out did not change, nor did gas units increase. Rig is investigating the issue with the sensors when we dump fluid to rockwasher. SPRS Q 7822' MD 3851' TVD, MW=9.20 ppg, 01:40 hours MP#1: 20 spm=440 psi, 30 spm=620 psi. MP #2: 20 spm=430 psi, 30 spm=610 psi. Page 51179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 • Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation San DepN (ftKB) EM Depth (BKB) 9/302017 9/30/2017 0.50 PRO04 DRILL CIRC P Obtain final survey and circulate hole 7,918.0 7,824.0 03:00 03:30 clean around BHA, backreaming stand from 7918'to 7824' with 270 gpm, 1955 psi, 50 rpm, 4.5k Tq. Orient to 16" left and rack back stand. 9/30/2017 9/30/2017 0.50 PROD4 DRILL OWFF P Blow down topdrive and monitor well 7,824.0 7,824.0 03:30 04:00 for flow - observe fluid level drop -6 inches over 30 minutes 9/30/2017 9/30/2017 0.50 PROD4 DRILL TRIP P Trip out of hole from 7824'to 7550' 7,824.0 7,550.0 04:00 04:30 MD. PUW 143k, SOW 111k. Observed 3-5k drag in open hole. No drag observed pulling BHA through window. 9/30/2017 9/30/2017 0.25 PROD4 DRILL CIRC P Pump dry job with 170 gpm, 760 psi. 7,550.0 7,550.0 04:30 04:45 1 Blow down top drive. 9/30/2017 9/30/2017 3.25 PROD4 DRILL TRIP P Trip out of hole from 7550' to 895' MD, 7,550.0 895.0 04:45 08:00 racking back 4" HWDP and 4" DP, monitoring displacement via trip tank. 9/30/2017 9/30/2017 0.25 PROD4 DRILL OWFF P Monitor well for flow at top of BHA - 895.0 895.0 08:00 08:15 well static. 9/30/2017 9/30/2017 2.25 PROD4 DRILL BHAH P Pull out of hole from 895'to surface. 895.0 0.0 08:15 10:30 Cleani off magnets and lay down. Rack back jar stand and lay BHA per SLB. Bit was in good shape, graded 0- O -NO -A -E -0 -NO -BHA. 9/30/2017 9/30/2017 0.50 PROD4 DRILL SHAH P Clean and clear rig floor of BHA and 0.0 0.0 10:30 11:00 mobilize RSS BHA to floor. 9/30/2017 9/30/2017 0.75 PROD4 DRILL W W WH P Make up stack washer and jet stack 0.0 0.0 11:00 11:45 with 20 bpm, 130 psi, 38% F/O, 10 rpm. 9/302017 9/30/2017 0.75 PROD4 DRILL RURD P Pull wearbushing, clean off, and re- 0.0 0.0 11:45 12:30 install same. 9/30/2017 9/30/2017 1.00 PROD4 DRILL BHAH P PJSM. Make up RSS BHA to 306' with 0.0 306.0 12:30 13:30 6-3/4" Smith AxeBlade PDC bit, X6 Powerddve, 4-3/4" Periscope, 4-3/4" ImPulse, 6-5/8" NM stabilizer, 4-3/4" flex NMDC, 4" HWDP, and 4-3/4" hydraulic jars. Monitor displacement vita pit #5. 9/30/2017 9/30/2017 1.00 PROD4 DRILL TRIP P Trip in hole from 306' to 2195' MD on 306.0 2,195.0 13:30 14:30 4" DP stands slick, monitoring displacement via pit #5. 9/302017 9/302017 0.25 PROD4 DRILL DHEQ P Fill pipe and shallow hole test MWD 2,195.0 2,195.0 14:30 14:45 with 200 gpm, 760 psi, 16% F/O - good test. Blow down top drive. 9/30/2017 9/30/2017 1.50 PROD4 DRILL TRIP P Trip in hole from 2195'to 5044' MD on 2,195.0 5,044.0 14:45 16:15 4" DP stands slick, monitoring displacement via pit #5 and filling pip every 20 x stands. 9/30/2017 9/30/2017 1.25 PROD4 DRILL PULD P Run in hole from 5044' to 6370' MD 5,044.0 6,370.0 16:15 17:30 picking up 4" DP singles from shed, PUW 106k, SOW 86k. Monitor displacement via pit #5 and fill pipe every 20 x stands. 9/30/2017 9/30/2017 0.50 PROD4 DRILL TRIP P Trip in hole from 6370' to 7124' MD on 6,370.0 7,124.0 1730 18:00 4" DP stands slick, monitoring displacement via pit #5, filling pipe every 20 x stands. Page 52179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sten rim. End Tim. dia (hd Phase op Cove ACWttr Coda Time P -r -x op.raZ son Depth (eKe) End Depth(mca) 9/30/2017 9/30/2017 1.50 PROD4 DRILL SVRG P Service topdrive.lnspect saver sub 7,124.0 7,124.0 18:00 19:30 and decision made to change out due to wear. 9/30/2017 9/30/2017 0.75 PROD4 DRILL TRIP P Trip in hole from 7124'to 7601' MD on 7,124.0 7,601.0 19:30 20:15 4" DP stands slick, monitoring displacement via pit #5. Fill pipe. 9/30/2017 9/30/2017 0.25 PROD4 DRILL TRIP P Run in hole from 7601'to 7670' MD, 7,601.0 7,670.0 20:15 20:30 picking up 4" DP stands with super sliders. PUW 115k, SOW 85k. Observe bit tagging up on top of whipstock at 7647' MD, max 5k set down. Attempt to trip past several times with no luck. Pick up above whipstock and put in 1.5 wraps and work down. Attempt to trip past with no luck. Pick up above whipstock, engage pump at 128 gpm, 510 psi, 12% F/O, put in 5 wraps, and attempt to wash past, no luck, still tagging up on top of whipstock, max 5k set down. Pick up above whipstock, increase rate to 212 gpm, 1140 psi, 16% F10 to help engage powerddve pads to rock bit past top of whipstock, put in 5 wraps, and wash down across window successfully. Once bit past top of whipstock, no drag observed across window. 9/30/2017 9/30/2017 0.25 PROD4 DRILL DLOG P Perform MAD pass from 7670' to 7,670.0 7,677.0 20:30 20:45 7677' MD with 242 gpm, 1430 psi, 18% Flo at 300 ft/hr per MWD. 9/30/2017 9/30/2017 1.75 PROD4 DRILL DLOG P Observe bit tagging up at 7677' on 7,677.0 7,918.0 20:45 22:30 concretion. Attempt to wash past several times, setting down 15k weight, no success. With bit and stabilizer in open hole (below window), engage rotary at 15 rpm, 3-4k Tq and ream down to 7692', logging per MWD at 214 gpm, 1172 psi, 16% F/0. Make up stand, engage pumps, and observe ability to wash down without needing anymore rotary. Continue washing down at 242 gpm, 1440 psi, 20% F/O from 7692'to 7918' MD, logging per MWD at 300 ft/hr. Stop and cycle pumps for surveys per DD. Take SPRs. SPRs @ 7878' MD 3828' ND, MW=9.20 ppg, 22:14 hours MP#1: 20 spm=360 psi, 30 spm=520 psi. MP #2: 20 spm=340 psi, 30 spm=510 psi. Page 53179 Report Printed: 1013012017 Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time L400:00 Startnd 9/30/2/2017 Time Our h n 1.50 Phaea PROD4 Op Code DRILL AeNviry Catle DDRL Time P -T -X ppem on Start Depth K8) Em Depen (m e) 22:30 P Directionally drill 6-3/4" production L3 7,918.0 8,043.0 lateral from 7918'to 8043' MD, 3823' TVD. Pump at 267 gpm, 1740 psi, 21 % F/O, ECD 10.36 ppg, MW 9.25 ppg. Rotate at 130 rpm with 4.5k Tq on-btm, 4k Tq off-btm. Max gas 115 units. 1k WOB. PUW 107k, SOW 84k, ROT 95k. ADT 1.24 hrs, Bit 1.24 hrs, Jars 43.22 hrs. OA pressure at midnight = 220 psi. Downhole losses for past 24 hours = 10 Wis. 10/1/2017 00:00 10/1/2017 06:00 6.00 PROD4 DRILL DDRL P Directionally drill 6-3/4" production L3 8,043.0 8,357.0 lateral in WestSak B sand from 8043' to 8357' MD, 3818' TVD. Pump at 269 gpm, 1729 psi, 21% F/O, ECD 10.34 ppg, MW 9.25 ppg. Rotate at 130 rpm with 5.5k Tq on-btm, 4k Tq off-btm. 2- 3k WOB. PUW 111 k, SOW 80k, ROT 92k. Max gas 229 units. ADT 5.03 hrs, Bit 6.3 hrs, Jars 48.28 hrs. Concretions drilled at 8089'- 8096', 8125'- 8140', 8190'- 8204', and 8331' - 8343'. SPRs @ 8066' MD 3822' TVD, MW=9.20 ppg, 00:23 hours MP#1: 20 spm=360 psi, 30 spm=540 psi. MP #2: 20 spm=360 psi, 30 spm=540 psi. 10/1/2017 06:00 10/1/2017 12:00 6.00 PROD4 DRILL DDRL P Directionally drill 6-3/4" production L3 8,357.0 8,871.0 lateral in WestSak B sand from 6357' to 8871' MD, 3817' TVD. Pump at 272 gpm, 1837 psi, 22% NO, ECD 10.6 ppg, MW 9.25 ppg. Rotate at 130 rpm with 6k Tq on-btm, 5.5k Tq off-btm. 2k WOB. PUW 112k, SOW 77k, ROT 95k. Max gas 238 units. ADT 4.16 hrs, Bit 10.46 hrs, Jars 52.44 hrs. Concretions drilled at 8361' - 8365', 8373'- 8375', and 8473'- 8476'. Page 54/79 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sort Time 17 Our (hr) phase Op Code Catle Time P -T -X Operation sort Depth mKa) End Depth (111<13) 10/1/2017 10/1/2017 1/2 6.00 PROD4 DRILL RL DDRL P Directionally drill 6-3/4" production L3 8,871.0 9,700.0 12:00 18:00 lateral in WestSak B sand from 8871' - to 9700' MD, 3836' TVD. Pump at 280 gpm, 2130 psi, 23% F/O, ECD 11.08 ppg, MW 9.25 ppg. Rotate at 180 rpm with 7k Tq on-btm, 61k Tq off-btm. 2k WOB. PUN 118k, SOW 81k, ROT 93k. Max gas 226 units. ADT 4.54 hrs, Bit 15.0 hrs, Jars 56.98 hrs Concretions drilled at 9027' - 9033' and 9116'- 9125' SPRs @ 8925' MD 3819' TVD, MW=9.20 ppg, 12:17 hours MP#1: 20 spm=440 psi, 30 spm=630 psi. MP #2: 20 spm=440 psi, 30 spm=590 psi. 10/1/2017 10/2/2017 6.00 PROD4 DRILL DDRL P Directionally drill 6-3/4" production L3 9,700.0 10,200.0 18:00 00:00 lateral in WestSak B sand from 9700' to 10,200' MD, 3836' TVD. Pump at 272 gpm, 2100 psi, 21 % NO, ECD 11.21 ppg, MW 9.20 ppg. Rotate at 180 rpm with 81k Tq on-btm, 7k Tq off- btm. 2-3k WOB. Max gas 150 units. PLAN 121k, SOW 62k, ROT 92k. ADT 4.46 hrs, Bit 19.48 hrs, Jars 61.46 hrs. Concretions drilled at 9713' - 9716', 9725'- 9748', 9770'- 9796', 9812'- 9815', 9824'- 9834', 9859'- 9876', 9900'- 9904', 9973'- 9974', and 101851-101911. OA pressure at midnight = 345 psi Downhole losses for past 24 hours = 42 bbls 10/2/2017 10/2/2017 6.00 PROD4 DRILL DDRL P Directionally drill 6-3/4" production L3 10,200.0 10,861.0 00:00 06:00 lateral in WestSak B sand from 10,200'to 10,861' MD, 3846' TVD. Pump at 281 gpm, 2254 psi, 21% F/O, ECD 11.2 ppg, MW 9.25ppg. Rotate at 180 rom with 81k on-btm Tq, 7.5k off - birth Tq. 2k WOB. Max gas 296 units. PUN 126k, SOW 60k, ROT 93k. ADT 4.7 hrs, Bit 24.18 hrs, Jars 66.16 hrs. SPRs @ 10245' MD 3837' TVD, MW=9.20 ppg, 00:15 hours MP#1: 20 spm=580 psi, 30 spm=780 psi. MP #2:20 spm=580 psi, 30 spm=800 psi. Concretions drilled at 10548'- 10552', 10567'- 10571', 10667'- 10674', 10680'- 10687', 10712'- 10716', and 10723'- 10727'. Page 55179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tune End Time Dw(hr) Phase Op Code Acta Code ty Time P-- T X Operation $ldrt Depdt n De End Depm (ttK6) 10/2/2017 10/2/2017 6.00 PROD4 DRILL DDRL P Directionally drill 6-3/4" production L3 10,861.0 11,582.0 06:00 12:00 lateral in WestSak B sand from 10,861' to 11,582' MD, 3875' TVD. Pump at 272 gpm, 2310 psi, 21% F/O, ECD 11.58 ppg, MW 9.25 ppg. Rotate at 180 rpm with 8.5k on-btm Tq, 8k off -blm Tq. 2-5k WOB. Max gas 207 units. PUW 129k, SOW 55k, ROT 93k. ADT 3.94, Bit 28.12 hrs, Jars 70.1 hrs. Note: Crossed fault at 10971' with 20' throw. Concretions drilled at 11021'- 11027' and 11347'- 11353'. 10/2/2017 10/2/2017 6.00 PROD4 DRILL DDRL P Directionally drill 6-3/4" production L3 11,582.0 12,360.0 12:00 18:00 lateral in WestSak B sand from 11,582' to 12,360' MD, 3855' TVD. Pump at 270 gpm, 2340 psi, 21 % F/O, ECD 11.37 ppg, MW 9.2ppg. Rotate at 180 rp with 9k on-btm Tq, 7k off-btm Tq. 34k WOB. PUW 1481k, unable to slack off after 12215' MD. ROT 89k. Max gas 180 units. ADT 4.68 hrs, Bit 32.8 hrs, Jars 75.78 hrs. SPRs @j 11673' MD 3868' TVD, MW=9.20 ppg. 12:26 hours MP#1: 20 spm=620 psi, 30 spm=840 psi. MP #2: 20 spm=610 psi, 30 spm=780 psi. Note: At -11,600' MD, observed formation losses increase to -15 bbl/hr and then Fluctuate from 5-20 bbls/hr onward. Performed dump/dilute at -11700'- still seeing issue with Flow % and gas reading - continue troubleshooting. Concretions drilled at 11586'- 11592', 11848'- 11864', 12164'- 12173', 12260'- 12281', and 12284'- 12287'. Page 56179 Report Printed: 10130/2017 ANIML Operations Summary (with Timetog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time EM Time Our (hr) Pryeae Op Cotle Adiviry Coda lima P -i -x Operation Stea Depth(ftKB) EM DOM (WS) 10/2/2017 10/3/2017 6.00 PROD4 DRILL DDRL P Directionally drill 6-3/4" production L3 12,360.0 12,964.0 18:00 00:00 lateral in WestSak B sand from 12,360'to 12,962' MD, 3871' TVD. Pump at 270 gpm, 2490 psi, 21 % F/O, ECD 11.56 ppg, MW 9.2ppg. Rotate at 130 rpm with 9k on-btm Tq, 81k off-btm Tq. 3k WOB. PUW 154k, unable to slack off, ROT 107k. Max gas 310 units. ADT 3.83 hrs, Bit 36.63 hrs, Jars 78.61 hrs. OA pressure at midnight = 290 psi Downhole losses over past 24 hours = 139 bbls. Note: Rig isolated dump line to rockwasher and inspected line - observed the 8ft of level section of 16" dump line was —80% packed off with cement and mud material. Cleaned out line, reinstalled, and discussed future mitigations to ensure we will be able to sufficiently clean this level section of line after future cement jobs. Concretions drilled at 12759'- 12771' and 12800'- 12802'. 10/3/2017 10/3/2017 6.00 PROD4 DRILL DDRL P Directionally drill 6-3/4" production L3 12,964.0 13,519.0 00:00 06:00 lateral in WestSak B sand from 12964' to 13519' MD, 3866' TVD. Pump at 272 gpm, 2645 psi, 21% F/O, ECD 11.71 ppg, MW 9.2ppg. Rotate at 160 rpm with 9k Tq on-btm, 8k Tq off-btm. 2-5k WOB. PUW 164k, unable to slack off, ROT 107k. Max gas 144 units. ADT 3.67 hrs, Bit 40.3 hrs, Jars 82.28 his. SPRs @ 13042' MD 3877' TVD, MW=9.20 ppg, 00:25 hours MP#1: 20 spm=690 psi, 30 spm=920 psi. MP #2: 20 spm=680 psi, 30 spm=910 psi. Concretions drilled at 13063' - 13075', 13232'- 13238', and 13320'- 13325'. 10/3/2017 10/312017 6.00 PROD4 DRILL DDRL P Directionally drill 6-3/4" production L3 13,519.0 14,079.0 06:00 12:00 lateral in WestSak B sand from 13519' to 14079' MD, 3852' TVD. Pump at 272 gpm, 2735 psi, 21 % F/O, ECD 11.97 ppg, MW 9.2 ppg. Rotate at 160 rpm with 9k Tq on-btm, 8k Tq off-btm. 3k WOB. PUW 168k, unable to slackoff, ROT 106k. Max gas 279 units. ADT 3.87 hrs, Bit 44.17 hrs, Jar 86.15 his. Concretions drilled at 13548' - 13553', 13686' - 13692', 13731' - 13739', 13750'- 13762', and 13771'- 13774'. Page 57179 ReportPrinted: 1011n/21117 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stmt Time End Time Dur (hr) Phase OP Cone AUivity Code Times P-T-% Opmbon Start Depth (WB) End Depih(flKB) 10/3/2017 10/3/2017 6.50 PROD4 DRILL DDRL P Directionally drill 6-3/4" production L3 14,079.0 14,686.0 12:00 18:30 lateral in WestSak B sand from 14079' to TO of 14686' MD, 3844' TVD. Pump at 272 gpm, 2770 psi, 21 % F/O, ECD 11.86 ppg, MW 9.2 ppg. Rotate at 180 rpm with 9.5k Tq on-btm, 8k Tq off- btm. 3k WOB. Max gas 110 units. ADT 5.1 hrs, Bit 49.27 hrs, Jars 91.25 hrs. Note: Remained in WestSak B Sand zone 100% throughout the L3 lateral. SPRs @ 10245' MD 3837' TVD, MW=9.20 ppg, 00:15 hours MP#1: 20 spm=580 psi, 30 spm=780 psi. MP #2: 20 spm=580 psi, 30 spm=800 psi. Concretions drilled at 14079'- 14093', 14098'- 14103', 14115'- 14123', 14126' - 14129', 14170' - 14177', 14201'- 14207', 14217'- 14222', 14335' - 14349', 14449' - 14450', 14466'- 14474', 14540'- 14562', and 14663'- 14668' 10/3/2017 10/3/2017 1.50 PROD4 CASING CIRC P Obtain final parameters, downlink 14,686.0 14,615.0 18:30 20:00 powerddve to neutral, and circulate i x bottoms up with 270 gpm, 2760 psi, 20% F/O, 180 rpm, 8k Tq, MW 9.2ppg in / 9.3ppg out. ECD 11.8 ppg. Total of 4500 strokes pumped. PUW 184k, SOW 47k, ROT 117k. Note: After circulating bottoms up, we were able to slack off at -47k HL. SPRs @ 10245' MD 3837' TVD, MW=9.20 ppg, 00:15 hours MP#1: 20 spm=580 psi, 30 spm=780 psi. MP #2: 20 spm=580 psi, 30 spm=800 psi. 10/3/2017 10/3/2017 0.50 PR554 CASING OWFF P Monitor well for Dow - observe fluid 14,615.0 14,615.0 20:00 20:30 level fall -4 ft over 30 minutes. 10/3/2017 10/4/2017 3.50 PROD4 CASING BKRM P Backream out of hole from 14615' to 14,615.0 13,332.0 20:30 00:00 13332' MD with 270 gpm, 2520 psi, 21 % F/O, 180 rpm, 7k Tq, ECD 11.41 ppg, PUW 160k, SOW 63k, ROT 115k Note: SOW = 53k at 14350' MD. OA pressure at midnight = 270 psi Downhole losses over past 24 hours = 182 bbls. 10/4/2017 10/4/2017 6.00 PROD4 CASING BKRM P Backream out of hole from 13336' to 13,332.0 10,540.0 00:00 06:00 10540' MD at 272 gpm, 2091 psi, 19% F/, ECD 10.81 ppg, 180 rpm, 6k To. PUW 118k, SOW 77k, ROT 93k. 10/4/2017 10/4/2017 5.50 PROD4 CASING BKRM P Backream out of hole from 10540' to 10,540.0 7,980.0 06:00 11:30 7980' MD with 272 gpm, 1875 psi, 19% F/0, 180 rpm, 5k Tq, ROT 92k. Page 58179 Report Printed: 10/3012017 Operations Summary (with Timelog Depths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log StanTime End Tune Dur (M) Phase Op Coda Aclrvity Code Time P -T-% 0peo""n Stan Depth OWS) End Deptlt (f1Ke) 10/4/2017 10/4/2017 0.75 PROD4 CASING TRIP P Trip out of hole on elevators from 7,980.0 7,593.0 11:30 12:15 7980'to 7593', observing no issues or drag pulling BHA through window. PUW 118k, SOW 85k 10/4/2017 10/4/2017 1.25 PROD4 CASING CIRC P Circulate bottoms up while 7,593.0 7,593.0 12:15 13:30 reciprocating from 7593'to 7503' with 270 gpm, 1815 psi, 20% F/O, 120 rpm, 3.3k Tq, ECD 10.25 ppg, MW intout 9.2ppg. Total of 3905 strokes pumped. PUW 112k, SOW 86k. 10/4/2017 10/4/2017 0.50 PROD4 CASING OWFF P Monitor well for flow. Hold PJSM for 7,593.0 7,593.0 13:30 14:00 slip/cut drilling line. 10/4/2017 10/4/2017 1.50 PROD4 CASING SLPC P Slip/cut drilling line. Calibrate blocks 7,593.0 7,593.0 14:00 15:30 and service rig. 10/4/2017 10/4/2017 2.50 PROD4 CASING TRIP P Trip out of hole on elevators racking 7,593.0 306.0 15:30 18:00 back 4" DP from 7593' to 306', monitoring displacement via trip tank. 10/4/2017 10/4/2017 1.00 PROD4 CASING BHAH P Pull out of hole from 306'to surface, 306.0 0.0 18:00 19:00 laying down L3 RSS drilling BHA. Monitor displacement via trip tank.Stabilizers were in gauge and bit looked good with no damaged/wom teeth and was in gauge. Graded 0 -0 - NO -A -X -0 -NO -TD. 10/412017 10/4/2017 0.50 PROD4 CASINGfBHAH AH P Clean and Gear floor of BHA 0.0 19:00 19:30 equipment. 10/4/2017 10/4/2017 1.00 COMPZ4 FISH 5 PJSM. Make up L-3 whipstock 229.0 19:30 20:30 retrieval BHA, scribe MWD, and RIH J229.0 to 229'MD - 348.48" toolface offset obtained. Monitor displacement via trip tank. 10/4/2017 10/4/2017 1.00COMPZ4 FISH IP P Trip in hole on 4" DP from 229'to 2,120.0 20:30 21:30 2120' MD, monitoring displacement via trip tank. 10/4/2017 10/4/2017 0.25 COMPZ4 FISH DHEO P Fill pipe and shallow hole test MWD 2,120.0 2,120.0 21:30 21:45 with 250 gpm, 940 psi, 19% F/O - good test. 10/4/2017 10/5/2017 2.25 COMPZ4 FISH TRIP P Trip in hole on 4" DP and THWDP 2,120.0 7,637.0 21:45 00:00 from 2120' to 7637' MD, stopping to fill pipe at 5050' MD, monitoring displacement via trip tank. OA pressure at midnight = 0 psi. Downhole losses for past 24 hours = 95 bbls. Page 59179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Our (hr) phma Op Code Activity Cotle Time P -T -X Operation s art oepm (flKB) End Depth (M(6) 10/5/2017 10/5/2017 0.75 COMPZ4 FISH FISH P Make up 4" DP single on top of stand 7,637.0 7,647.0 00:00 00:45 #79, fill pipe, and obtain parameters. PUW 143k, SOW 109k with pumps off, PUW 1381k and SOW 107k with pumps on at 251 gpm. Pump at 251 gpm, 1358 psi, 17% F/O and orient to 155° right. RIH and jet retrieval slot (retrieval slot 5.23' down from top of whipstock). Pick up above top of whipstock and orient to 22° left. RIH and set down 81k on bottom of retreival slot with hook right on depth. Pick up and confirm latched. Kill pump and start jarring to pull free. Increase jarring weight in stages from -40k overpulll. Observe whipstock pull free when jarring with 220k HL (77k overpull). Pick up and confirm whipstock free, PUW 143k. Observe fluid level drop to down blind rams, -25 ft. 10/5/2017 10/5/20171.50 COMPZ4 FISH CIRC P Lay down 4" DP single, Kelly up to 7,647.0 7,647.0 00:45 02:15 stand #79 and circulate 2 x bottoms up at 251 gpm, 1330 psi. No gas observed at bottoms up. Total of 18 bbls required to fill hole after pulling whipstock. 10/5/2017 10/5/2017 0.25 COMPZ4 FISH TRIP P Drop 2.10" hollow drift on -100' of wire 7,647.0 7,647.0 02:15 02:30 on stand #79. Pull up and rack back stand per Baker. 10/5/2017 10/5/2017 0.50 COMPZ4 FISH OWFF P Monitor well for flow -observe fluid 7,647.0 7,647.0 02:30 03:00 level drop -2 ft. Service top drive. 10/5/2017 10/5/2017 4.50 COMPZ4 FISH TRIP P Trip out of hole racking back 4" HWDP 7,647.0 76.0 03:00 07:30 and 4" DP from 7647'10 76' at top of L3 whipstock, monitoring displacement via trip tank, stage up pulling speed to 80 ff/min max. 10/5/2017 10/5/2017 3.00 COMPZ4 FISH SHAH P Lay down L3 whipstock BHA per 76.0 0.0 07:30 10:30 Baker. Observe mill pattern extend past bottom of slide to bottom of whipstock (-1 ft). Clean and clear rig floor of whipstock BHA. 10/5/2017 10/5/2017 1.00 COMPZ4 WHDBOP RURD P Flush and drain stack, pull0.0 0.0 10:30 11:30 wearbushing, and install test plug. Rig up 4-1/2" test joint and test assembly. Purge air out of lines with freshwater. Page 60/79 Report Printed: 1013012017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time 10/5/2017 Ertl Tim 10/5/2017 Da (hr) 4.00 phase COMPZ4 OP Code WHDBOP Activity Code BOPE Time P -T -X P Operation Test BOPE with 4" and 4-1/2" test joint Start Depth (ftKB) 0.0 EM Depth(ftKB) 0.0 11:30 15:30 to 250/3500 psi 5/5 min, witness waived by AOGCC rep Chuck Scheve. Test Sequence as follows: Install 4-1/2" test joint 1) Annular, Choke valves #1, 12, 13, & 14, 4" Kill, and 4" XT39 Dart valve. 2) Choke valves #9 and 11, Mezzanine Kill valve, and 4" XT39 FOSV. 3) Choke valves #8 and 10, and HCR Kill 4) Choke valves #6 and 7, Manual Kill, Upper IBOP 5) Manual and Super chokes (tested to 2000 psi) 6) Choke valves #2 and 5, and Lower IBOP 7) Lower 3-1/2" x 6" rams Remove test joint 8) Blind rams, Choke valves #3 and 4 Install 4" lest joint 9) Annular and HCR choke 10) Manual choke 11) Lower 3-1/2" x 6" rams Perform koomey drawdown test: System Pressure = 2,950 psi PSI after closure = 1,750 psi 200 psi Attained with 2 x electric pumps = 8 seconds Full Pressure attained with 2 x electric and 2 x air pumps = 50 seconds N2 = 6 each @ 2,075 psi Tested all gas and H2S sensors, PVT and flow alarms both audio and visual, and functioned primary and remote BOP controls - all good. Upper 7-5/8" casing rams not tested. 10/5/2017 10/5/2017 1.00 COMPz4 WHDBOP RURD P Rig down and blow down test 0.0 0.0 15:30 16:30 equipment. Re -install wearbushing. 10/5/2017 10/6/2017 7.50 COMPZ4 CASING PUTB P PJSM. Make up bent shoe and run in 0.0 6,168.0 16:30 00:00 hole with 4-1/2" 11.6# L-80 IBTm slotted liner/ 4-1/2" 12.6# L-80 TXPm blank liner per tally to 6168' MD, monitoring displacement via trip tank. MUT of IBTm = 4500 ft -lbs. MUT of the blank 12.6# L-80 TXPm joints = 7000 ft -lbs. Install 1 x 6-1/8" Volant thick-walled centralizer free-floating on each joint. PUW 87k, SOW 70k. OA pressure at midnight = 0 psi Downhole losses over past 24 hours = 74 bbls Page 61179 ReportPrinted: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Slan TIM Ena Time Dur (hr) Phase Op cotle Activity Cvtle Tme P -T -X Operation Start Cepa, MKB) End Depot t tKB) 10/6/2017 10/6/2017 1.50 COMPZ4 CASING PUTB P Run in hole with 4-1/2" 11.6# L-80 6,168.0 6,996.0 00:00 01:30 IBTnn slotted liner/ 4-1/2" 12.6# L-80 TXPm blank liner per tally from 6168' to 6996' MD, monitoring displacement via trip tank. MUT of IBTnn = 4500 ft - lbs. MUT of the blank 12.6# L-80 TXPm joints = 7000 ft -lbs. Install 1 x 6- 1/8" Volant thick-walled centralizer free -Floating on each joint. Pick up 1 x Baker 6" OD swell packer (2.67' element) with centralizer above and below. PUW 95k, SOW 72k. 10/6/2017 10/6/2017 1.00 COMPZ4 CASING OTHR P Pick up MWD collar and install 6,996.0 01:30 02:30 Slimpulse tool. Pick up Baker B-3 .7,030.0 Flanged Hook hanger and M/U per Baker. Scribe MWD to 180' off from hook, toolface offset = 303.55°. Run in hole to from 6996' tp 7030' MD. 10/6/2017 10/6/2017 0.25 60MPZ4 CASING RUNL P Run L3 lower completion in hole on 4" 7,030.0 7,600.0 02:30 02:45 DP stands from derrick from 7030'to 7600' MD, monitoring displacement via trip tank. 10/6/2017 10/6/2017 0.25 COMPZ4 CASING DHEQ P Circulate through running tools and 7,600.0 7,600.0 02:45 03:00 shallow hole test MWD tool with 90 gpm, 260 psi, 11 % F/O - good test. 10/6/2017 1016/2017 4.00 COMPZ4 CASING RUNL P Run L3 lower completion in hole on 4" 7,600.0 14,622.0 03:00 07:00 DP / 4" HWDP stands from derrick from 7600' to 14622' MD, monitoring displacement via trip tank and allowing pipe to self -fill. No issues running through window with bent shoe. 10/6/2017 07:00 10/6/2017 1.00 COMPZ4 CASING RUNL P Orient to 160° right with 92 gpm, 540 14,622.0 14,668.0 08:00 psi, PUW 166k, SOW 92k. Run in hole to 14668' MD, no drag observed. Pick up above window, orient to 25° left, run in and engage hook on window at 14667.74' MD (3.31' deep to plan), set down 20k weight. Observe orientation roll to 8' left. Pick up —25 ft, run in and re-engage hook on window at same depth, set down 20k. Confirm - orientation at 8° left. 10/6/2017 10/6/2017 0.75 COMPZ4 CASING CIRC P Drop 29/32" phenolic ball and pump 14,668.0 7,644.0 08:00 08:45 down at 127 gpm, 825 psi, 12% F/O for 300 strokes, then 86 gpm, 500 psi, 9% Flo for 200 strokes, then 64 gpm, 375 psi, 8% F/O for 100 strokes, then 43 gpm, 276 psi, 4% F/O to seat ball - seat at 635 strokes. Pressure up to 3500 psi to release from hook hanger and hold for 1 minute. Continue pressuring up to shear out ball seat, observe shear at 4270 psi (pinned for 4000 psi). Pick up and confirm released from hook hanger with PUW 143k. Confirm circulation with 85 gpm, 300 psi, 8% F/O. Top of hook hanger at 7644.62' MD. Page 62179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sten Tme End Tme Dur(hr) Phase OP Code Ae Ry Code Time P -T -X Operation SW Depot (MB) EM DOW (W13) 10/6/2017 10/6/2017 0.25 COMPZ4 WELLPR OWFF P Monitor well for flow and confirm 7,644.0 7,644.0 08:45 09:00 static. 10/6/2017 10/6/2017 2.50 COMPZ4 WELLPR TRIP P Trip OOH on elevators from 7644'to 7,644.0 0.0 09:00 11:30 surface, racking back 4" HWDP and 4" DP, monitoring displacement via trip tank. 10/6/2017 10/6/2017 0.50 COMP24 WELLPR SHAH P Lay down mle MWD and 0.0 0.0 11:30 12:00 Baker running tools. - 10/6/2017 10/6/2017 0.50 C0MPZ4 WELLPR SHAH P Clean and clear rig floor of running 0.0 0.0 12:00 12:30 tools. 10/6/2017 10/6/2017 1.50 C0MPZ4 RWRID RURD P Rig up GBR torque tum and casing 0.0 0.0 12:30 14:00 equipment for running LEM. 10/6/2017 10/6/2017 2.50 C0MPZ4 RWRID PUTB P PJSM. Make up LEM / ZXP assembly 0.0 328.0 14:00 16:30 for L3 lateral with SLS SlimPulse installed. GBR utilize torque turn while making up TXP connections to 7000 It -lbs, no issues observed. Scribe MWD offset to 92°. Had issue stinging in seal assembly but eventually got it installed. Make up 2 x Baker magnets and XO and RIH to 328' MD. 10/6/2017 10/6/2017 0.50 COMPZ4 RWRID CIRC P Run in hole on 1 x stand 4" DP to 420' 420.0 420.0 16:30 17:00 MD and circulate through LEM assembly at 30 gpm, 180 psi, no issues observed. Blow down topdrive. 10/6/2017 10/6/2017 1.00 COMPZ4 RWRID RCST P Run in hole with L3 LEM / ZXP 420.0 1,741.0 17:00 18:00 assembly on 4" DP from 420' to 1741' MD, monitoring displacement via trip tank. W WT inspect and adjust super sliders as needed. 10/6/2017 10/6/2017 1.00 COMPZ4 RWRID DHEO P Shallow hole test MWD tool. Increase 1,741.0 1,741.0 18:00 19:00 flow from 90 gpm up to 120 gpm, cycling pumps twice, and observe tool turn on. Confirm setting for gravity toolface - all good. 10/6/2017 10/6/2017 4.25 COMPZ4 RWRID RCST P Run in hole with L3 LEM /ZXP 1,741.0 7,638.0 19:00 23:15 assembly on 4" DP and 4" HWDP from 1741' to 7638' MD, monitoring displacement via trip tank. W WT inspect and adjust super sliders as needed. Calculated displacement = 58 bbls, Actual displacement = 44.8 Wis. Note: Total of 10 x SS sleeves replaced and 22 x SS sleeves flipped to distribute wear. No stop collars needed to be replaced. 10/6/2017 10/6/2017 0.50 COMPZ4 RWRID CIRC P Kelly up and establish circulation at 7,638.0 7,638.0 23:15 23:45 107 gpm, 838 psi, 11% F/O. Increase rate to 120 gpm, 974 psi, 12% F/O with no sign of signal to MWD - cycle pumps and increase rate to 132 gpm, 1024 psi, 12% F/O and observe pressure drop to 800 psi and tool start transmitting signal. Page 63179 Report Printed: 1 013 012 01 7 Operations Summary (with Timelog Depths) 11-1-102 • r Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End TimOur (ho Phase Op Cade Activity Code Time P -T -X O Aeration Start Depth rt D. EM Oepm (flx8). 10/6/2017 10/7/2017 0.25 COMPZ4 RWRID RCST P Orient LEM to 80° left with 132 gpm, 7,638.0 7,735.0 23:45 00:00 806 psi, 12% F/O and RIH to 7735' MD (stand #79 buried). No issues running muleshoe through hook hanger. Make up 4" DP single, kelly up, establish circulation at 127 gpm, 770 psi, 12% F/O. OA pressure at midnight = 0 psi Downhole losses for past 24 hours = 53 bbls 100/2017 10/7/2017 0.50 COMPZ4 RWRID PACK P RIH from 7735' and observe seals 7,735.0 7,753.1 00:00 00:30 tagging up on top of L2 seal bore extension at 7738' MD- work seals in SBE down @ 127 gpm, 760 psi, 12% F/O, setting down max of 15k weight. Once seals worked in and moving down, observe -6k seal drag through SBE. Latch LEM into hook hanger on depth @ 7644.62' MD, set down 15K, observed tool face roll from 80 Deg L to 28 Deg L. Pick up I 0 over. Set down 20K then pulled 15K over to confirm LEM latched into hook hanger, good. Tool face still @ 28 deg L. 10f712017 10/7/2017 0.50 COMPZ4 RWRID PACK P Set ZXP liner top packer, drop 16/8" 7,753.1 7,753.1 00:30 01:00 frac ball and pump down 3 bpm= 770 psi, slow down to 1.5 bpm=355 psi. Ball on seat @ 55 bbls away, pressure up to set packer. Observed packer set @ 2300 psi, cont to pressure up to 4000 psi to release. 10/7/2017 10/72017 0.50 COMPZ4 RWRID PRTS P P/U 3'@ 143K P/U, Gose annular 7,753.1 7,751.0 01:00 01:30 preventer and pressure test ZXP liner top packer to 3500 psi f/ 10 min on chart, good. 10/7/2017 10/7/2017 0.75 COMPZ4 RWRID CRIH P Spot corrosion inhibited brine f/ 7751' 7,751.0 7,639.0 01:30 02:15 MD to 7639' MD( calc TOW @ 7376' MD) Pumped 25 bbls of Cl brine followed by 73 bbls of drilling mud, pumped @ 255 gpm=870 psi. 10/7/2017 10/72017 0.50 COMPZ4 RWRID OWFF P OWFF f/ 30 min, static to 2" below 7,639.0 7,639.0 02:15 02:45 flowline. 10!7/2017 10/72017 2.50 COMPZ4 RWRID TRIP P POOH on elevators f/ 7639' MD to 7,639.0 0.0 02:45 05:15 surface. Calculated displacement= 52.8 bbls, Actual displacement= 57.5 bbls. ( 4.7 bbl loss) 10/72017 10/7/2017 1.00 COMPZ4 RWRID BHAH P UD Baker running tools and SLB 0.0 0.0 05:15 06:15 MWD. 10/7/2017 10/7/2017 1.50 PROD5 WHPST SHAH P Mobilize L4 whipstock BHA to rig floor. 0.0 0.0 06:15 07:45 Page 64179 Report Printed: 1013012017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan 7ma End Tune Our (fir) Phase Op Cotle P.uavdy C Time P -T-% eiafionotle OP Start Dew MKB) End Depth (nK6} 10/7/2017 10/7/2017 3.00 PROD5 WHPST BHAH P PJSM. M/U Milling BHA as per Baker. 0.0 319.0 07:45 10:45 M/U window mill, lower and upper mills, 1 HWDP, XO, goat sub and SLB slimpulse. Scribe MWD to window mill, 187 Deg tool face offset. Stand milling assy back in derrick. PIU Baker Whipstock and built anchor easy below as per BHA order. M/U milling assy to whipstock easy as per tally w/ 25K shear boll. Verified 3 screws installed in Anchor for shear rating of 10,500K. Confirmed shipping bolt is removed from anchor. RIH to 319'. 10/7/2017 10/7/2017 0.75 PRODS WHPST TRIP P Trip in hole on 4" DP stands from 319' 319.0 1,350.0 10:45 11:30 to 1350' MD, running speed of 60 ft/min, monitoring displacement via trip tank. 10/7/2017 10/7/2017 0.25 PRODS WHPST DHEQ P Shallow hole test MWD tool with 205 1,350.0 1,350.0 11:30 11:45 gpm, 490 psi, 15°k F/O -good test. Blow down top drive. 10/7/2017 10/7/2017 4.25 PROD5 WHPST TRIP P Trip in hole on 4" DP / 4" HWDP 1,350.0 7,360.0 11:45 16:00 stands from 1350' to 7360' MD, running speed of 60 ft/min, monitoring displacement via trip tank. Calculated _ displacement = 49.6 bbls, Actual displacement = 45.5 MIS (4.1 bbl loss) 10/7/2017 10/7/2017 1.25 PROM WHPST WPST P Kelly up on stand #76. Establish 7,360.0 7,360.0 16:00 17:15 circulation and stage pumps up to 282 gpm, 1480 psi, 18% F/O until signal obtained with SlimPulse. Orient whipstock to 23° left. PUW 136k, SOW 108k 10/7/2017 10/7/2017 0.50 PROM WHPST WPST P Wash down from 7360'to 7453'. Kelly 7,360.0 7,377.0 17:15 17:45 up on stand #77, wash down at 179 gpm, 880 psi, 15% F/O and tag L3 liner top with No -Go at 7461.18' MD (0.76' deep, —amount that pusher tool compresses LTP). Confirm orientation at 23" left, kill pump, set down 10k weight, observing good indication of anchor shear at 8k down. Pick up to 146k HL (10k overpull) and confirm anchor set. Shear bolt with 321k set down weight. Pick up and confirm free with PUW 140k. Top of window @ 7377.00' MD Btm of window @ 7390.60' MD Page 65179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Steri Time End Time our (hr) Phase Op code Agiviry Cade Time e P -T -X pperehon Start Depth (MB) EM Depth (WB) 10/7/2017 10/8/2017 6.25 PROD5 WHPST MILL P Establish parameters with 282 gpm, 7,377.0 7,394.0 17:45 00:00 1509 psi, 19% NO, 80 rpm, 3.5k Tq. Mill window per Baker from 7377' to 7394' MD with 282 gpm, 1560 psi, 20% F/O, 100 rpm, 3-5k Tq, 1-3k WOB. PUW 131k, SOW 108k, ROT 111 k. Pump super sweeps every 5' per Baker, observing moderate increase of metal cuttings over shakers at bottoms up. OA pressure at midnight = 0 psi Downhole losses for past 24 hous = 9 bbls 10/8/2017 10/8/2017 4.50 PROD5 WHPST MILL P Mill L4 window from 7394'to 7412' MD 7,394.0 7,412.0 00:00 04:30 with 282 gpm, 1620 psi, 20% F/O, 100 rpm, 3-5k Tq, 2-8k WOB, PUW 131 k, SOW 108k ROT 111 k. Pump super sweep at TD. Top of window @ 7377.00' MD Btm of window @ 7390.60' MD -5' of gauge hole @ 7396' MD Rathole to 7412' MD 10/8/2017 10/8/2017 0.75 PROD5 WHPST REAM P Circulate sweep around to surface and 7,412.0 7,348.0 04:30 05:15 work mills through window with 282 gpm, 1630 psi, 22% F/O, 100 rpm, 3k Tq. Observed moderate increase in metal cuttings at surface as sweep came around. Kill rotary and drop rate to 1 bpm, 430 psi, 3% F/O. Trip through window with no issues, observed 0-1k drag. PUW 135k, SOW 109k. Pull up above window to 7348' MD. 10/8/2017 10/8/2617 0.50 i PROD5 WHPST CIRC P Circulate at 255 gpm, 1371 psi, 19% 7,348.0 7,348.0 05:15 05:45 F/O and confirm MW 9.2 ppg in/out. 10/8/2017 10/8/2017 0.50 PRODS WHPST FIT P Rig up and perform FIT for 1-4 window 7,348.0 7,348.0 05:45 06:15 to 13.0 ppg EMW (3737.9' TVD) using 9.2ppg FloPro. Close annular, pump down drill pipe and IA with mud pump #1. Pressure up to 739 psi and shut in, observe pressure drop to 590 psi after 10 minutes. Pumped 1.4 bble, returned 1.0 We. Blowdown lines. 10/8/2017 10/8/2017 0.50 PRODS WHPST OWFF P Monitor well for Flow - well static. 7,348.0 7,348.0 06:15 06:45 10/8/2017 10/8/2017 0.25 PRODS WHPST TRIP P Trip OOH from 7348'to 6810' MD, 7,348.0 6,810.0 06:45 07:00 monitoring displacement via trip tank. 10/8/2017 10/8/2017 0.25 PRODS WHPST CIRC P Pump dry job. 6,810.0 6,810.0 07:00 07:15 10/8/2017 10/8/2017 2.25 PROD5 WHPST TRIP P Trip OOH from 681(y to 232' MD, 6,810.0 232.0 07:15 09:30 racking back 4" HWDP and 4" DP, monitoring displacement via trip tank. Page 66179 Report Printed: 1013012017 Operations Summary (with Timelog Depths) IH -102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Time End rim Dur (hr)Phase OP OP Code AcRy Code Time P -T -X oparaeon sten Depth htKg End Depth iftKB). 10/8/2017 10/8/2017 1.50 PROD5 BHAH P Lay down L4 milling BHA and clean on 232.0 0.0 09:30 11:00 magnets. Observe pockets on each magnet full with metal cuttings. Gauge mills. Upper 6-3/4" Mill - In Gauge Lower 6-5/8" Mill - 1/4" undergauge Window 6-3/4" Mill - 3/8" undergauge 10/8/2017 10/8/2017 0.50 PRODS WHPST W W WH P IMakeup stackwasher and jet stack. 0.0 0.0 11:00 11:30 SIMOPS - Clean and clear rig floor of BHA components. 10/8/2017 10/8/2017 0.50 PRODS WHPST SVRG P Service dg. Grease blocks, crown, 0.0 0.0 11:30 12:00 topdrive, and washpipe. 10/8/2017 10/8/2017 3.00 PROD5 WHPST SHAH P PJSM. Prep rig floor and pipeshed for 0.0 897.0 12:00 15:00 BHA and confirm tally. Make up Motor BHA per SLB to 897' MD, monitoring displacement via trip tank. Re -run 6- 3/4" Smith Milltooth bit. Run new 1.5° mud motor. MWD scribed to 182° toolface offset. 10/8/2017 10/8/2017 0.25 PROD5 WHPST TRIP P Trip in hole from 897'to 1840' MD, 897.0 1,840.0 15:00 15:15 monitoring displacement via trip tank. 10/8/2017 10/8/2017 0.75 PROD5 WHPST DHEO P Shallow hole test MWD with 209 gpm, 1,840.0 1,840.0 15:15 16:00 782 psi, 18% F/O - good lest. Blowdown top drive. 10/6/2017 10/8/2017 3.00 PROD5 WHPST TRIP P Trip in hole from 1840'to 7244' MD, 1,840.0 7,244.0 16:00 19:00 monitoring displacement via trip tank, filling pipe every 20 x stands. PUW 116k, SOW 86k. 10/8/2017 10/8/2017 0.50 PROD5 WHPST CIRC P Fill pipe and orient motor to 10° left 7,244.0 7,300.0 19:00 19:30 with 228 gpm, 1356 psi, 16% FIO. 10/8/201710/8/2017 0.25 PROD5 WHPST TRIP P Trip in hole from 3300'to 7412' D. 7,300.0 7,412.0 19:30 19:45 SOW 85k. No drag observed while running bit across window. Started seeing 1-7k drag after 7396' (end of gauge hole) and continued tripping to 7412', tagging up with 10k weight. Page 67/79Report Printed: 10/30/2017 • Operations Summary (with Timelog Depths) IH-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sten Time 10/8/2017 End Time 10/9/2017 Dur(hnPheae 4.25 PRODS Op Code DRILL A c6vity Cade DDRL lima P-T-X Operatlan Sten Depth MKB) End Depth (flKB) 19:45 00:00 P Directionally drill 6-3/4" L4 "D" lateral 7,412.0 7,524.0 from 741210 7524' MD, 3815' TVD. Pump at 231 gpm, 1442 psi on-btm, 1383 psi off-btm, 17% F/O. Rotate at 40 rpm with 3-4k Tq on-btm, 3k Tq off- btm. 3-18k WOB. PUW 116k, SOW 82k, ROT 92k. AST 2.29 hrs, ADT 2.8 hrs, Bit 12.59 hrs, Jars 94.05 hrs. Displace milling fluid out of well with new/used 9.2 ppg FloPro at 7477' MD. Concretions drilled from 7412'- 7419', 7428'- 7432', 7434'- 7440', and 7450' to 7453'. Utilize rig's twister system to help transfer weight down to bit when sliding through concretions. SPRs @ 7430' MD 3750' TVD, MW=9.25 ppg, 21:30 hours MP#1: 20 spm=550 psi, 30 spm=720 psi. MP #2: 20 spm=550 psi, 30 spm=720 psi. OA pressure at midnight = 0 psi Downhole losses for past 24 hours = 2 bbls 10/9/2017 00:00 10/9/2017 02:00 2.00 PRODS DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 7,524.0 7,650.0 from 7524' MD to TD of 7650' MD, 3815' TVD. Pump at 231 gpm, 1352 psi on-btm, 1270 psi off-btm, 17% F/O. Rotate at 40 rpm with 3-4k Tq on- btm, 3k Tq off-btm. 3-18k WOB. PUW 116k, SOW 82k, ROT 93k. AST .86 hrs, ADT 1.09 hrs, Total Bit 13.68 hrs, Jars 95.16 hrs.. SPRs @ 7524' MD 3815' TVD, MW=9.2 ppg, 00:18 hours MP#1: 20 spm=380 psi, 30 spm=540 psi. MP #2: 20 spm=380 psi, 30 spm=540 psi. 10/9/2017 02:00 1019/2017 02:30 0.50 PROD5 DRILL BKRM P Backream OOH fl 7650' MD to 7525' 7,650.0 7,525.0 MD, Rotate @ 40 rpm's w/ 3 K Tq, pump @ 230 gpm= 1270 psi, ROT= 96K. 10/9/2017 02:30 10/912017 02:45 0.25 PROD5 DRILL CIRC P Orient motor to 20 deg L @ 7525' MD, 7,525.0 7,525.0 before BHA enters the slide. 10/9/2017 02:45 10/912017 03:00 0.25 PROD5 DRILL OWFF P OWFF, static. 7,525.0 7,525.0 10/9/2017 03:00 10/9/2017 03:30 0.50 PRODS DRILL TRIP P POOH on elevators f/ 7525' MD to 7,525.0 7,146.0 7146' MD, Observed 12K overpull @ 7445' MD, slack off and work back though. Pulled up through w/ 3-5k drag. No overpull observed when pulling bit through window. Page 68179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) IH-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stent Time Entl Tuna Dur Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) EM Depm(ttKa) 10/9/2017 10/9/2017 4.50 PRODS DRILL TRIP P Pull OOH on elevators from 7146'to 7,146.0 897.0 03:30 08:00 897', monitoring displacement via trip tank. Rack back 4" DP stands with good hardbanding and lay down 19 x stands containing joints with worn hardbanding. Calculated displacement = 42 bbls, Actual displacement = 44.5 bbls. 10/9/2017 10/9/2017 1.50 PROD5 DRILL BHAH P Confirm well static. PJSM. Pull OOH 897.0 0.0 08:00 09:30 laying down Motor BHA, cleaning off magnets. Observe pockets —1/2 full with metal cuttings. Bit was in good shape and in gauge. Graded 0-0-NO- A-X-0-NO-BHA. Monitor displacement via trip tank. 10/9/2017 10/9/2017 0.50 PROD5 DRILL W W WH P Make up stackwasher and jet slack. 0.0 0.0 09:30 10:00 UD same. 10/912017 10/9/2017 1.00 PROD5 DRILL BHAH P PJSM. Make up L4 RSS drilling BHA 0.0 307.0 10:00 /too per SLB to 307' MD, monitoring displacement via trip tank. 10/9/2017 10/9/2017 0.75 PR5D5 DRILL PULD P Run in hole on 4" DP singles from pipe 307.0 1,254.0 11:00 11:45 shed from 307'to 1254' MD, monitoring displacement via trip tank. 10/9/2017 10/9/2017 0.50 PRODS DRILL DHEQ P Shallow hole test MWD with 210 gpm, 1,254.0 1,254.0 11:45 12:15 755 psi, 16% F/O - good test. Blow down top drive. 10/9/2017 10/9/2017 0.75 PROD5 DRILL PULD P Run in hole on 4" DP singles from pipe 1,254.0 2,106.0 12:15 13:00 shed from 1254' to 2106' MD, monitoring displacement via trip tank. Note: Total of 57 joints picked up to replace the stands layed down due to worn hardbanding. 10/9/2017 10/9/2017 2.75 PROD5 DRILL TRIP P Trip in hole on 4" DP from 2106'to 2,106.0 7,210.0 13:00 15:45 7210' MD, monitoring displacement via trip tank, filling pipe every 20 x stands. PUW 110k, SOW 81k 10/9/2017 10/9/2017 1.25 PRODS DRILL SLPC P Slip and cut 58' of drill line. Calibrate 7,210.0 7,210.0 15:45 17:00 blocks. Monitor well via hole fill. 10/9/2017 10/9/2017 0.25 PROD5 DRILL TRIP P Trip in hole on 4" DP from 7210'to 7,210.0 7,400.0 17:00 17:15 7400' MD, monitoring displacement via trip tank. No drag observed tripping bit across window. PUW 114k, SOW 83k. Calculated displacement = 53 bbls, Actual displacement = 53.6 bbls. 10/9/2017 10/9/2017 0.25 PRODS DRILL CIRC P Fill pipe and obtain slow pump rates. 7,400.0 7,400.0 17:15 17:30 SPRs @ 7400' MD 3744' TVD, MW=9.2 ppg, 17:15 hours MP#1: 20 spm=400 psi, 30 spm=580 psi. MP #2: 20 spm=390 psi, 30 spm=570 psi. 10/9/2017 10/9/2017 1.75 PROD5 DRILL DLOG P Perform MAD pass from 7400' to 7,400.0 7,650.0 17:30 19:15 7650' MD at 300 R/hr with 200 gpm, 1000 psi, 14% F/O. Stop and shoot surveys per DD. Observe 1-6 k drag while washing down. Page 69179 Report Printed: 10/30/2017 DOYON 142 0600 06:00 12:00 12:00 118:00 Operations Summary (with Timelog Depths) IH -102 Cod. Job: DRILLIN(; ORll:IrJA1 from 7650' to 7976' MD, 3759' TVD. Pump at 272 gpm, 1748 psi, 21 % F/O, ECD 10.31 ppg, MW 9.2 ppg. Rotate at 140 rpm with 3-5k Tq on-btm, 2k Tq off-bim. 3k WOB. PUW 109k, SOW 81 k, ROT 94k. Max gas 87 units. ADT 3.8 hrs, Bit 3.8 hrs, Jars 98.96 hrs. OA pressure at midnight - 0 psi Downhole losses for past 24 hours = 3 from 7976'to 8338' MD, 3751' TVD. Pump at 272 gpm, 1820 psi, 21 % F/O, ECD 10.50 ppg, MW 9.2+ ppg. Rotate at 140 rpm with 3-6k Tq on-btm, 3k Tq off-btm. 3k WOB. PUW 110k, SOW 76k, ROT 92k. Max gas 105 units. ADT 4.98 hrs, Bit 8.78 hrs, Jars 103.94 hrs. SPRS @ 7976' MD 3744' TVD, MW=9.2 ppg, 00:30 hours MP#1: 20 spm=370 psi, 30 spm=550 psi. MP #2: 20 spm=380 psi, 30 spm=510 from 8338' to 8650' MD, 3753' TVD. Pump at 275 gpm, 1885 psi, 21% F/O, ECD 10.58 ppg, MW 9.2+ ppg_ Rotate at 120-140 rpm with 3-6k Tq on-btm, 4k Tq off-btm. 3-7k WOB. PUW 112k, SOW 73k, ROT 89k. Max gas 391 units. ADT 4.8 hrs, Bit 13.58 hrs, Jars 108.74 his. from 8650' MD, 3753' TVD - 6,265' MD 3,763' TVD. Pump at 275 gpm, 1905 psi, 20% F/O, ECD 10.58 ppg, MW 9.3 ppg. Rotate at 150 rpm with 5 -6k TO on-btm, 5k TO off-bim. 1-10k WOB. PUW 118k, SOW 71 k, ROT 93K. Max gas 425 units. ADT 5.9 hrs, Bit 18.13 hrs, Jars 113.29 hrs. SPRs @ 7,728' MD 3,753' TVD, MW=9.3 ppg, 13:30 hours MP#1: 20 spm=460 psi, 30 spm=650 MP #2: 20 spm=460 psi, 30 spm=640 psi. Rig: DOYON 142 Operations Summary (with Timelog Depths) 1H-102 Job: DRILLING ORIGINAI I siert Time I End True I Dur fM I an... I 1 _ _ 1 ___ _ _., I I sten Deem I 10/10/2017 10/11/2017 6.00 -____ PROD5 _•.,_.„. DRILL �M.Vnlr , v DDRL uum r_, -n P "p wn Directionally drill6-3/4'L4"D"lateral MKS) 9,265.0 End DePM(Wlir 9,653.0 18:00 00:00 from 6,265' MD 3,763' TVD - 9,653' MD 3,774' TVD. Pump at 275 gpm, 1,896 psi, 21% F/O, ECD 10.61 ppg, MW 9.3 ppg. Rotate at 150 rpm with 6k TQ on-btm, 5k TQ off-btm. 1-5K WOB. UP WT= 117K, DWN WT= 72K, ROT 93K. Max gas 303 units. ADT 4.7 hrs, Bit 22.83 hrs, Jars 117.99 hrs. 10/11/2017 00:00 10/11/2017 06:00 6.00 PRODS DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 9,653.0 9,850.0 from 9,653' MD 3,774' TVD - 9,850' MD 3,777' TVD . Pump at 275 gpm, 1,896 psi, 21 % F/O, ECD 10.61 ppg, MW 9.3 ppg. Rotate at 150 rpm with 6k TQ on-btm, 5k TQ off-btm. 1-5K WOB. UP WT = 117K, DWN WT = 72K, ROT 93K. Max gas 303 units. ADT 4.7 hrs, Bit 22.83 hrs, Jars 117.99 hrs. SPRs @ 9,681" MD 3,775' TVD, MW=9.2+ ppg, 01:30 hours MP#1: 20 spm=390 psi, 30 spm=580 psi. MP #2: 20 spm=400 psi, 30 spm=580 psi. 10/11/2017 06:00 10/11/2017 12:00 6.00 PRODS DRILL Directionaly drill 6-3/4" L4 "D" lateral 9,850.0 10,065.0 from 9,850' MD 3,777' TVD - 10,065' MD 3,777' TVD . Pump at 277 gpm, 1,948 psi, 21 % F/O, ECD 10.52 ppg, 7ADT-4.19 MW 9.2+ ppg, Rotate at 120 rpm with 6k TQ on-btm, 5k TQ off-btm. 1-5K WOB. UP WT = 119K, DWN WT = 70K, ROT 92K. Max gas 44 units. hrs, Bit 26.75 hrs, Jars 126.1 hrs. 10/11/2017 12:00 10/11/2017 18:00 6.00 PRODS DRILL DDRL P Directionally drill6-31V L4"D'lateral 10,065.0 10,537.0 from 9,850' MD 10,065' MD 3,777' TVD - 10,537' MD 3,780' TVD . Pump at 272 gpm, 1,990 psi, 21 % F/O, ECD 10.52 ppg, MW 9.2+ ppg, Rotate at 120 rpm with 7K TQ on-btm, 6K TQ off -btm. 2K WOB. UP WT = 122K, DWN WT = 68K, ROT 93K. Max gas 259 units. ADT 4.48 hrs, Bit 36.23 hrs, Jars 131.39 hrs. SPRs @ 10,156"' MD 3,771' TVD, MW=9.2+ppg, 13:15 hours MP#1: 20 spm=460 psi, 30 spm=660 psi. MP #2: 20 spm=440 psi, 30 spm=590 psi Page 71/79 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sten Tme 10/11/2017 End Thee 10/12/2017 Our hr ( ) 6.00 Phare PROD5 Op Code DRILL gcliWty Cotla DDRL Time P.T-X Operation Start Depth (ftm) End Depth CWB)p 18:00 00:00 P Directionally drill 6-314" L4 "D' lateral 10,537.0 10,792.0 from 10,537' MD 3,780' TVD - 10,792' MD 3,790' TVD . Pump at 272 gpm, 2.013 psi, 21% F/O, ECD 10.52 ppg, MW 9.2+ ppg, Rotate at 120 rpm with 7K TO on-btm, 6K TO off-btm. 2-5K WOB. UP WT= 123K, DWN WT= 67K, ROT 94K. Max gas 185 units. ADT 5.21 hrs, Bit 41.44 hrs, Jars 136.6 hrs. 10/12/2017 00:00 10/12/2017 06:00 6.00 PROD5 DRILL DDRL P Directionally drill 6-3/4"L4"D"lateral 10,792.0 10,980.0 from10,792' MD 3,790' TVD - 10,980' MD 3,791' TVD. Pump at 272 gpm, 2.050 psi, 21% F/O, ECD 10.92 ppg, MW 9.2+ ppg, Rotate at 120 rpm with 7K TO on-btm, 6K TO off-btm. 1,993 PSI off BTM 2-5K WOB. UP WT = 128K, DWN WT = 55K, ROT 94K. Max gas 66 units. ADT 5.43 hrs, Bit 46.87 his, Jars 142.03 hrs. SPRs @ 10,820"' MD 3,792' TVD, MW=9.2+ ppg, 00:30 hours MP#1: 20 spm=500 psi, 30 spm=700 psi. MP #2: 20 spm=510 psi, 30 spm=680 psi 10/12/2017 06:00 10/12/2017 12:00 6.00 PROD5 DRILL DDRL P Directionally drill 6-3/4"L4 "D" lateral 10,980.0 11,535.0 from10,980' MD 3,791' TVD - 11,535' MD 3,802' TVD. Pump at 272 gpm, 2.200 psi, 21 % F/O, ECD 11.7 ppg, MW 9.2+ ppg, Rotate at 120 rpm with 8K TO on-btm, 6K TO off-btm. 2,150 PSI off BTM 2-5K WOB. UP WT = 126K, DWN WT = 59K, ROT 96K. Max gas 53 units. ADT 4.55 hrs, Bit 51.42 hrs, Jars 146.58 hrs. 10/12/2017 12:00 10/12/2017 1800 6.00 PROD5 DRILL DDRL P Directionally drill -6-3/4L4 -D" lateral 11,535.0 12,249.0 from11,535' MD 3,802' TVD - 12,249' MD 3,789' TVD. Pump at 272 gpm, 2.398 psi, 21 % F/0, ECD 1146 ppg, MW 9.2+ ppg, Rotate at 110 rpm with 8K TO on-btm, 7K TO off-btm. 2,390 PSI off BTM 1-2K WOB. UP WT = 137K, DWN WT = 52K, ROT 92K. Max gas 261 units. ADT 4.61 hrs, Bit 56.03 hrs, Jars 151.19 hrs. SPRs @ 11,577"' MD 3,802' TVD, MW=9.4+ ppg, 12:30 hours MP#1: 20 spm=600 psi, 30 spm=810 psi. MP #2: 20 spm=600 psi, 30 spm=820 psi Page 72/79 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 11-1-102 Rig: DOYON 142 Time Log Job: DRILLING ORIGINAL Stall Time 10/12/2017 End Time 10/13/2017 Durthr) 6.00 Phase PROD5 Op Code DRILL Actwy Cade DDRL Time P-T-X start Depth 12 Em Depth,503.0 18:00 00:00 P Directionally ddll63/4/4�L4 "D" lateral 249.0 from 12,249' MD 3,789' TVD - 12,503 MD 3,789' TVD. Pump at 272 gpm, 2.390 psi, 21% F/O, ECD 11.41 ppg, MW 9.2+ ppg. Rotate at 120 rpm with 9K TQ on-btm, 8K TQ off-btm. 2,380 PSI off BTM 2-5K WOB. UP WT = 139K, DWN WT = 52K, ROT 94K. Max gas 261 units. ADT 4.91 hrs, Bit 60.94 hrs, Jars 156.1 hrs. 10/13/2017 00:00 10/13/2017 06:00 6.00 PROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 12,503.0 12,921.0 from12,503 MD 3,789' TVD - 12,921' MD 3,808' TVD . Pump at 277 gpm, 2.397 psi, 23% F/O, ECD 11.53 ppg, MW 9.2+ ppg, Rotate at 120 rpm with 9K TQ on-btm, 7K TQ off-btm. 2,380 PSI off BTM 2-5K WOB. UP WT = 154K, DWN WT = 56K, ROT 106K. Max gas 93 units. ADT 4.57 hrs, Bit 65.51 hrs, Jars 160.67 hrs. 10113/2017 06:00 10/13/2017 12:00 6.00 5ROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 12,921.0 13,217.0 from12,921' MD 3,808' TVD - 13,217' MD 3,813' TVD . Pump at 279 gpm, 2.550 psi, 23% F/O, ECD 11.48 ppg, MW 9.2+ ppg, Rotate at 100 rpm with 9K TQ on-btm, 7.5K TQ off-btm. 2,500 PSI off BTM 1-6K WOB. UP WT = 154K, DWN WT = 56K, ROT 106K. Max gas 178 units. ADT 4.89 hrs, Bit 70.40 his, Jars 165.56 hrs. SPRs @ 13,264" MD 3,814' TVD, MW=9.4 ppg, 06:45 hours MP#1: 20 spri psi, 30 spm=800 psi. MP #2: 20 spm=580 psi, 30 spm=820 psi 1O/13/ 0017 12:00 10/13/2017 18:00 6.00 PROD5 DRILL DDRL P Directionally drill 6-3/4" L4 "D" lateral 13,217.0 13,476.0 from13,217' MD 3,813' TVD - 13,476' MD 3,796' TVD . Pump at 277 gpm, 2.597 psi, 23% F/O, ECD 11.62 ppg, MW 9.2+ ppg, Rotate at 120 RPM with 9K TQ on-btm, 8K TQ off-btm. 2,572 PSI off BTM "K WOB. UP WT = 160K, DWN WT = K, ROT 109K. Max gas 403 units. ADT 5.33 hrs, Bit 75.73 hrs, Jars 170.89 hrs. SPRs @ 13,529" MD 3,801' TVD, MW=9.4 ppg, 14:10 hours MP#1: 20 spm=640 psi, 30 spm=880 psi. MP #2:20 spm=640 psi, 30 spm=840 psi Page 73/79 Report Printed: 10/30/2017 Summary (with Timelog Depths) 1H-102 lipOperations Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stolt Tmie 10/13/2017 End Time 10/14/2017 Our hr ( ) 6.00 Phase PROD5 Op Code DRILL Activity Coee Time P•T-X Operation Start Degh (W) EW Depth tflKB) 18:00 00:00 DDRL P Directionally drill 6-3/4" L4 "D" lateral 13,476.0 13,961.0 from 13,476' MD 3,796' TVD to 13,961' MD 3,798' TVD . Pump at 277 gpm, 2.687 psi, 23% F/O, ECD 11.62 ppg, MW 9.2+ ppg. Rotate at 120 RPM with 91K TQ on-btm, 8K TQ off- b1m. 2,680 PSI off BTM 1-61K WOB. UP WT= 165K, OWN WT= K, ROT 109K. Max gas 669 units. ADT 4.17 hrs, Bit 79.90 hrs, Jars 175.06 hrs. 10/14/2017 00:00 10/14/2017 06:45 6.75 PRODS DRILL DDRL P Directionally drill -6-3/4L4 "D" lateral 13,961.0 14,670.0 from 13,961' MD 3,798' TVD to 14,670' TVD 3,779' TVD . Pump at 275 gpm, 2,760 psi, 23% F/O, ECD 11.78 ppg, MW 9.2+ ppg W/2% lube. Rotate at 140 RPM with 10K TQ on- btm, 81K TQ off-btm. 2,750 PSI off BTM 1-6K WOB. UP WT= 178K DWN WT = K, ROT 119K. Max gas 150 units. ADT 5.07 hrs, Bit 84.97 hrs, Jars 180.13 hrs. SPRs @ 13,974" MD 3,789' TVD, MW=9.4+ ppg, 00:09 hours MP#1: 20 spm=680 psi, 30 spm=920 psi. MP #2: 20 spm=670 psi, 30 spm=920 psi 10/14/2017 06:45 10/14/2017 08:00 1.25 PROD5 CASING CIRC P CBU during reciprocation from 14,670' 14,670.0 14,670.0 MD - 14,630' MD UP DWN // 275 GPM @ 2,150 PSI, 21 % FO 120 RPM, 8K TQ with 11.45 ECD. STKS PUMPED = 4,618. MW 1/0 = 9.3 PPG. UP WT= 178K DNW = K, ROT 119K. 7.8K TQ. SPRs @ 14,670" MD 3,780' TVD, MW=9.3 ppg, 08:00 hours MP#1: 20 spm=660 psi, 30 spm=920 psi. MP #2: 20 spm=670 psi, 30 spm=920 psi 10/14/2017 10/14/2017 0.50 PR0D5 CASING OWFF P OWFF dropped 18". 14,670.0 14,670.0 08:00 08:30 10/14/2017 08:30 10/14/2017 3.50 PROD5 CASING BKRM P BKRM OOH From 14,670' MD - 14,670.0 13,332.0 12:00 13,332' MD. 275 GPM @ 2,360 PSI. 21% F/0@120 RPM, 7.3K TQ. 11.18 EC, UP WT=150K DWN WT=61 K. DWN WT @ 14,250' = 50K 13,793' MD = 64K. 10/14/2017 12:00 10/14/2017 6.00 PROD5 CASING BKRM P BKRM OOH From 13,332' MD - 131332.0 10,551.0 18:00 10,551' MD. 270 GPM @ 1,975 PSI. 20% F/O @120 RPM, 6K TO. 10.8 ECD, UP WT = 92K @ full pump rate 10/14/2017 18:00 10/15/2017 00:00 6.00 PROD5 CASING BKRM P BKRM OOH From 10,551' MD - 7,690' 10,551.0 7,690.0 MD. 270 GPM @ 1,754 PSI. 20% FIC, @120 RPM, 5K TO. 10.8 ECD, UP WT = 88K @ full pump rate. UP WT=112K DWN WT=80K. Page 74179 Report Printed: 1 013 0/2 01 7 e Operations Summary (with Timelog Depths) 1H-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Tirtre Dur (hr) Phase DP Cade ACtiWty Code Time P -T -X operation scan Depth MKS) EM Depth(WS) 10/152017 10/15/2017 1.75 PROD5 CASING TRIP P POOH on elevators. F/7,690' MD UP 7,690.0 7,314.0 00:00 01:45 WT=118K. OWN WT=81K Encountered drag at 7,533' MD so slacked off with 1 O OWN WT. Bring on pumps to circulate possible fill/junk. PU to 130K UP WT for check. 3X jar licks down to free up. RIH Ito 7,592' MD and bring pumps up to 275 GPM 1,710 PSI DPP. PUH to 7,502' MD 2X to wash / smear area with 7K drag. PUH to 7,314' MD at 116K UP WT 84K DWN WT. 10/15/2017 10/15/2017 1.25 PROD5 CASING CIRC P -Circ -while rotating from 7,309'to 7,314.0 7,223.0 01:45 03:00 7,223' MD with 275 GPM 1,760 PSI 20% F/O, 120 RPM with 4K TQ. ECD = 10.32 PPG EMW. UP WT = 108K, DWN WT=85K. Total STKS=4,611. 9.3 PPG MW IN/OUT. 10/15/2017 10/15/2017 0.25 5R0D5 CASING OWFF P OWFF. 7,223.0 7,223.0 03:00 03:15 10/152017 10/15/2017 0.25 PRODS CASING SVRG P Service crown /top drive. 7,223.0 7,223.0 03:15 03:30 10/15/2017 10/15/2017 0.50 PRODS CASING TRIP P STND BK 2 stands DP to 7,125' MD. 7,223.0 7,125.0 03:30 04:00 Pump dry job / install stripping rubber. 10/152017 10115/2017 6.50 PRODS CASING PULD P PULD drill pipe sideways from 7,125' 7,125.0 306.0 04:00 10:30 to 306' MD. Monitor disp via TT. UP wt=49K DWN WT=54K. 10/152017 10/152017 1.50 PRODS CASING BHAH P Lay down BHA #26 as per DD. 306.0 0.0 10:30 12:00 Monitor disp via TT. 10/152017 10115/2017 0.75 PROD5 CASING BHAH P Clear rig floor of SLB tools BHA #26 0.0 0.0 12:00 12:45 and clean same. 10/15/2017 10/15/2017 1.50 COMPZS FISH BHAH P MU hook BHA #27 as per Baker Rep. 0.0 225.0 12:45 14:15 UP WT = 47K DWN WT 52K. Monitor disp via TT. 10/152017 10/15/2017 3.75 COMPZ5 FISH TRIP P RIH with HOOK asym from 225' to 225.0 7,391.0 14:15 18:00 7,351' MD. UP WT = 136K DWN WT = 111 K. Monitor disp via TT. Shallow holm test MWD at 1,650' with 252 GPM PSI 1,681. 28% F/O. (PASSED). 9o/15/2o17 10/152017 0.50 COMPZ5 FISH FISH P Orient hook to 160 DEG R. with 233 7,391.0 7,350.0 18:00 18:30 GPM 1,141 PSI DPP. 16%F/O. Wash down to 7,391' MD. Engage hook top of Whipstock at 23 DEG L highside as per BOT. Attemp to straight pull with 80K over.. NOPE. Jar 1X 20K, 40K, 60K over before release. UP WT= 138K. 10/15/2017 10/15/2017 1.50 COIAPZ5 FISH CIRC P Circulate 2X BU. 7,350' MD with 246 7,350.0 7,350.0 18:30 20:00 GPM @ 1,219 PSI DPP. 17% F/O --- Lost45BBLS when seals pulled. 85 BBLS lost during circ. Pumped 4,590 STKS 1O/15 01017 10/15/2017 0.50 COMPZS FISH OWFF P OWFF. static 7,350.0 7,350.0 20:00 20:30 10/15/2017 10/162017 3.50 COMPZ5 FISH TRIP P POOH from 7,350' MD - 2,220' MD 7,350.0 2,220.0 20:30 00:00 UP WT = 75K. Monitor Disp via TT. 10/16/2017 10/16/2017 1.50 50MPZ5 FISH TRIP 5 Continue to POOH with Whipstock 2,220.0 319.0 00:00 01:30 fishing assym from 2,200' MD to 319' MD. Monitor disp via TT. Page 75179 Report Printed: 10/30/2017 Operations Summary (with Timelog Depths) 11-1-102 Rig: DOYON 142 Job: DRILLING ORIGINAL Time log Step Tim 10/16/2017 Time 10/16/2017 Our (hr) 2.25 Phase COMPZ5 CP Cotle FISH A<fiviry Cope Time P-T-X Opeembw SW Depen MKB) EW Depth (WB) 01:30 03:45 BHAH P LD Whipstock and all Baker fishing 319.0 0.0 tools as per BOT rep. Monitor disp via TT. 10/16/2017 10/16/2017 1.00 COMPZ5 FISH BHAH P Send all Baker fishing tools down 0.0 0.0 03:45 04:45 beaver slide and or pipe shed. Wash rig Floor. 10/16/2017 10/16/2017 0.25 50MPZ5 CASING SFTY P PJSM 0.0 0.0 04:45 05:00 10/16/2017 10/16/2017 0.50 COMPZ5 CASING RURD P Mak up lower sompletion assy. Pick 0.0 0.0 05:00 05:30 up and test handeling equipment. Make up same. 10/16/2017 10/16/2017 0.75 COMPZ5 CASING PUTB P RIH with 4 1/2" 11.6# L-80 IBTM/TXP 0.0 254.0 05:30 06:15 slotted / Blank lower liner asym as per detail to 254' MD. Installing cent on all joints as per program. TO IBTM to 4.5K FT/LB 10/16/2017 10/16/2017 0.50 C0MPZ5 CASING EQRP T Change out to spare GBR casing 254.0 254.0 06:15 06:45 power unit. Was on location. Quick changeover. 10/16/2017 10/16/2017 8.50 COMPZ5 CASING PUTB P Continue to RIH with 4 10 11.6# 254.0 7,252.0 06:45 15:15 IBTM / TXP slotted / Blank liner as per detail. UP WT=95K OWN WT=75K Monitor disp via TT. Install 6.25" cent on all joints while RIH. IBTM TO = 4.5 FT/LB. TXP TQ = 7K FT/LB. 10/16/2017 10/16/2017 0.75 450MPZ5 CASING OTHR P PU hook hanger assym, slim pulse 7,252.0 7,285.0 15:15 16:00 MWD and scribe as per BOT/ SLB. 10/16/2017 16:00 10/16/2017 2.00 COMPZ5 CASING RUNL P Continue to RIH with liner as per tally. 7,285.0 8,795.0 18:00 Monitor disp via TT. 10/16/2017 18:00 10/16/2017 0.50 COMPZS CASING DHEQ P Shallow hole test MWD. 100 GPM @ 8,795.0 8,795.0 18:30 353 PSI DPP. 10% F/O (PASSED). 10/16/2017 10/16/2017 4.00 COMPZ5 CASING RUNL P Continue to RIH with 4" DP / HWDP 8,795.0 14,591.0 18:30 22:30 from 8,795' MD to 14,591' MD. Monitoring disp via TT. UP WT = 169K OWN WT = 87K. 10/16/2017 10/1612017 1.00 COMPZ5 CASING OTHR P Kelly up and orient to 157 DEG R high 14,591.0 14,655.0 22:30 23:30 side with 92 GPM @ 530 PSI 9% F/O. Wash OWN from 14,591' MD to 14,655' MD. Orient to 13 DEG left highside and hang hook hanger as per Baker REP. 10/16/2017 10/17/2017 0.50 COMPZ5 CASING CIRC P Drop 29/32 ball and pump down at 85 14,655.0 14,652.0 23:30 00:00 GPM 515 PSI DPP. 8% F/O. slow rate to 62 GPM, 375 PSI with 7 1/2 FO/ at 400 SKS. 10/17/2017 10/17/2017 0.50 COMPZ5 CASING CIRC P Continue to pump 29/32" ball on seat 14,652.0 7,351.0 00:00 00:30 at 1 BPM @ 605 strokes pressure up to 3,800 PSI and release. PU 114K UP WT. Pressur eup to 4,250 PSI DPP and shear out ball seat. Tag up to confirm depth w 5K OWN WT. OWN WT = 111 K PUH above liner to 7,351' MD. 10/17/2017 10/17/2017 0.25 COMPZ5 WELLPR OWFF P OWFF 10 min. Dropped I. 7,351.0 7,351.0 00:30 00:45 10/17/2017 10/17/2017 0.75 COMPZS WELLPR CIRC P PUH to 7,190' MD and pump dryjob. 7,351.0 7,190.0 00:45 01:30 Install strippin rubbers + BD TD. 10/17/2017 10/17/2017 3.50 COMPZ5 WELLPR TRIP P POOH from 7,190' MD to 90' MD 7,190.0 90.0 01:30 05:00 monitor DISP via TT. Page 76179 Report Printed: 10/30/2017 DOYON 142 Phase 05:00 05:45 10117/2017 10/17 05:45 06:00 10/17/2017 10/17, 06:00 07:00 10/17/2017 10/17 07:00 07:15 10/17/2017 10/17/ 07:15 09:30 10/17/2017 10/17/; 09:30 10:30 10/17/2017 10/17/; 10:30 11:00 10/17/2017 10/17/2 11:00 14:15 10/17/2017 10/17/21 14:15 ts-nn 16:00 i6:45 19:15 10/17/2017 10/18, 19:15 00:00 1rrrr 105:30 06:15 Operations Summary (with Timelog Depths) 1H-102 Inh• nDll r rr.rn r.......... sheared as per BOT rep, and SLB Rep. Monitor DISP via MD - 1,667' MD. Monitor disp via 350 PSI w/10% F/O. (PASSED) BD - 7,459' MD. UP WT= 137K DWN WT = 107K Monitor disp via TT. Kelly up and orient to 30 DEG left High side @ 127 GPM 785 PSI, 13% F/O. Wash down and set LEM as per BOT REP. Drop 1.625" ball to set ZXP PKR and release running tool. Pump down at 150 GPM 954 PSI with 13% F/O Ball on seat at 520 STKS. Pressure up to 2,800 PSI. Witness set at 2,350 PSI DPP. Pressure up to 3,550 PSI DPP to ensure released. BD TD. Bottom of non locating seal assym = 7,495' MD. PT ZXP liner top PKR to 3,500 PSI for 30 min (PASSED). 30 STKS to pressure up with 2.8 BBLS bled back. u �.cµece wea as per program to 9.4 PPG brine. Pump 38 BBL spacer @ 150 GPM 650 PSI with 13% F/O. Chase with 9.4 PPG brine with 150 GPM. ICP = 650 PSI DPP FCP = 376 DPP. 11 % F/O total stks 3,748. Continue to pump and Spot 25 BBL hich vis pill at liner top packer with 150 GPM 443 PSI DPP 10% F/O total stks pumped= 939 BD TD with simops of UD three STDS left in derrick via mousehole and single oint elevators. my - J,a5z' MD removing SS on rig floor. Monitor Disp via TT. UP WT = 88K. DWN WT=80K. Continue pulling out of hole F/3,95Z MD. Laying down 4" Drillpie & Super Sliders. Monitor -ay down ZXP running tool, Clear anc :lean dg floor. 12:00 19:45 05:30 15 100:00 12:00 04:15 05:30 :15 03:15 DOYON 142 Operations Summary (with Timelog Depths) IH -102 AAh- 11011 r JLI ............ Ldivlaomement i est tools prior to running in nitor well via trip tank. ole with USIT & CBL tools vi; 6,950 MD. Monitor via trip tank. ure = 0 d loss 54 bbls. POOH logging with Usit and CBL fron 6,950' MD. Monitoring Displacement via TT. RD SLB wieline and Wellteh equipment. Empty stack and pull wear ring. Instal lest plug. Rig up test equipment waived witness at 1830 hrs.)). Continue to test BOPE to 250/3500 PSI as per permit to drill with 4 1/2" 1- 80 test joint. Kill HCR failed initial lest / greased and passed. Klg up and RIH with -4-1/2" 12,6# TXP L-80 production tubing with completion equipment as per approved program. Pressure test DH gauge to 5000 psi as per proceedure for 5 min. Install Cannon Clamps on all connections and monitoring pressure gauge on the fly. TO all connections in TO TURN mode to 7K ft / LB. UP WT = 98K DWN WT = 76K. Witnessed drag as stinging into seal asym and tagged up at 7,292' with 10K DWN. IA 1/500 PSI. (GOOD) -r-• �. oow �J as per program at 211 GPM 480 PSI, 10% F/O Chase Cl with 105 BBLS of 9.4 PPG brine 211 GPM 573 PSI 15% F/O. Total STKS pumped = 1,273. SIMOPS RD RILDS. Sim ops RD / BD cement T/5,000 psi 10 min. each. Test witnessed by CPAI rig superviser. Test IA to 1,000 psi for 5 min. All tests good - Charted. Drop ball &rod. R/U & test tubing & IA to 3,500 psi 30 min each. Tests charted. Good tests. Bleed down tubing to zero to shear SOV. DOYON 142 Operations Summary (with Timelog Depths) 1H-102 cwe Inh• 111211 1 u1n i..,....... 14:00 ei rreeze Protect. 3 BPM @ 500 FCP = 3 BPM AT 550 PSI. SI rig down. in:uu 15:30 -- --"" "' vv.Wo�r FRZP P Install 10/20/2017 15:30 10/20/2017 0.50 COMPZ5 WHDBOP MPSP utube. joint &lay down. Drain stack & blow 16:00 P SET B 10/20/2017 10/212017 8.00 COMPZ5 MOVE 16:00 down choke, kill and hole fill lines. 10/20/2017 03:45 10/20/2017 04:15 0.50 COMPZ5 WHDBOP MPSP P Set BPV. Test BPV from below to 2,500 psi for 10 min. Test charted, 1020/2017 04:15 10/20/2017 07:30 3.25 COMPZ5WHDBOP NUND Good test. P Nipple down BOP stack and rack bac on pedestal. Remove choke and kill lines. Lay down 10 -hi pressure riser. 10/20/2017 07:30 10/20/2017 09:15 1.75 COMPZ5 WHDBOP NUND P Clean out hanger void. Nipple up 10/20/2017 09:15 10/20/2017 0.75 COMPZ5 WHDBOP PRTS Production tree. 10:00 P Test hanger void to 5,000 psi for 15 10/202017 10:00 10/20/2017 0.75 COMPZ5 WHDBOP NUND min. Good test. 10:45 P Terminate tec wire &test 10/20/2017 10:45 10/20/2017 12:00 1.25 COMPZ5 WHDBOP PRTS P Flood lines antl tree with diesel. Test 250/5,000 for 10 min each. Tests good and tests charted. Rig down from test. 10/20/2017 12:00 10/20/2017 taan 0.50 COMPZ5 WHDBOP MPSP o �. ., .._.. _ 14:00 ei rreeze Protect. 3 BPM @ 500 FCP = 3 BPM AT 550 PSI. SI rig down. in:uu 15:30 -- --"" "' vv.Wo�r FRZP P Install 10/20/2017 15:30 10/20/2017 0.50 COMPZ5 WHDBOP MPSP utube. 16:00 P SET B 10/20/2017 10/212017 8.00 COMPZ5 MOVE 16:00 00*0n MOB P .._.._ . NADConversion Kuparuk River Unit Kuparuk 1H Pad IH -102 1H-102 NAD 27 ConocoPhillips Definitive Survey Report 27 September, 2017 ConocoPhillips ConocoP h i l l i ps Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 11-1-102 Project: Kuparuk River Unit TVD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Site: Kupamk 1 H Pad MD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Well: Rig: 11-1-102 North Reference: True Wellbore: 1H-102 Survey Calculation Method: Minimum Curvature Design: 11-1-102 Database: OAKEDMP2 40ject Kupamk River Unit, North Slope Alaska, United States lap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level leo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point lap Zone: Alaska Zone 04 Using geodetic scale factor Well Rig: 1H-102 Magnetics Model Name Sample Date Well Position +N/S 0.00 usft Northing: 5,980,662.56 usft Latitude: 70° 21'28.630 N Survey Date +E/ -W 0.00 usft Easting: 549,577.46 usft Longitude: 149° 35'50.423 W Position Uncertainty MWD+IFR-AK-CAZSC 0.00 usft Wellhead Elevation: usft Ground Level: 54.00 usft Wellbore 1H-102 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (usft) (oars) Survey (Wellbore) Tool Name Description Survey Date 67.62 BGGM2017 9/15/2017 GYD�GC-SS 17.49 80.95 57,491 Design 11-1-102 MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC 8/24/2017 10:12 Audit Notes: 8,533.681H-102 Srvy 3 -SLB MWD+GMAG(1H- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 8/271201712:16 Version: 1.0 Phase: ACTUAL Tie On Depth: 38.62 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (ft) (usft) (usft) (usft) (1) 0.00 38.62 0.00 0.00 124.62 Survey Program Data From To (usft) (oars) Survey (Wellbore) Tool Name Description Survey Date 67.62 1,009.26 1H-102 Srvy 1 - SLB_GWD70 (1H-102) GYD�GC-SS Gyrodata gyro single shots 8/24/2017 10:04 1,050.36 1,678.041H-102 Srvy 2- SLB _MWD+GMAG(1 H- MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC 8/24/2017 10:12 1,777.33 8,533.681H-102 Srvy 3 -SLB MWD+GMAG(1H- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 8/271201712:16 8,577.06 8,577.061H-102 Srvy 4-SLB_MWD-INC_Filler(1 MWD -INC -ONLY MWD -INC -ONLY -FILLER 9/5/2017 9:03:0- 8.67102 12,899+091H-102 Srvy 5-SLB_MWD+GMAG(11-1- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 9/5/2017 9:06:0 Survey Map Nap Vertical MD In Azi TVD TVDSS +WS +E/ -W Northing EasUng OLS Section (Usft) (°) r) (usft) (usft) (usft) (usft) (ft) (ft) r/too) (1t) Survey Toof Name 38.62 0.00 0.00 38.62 -54.00 0.00 0.00 5,980,662.56 549,57]46 0.00 000 UNDEFINED 67.62 0.19 41.29 67.62 -25.00 0.04 0.03 5,980,662.60 549,577.49 066 0.01 GYD-GCSS(1) 165.90 0.45 13201 16590 73.28 -0.10 043 5,9SQ662A6 549,577.89 0.50 041 GYD-GC-SS(1) 258.98 1.01 128.15 258.97 166.35 -0.85 1.34 5,980,651.72 549,578.81 0.60 1.59 GYD-GC-SS(1) 354.48 3.34 138.19 354.40 261.78 -34 3.86 5,980,659.14 549,581.34 2A6 5.13 GYD-GCSS(1) 447.17 4.61 135.26 44686 354.24 -8.10 828 5,980,654.51 549,585.79 1.39 11.42 GYD-GCSS(1) 539.82 5.77 132.42 539.13 446.51 -13.89 14.34 5,960,64877 549,591.89 1.28 1989 GYD-GC-SS(1) 632.84 7.61 134.49 631.51 538.89 -21.36 22.19 5,980,641.35 549,599.79 1.99 30.39 GYD-GC-SS(1) 725.82 an 137.82 723.54 630.92 -30.93 31.34 5,980,631.84 549,609.00 1.35 43.36 GYD-GC-SS(1) 821.24 10.73 141.32 817.58 724.96 -03.25 41.78 5,980,619.59 549,619.52 2.15 58.95 GYD-GC-SS(1) 92712017 2:04:26PM Page 2 COMPASS 500014 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Rig: 1H-102 Project Kupamk River Unit TVD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Well: Rig: 1H-102 North Reference: True Wellboni: 11-1-102 Survey Calculation Method: Minimum Curvature Design: 1H-102 Database: OAKEDMP2 9272017 2:04:26PM Page 3 COMPASS WW. 14 Build 85 MeP VeNimAzi FSu"eyMaP ND 7VDSS +NIS +E/ -W Northing Faagrlg DLS Secdon(1) (usft) (usft) (usft) (usft) (ft) (ft) ("/100') (R) Survey Tool Name 139.61 908.57 81595 57.91 53.90 598060501 549,631.74 2.35 7726 GYD-GC-SS(1) 136.85 1,000.84 908.22 -74.90 69.13 5,980,588.13 549,64].08 2.22 W.4 GYDSC-SS(1) 135.96 1,040.49 947.87 52.75 7661 5,980,580.32 549,654.61 2.10 11006 MWD+IFR-AK-CAZ-SC(2) 1,144.89 17.17 134.37 1,131.15 1,038.53 -101.72 95.49 5,980,561.49 549,673.61 1.61 136.37 MWD+IFR-AK-CAZ-SC(2) 1,239.16 20.84 134.25 1,220.26 1,127.64 -123.16 117.46 5,900,54020 549,695.72 3.89 166.63 MWD+IFR-AK-GAZSC(2) 1,334.20 2471 136.54 1,307.88 1,215.26 -149.38 143.24 5,980,514.14 549,721,67 4.18 202.75 MWD+IFR-AK-CAZ-SC(2) 1,428.98 27.54 137.49 1,392.97 1,300.35 -179.92 171.68 5,980,48380 549,750.31 3.02 243.50 MND+IFR-AK-CAZ-SC(2) 1,523.25 28.14 137.93 1,476.33 1,383.71 -212.49 201.30 5,980,451.43 549,780.14 0.67 285.38 MWD+IFR-AK-CAZ-SC(2) 1,618.09 28.94 137.33 1,559.64 1,467.02 -245.96 231.84 5,900,418.16 549,810.90 0.90 330.53 MWD+IFR-AK-CAZSC(2) 1,678.04 29.99 135.80 1,611.84 1,519.22 -267.37 252.11 5,980,396.89 549,831.31 2.15 359.38 MWD+1FR-AK-CAZ-SC (2) 1,77100 33.38 13512 1,690.93 1,598.31 -302.34 286.17 5,900,362.15 549,86560 365 407.28 NOT an Actual Survey 10 374" x 13472^ 1,777.33 3361 135.72 1,696.21 1,603.59 -304.85 288.61 5,980,359.66 549,868.W 3.65 410.71 MWD+IFR-AK-CAZ-SC(3) 1,801.61 34.53 134.79 1,716.32 1,623.70 314.50 298.19 5,980,350.07 549,877.69 4.35 424.07 MWD+IFR-AK-CAZSC(3) 1,896.66 37.81 133.50 1,793.04 1,700.42 -353.55 338.45 5,980,311.29 549,918.21 3.54 479.39 MWD+IFR-AK-CAZ-SC(3) 1,991,93 40.86 131.83 1,866.72 1774.10 394.45 382.87 5,900,27070 549,962.89 3.39 539.18 MWD+1FR-AK-CAZSC(3) 2,086.48 43.97 130.99 1,936.52 1,843.90 -036.61 430.70 5,980,228.85 550,011.00 3.34 60250 MWD+IFR-AK-CAZ-SC(3) 2,184.36 47.16 129.49 2,005.04 1,912.42 -481.73 484.06 5,W.18409 550,064.65 3.4 672.04 MWD+1FR-AK-CAZ-SC(3) 2,276.23 50.08 128.77 2,065.76 1,973.14 -525.22 537.53 5,980,140.96 550,118.40 3.23 740.76 MWD+IFR-AK-CAZ-SC(3) 2,371.48 53.12 127.35 2,124.92 2,032.30 571.22 596.31 5,980,09536 550,177.48 340 81526 MWD+IFR-AK-CAZ-SC(3) 2,464.98 55.35 124.47 2,179.57 2,086.95 815.68 657.76 5,980,051.30 550,23921 3.45 891.09 MWD+1FR-AK-CAZSC(3) 2,559.60 56.73 122.73 2,232.43 2,139.81 859.10 723.12 5,980,008.32 550,304.86 2.11 969.55 MWD+IFR-AK-CAZ-SC(3) 2,653.87 58.79 122.43 2,282.72 2,190.10 -702.03 790.31 5,979,965.84 550,372.32 2.20 1,049.23 MWD+IFR-AK-CAZSC(3) 2,748.30 59.37 121.74 2,331.24 2,238.62 -745.06 858.95 5,979,92527 550,41.23 0.88 1,130.16 MWD+IFR-AK-CAZ-SC(3) 2,843.07 61.40 121.48 2,378.07 2,285.45 -788.24 929.11 5,979,88056 550,511,67 2.16 1,212.43 MWD+IFR-AK-CAZSC(3) 2,937.25 65.11 121.93 2,420.45 2,327.83 -832.44 1,000.65 5,979,836.84 550,583.50 3.96 1,296.41 MWD+1FR-AK-CAZSC(3) 3,032.88 69.13 121.16 2,457.62 2,365.00 -878.52 1,075.72 5,979,791 27 550,658.87 4.27 1,384.37 MWD+IFR-AK-CAZ-SC (3) 3,126.86 71.43 121.37 2,489.33 2,396.71 -92443 1,151.34 5,979,745.86 550,734.78 2.46 1,472.68 MWD+IFR-AK-CAZSC(3) 3,221.95 7262 121.37 2,51867 2,426.05 -971.51 1,228.56 5,979,69929 550,812.31 1.25 1,562.98 MWD+IFR-AK-CAZ-SC(3) 3,316.46 73.03 121.69 2,546.58 2,453.96 -1,018.73 1,305.53 5,979,65259 550,889.57 0.54 1,653.15 MWD+IFR-AK-CAZ-SC(3) 3,410.86 73.34 122.71 2,573.89 2,481.27 -1,066.89 1,381.99 5,979,604.95 550,966.35 1.09 1,743.43 MWD+IFR-AK-CAZ-SC(3) 3,506.07 73.21 122.55 2,601.29 2,500.67 -1,116.05 1,45818 5,979,556.30 551,043.45 0.21 1,834.55 MWD+IFR-AK-CAZSC(3) 3,601.42 73.21 122.70 2,628.83 2,536.21 -1,165.27 1,535.66 5,979,507.59 551,120.65 0.15 1,925.78 MWD+IFR-AK-CAZ-SC(3) 3,696.85 73.21 122.29 2,656.40 2,563.78 -1,214.35 1,612.72 5,979,459.03 551,198.03 0.41 2,017.03 MWD+IFR-AK-CAZSC(3) 3,791.46 73.30 12098 2,683.66 2,591.04 -1,261.87 1,689.85 5,979,412.03 551,27546 1.33 2,107.56 MND+IFR-AK-CAZSC(3) 3,886.74 73.14 118.95 2,711.17 2,618.55 -1,307.43 1,768.88 5,979,366.99 551,354.78 2.05 2,198.47 MWD+1FR-AK-CAZ-SC(3) 3,981.94 73.09 119.64 2,738.82 2,646.20 -1,352.00 1,848.32 5,979,322.95 551,434.51 010 2,289.17 MND+IFR-AK-CAZSC (3) 4,076.41 73.30 11987 2,766.13 2,673.51 -1,396.88 1,926.84 5,979,278.59 551,513.31 0.32 2,37928 MWD+IFR-AK-CAZSC(3) 4,171,02 73.17 118.99 2,793.42 2,700.80 -1,441.40 2,005.73 5,979,234.61 551,592.49 0.90 2,469.50 MWD+1FR-AK-CAZ-SC(3) 4,266.02 73.05 119.53 2,821.02 2,728.40 -1,485.83 2,085.04 5,979,190.71 551,672.08 0.56 2,560.01 MND+IFR-AK-CAZ-SC (3) 4,360.46 73.01 119.04 2,848.57 2,755.95 -1,530.01 2,163.83 5,979,147.05 551,751.15 0.50 2,649.94 MWD+IFR-AK-CAZSC(3) 9272017 2:04:26PM Page 3 COMPASS WW. 14 Build 85 i ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Rig: 11-1-102 Project: Kuparuk River Unit TVD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1 H-102 actual @ 92.62ush (Doyon 142) Well: Rig: 1H-102 Nosh Reference: True Wellboro: 1 H-102 Survey Calculation Method: Minimum Curvature Design: 1 H-102 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Aid TVD TVDSS +N/3 +E/ -W Northing Easting DLS Section (usft) 0 0 (usft) (usft) (USM Will) (fit) (ft) (°/100) (ft) Survey Tool Name 4,455.58 72.90 119.77 2,876.45 2,783.83 -1574.66 2,243.05 5,979,102.93 551,830.66 0.74 2,740.51 MWD+IFR-AK-CAZSC(3) 4,549.81 72.87 120.06 2,904.19 2,811.57 -1,619.57 2,321.11 5,979,05854 551,90901 0.30 2,830.26 MWD+IFR-AK-CAZ-SC(3) 4,644.52 73.20 118.40 2,931.82 2,839.20 -0,663.81 2,400.16 5,979,014.84 551,988.35 1.71 2,920.44 MWD+IFR-AK-CAZSC(3) 4,739.99 72.42 114.51 2,960.05 2,867.43 -1,704.44 2,481.79 5,978,974.75 552,07024 3.98 3,010.70 MWD+IFR-AI(-CAZ-SC(3) 4,786.24 72.31 110.47 2,974.05 2,881.44 -1,721.29 2,522.51 5,978,958.17 552,11106 8.33 3,053.79 MWD+IFR-AK-CAZ-SC(3) 4,83376 72.48 108.23 2,988.44 2,895.82 -1,736.30 $565.24 51978,943.45 552,153.89 4.51 3,097.48 MWD+IFR-AK-CAZ-SC(3) 4,928.09 7221 103.78 3,01706 2,924.44 -1,761.08 2,651.62 5,978,919.24 552,240.42 4.50 3,182.64 MWD+IFR-AK-CAZ-SC(3) 5,022.87 71.11 100.68 3,046.89 2,954.27 -1,780.14 2,739.52 5,978,900.76 552,328.44 3.31 3,265.81 MWD+IFR-AK-CAZSC(3) 5,07023 71.27 98.69 3,062.16 2,969.54 -1,78768 2,783.71 5,978,89352 552,37267 3.99 3,306.45 MWD+IFR-AK-CAZSC(3) 5,116.77 71.68 96.97 3,076.95 2,984.33 -1,793.69 2,827.43 5,978,887.79 552,41642 3.61 3,345.84 MWD+IFR-AK-CAZ-SC(3) 5,211.19 72.12 93.77 3,105.29 3,01367 -1,802.09 2,916.77 5,978,879.99 552,505.81 3.25 3,424.13 MWD+IFR-AK-CAZSC(3) 5,305.75 71.74 88.59 3,13564 3,043.02 -1,803.94 3,006.61 5,978,878.73 552,59565 5.22 3,499.12 MWDNFR-AK-CAZ-SC(3) 5,400.08 71.70 83.77 3,165.24 3,072.62 -1,797.98 3,095.95 5,978,885.29 552,684.94 4.85 3,569.25 MWD+IFR-AK-CAZ-SC(3) 5,49526 72.32 8129 3,194.64 3,102.02 -1,786.21 3,18510 5,978,897.65 552,774.60 2.56 3,636.41 MWD+IFR-AK-CAZSC(3) 5,590.01 72.15 76.05 3,223.57 3,130.95 -1,768.49 3,274.13 5,978,915.95 552,862.91 5.27 3,699.12 MWD+IFR-AK-CAZ-SC(3) 5,685.45 72.61 7023 3,252.48 3,159.86 -1,742.11 3,351.14 5,978,942.90 552,949.73 5.83 3,755.73 MWD+IFR-AK-CAZ-SC(3) 5,779.73 73.02 64.52 3,280.36 3,187.74 -1,707.48 3,444.24 5,978,978.08 553,032.59 5.80 3,804,4 MWD+IFR-AK-CAZ-SC(3) 5,874.02 73.87 63.54 3,307.23 3,214.61 -1,667.90 3,525.49 5,979,018.19 553,113.57 1.34 3,848.61 MWD+IFR-AK-CAZ-SC(3) 5,968.69 74.38 63.99 3,333.12 3,240.50 -1,627.64 3,60717 5,979,05898 553,194.97 0.71 3,893.16 MWD+IFR-AK-CAZSC(3) 6,063.17 74.61 63.93 3,358.38 3,265.76 -1,587.68 3,688.97 5,979,099.49 553,276.50 0.25 3,937.76 MWD+IFR-AK-CAZ-SC(3) 6,156.96 74.68 58.30 3,383.23 3,29061 -1,544.01 3,768.12 5,979,143.67 553,355.35 579 3,978.09 MWD+IFR-AK-CAZ-$C(3) 6,252.33 74.03 54.53 3,408.96 3,316.34 -1,49322 3,844.61 5,979,194.96 553,431.50 3.87 4,012.18 MWD+IFR-AK-CAZ-SC(3) 6,346.97 7268 51.05 3,436.08 3,34346 -1,438.41 3,916.82 5,979,250.25 553,503.33 3.80 4,040.45 MWD+IFR-AK-CAZ-SC(3) 6,441.76 72.16 48.05 3,464.71 3,372.09 -1,379.79 3,965.58 5,979,309.31 553,571.69 3.07 4,063.73 MWD+IFR-AK-CAZSC(3) 6,537.27 73.10 45.02 3,493.23 3,400.61 -1,31709 4,051.72 5,979,372,4 553,63742 3.18 4,082.53 MWD+IFR-AK-CAZ-SC(3) 6,585.21 73.18 41.30 3,507.14 3,414.52 -1,283.63 4,083.10 5,979,406.11 553,668.57 743 4,089.34 MWD+IFR-AK-CAZ-SC(3) 6,632.17 72.64 38.72 3,520.94 3,428.32 -1,249.25 4,111.96 5,979,44067 553,697.19 5.38 4,093.56 MWD+IFR-AK-CAZ-SC(3) 6,727.59 71.99 32.96 3,549.95 3,457.33 -1,17560 4,165.17 5,979,514.67 553,74991 5.79 4,095.50 MWD+IFR-AK-CAZSC(3) 6,822.80 72.62 27.41 3,578.91 3,486.29 -1,097.23 4,210.74 5,979,593.33 553,794.96 5.59 4,088.47 MWD+IFR-AK-CAZ-SC(3) 6,915.59 72.83 23.59 3,606.48 3,513.86 -1,017.27 4,248.88 5,979,673.53 553,832.57 3.94 4,074.43 MWD+IFR-AK-CAZ-SC(3) 7,011.34 7249 19.50 3,635.02 3,542.40 -932.28 4,282.44 5,979,758.73 553,865.56 4.09 4,053.75 MWD+IFR-AK-CAZ-SC(3) 7,104.01 73.90 18.26 3,661.82 3,569.20 -848.34 4,311.14 5,979,842.85 553,893.70 1.99 4,029.68 MWD+IFR-AK-CAZSC(3) 7,198.95 73.27 13.49 3,688.66 3,596.04 -760.78 4,336.05 5,979,930.57 553,918.03 4.86 4,000.43 MWD+IFR-AK-CAZ-SC(3) 7,293.52 74.08 7.89 3,715.26 3,622.64 571.64 4,352.87 5,980,019.81 553,934.25 5.75 3,969..62 MWD+IFR-AK-CAZ-SC(3) 7,387.86 74.53 4.10 3,740.79 3,648.17 -581.33 4,362.35 5,980,110.17 553,943.13 3.90 3,920.11 MWD+IFR-AK-CAZ-SC(3) 7,481.81 74.18 4.40 3,766.13 3,673.51 -491.11 4,369.05 5,980,200.43 553,949.24 0.48 3,874.36 MWD+IFR-AK-CAZSC (3) 7,576.96 74.34 2.50 3,791.94 3,699.32 399.70 4,374.56 5,980,291.86 553,954.15 1.93 3,826.96 MWD+IFR-AK-CAZ-SC (3) 7,673.24 74.65 2.56 3,817.68 3,725.06 307.01 4,378.66 5,980,38456 553,957.63 0.33 3,777.67 MWD+IFR-AK-CAZ-SC(3) 7,768.14 74.30 2.49 3,843.08 3,750.46 -215.66 4,382.68 5,980,475.93 553,961,05 0.38 3,729.08 MWD+IFR-AK-CAZSC(3) 7,852.66 7462 1.95 3,868.40 3,775.78 -124.67 4,38621 5,98,566.94 553,963.97 065 3,650.28 MWD+IFR-AK-CAZ-SC(3) 912712017 2:04.'26PM Page 4 COMPASS 5000.14 Build 85 Company: NADConversion Project: Kuparuk River Unit site: Kuparuk 1 H Pad Wall- Rig: 1 H-102 Wellbore: 11-1-102 Design: 11-1-102 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Rig: 1H-102 1 H-102 actual @ 92.62usft (Doyon 142) 1 H-102 actual @ 92.62usft (Doyon 142) True Minimum Curvature OAKEDMP2 9272017 2:04:26PM Page 5 COMPASS 5000 14 Build 85 Map Map Vertical MD Inc An TVD TOSS +N/ -S +FJ -W Northing Eastirg OLS Section (usft) V) V) (usft) (usft) (usft) (usft) (ft) (ft) (%1001 (ft) Survey Tool Name 7,957.29 74.34 1.22 3,893.72 3,801.10 -33.52 4,388.73 5,980,658.09 553,965.89 0.80 3,630.58 MWD+IFR-AKCAZ-SC (3) 8,051.73 7448 0.70 3,919.10 3,826.48 57.43 4,390.26 5,980,74904 553,966.82 0.55 3,580.15 MWD+IFR-AK-CAZSC(3) 8,146.14 74.91 0.36 3,944.02 3,851.40 14649 4,391.10 5,980,840.09 553,967.05 0.57 3,529.11 MWD+IFR-AK-CAZ-SC(3) 8,240.14 7925 0.22 3,965.04 3,872.42 240.08 4,391.56 5,980,931.68 553,966.91 4.62 3,477.45 MWD+1FR-AK-CAZ-8C(3) 8,335.71 83.18 0.49 3,979.63 3,887.01 334.51 4,392.15 5,981,026.10 553,966.87 4.12 3,42428 MWD+IFR-AK-CAZSC(3) 8,430.45 88.01 1.29 3,986.90 3,89428 428.93 4,39362 5,981,120.52 553,967.72 5,17 3,371.84 MWD+1FR-AK-CAZ-SC(3) 8,524.31 88.65 060 3,989.64 3,897.02 522.74 4,395.17 5,981,214.32 553,968.64 1.00 3,319.81 MWD+IFR-AK-CAZ-SC(3) 8,533.68 88.54 359.99 3,989.87 3,897.25 532.11 4,395.21 5,981,223.69 553,968.63 6.61 3,314.53 MWD+IFR-AK-CAZ-SC(3) 8,577,06 88.T/ 359.85 3,990.89 3,898.27 575.47 4,395.15 5,981,26205 55396828 0.62 3,289.84 MWD -INC ONLY 4 8,591.00 89.04 359.81 3,991.15 3,898.53 589.41 4,395.11 5,981,280.99 553,968.15 1.94 3,281.89 NOT an Aclual Survey 7-W, s 9.718" 8,672.02 90.59 359.55 3,991.42 3,898.80 670.43 4,39466 5,981,361.99 553,967.16 1.94 3,23548 MWD+IFR-AK-CAZSC(5) 8,766.40 90.41 359.34 3,990.59 3,897.97 764.80 4,393.74 5,981,456.35 553,965.62 0.29 3,18111 MWD+IFR-AK-CAZSC(5) 8,861.92 89.77 358.55 3,990.44 3,897.82 860.30 4,391.99 5,981,551.83 553,963.23 1.06 3,125.41 MWD+IFR-AK-CAZ-SC(5) 8,956.32 89.61 357.37 3,990.96 3,898.39 954.64 4,388.64 5,981,646.13 553,95926 127 3,069.05 MWD+IFR-AK-CAZ-SC(5) 9,051.14 8953 357.07 3,991.67 3,89905 1,049.34 4,364.04 5,981,740.79 553,954.03 0.33 3,011.46 MWD+1FR-AK-CAZSC(5) 9,146.23 90.17 358.70 3,991.92 3,899.30 1,144.37 4,380.53 5,981,835.78 553,949.90 1.84 2,954.58 MWD+IFR-AK-CAZ-SC(5) 9,240,50 90.03 35949 3,991.75 3,899.13 1,238.62 4,379.04 5,981,930.02 553,947.78 0.85 2,89960 MWD+IFR-AK-CAZ-SC(5) 9,335.07 9168 359.13 3,990.34 3,89712 1,333.17 4,377.90 5,982,024.55 553,946.02 1.79 2,845.14 MWD+IFR-AK-CAZ-SC(5) 9,431,06 91.67 0.48 3,987.53 3,894.91 1,429.12 4,377.58 5,982,12048 553,945.06 1.41 2,790.36 MWD+IFR-AK-CAZSC(5) 9,525.17 8949 0.42 3,986.58 3,893.96 1,523.21 4,378.32 5,982,21457 553,945.17 2.32 2,737.51 MWD+IFR-AK-CAZ-SC(5) 9,620.04 90.18 0.55 3,98686 3,894.24 1,618.06 4,379.12 5,982,309.43 553,945.35 0.74 2,684.27 MWD+IFR-AK-CAZ-SC(5) 9,71468 88.36 0.62 3,988.06 3,895.44 1,712.70 4,380.09 5,982,404.05 553,945.69 1.92 2,631.30 MWD+IFR-AKCAZ-SC(5) 9,808.64 86.98 357.22 3,991.88 3,899.26 1,806.55 4,378.32 5,982,497.88 553,943.30 3.90 2,576.52 MWD+1FR-AKCAZSC(5) 9,900.53 86.57 354.06 3,997.05 3,904.43 1,898.02 4,371.34 5,982,58929 553,935.72 3.46 2,518.81 MWD+IFR-AK-CAZ-SC(5) 9,991.81 87.19 34927 4,002.02 3,909.40 1,988.18 4,358.13 5,982,679.34 553,921.92 528 2,456.72 MWD+IFR-AK-CAZ-SC(5) 10,08270 89.17 345.80 4,004.91 3,91229 2,076.86 4,338.53 5,982,767.89 553,901.73 4.39 2,390.20 MWD+IFR-AK-CAZ-SC(5) 10,175.03 90.03 344.43 4,005.56 3,912.94 2,166.09 4,314.81 5,982,856.95 553,877.42 115 2,319.98 MWD+IFR-AKCAZSC(5) 10,265.69 90.75 343.05 4,004.94 3,912.32 2,253.12 4,289.43 5,982,94380 553,851.47 1.72 2,24985 MWD+IFR-AK-CAZ-SC(5) 10,358.97 89.72 347.53 4,004.56 3,911.94 2,343.31 4,265.75 5,983,033.83 553,827.19 4.93 2,178.92 MWD+IFR-AK-CAZ-SC(5) 1Q45129 90.10 353.55 4,004.70 3,912.08 2,434.34 4,250.58 5,983,124.74 553,811.43 6.53 2,114.72 MWD+IFR-AKCAZ-SC(5) iQ543.80 88.55 358.56 4,005.79 3,913.17 2,526.59 4,244.22 5,983,21894 553,504.45 567 2,057.07 MWD+IFR-AKCAZSC(5) 10,635.34 89.21 1.04 4,007.58 3,914.96 2,618.10 4,243.90 5,983,308.44 553,803.53 2.80 2,004.81 MWD+IFR-AK-CAZ-SC(6) 10,727.85 89.52 1.56 4,008.61 3,915.99 2,710.58 4,246.00 6,983400 92 553,805.02 0.65 1,953.99 MWD+IFR-AK-CAZ-SC(5) 10,818.96 89.24 1.66 4,009.59 3,91697 2,801.65 4,248.56 5,983,49200 553,806.97 0.33 1,904.35 MWD+IFR-AKCAZSC(5) 10,911.12 68.33 1.79 4,01155 3,918.93 2,893.75 4,251.33 5,983,584.10 553,809.14 1.00 1,854.31 MWD+IFR-AK-CAZ-SC(5) 11,004.59 88.16 1.56 4,014.41 3,921.79 2,987.13 4,254.06 5,983,67749 553,811.25 0.31 1,803.50 MWD+IFR-AK-CAZ-SC(5) 11,095.59 86.50 0.54 4,018.65 3,925.03 3,078.02 4,25573 5,983,76837 553,812.31 2.14 1,753.23 MWD+IFR-AKCAZSC(5) 11,187.29 85.96 358.54 4,02468 3,932.06 3,169.51 4,255.00 5,983,859.85 553,810.97 2.25 1,700.64 MWD+IFR-AK-CAZ-SC(5) 11,282.17 85.88 356.05 4,031.43 3,938.81 3,254.04 4,250.53 5,983,954.34 553,805.88 2.62 1.643.26 MWD+IFR-AK-CAZ-SC(5) 11,37343 86.89 355.12 4,037.18 3,944.56 3,354.84 4,24352 5,984,045.09 553,79827 1.50 1,585.90 MWD+IFR-AK-CAZ-SC(5) 9272017 2:04:26PM Page 5 COMPASS 5000 14 Build 85 Conocolphillips Definitive Survey Report Company: NADConvemion Local Co-ordinate Reference: Well Rig: 1 H-102 Projects Kuparuk River Unit TVD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Sita: Kuparuk 1H Pad MD Reference: 1H-102 actual Q 92.62usft (Doyon 142) Wait Rig: 11-1-102 North Reference: True Wellbore: 1 H-102 Survey Calculation Method: Minimum Curvature Design: 1H-102 Database: OAKEDMP2 Survey 0 Surface Coordinates El Declination & Convergence GRS Survey Corrections Q Survey Tool Codes DabM'z9eM Mraiwa Brandon Temple SLB DE: KelseyHallford Client Representative. Date: Map Map Vertical MD Inc Art TVD TvDSs +W -s +E/ -W Northing Eaeting DLS Section (usft) (% (°) (usft) (USM (usft) (usft) (ft) (ft) (/1001 (1t) Survey Tool Name 11,465.69 8859 354.42 4,040.82 3,948.20 3,446.64 4,235.12 5,984136.82 553,789.26 1.99 1,526.82 MWD+IFR-AK-CAZSC(5) 11,556.63 89.94 355.12 4,041.99 3,949.37 3,537.19 4,22683 5,98,227.31 553,780.37 1.67 1,468.55 MWD+IFR-AK-CA7-SC(5) 11,649.60 92.35 355.70 4,040.13 3,947.51 3,629.84 4,219.39 5,984,319.89 553,772.32 2.67 1,409.79 MWD+IFR-AKCAZSC(5) 11,741.18 92.45 359.34 4,03629 3,943.67 3,721.24 4,215.43 5,984,41125 553,767.76 3.97 1,354.61 MWD+IFR-AK-CAZSC(5) 11,834.01 91.19 0.11 4,033.35 3,940.73 3,814.02 4,214.99 5,964,504.02 553,766]0 1.59 1,301.53 MWD+IFR-AKCAZSC(5) 11,926.28 91.63 359.99 4,031.08 3,938.46 3,906.26 4,215.07 5,984,596.25 553,76617 049 1,249.18 MWD+IFR-AKCAZSC(5) 12,018.18 92.17 1.66 4,028.03 3,935.41 3,998.10 4,216.39 5,984,688,08 553,768.89 1.91 1,19809 MWO+IFR-AKCAZ-SC (5) 12,111.54 91.70 0.91 4,024.88 3,932.26 4,091.38 4,218.48 5,984,781.37 553,768.36 0.95 1,146.81 MWD+IFR-AKCAZSC(5) 12,199.78 91.11 0.45 4,022.71 3,930.09 4,179.58 4,219.53 5,984,869.57 553,768.82 0.85 1,097.56 MWD+IFR-AKCAZSC(5) 12,291.94 90.99 1.00 4,021.02 3,928.40 4,271.72 4,22069 5,984,961.71 553,769.38 0.61 1,046.17 MWD+IFR-AK-CAZ-SC(5) 12,382.53 90.61 3.23 4,019.76 3,927.14 4,36223 4,224.04 5,985,05223 553,772.12 2.50 997.49 MWD+IFR-AKCAZSC(5) 12,475.25 89.87 2.12 4,019.37 3,926.75 4,454.85 4,228.36 5,985,144.86 553,775.84 1.44 948.43 MWD+IFR-AK-CAZ-SC(5) 12,568.48 89.77 2.90 4,019.66 3,927.04 4,547.99 4,232.45 5,985,23802 553,T9.30 0.84 898.87 MM1FR-AKCAZ-SC(5) 12,659.85 90.34 0.13 4,019.58 3,926.96 4,639.33 4,234.86 5,985,329.36 553,781.11 3.09 848.96 MWD+IFR-AKCAZSC(5) 12,75268 89.21 35867 4,019.94 3,927.32 4,732.14 4,233.89 5,985,422.16 653,779.53 1.99 795.43 MWD+IFR-AK-CAZ-SC(5) 12,790.00 89.25 358.44 4,02044 3,927.82 4,769.44 4,232.95 5,985,459.45 553,778.34 0.62 773.46 NO7anAdualSurvay 4.1124 x 6-3hr 12,844.88 89.30 358.11 4,021.14 3,928.52 4,824.29 4,231.30 5,985,514.28 553,776.33 0.62 740.94 MWD+IFR-AK-CAZ-SC(5) 12,899.09 89.30 35862 4,021.80 3,929.18 4,878.48 4,229.75 5,985,558.45 553,774.42 0.94 708.88 MWD+IFR-AKCAZ-SC(5) 12,960.00 89.30 358.62 4,022.55 3,929.93 4,939.37 4,228.29 5,985,629.32 553,772.55 0.00 673.08 PROJECTED to TD Final Definitive Survey Verified and Signed -off All targets andlor "I1 position objectives have been achieved. '.'E Yes ,-j No I have chocked to the best of my ability that the following data is correct: 0 Surface Coordinates El Declination & Convergence GRS Survey Corrections Q Survey Tool Codes DabM'z9eM Mraiwa Brandon Temple SLB DE: KelseyHallford Client Representative. Date: 09/2712017 927/2017 2:04:26PM Page 6 COMPASS 5000.14 Build 85 Cement Details Description Conductor Cement Cementing StartDate 1/11/201618:15 Cementing End Date 1/11/201622:15 Wellbore Name iH-102 Comment Cement Stages Stage # 1 Description Conductor Cement Objective cement 20" x 34" Insulated conductor in 42" hole Top Depth (ftKB) 43.1 Bottom Depth (ftKB) 118.6 Full Return? No Vol Cement... Top Plug? No Btm Plug? No Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) ReciP7 No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) 105.0 Tag Method Drill Bit Depth Plug Drillea Out To (ftKB) Drill 118.6 Out Diameter (in) 13 1/2 Comment Cement Fluids 8 Atltlitives Fluid Fluid Type 3500 mix Fluitl Description Estimated Top (ftKB) 43.1 Est Elm (ftKB) 118.6 Amount (sacks) Class Volume Pumpetl (bbl) Yield JftI.aCKJ Mix H2g Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa-s) Thickening Time (hr) CmprStr 1 (psi) Additives Atltlitive Type Concentration Conc Unit label I rage i/i ReportPrinted: 11/14/20171 e Cement Detail Repoli 11-1-102 String: Surface Casing Cement Job: DRILLING ORIGINAL, 8122/201718:00 Cement Details Description Cementing Start Date Cementing End Dat Wellbore Name Surface Casing Cement 8/25/2017 1815 8,25/20,722. 07 1H-102 Comment Stage pumps up to 8 BPM 290 PSI DPP with 268 PSI FDPP. 23% F/O. While recip from 1,740-1770' MD. Pump maker sweep and observe back at 3,650 STKS. 12,000 Total stks pumped @ 8 BPM. UP WT = 117K OWN WT = 109K. Line up SLB pump 5 BBLS CW100, PT lines & chart 3,500 PSI test. Pump remainder CW for total BBLS of 40 @ 3.1 BPM 75 PSI DPP, 15% F/O. Batch up and pump'77.4 BBLS 10.5 PPG Mud Push. @ 3.5 BPM 115 PSI DPP. 19% F/O. Drop BTM plug. Batch and pump 298 BBLS of 11# cement ( yield 1.91 cuft/sx, mix water 6.828 gal/sx, thickening time 6hr 22 min) @ 5.6 BPM 180 PSI DPP, 21% F/O. Batch and pump 61.9 BBLS 12# tail cement (yield 1.65 cuf /sx, mix water 5.733 gal/sx, thickening time 4 hr 1 min) and pump at 4 BPM 164 PSI DPP with 19% F/O. Drop top plug and pump with 10 BBLS H2O, UP WT = 111 K-DWN WT = 95K. Chase cement with dg pumps utilizing 9.6# mud @ 5 BPM 330 PSI 31-55% F/O. from 1356 STKS reduce rale to 3 BPM 300 PSI FCP 56% F/O. Bump plug at 1,502 STKS at 2207. increase pressure to 1,082 PSI and hold for 5 min. Bleed off pressure and check floats. GOOD. Cement in place at 2207 hrs. Recip until last 30 bbls pumped. Circulated contaminated cement to surface 67.7 bbls prior to bumping the plug, circulated 9 bbls of good 11. ppg cement to surface. CIP 2207 hrs 812 512 01 7. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement Cement 10 3/4" 42.0 1,777.0 Yes 9.0 Yes Yes Q Pump Init (bbl/m... Q Pump Final (bbl/... IQ Pump Avg (bb9... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotatedl Pipe RPM (rpm) 51 3 5 286.0 1,082.0 Yes 30.00 No I 7a99etl Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Bit 1,777.0 97/8 Comment Stage pumps up to 8 BPM 290 PSI DPP with 268 PSI FDPP. 23% F/O. While recip from 1,740-1770' MD. Pump maker sweep and observe back at 3,650 STKS. 12,000 Total stks pumped @ 8 BPM. UP WT = 117K OWN WT = 109K. Line up SLB pump 5 BBLS CW100, PT lines & chart 3,500 PSI test. Pump remainder CW for total BELS of 40 @ 3.1 BPM 75 PSI DPP. 15% F/O. Batch up and pump 77.4 BBLS 10.5 PPG Mud Push. @ 3.5 BPM 115 PSI DPP. 19% F/O. Drop BTM plug. Batch and pump 298 BBLS of 11# cement ( yield 1.91 wft/sx, mix water 6.828 gal/sx, thickening time 6hr 22 min) @ 5.6 BPM 180 PSI DPP, 21% F/O. Batch and pump 61.9 BBLS 12# tail cement (yield 1.65 cufl/sx, mix water 5.733 gal/sx, thickening time 4 hr 1 min) and pump at 4 BPM 164 PSI DPP with 1g% F/O. Drop lop plug and pump with 10 BBLS H2O, UP WT = 111 K-DWN WT= 95K. Chase cement with rig pumps utilizing 9.6# mud @ 5 BPM 330 PSI 31-55% F/O. from 1356 STKS reduce rate to 3 BPM 300 PSI FCP 56% F/O. Bump plug at 1,502 STKS a12207. increase pressure to 1,082 PSI and hold for 5 min. Bleed off pressure and check floats. GOOD. Cement in place at 2207 hrs. Recip until last 30 bbls pumped. Circulated contaminated cement to surface 67.7 bbls prior to bumping the plug; rarculated 9 bbis of good 11. ppg cement to surface. CIP 2207 hrs 8/25/2017. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top IRKS) Est Btm IRKS) Amount (sacks) Class Volume Pumped (bbl) MudPush II 1 1 1 1 1 1 77,4 Yield (Ir/sack) Mix H2O Ratio (seven... Free Water (%) Density ub/gal)Plastic Viscosity pa -S) Time (hr) CmprStr 1 (psi) oso 10 60 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 42.0 1,250.2 876 1 298.0 Yield m/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (lbigal)Plastic Viscosity (Pa•s) Thickening Time (hr) Cmprstr 1 (psi) 1.91 6.83 11.00 6.37 Additives Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D185 Dispersant 0.08 %BWOC Additive Type Concentration Conc Unit label D177 Retarder 0.02 gal/sx Fluid Fluid TypeFluitl Description Estimated Top (ftKB) Est Bim (tate) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 1,250.2 1,777.0 211 61.9 Yield (Wisack) Mix H2O Ratio (gal/sa... Free water (%) Density (lb/gal)Plastic Viscosity (Pa•a) Thickening Time (hr) CmprStr 1 (psi) 1.65 5.73 12.02 4.00 Additives Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D185 Dispersant 0.1 %BWOC Additive Type ConcentrationConc unit label D177 Retarder 0.005 gallsx Page 1/2 ReportPrinted: 11/14/2017 Cement Detail Report 11-1-102 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 8/22/2017 18:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 9/3/2017 03:00 9!3/2017 06:10 1H- 102 Comment Pump cement job as follows: SLB pump 5 bbls freshwater and pressure test lines to 400 / 3500 psi - good test. Pump 50 bbls 12.5ppg Mudpush at 3 bpm, ICP 450 psi, FCP 210 psi. Drop Davis Lynch anti -rotational bottom plug. Batch mix cement, cement wet at 03:46 hrs. SLB pump total of 239.3 bbls 15.8ppg Class G cement. Pumped 170 bbls alb bpm, ICP 459 psi, FCP 315 psi. Then observe "H" pump fail so swap to "G' pump which has slightly lower rate capacity. Did not have to stop pumping but rate briefly dropped to -3 bpm. Continue pumping additional cement at -4.5 bpm, ICP 230 psi, FCP 190 psi. Drop Davis Lynch anti - rotational top plug. SLB pump 10 bbls freshwater at 4 bpm, 120 psi. Reciprocate pipe -15 ft, PUW 220k, SOW 95k. Swap to rig mud pump #1 and displace cement with 9.3ppg LSND at 8 bpm for 3250 strokes, ICP 242 psi, FCP 1587 psi. Drop rate to 3 bpm and continue displacing cement, ICP 1120 psi. Bump plug at 3797 strokes, FCP 1423 psi. Pressure up to 2000 psi and hold for 5 minutes. Bleed off and check floats - floats holding. Cement in place @ 06:10 hrs. Note: Total downhole losses throughout cement job = 11 bbls Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing Cement Intermediate 4,250.0 8,591.0 No Yes Yes Cement casing O Pump /nit (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 1,423.0 2,085.0 Yes 15.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) -rut Diameter (in) 63/4 Comment Pump cement job as follows: SLB pump 5 bible freshwater and pressure test lines to 400 / 3500 psi - good test. Pump 50 bbis 12.5ppg Mudpush at 3 bpm, ICP 450 psi, FCP 210 psi. Drop Davis Lynch anti -rotational bottom plug. Batch mix cement, cement wet at 03:46 hrs. SLB pump total of 239.3 bbls 15.8ppg Class G cement. Pumped 170 bbls at 6 bpm, ICP 459 psi, FCP 315 psi. Then observe "H" pump fail so swap to "G' pump which has slightly lower rate capacity. Did not have to stop pumping but rate briefly dropped to -3 bpm. Continue pumping additional cement at -4.5 bpm, ICP 230 psi, FCP 190 psi. Drop Davis Lynch anti - rotational top plug. SLB pump 10 bbls freshwater at 4 bpm, 120 psi. Reciprocate pipe -15 ft, PUW 220k, SOW 95k. Swap to rig mud pump #1 and displace cement with 9.3ppg LSND at 8 bpm for 3250 strokes, ICP 242 psi, FCP 1587 psi. Drop rate to 3 bpm and continue displacing cement, ICP 1120 psi. Bump plug at 3797 strokes, FCP 1423 psi. Pressure up to 2000 psi and hold for 5 minutes. Bleed off and check floats - floats holding. Cement in place @ 06:10 hrs. Note: Total downhole losses throughout cement job = 11 bbls Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB)Est Btm (ftKe) Amount (sacks) Class Volume Pumped (bbl) Mud Push 3,317.0 4,250.0 1 50.0 Yield (ft /sack) Mix H2O Ratio (gal/es... Free Water (%) Density (lb/gal) Plastic Viscosity (Pais) Thickening Time (hr) Cmprstr 1 (psi) 12.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Bim (ftKB) Amount (sacks) Class Volume Pumped (bbl) Cement 4,250.0 8,591.0 1,159 G 239.3 Yield m --sack) Mix H2O Ratio (gallsa... Free Water (%) Density (lWgal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.12 15.80 1 4.30 Additives Additive Type Concentration Cone Unit label D255 aFluid Loss 0.5 %BWOC Additive Type Concentration Cone Unit label D047 Antifoam 0.05 gal/sx Additive Type Concentration Cone Unit label D065 Dispersant 0.3 %BWOC Page 111 Report Printed: 11/14/2017 RECEIVED 21 7097 mbar er 9 AOGCCransmittal #: 260CT17-SP01 Drilling & Measurements DATA LOGGED Product Delivery \'. 1 \- 1201'% :.I. K. BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well Name: 1H-102 Service Order #: 17AKA0021 Date Dispatched: 26 -Oct -17 Dispatched By: Stephanie Pacillo Product Description Hardcopy Digital Copy Logging Date Color Log Prints: 4 Contents on CD 8 -Sep -17 Scope Resistivity 2" MD x x 2" TVD x x 5" MD x x 5' TVD x x Digital Data NIA Contents on CD LAS/DLIS Data x Surveys 2 Contents on CD Directional Survey Nad27 x x Directional Survey Nad83 x x CD 1 Contents on CD Data: DLIS/ LAS x Graphics: PDF x Surveys: PDF/TXT x Please sign and email a copy to: Please sign and email a copy to: Tom.Osterkamo(aD,conocophillips.com Alaska PTSPrintCenter(a)slb.com Attn: Tom Osterkamp Attn: Stephanie Pacillo Received By: RECEIVED OCT 2 6 2017 FINAL AOGCC NADConversion Kuparuk River Unit Kuparuk 1H Pad 1H-102 1H-102 NAD 27 ConocoPhillips Definitive Survey Report 27 September, 2017 21 7097 28 74 8 ConocoPhillips ConoccPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Rig: 1H-102 Project: Kuparuk River Unit TVD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Well: Rig: 1H-102 North Reference: Time Wellbore: 1H-102 Survey Calculation Method: Minimum Curvature Design: 1 H-102 Database: OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States 54.00 usft Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) (°/700') Using Well Reference Point Map Zone: Alaska Zone 04 0.00 Using geodetic scale factor Well Rig: 1H-102 Well Position +N/ -S 0.00 usft Northing: 5,980,662.56 usft Latitude; 70" 21' 28.630 N 67.62 +E/ -W 0.00 usft Easting: 549,577.46 usft Longitude: 149° 35'50.423 W Position Uncertainty Direction 0.00 usft Wellhead Elevation: (usft) usft Ground Level: 54.00 usft Wellbore 11-1-102 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2017 9/15/2017 17.48 60.85 57,491 Design 1H-102 Date Gyrodata gyro single shots From To Audit Notes: (usft) (usft) Survey (Wellbore) Tool Name 67.62 Version: 1.0 Phase: ACTUAL Tie On Depth: 38.62 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction MWD-INC_ONLV (usft) (usft) (usft) (°) (°) 38.62 0.00 0.00 124.62 Vey Program Date Gyrodata gyro single shots From To 8/24/201710'12 (usft) (usft) Survey (Wellbore) Tool Name 67.62 1,009.26 1H-102 Srvy 1 - SLB GWD70 (1H-102) GVD-GC-SS 1,050.36 1,678.041H-102 Srvy 2 -SLB MWD+GMAG(1 H- MWD+IFR-AK-CAZ-SC 1,777.33 8,533+681H-102 Srvy 3-SLB_MWD+GMAG(1 H- MWD+IFR-AK-CAZ-SC 8,577.06 8,577.061H-102 SrW 4- SLS _MWD-INC_Filler(1 MWD-INC_ONLV 8,672.02 12,899.091H-102 Srvy 5-SLBMWD+GMAG(1H- MWD+IFR-AK-CAZ-SC Survey Description Survey Date Gyrodata gyro single shots 8/24/2017 10:04 MWD+IFR AK CAZ SCC 8/24/201710'12 MWD+IFR AK CAZ SCC 8/27/2017 12:16 MWD -INC -ONLY -FILLER 9/5/2017 9:03:0 MWDHFR AK CAZ SCC 9/5/2017 9:06:0 927!2017 2:04:26PM Page 2 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +N/.S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/700') (ft) Survey Tool Name 38.62 0.00 0.00 38.62 -54.00 0.00 0.00 5,980,662.56 549,577.46 0.00 0.00 UNDEFINED 67.62 0.19 41.29 67.62 -25.00 0.04 0.03 5,980,662.60 549,577.49 0.66 Oct GVD-GC-S$ (1) 165.90 0.45 132.01 165.90 7328 -0.10 0.43 5,980,66246 549,577.89 0.50 0.41 GVD-GC.SS(1) 258.98 1.01 128.15 258.97 166.35 -0.85 1.39 5,980,661.72 549,578.81 0.60 1.59 GVD-GC-SS(1) 354.48 3.34 138.19 354.40 261.78 -344 3.86 5,980,659.14 549,581.34 2.46 5.13 GVD-GC-$S(1) 447.17 4.61 135.26 446.86 354.24 -8.10 8.28 5,980,654.51 549,585.79 1.39 11.42 GVD-GC-SS(1) 539.82 5.77 13242 539.13 446.51 -13.89 14.34 5,980.648.77 549,591.89 1.28 19.89 GVD-GC-SS(1) 632.84 7.61 134.49 631.51 538.89 -21.36 22.19 5,980,641.35 549,599.79 1.99 30.39 GVD-GC-SS (1) 725.82 6.77 137.82 723.54 630.92 -30.93 3134 5,98D631.64 549,609.00 1.35 43.36 GVD-GC-SS(1) 821.24 1013 141.32 817.58 724.96 -43.25 41.78 5,980,619.59 549,619.52 2.15 58.95 GVD-GC-SS(1) 927!2017 2:04:26PM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Rig: 1 H-102 Project: Kuparuk River Unit TVD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Site: Kupamk 1 H Pad MD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Well: Rig: 11-1-102 North Reference: True Wellbore: 1H-102 Survey Calculation Method: Minimum Curvature Design: 1H-102 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DSS Section (weft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 91420 12.89 139.61 908.57 81595 -57.91 53.90 5,980,60501 549,631.74 2.35 77.26 GYD-GC-SS(1) 1009.26 14.89 136.85 1,000.84 908.22 -74.90 69.13 5,980,568.13 549,647.08 2.22 99.44 GYD-GPSS(1) 1,050.36 15.72 135.% 1,040.49 947.87 -82]5 76.61 5,980,580.32 549,654.61 2.10 110.06 MWD+IFR-AK-CAZ-SC(2) 1,144.89 17.17 134.37 1,131.15 1,038.53 -10172 95.49 5,980,561.49 549,673.61 1.61 136.37 MWD+IFR-AK-CAZ-SC(2) 1,239.16 20.84 134.25 1,220.26 1,127.64 -123.16 117.46 5,980,54020 549,695.72 3.89 16663 MWD+IFR-AK-CAZ-SC(2) 1,334.20 24.71 136.54 1,307.88 1,215.26 -149.38 143.24 5,980.514.14 549,721.67 4.18 202.75 MWD+IFR-AK-CAZ-SC(2) 1,428.98 27.54 137.49 1,392.97 1,300.35 -179.92 171.68 5,980,483.80 549,750.31 3.02 243.50 MWD+IFR-AK-CAZ-SC(2) 1,523.25 28.14 137.93 1,47633 1,383.71 -212.49 201.30 5,980,451.43 549,780.14 0.67 286.38 MWD+IFR-AK-CAZ-SC(2) 1,618.09 2894 137.33 1,559.64 1,467.02 -245.96 231.84 5,980,418.16 549,610.90 0.90 330.53 MWD+IFR-AK-CAZ-SC(2) 1,678.04 29.99 135.80 1,611.84 1,519.22 -267.37 252.11 5,980,396.89 549.831.31 2.15 359.38 MWD+IFR-AK-CAZ-SC(2) 1,771.00 33.38 135.72 1,690.93 1,598.31 -302.34 286.17 5,980,362.15 549,865.60 365 407.28 Till AChli(SiI1YRy 10 3/4" z 13.1/2' 1,77233 33.61 135.72 1,696.21 1,603.59 -304.85 28861 5,980.359.66 549,868.06 3.65 410.71 MWD+IFR-AK-CAZ-SC(3) 1,801.61 34.53 13479 1,716.32 1,623.70 -314.50 298.19 5,980,350.07 549,677.69 4.35 424.07 MWD+IFR-AK-CAZ-SC (3) 1,896.66 37.81 133.50 1,793.04 1,700.42 -353.55 338.45 5,980.311.29 549,918.21 3.54 479.39 MWD+IFR-AK-CAZ-SC(3) 1,991.93 40.86 131.83 1,866.72 1,774.10 -394.45 382.87 5,980,27070 $49,962.69 3.39 539.18 MWD+IFR-AK-CAZ-SC(3) 2,086.48 43.97 130.99 1,936.52 1843.90 -43661 430.70 5,980,228.85 550011.00 3.34 602.50 MWD+IFR-AWCAZ-SC(3) 2,184.36 47.16 129.49 2,005.04 1,91242 -08173 484.06 5,980,184.09 550,064.65 3.44 672.04 MWD+IFR-AK-CAZ-SC(3) 2,276.23 5006 12877 2,065.76 1,973.14 -525.22 537.53 5,980,140.96 550,11840 3.23 74076 MWD+1FR-AK-CAZ-SC(3) 2,371.48 53.12 127.35 2,124.92 2,032.30 571.22 596.31 5,980,095.36 550,177.48 3.40 81526 MWD+IFR-AK-CAZ-SC(3) 2,464.98 55.35 124.47 2,179.57 2,086.95 -615.68 657.76 5,980,051.30 550,239.21 3.45 891.09 MWD+1FR4K-CAZSC(3) 2,559.60 5673 122.73 2.232.43 2,139.61 -659.10 723.12 5,980,008.32 550,304.86 2.11 969.55 MWD+IFR-AK-CAZ-SC(3) 2653.87 58.79 12243 2,282.72 2,190.10 -702.03 790.31 5,979,96584 550,372.32 2.20 1,049.23 MWD+IFR-AK-CAZ-SC(3) 2,748.30 59.37 121.74 2,331.24 2,238.62 -745.06 85895 5,979,923.27 550,441.23 0.88 1,130.16 MWD+IFR-AK-CAZ-SC(3) 2,643.07 61.40 121.48 2,378.07 2,28545 -788.24 929.11 5,979,880.56 550,511.67 2.16 1,212.43 MWD+IFR-AK-CAZ-$C(3) 2,937,25 65.11 121.93 2,420.45 2,327.83 -832.44 1,000.65 5,979,836.84 550,583.50 3.96 1,296.41 MWD+IFR-AK-CAZ-SC(3) 3,032.88 69.13 121.16 2,457.62 2,365.00 -878.52 1,075.72 5,979,79127 550,658.87 4.27 1,384.37 MWD+IFR-AK-CAZ-SC(3) 3,126.86 71.43 121.37 2,489.33 2,396.71 -924.43 1,151.34 5,979,745.86 550,734.78 2.46 1,47268 MWD+IFR-AK-CAZ-SG(3) 3,221.95 72.62 121.37 2,51867 2,426.05 -971.51 1,228.56 5,979,69929 550,812.31 1.25 1,562.98 MWD+IFR-AK-CAZ-SC(3) 3,31646 73.03 121.69 2,546.58 2453.96 -1,01873 1,305.53 5,979,652.59 550,889.57 0.54 1653.15 MWD+IFR-AK-CAZ-SC(3) 3,410.86 73.34 122.71 2,57389 2,481.27 -1,066.89 1,381.99 5,979,604.95 550.966.35 1.09 1,743.43 MWD+IFR-AK-CAZ-SC(3) 3,506.07 7321 122.55 2,601.29 2,50867 -1,116.05 1,458.78 5,979,556.30 551,04345 0.21 1,834.55 MWD+IFR-AK-CAZ-SC(3) 3,601.42 7321 122.70 2,628.83 2,535.21 -1,165.27 1,535.66 5,979,507.59 551,12065 0.15 1,925.78 MWD+IFR-AK-CAZ-SC(3) 3,696.85 73.21 122.29 2,656.40 2,563.78 -1,214.35 1,612.72 5,979,45903 551,198.03 0.41 2,017.08 MWD+IFR-AK-CAZ-SC(3) 3,791.46 7330 120.98 2,683.68 2.591.04 -1,261.87 1,689.85 5.979,41203 551,275.46 1.33 2,107.56 MWD+IFR-AK-CAZ-SC(3) 3,886.74 73.14 118.95 2.711.17 2,61855 -1,307.43 1 ]68.88 5,979,366.99 551,354.78 2.05 2,198.47 MWD+IFR-AK-CAZ-SC (3) 3,981.94 73.09 119.69 2,738.82 2,646.20 -1,352.00 1,848.32 5,979,322.95 551,434.51 0.70 2,289.17 MWD+IFR-AK-CAZ-SC(3) 4,07641 73.30 119.87 2,766.13 2,673.51 -1,396.88 1,926.84 5,979,278.59 551,513.31 0.32 2,379.28 MWD+IFR-AK-CAZ-SC(3) 4,17102 73.17 118.99 2,793.42 2,700.80 -1,441.40 2,005.73 5,979,234.61 551,592.49 0.90 2,469.50 MWD+IFR-AK-CAZ-SC(3) 4,266.02 7306 119.53 2,821.02 2,72840 -1,485.83 2,085.04 5,979,190.71 551,672.08 0.56 2,560.01 MWD+IFR-AK-CAZ-SC(3) 4,360.46 73.01 11904 2,848.57 2,755.95 -1,530.01 2,163.83 5,979,147.05 551,751.15 0.50 2,649.94 MWD+1FR-AK-CAZ-SC(3) 9272017 Z04:26PM Page 3 COMPASS 5000.14 Build 85 I ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Rig: 11-1-102 Project: Kupamk River Unit TVD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Site: Kupamk 1H Pad MD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Well: Rig: 1H-102 North Reference: True Wellbore: 1 H-102 Survey Calculation Method: Minimum Curvature Design: 1 H-102 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +El -W Northing Easgng DLS Section (usft) V) (°) (usft) (usft) lust) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4.455.58 72.90 119.77 2,876.45 2,783.83 -1,574.66 2,243.05 5,979,10293 551,830.% 0]4 2,740.51 MWD+IFR-AK-CAZ-SC (3) 4,549.81 72.87 120.06 2,904.19 2,811.57 -1,619.57 2,321.11 5,979,058.54 551,909.01 0.30 2,830.26 MWD+1FR-AK-CAZ-SC(3) 4,644.52 73.20 11840 2,931.82 2,839.20 -1,663.81 2,400.16 5.979,014 84 551,988.35 1.71 2,92044 MWD+IFR-AK-CAZ-SC(3) 4739.99 72.42 114.51 2,960.05 2,867.43 -1,704.44 2.481.79 5,978,974.75 552,070.24 3.98 3,01070 MWD+IFR-AK-CAZ-SC(3) 4,786.24 72.31 110.47 2,974.06 2,881.44 -1721.29 2.522.51 5,978,958.17 552,111.06 8.33 3,053.79 MWD+IFR-AK-CAZ-SC(3) 4,833.76 72.48 108.23 2.988.44 2,895.82 -1,736.30 2565.24 5,978,943.45 552,153.89 4.51 3,097.48 MWD+IFR-AK-CAZ-SC(3) 4,928.09 7221 103.78 3,017.06 2,92444 -1.761.08 2,651.62 5,978,919.24 552.240.42 4.50 3,182.64 MWD+IFR-AK-CAZ-SC(3) 5.02287 71.11 10068 3.046.89 2,954.27 -1,780.14 2.739.52 5,978,900.76 552,328.44 3.31 3,265.81 MWD+IFR-AK-CAZ-SC(3) 5,070.23 71.27 98.69 3,062.16 2,969.54 -1787.68 2,783.71 5,978,893.52 552,372.67 3.99 3,306.45 MWD+IFR-AK-CAZ-SC(3) 5,116.77 71.68 96.97 3,076.95 2,984.33 -1,79369 2,827.43 5,978,88779 552,416.42 3.51 3,34584 MWD+IFR-AK-CAZ-SC(3) 5,211.19 72.12 93.77 3,106.29 3,013.67 -1,802.09 2,916.77 5,978.87999 552,505.81 3.25 3,424.13 MWD+IFR-AK-CAZ-SC(3) 5,305.75 71.74 88.59 3,135.69 3,043.02 .1,803.94 3,00661 5,978,878.73 552,59565 522 3,499.12 MWD+IFR-AK-CAZ-SC(3) 5,400.08 71.70 83.77 3,165.24 3,072.62 -1,797,98 3,095.95 5,978,885.29 552,684.94 4.85 3,569.25 MWD+IFR-AK-CAZ-SC (3) 5,495.26 72.32 81.29 3,194.64 3,102.02 -1)86.21 3,185.70 5,978,897.65 552,774.60 2.56 3,636.41 MWD+IFR-AK-CAZ-SC(3) 5,590.01 72.15 76.05 3,223.57 3,130.95 -1,768,49 3,274.13 5,978,915.95 552,862.91 5.27 3,699.12 MWD+IFR-AK-CAZ-SC(3) 5,685.45 72.61 70.23 3252.48 3,159.86 -1,742.11 3,361.14 5,976.94290 552,949.73 5.83 3,755.73 MWD+IFR-AK-CAZ-SC(3) 5,779.73 73.02 64.52 3,280.36 3,187.74 -1,707.48 3.444.24 5,978,978.08 553,032.59 580 3,80444 MWD+IFR-AK-CAZ-SC(3) 5,874.02 73.87 63.M 3,307.23 3,21461 -1,667.90 3,52549 5,979,018.19 553,113.57 1.34 3.848.81 MW0+IFR-AK-CAZ-SC(3) 5,968.69 74.38 63.99 3,333.12 3,240.50 -1,627.64 3,607.17 5,979,058.98 553,194.97 0.71 3,893.16 MM+IFR-AK-CAZ-SC(3) 6,063.17 74.61 63.93 3,358.38 3,265.76 -1,587.68 3,688.97 5,979,099.49 553,276.50 0.25 3,937.76 MWD+IFR-AK-CAZ-SC(3) 6,156.96 7468 58.30 3,383.23 3,290.61 -1,544.01 3,768.12 5,979,14367 553,355.35 5.79 3,978.09 MWD+IFR-AK-CAZ-SC(3) 6,252.33 74.03 54.53 3,408.96 3,316.34 -1,493.22 3,844.61 5,979.194.96 553,431.50 3.87 4,012.18 MWD+IFR-AK-CAZ.SC(3) 6,346.97 72.68 51.05 3,436.08 3,343.46 -1,438.41 3,916.82 5,979,250.25 553,503.33 3.80 4,040.45 MWD+1FR-AK-CAZ-SC (3) 6,44176 72.16 48.05 3,464.71 3,372.09 -1,379.79 3,985.58 5,979,309.31 553,571.69 3.07 4,063.73 MWD+IFR-AK-CAZ-SG(3) 6,537.27 73.10 45.02 3,493.23 3,400.61 -1,317.09 4,051.72 5,979,372.44 553,637.42 3.18 4,082.53 MWD+IFR-AK-CAZ-SC(3) 6,58521 73.18 41.30 3,507.14 3,414.52 -1,283.63 4,083.10 5,979,406.11 553,668.57 7.43 4,089.34 MWD+IFR-AK-CAZ-SC(3) 8632.17 7264 38.72 3,52094 3,428.32 -1,249.25 4,111.98 5,979,44067 553,697.19 5.38 4,093.56 MW1)+IFR-AK-CAZ-SC(3) 6,72259 7199 32.96 3,549.95 3,457.33 -1,17560 4.165.17 5,979,514.87 553,749.91 5.79 4,095.50 MWD+IFR-AK-CAZ-SC(3) 6,822.80 72.62 2741 3,578.91 3,486.29 -1,097.23 4,210]4 5,979.593.33 553,794.96 5.59 4,08847 MWD+IFR-AK-CAZ-SC (3) 6,915.59 72.83 23.59 3,606.48 3,513.86 -1,017.27 4,24888 5,979,673.53 553,832.57 3.94 4,074.43 MW0+IFR-AK-CAZ-SC(3) 7,011.34 7249 19.50 3,635.02 3,542.40 -932.28 4.282.44 5,979,75873 553,865.56 4.09 4,053]5 MWD+IFR-AK-CAZ-SC(3) 7,104.01 73.90 18.26 3,661.82 3,569.20 -848.34 4,311.14 5,979,84285 553,893]0 1.99 4,02968 MWD+1FR-AK-CAZ-SC(3) 7.19895 73.27 13.49 3,68B 66 3,596.04 -760.78 4,336.05 5,979,93057 553,918.03 4.86 4,000.43 MWD+IFR-AK-CAZ-SC(3) 7,293.52 7408 7.89 3,715.26 3,622.64 -671.64 4,352.87 5,980,019.81 553,934.25 5.75 3,96362 MWD+IFR-AK-CAZ-SC(3) 7,387.86 74.53 4.10 3,740.79 3,648.17 -581.33 4,362.35 5,980,110.17 553.943.13 3.90 3,920.11 MWD+IFR-AK-CAZ-SC (3) 7,48181 74.18 4.40 3,766.13 3,673.51 491.11 4,369.05 5,980,20043 553,949.24 0.48 3,874.36 MWD+IFR-AK-CAZ.SC(3) 7,576.96 74.34 2.50 3,791.94 3,699.32 -399.70 4,374.56 5,980,291.86 553,954.15 1.93 3,826.96 MWD+IFR-AK-CAZ-SC (3) 7,673.24 74.65 2.56 3,817.68 3,725.06 -307.01 4,378.66 5,980,384.56 553,957.63 0.33 3,777.67 MWD+IFR-AK-CAZ-SC(3) 7,768.14 74.30 2.49 3,843.08 3,750.46 -21586 4,382.88 5,980,475.93 553,961.05 0.38 3,729.08 MWD+IFR-AK-CAZ-SC(3) 7,862.66 7462 1.95 3,868.40 3,775.78 -124.67 4,386.21 5,980,566.94 553,963.97 0.65 3,680.28 MWD+IFR-AK-CAZ-SC(3) 927@017 2:04:26PM Page 4 COMPASS 5000.14 Build 85 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/ -W Northing Easting DLS Section (usft) 0 0 (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,957.29 74.34 122 3,893.72 3,801.10 -33.52 4,388.73 5,980,658.09 553,965.89 0.80 3,630.58 MWD+IFR-AK-CAZ-SC(3) 8,05173 74.48 0.70 3,919.10 3,82648 57.43 4,390.26 5,980,749.04 553,965.82 0.55 3,580.15 MWD+IFR-AK-CAZ-SC(3) 8,146.14 74.91 0.36 3,944.02 3,851.40 148.49 4,391.10 5,980,840.09 553,967.05 0.57 3,529.11 MWD+IFR-AK-CAZ-SC(3) 8,240.14 79.25 0.22 3,985.04 3,872.42 240.08 4,391.56 5,980,93168 553,966.91 4.62 3477.45 MWD+IFR-AK-CAZ-SC(3) 8,335.71 83.18 0.49 3,979.63 3,887.01 334.51 4,392.15 5,981,026.10 553,966.87 4.12 3,424.28 MWD+IFR-AK-CAZ-SC (3) 8.430.45 88.01 1.29 3,98690 3,894.28 428.93 4,393.62 5,981,120.52 553,%7]2 5.17 3,371.84 MWD+IFR-AK-CAZ-SC(3) 8,524.31 88.65 060 3,989.64 3,89702 522.74 4,395.17 5,981,214.32 553,968.64 1.00 3,319.81 MWD+IFR-AK-CAZ-SC(3) 8,533.68 88.54 359.99 3,989.87 3,897.25 532.11 4,395.21 5,98122369 553,968.63 6.61 3,314.53 MWD+IFR-AK-CAZ-SC(3) 8,577.06 88.77 359.85 3,990.89 3,898.27 575.47 4,395.15 5,981,267.05 553,96828 062 3,289.84 MWD -INC ONLY 4 8,591.00 89.04 359.81 3,991.15 3,898.53 589.41 4,395.11 5,981,280.99 553,968.15 1.94 3,281.89 NOT an ADWel Survey 7.6/6" x 9-719" 8,67202 9859 359.55 3,991.42 3,898.80 67043 4,394.65 5,981,361.99 553,967.16 1.94 3,235.48 MWD+IFR-AK-CAZ-SC(5) 8.76840 9041 359.34 3,990.59 3,897.97 764.80 4.393.74 5,981,456 35 553,965.62 0.29 3,181.11 MWD+IFR-AK-CAZ-SC(5) 8,861.92 89.77 358.56 3,990.44 3,897.82 860.30 4,391.99 5,981551.83 553,963.23 1.06 3,125.41 MWD+IFR-AK-CAZ-SC(5) 8.956.32 89.61 357.37 3,990.96 3,898.34 954.64 4,38864 5,981,646.13 553.959.26 127 3069.05 MWD+IFR-AK-CAZ-SC(5) 9,051.14 89.53 357.07 3,99167 3.899.05 104934 4,384.04 5,981,74879 553,954.03 0.33 3,01146 MWD+1FR-AK-CAZ-SC(5) 9,14623 90.17 358.70 3,991.92 3,899.30 1,144.37 4,380.53 5,981,83538 553,949.90 1.84 2,954.58 MWD+IFR-AK-CAZ-SC(5) 9,240.50 90.03 35949 3,991.75 3,899.13 1,238.62 4,379.04 5,981,930.02 553,94738 0.85 2,899.81) MWD+IFR-AK-CAZ-SC(5) 9,335.07 91.68 359.13 3,990.34 3,89772 1,333.17 4,377.90 5,982,024.55 553,946.02 1.79 2,845.14 MWD+IFR-AK-CAZ-SC(5) 9,431.% 91.67 048 3,987.53 3,894.91 1429.12 4,377.58 5,982,120.48 553,945.06 141 2,790.36 MWD+IFR-AK-CAZ-SC(5) 9,525.17 89.49 0.42 3,986.58 3,893.96 1,523.21 4,378.32 5,982,214.57 553,945,17 2.32 2,737.51 MWD+IFR-AK-CAZ-SC(5) 9,620.04 90.18 0.55 3,986.86 3,894.24 1,618.08 4,379.12 5,982,309.43 553045.35 0,74 2,684.27 MND+IFR-AK-CAZ-SC (5) 9,71468 88.36 0.62 3,988.06 3,895.44 1,71270 4,380.09 5,982,404.05 553,945.69 1.92 2,631.30 10WD+1FR-AK-CAZ-SC 15) 9,808.64 85.98 357.22 3,991.88 3,899.26 1,8%.55 4,37832 5,982,497.88 553,943.30 3.90 2,576.52 MWD+1FR-AK-CAZ-SC(5) 9,9%.53 86.57 354.06 3,997.05 3,904.43 1,898.02 4,371.34 5,982.589.29 553,935.72 346 2,516.81 MWD+IFR-AK-CAZ-SC(5) 9,991.81 87.19 349.27 4,002.02 3,909.40 1,988.18 4,358.13 5,982,679.34 553,921.92 5.28 2,456.72 MWD+IFR-AK-CAZ-SC(5) 10,082.70 89.17 345.80 4,004.91 3,91229 2,076.86 4,338.53 5,982,76789 553,90133 4.39 2,390.20 MWD+IFR-AK-CAZ-SC(5) 10,175.03 90.03 344.43 4,005.56 3,912.94 2,166.09 4,314.81 5,982,856.95 553,877.42 1.75 2,31998 MWD+IFR-AK-CAZ-SC(5) 10,265.69 90.75 343.05 4,004.94 3,912.32 2253.12 4,28943 5,982,943.80 553,851.47 172 2,249.65 MWD+1FR-AK-CAZ-5C(5) 10.358.97 89.72 347.53 4,004.56 3,911.94 2,343.31 4,265.75 5,983,033.83 553,827.19 4.93 2,178.92 MWD+IFR-AK-CAZ-SC(5) 10,451.29 90.10 353.55 4,004.70 3,912.08 2,434.34 4,250.58 5,983,124.74 553,811.43 6.53 2,114.72 MWD+IFR-AK-CAZ-SC(5) 10,543.80 88.55 358.56 4,%5.79 3,913.17 2,526.59 4,244.22 5,983,216.94 553,804.45 567 2,057.07 MWD+IFR-AK-CAZ-SC(5) 10,635.34 89.21 1.04 4,007.58 3,914.96 2,618.10 4.243.90 5,98330844 553,803.53 2.80 2,004.81 MWD+IFR-AK-CAZ-SC(5) 10,727.85 89.52 1.56 4,008.61 3,91699 2.710.58 4,246.00 5,983,400.92 553,805.02 0.65 1,953.99 MWD+IFR-AK-CAZ-SC (5) 10,818.96 89.24 1.66 4,009.59 3,916.97 2,801.65 4,248.56 5,983,492.00 553,806.97 0.33 1,904.35 MWD+IFR-AK-CAZ-SC (5) 10,911.12 88.33 1.79 4,011.55 3,918.93 2,893.75 4.251.33 5,983,584.10 553,809.14 1.00 1,854.31 MWD+IFR-AK-CAZ-SC(5) 11,004.59 88.16 1.56 4,014.41 3,921.79 2,987.13 4,254.06 5,983,67749 553,811.25 0.31 1,803.50 MWD+IFR-AK-CAZ-SC(5) 11,095.59 86.50 0.54 4,018.65 3,926.03 3,078.02 4,255.73 5,983,768.37 553,812.31 2.14 1,753.23 MWD+IFR-AK-CAZ-SC (5) 11,187.29 85.96 358.54 4,024.68 3,932.06 3,169.51 4,255.00 5,983,85985 553,810.97 2.25 1,700.64 MWD+IFR-AK-CAZ-SC(5) 11.282.17 85.88 356.05 4,031 43 3,938.81 3,264.04 4,250.53 5,983,954.34 553,805.88 2.62 1,643.26 MWD+IFR-AK-CAZ-SC (5) 11,37343 8689 355.12 4,037.18 3,944.56 3,354.84 4,243.52 5,984.045.09 553,798.27 1.50 1,585.90 MWD+IFR-AK-CAZ-SC(5) 927/2017 2:04:26PM Page 5 COMPASS 5000.14 8uil0 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Rig: 1 H-102 Project: Kuparuk River Unit TWO Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Site: Kupamk 1 H Pad MD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Well: Rig: 1H-102 North Reference: True Wellbore: 1H-102 Survey Calculation Method: Minimum Curvature Design: 1 H-102 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/ -W Northing Easting DLS Section (usft) 0 0 (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,957.29 74.34 122 3,893.72 3,801.10 -33.52 4,388.73 5,980,658.09 553,965.89 0.80 3,630.58 MWD+IFR-AK-CAZ-SC(3) 8,05173 74.48 0.70 3,919.10 3,82648 57.43 4,390.26 5,980,749.04 553,965.82 0.55 3,580.15 MWD+IFR-AK-CAZ-SC(3) 8,146.14 74.91 0.36 3,944.02 3,851.40 148.49 4,391.10 5,980,840.09 553,967.05 0.57 3,529.11 MWD+IFR-AK-CAZ-SC(3) 8,240.14 79.25 0.22 3,985.04 3,872.42 240.08 4,391.56 5,980,93168 553,966.91 4.62 3477.45 MWD+IFR-AK-CAZ-SC(3) 8,335.71 83.18 0.49 3,979.63 3,887.01 334.51 4,392.15 5,981,026.10 553,966.87 4.12 3,424.28 MWD+IFR-AK-CAZ-SC (3) 8.430.45 88.01 1.29 3,98690 3,894.28 428.93 4,393.62 5,981,120.52 553,%7]2 5.17 3,371.84 MWD+IFR-AK-CAZ-SC(3) 8,524.31 88.65 060 3,989.64 3,89702 522.74 4,395.17 5,981,214.32 553,968.64 1.00 3,319.81 MWD+IFR-AK-CAZ-SC(3) 8,533.68 88.54 359.99 3,989.87 3,897.25 532.11 4,395.21 5,98122369 553,968.63 6.61 3,314.53 MWD+IFR-AK-CAZ-SC(3) 8,577.06 88.77 359.85 3,990.89 3,898.27 575.47 4,395.15 5,981,267.05 553,96828 062 3,289.84 MWD -INC ONLY 4 8,591.00 89.04 359.81 3,991.15 3,898.53 589.41 4,395.11 5,981,280.99 553,968.15 1.94 3,281.89 NOT an ADWel Survey 7.6/6" x 9-719" 8,67202 9859 359.55 3,991.42 3,898.80 67043 4,394.65 5,981,361.99 553,967.16 1.94 3,235.48 MWD+IFR-AK-CAZ-SC(5) 8.76840 9041 359.34 3,990.59 3,897.97 764.80 4.393.74 5,981,456 35 553,965.62 0.29 3,181.11 MWD+IFR-AK-CAZ-SC(5) 8,861.92 89.77 358.56 3,990.44 3,897.82 860.30 4,391.99 5,981551.83 553,963.23 1.06 3,125.41 MWD+IFR-AK-CAZ-SC(5) 8.956.32 89.61 357.37 3,990.96 3,898.34 954.64 4,38864 5,981,646.13 553.959.26 127 3069.05 MWD+IFR-AK-CAZ-SC(5) 9,051.14 89.53 357.07 3,99167 3.899.05 104934 4,384.04 5,981,74879 553,954.03 0.33 3,01146 MWD+1FR-AK-CAZ-SC(5) 9,14623 90.17 358.70 3,991.92 3,899.30 1,144.37 4,380.53 5,981,83538 553,949.90 1.84 2,954.58 MWD+IFR-AK-CAZ-SC(5) 9,240.50 90.03 35949 3,991.75 3,899.13 1,238.62 4,379.04 5,981,930.02 553,94738 0.85 2,899.81) MWD+IFR-AK-CAZ-SC(5) 9,335.07 91.68 359.13 3,990.34 3,89772 1,333.17 4,377.90 5,982,024.55 553,946.02 1.79 2,845.14 MWD+IFR-AK-CAZ-SC(5) 9,431.% 91.67 048 3,987.53 3,894.91 1429.12 4,377.58 5,982,120.48 553,945.06 141 2,790.36 MWD+IFR-AK-CAZ-SC(5) 9,525.17 89.49 0.42 3,986.58 3,893.96 1,523.21 4,378.32 5,982,214.57 553,945,17 2.32 2,737.51 MWD+IFR-AK-CAZ-SC(5) 9,620.04 90.18 0.55 3,986.86 3,894.24 1,618.08 4,379.12 5,982,309.43 553045.35 0,74 2,684.27 MND+IFR-AK-CAZ-SC (5) 9,71468 88.36 0.62 3,988.06 3,895.44 1,71270 4,380.09 5,982,404.05 553,945.69 1.92 2,631.30 10WD+1FR-AK-CAZ-SC 15) 9,808.64 85.98 357.22 3,991.88 3,899.26 1,8%.55 4,37832 5,982,497.88 553,943.30 3.90 2,576.52 MWD+1FR-AK-CAZ-SC(5) 9,9%.53 86.57 354.06 3,997.05 3,904.43 1,898.02 4,371.34 5,982.589.29 553,935.72 346 2,516.81 MWD+IFR-AK-CAZ-SC(5) 9,991.81 87.19 349.27 4,002.02 3,909.40 1,988.18 4,358.13 5,982,679.34 553,921.92 5.28 2,456.72 MWD+IFR-AK-CAZ-SC(5) 10,082.70 89.17 345.80 4,004.91 3,91229 2,076.86 4,338.53 5,982,76789 553,90133 4.39 2,390.20 MWD+IFR-AK-CAZ-SC(5) 10,175.03 90.03 344.43 4,005.56 3,912.94 2,166.09 4,314.81 5,982,856.95 553,877.42 1.75 2,31998 MWD+IFR-AK-CAZ-SC(5) 10,265.69 90.75 343.05 4,004.94 3,912.32 2253.12 4,28943 5,982,943.80 553,851.47 172 2,249.65 MWD+1FR-AK-CAZ-5C(5) 10.358.97 89.72 347.53 4,004.56 3,911.94 2,343.31 4,265.75 5,983,033.83 553,827.19 4.93 2,178.92 MWD+IFR-AK-CAZ-SC(5) 10,451.29 90.10 353.55 4,004.70 3,912.08 2,434.34 4,250.58 5,983,124.74 553,811.43 6.53 2,114.72 MWD+IFR-AK-CAZ-SC(5) 10,543.80 88.55 358.56 4,%5.79 3,913.17 2,526.59 4,244.22 5,983,216.94 553,804.45 567 2,057.07 MWD+IFR-AK-CAZ-SC(5) 10,635.34 89.21 1.04 4,007.58 3,914.96 2,618.10 4.243.90 5,98330844 553,803.53 2.80 2,004.81 MWD+IFR-AK-CAZ-SC(5) 10,727.85 89.52 1.56 4,008.61 3,91699 2.710.58 4,246.00 5,983,400.92 553,805.02 0.65 1,953.99 MWD+IFR-AK-CAZ-SC (5) 10,818.96 89.24 1.66 4,009.59 3,916.97 2,801.65 4,248.56 5,983,492.00 553,806.97 0.33 1,904.35 MWD+IFR-AK-CAZ-SC (5) 10,911.12 88.33 1.79 4,011.55 3,918.93 2,893.75 4.251.33 5,983,584.10 553,809.14 1.00 1,854.31 MWD+IFR-AK-CAZ-SC(5) 11,004.59 88.16 1.56 4,014.41 3,921.79 2,987.13 4,254.06 5,983,67749 553,811.25 0.31 1,803.50 MWD+IFR-AK-CAZ-SC(5) 11,095.59 86.50 0.54 4,018.65 3,926.03 3,078.02 4,255.73 5,983,768.37 553,812.31 2.14 1,753.23 MWD+IFR-AK-CAZ-SC (5) 11,187.29 85.96 358.54 4,024.68 3,932.06 3,169.51 4,255.00 5,983,85985 553,810.97 2.25 1,700.64 MWD+IFR-AK-CAZ-SC(5) 11.282.17 85.88 356.05 4,031 43 3,938.81 3,264.04 4,250.53 5,983,954.34 553,805.88 2.62 1,643.26 MWD+IFR-AK-CAZ-SC (5) 11,37343 8689 355.12 4,037.18 3,944.56 3,354.84 4,243.52 5,984.045.09 553,798.27 1.50 1,585.90 MWD+IFR-AK-CAZ-SC(5) 927/2017 2:04:26PM Page 5 COMPASS 5000.14 8uil0 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Rig: 1H-102 Project: Kuparuk River Unit TVD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1H-102 actual @ 92.62usft (Doyon 142) Well: Rig: 1H-102 North Reference: True Wellbore: 1H-102 Survey Calculation Method: Minimum Curvature Design: 1H-102 Database: OAKEDMP2 Survey Map Map Vertical MD Inc AN TVD TVDSS +N/ -S +EI -W Northing Easting OLS Section (usft) (") (") (usft) (usft) (usft) (usft) (ft) (ft) (°I100-) (ft) Survey Tool Name 1146569 88.59 35442 4,040.82 3,948.20 3,446.64 4,235.12 5,984,136.82 553.78926 1.99 1,528.82 MWD+1FR-AK-CAZ-SC(5) 11,55663 89.94 355.12 4,041.99 3,949.37 3,537.19 4,226.83 5,984,227.31 553,780.37 1.67 1,468.55 MWD+1FR-AK-CAZ-SC(5) 11,64960 9235 35530 4,040.13 3,947.51 3,629.84 4,219.39 5,98,319 89 553,772.32 267 1,409.79 MWD+IFR-AK-CAZ-SC(5) 11,741.18 92.45 359.34 4,036.29 3,943.67 3,721.24 4,215.43 5,984,411.25 553,767.76 3.97 1,354.61 MWD+1FR-AK-CAZ-SC (5) 11,834.01 91.19 0.11 4,033.35 3,94073 3,814.02 4,214.99 5,984,50402 553,766.70 1.59 1301.53 MWD+IFR-AK-CAZ-SC(5) 11,926.28 91.63 M999 4,031.08 3,938.46 3,9D5.26 4,215.07 5,984.596.25 553,766.17 0.49 1,249.18 MWD+1FR-AK-CAZSC(5) 12,018.18 92.17 166 4,028.03 3,93541 3.998.10 4,21639 5,984,688.08 553,766,89 191 1,198.09 MWD+IFR-AK-CAZ-SC(5) 12,111.54 9130 091 4,024.88 3,932.26 4.091.38 4,21848 5,984,781.37 553,768.36 0.95 1,146.81 MWD+IFR-AK-CAZ-SC(51 12,19978 91.11 045 4,02271 3,930.09 4,179.58 4,21953 5,984,869.57 553,768.82 0.85 1097.56 MWD+IFR-AK-CAZ-SC(5) 12,291.94 90.99 100 4,021.02 3,928.40 4,271.72 4,220.69 5,984.961.71 553,769.38 0.61 1,046.17 MWD+IFR-AK-CAZ-SC (5) 12,382.53 9061 323 4,01976 3,927.14 4.362.23 4,224.04 5,985.052.23 553,772.12 2.50 99749 MWD+IFR-AK-CAZ-SC(5) 12,475.25 89.87 2.12 4,019.37 3,92635 4,454.85 4,228.36 5,985.144.86 553,775.84 1.44 948.43 MWD+IFR-AK-CAZ-SC(5) 12,568.48 89.77 2.90 4,019.66 3,927,04 4,547.99 4,232.45 5,985,238.02 553,779.30 0.84 898.87 MWD+IFR-AK-CAZ-SC(5) 12,659.86 90.34 0.13 4,019.58 3,926.% 4,639.33 4,234.86 5,985,329.36 553,781.11 3.09 848.96 MWD+IFR-AK-CAZ-SC(5) 12,752.68 8921 358.67 4,019.94 3,927.32 4,732.14 4,233.89 5,985,422.16 553,779.53 199 795.43 MWD+1FR-AK-CAZ-SC(5) 12,790.00 89.25 358.44 4,020.44 3,927.82 4,769.44 4,232.95 5,985,459.45 553,778.34 062 773.46 �TeNt AfDMl iitlflry 4-1124: 6-9/4" 12,844.88 89.30 358.11 4,021.14 3,928.52 4,824.29 4,231.30 5,985,514.28 553,776.33 0.62 740.94 MWD+IFR-AK-CAZSC(5) 12,899.09 89.30 358.62 4,021.80 3,929.18 4,878.48 4,229.75 5,985,568.45 553,774.42 0.94 708.88 MWD+IFR-AK-CAZSC(5) 12,960.00 8930 358.62 4.022.55 3,929.93 4,939,37 4,228.29 5.985,629.32 553.772.55 0.00 673.08 PROJECTED to TD Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. Yes No I have checked to the best of my ability that the following data is correct: L -J Surface Coordinates P1 Declinabon & Convergence p GRS Survey Corrections 0 Survey Tool Codes ass,b:9w 6st.W. Brandon Temple SLB DE: oRae`°:o11099 Kelsey Hallford Client Representative: Date: 09127!2017 927/2017 2:04 26P Page 6 COMPASS 5000.14 Build 85 [FINAL] RECEIVED OCT 2 6 2017 AOGCC ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad 1H-102 1 H-102 ConocoPhillips Definitive Survey Report 25 September, 2017 21 7097 28748 ConocoPhillips Company: ConowPhillips(Alaska) Inc. -Kupl Project: Kupamk River Unit Site: Kupamk 1 H Pad Well: Rig: 1H-102 Wellbore: 1 H-102 Design: 1H-102 ConocoPhillips Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Rig: 1H-102 1H-102 actual @ 92.62usft (Doyon 142) 1H-102 actual @ 92.62usft (Doyon 142) True Minimum Curvature OAKEDMP2 -roject Kupamk River Unit, North Slope Alaska, United States Aap System: US State Plane 1983 System Datum: Mean Sea Level iso Datum: North American Datum 1983 Using Well Reference Point lap Zone: Alaska Zone 4 Using geodetic scale tactor Veil Rig: 1H-102 From To Audit Notes: (usft) Survey( Wellbore) 67.62 Well Position +NIS 0.00 usft Northing: 5,980,414.37 usft Latitude: 70'21'27.5831 +N/ -S -EFW 0.00 usft Easting: 1,689,609.08 usft Longitude: 149° 36' 1.638 V 'osition Uncertainty 0.00 0.00 usft Wellhead Elevation: usft Ground Level: 54.00 usf Vellbore 111-102 nagnetics Model Name Sample Date Declination Dip Angle Field Strength (9 PI (nT) BGGM2017 9/15/2017 1749 80.95 57,490 Design 1H-102 Date 9/25/2017 From To Audit Notes: (usft) Survey( Wellbore) 67.62 1,009.26 11-1-102 Srvy 1 - SLB_GWD70 (11-1-102) Version: 1.0 Phase: ACTUAL Tie On Depth: 38.62 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction TVDSS (usft) (usft) (usft) (I Easting 38.62 0.00 0.00 124.62 Survey Program Date 9/25/2017 From To (usft) (usft) Survey( Wellbore) 67.62 1,009.26 11-1-102 Srvy 1 - SLB_GWD70 (11-1-102) 1,050.36 1,678.04 1 H-102 Srvy 2 - SLB _MWD+GMAG (1 H- 1,777.33 8,533.681H-102 Srvy 3 - SLB _MWD+GMAG(1H- 8,577.06 8,577.061H-102 Srvy 4- SLB _MWD-INC_Filler It 8,672.02 12,899.09 1 H-102 Srvy 5 - SLB_MWD+GMAG (1 H - Survey Tool Name Description GYD-GC-SS Gyrodata gyro single shots MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD -INC ONLY MWD -INC -ONLY -FILLER MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey Date 8/24/2017 10:04 8/24/2017 10:12 8/27/2017 12:16 9/5/2017 9:03:3. 9/5/2017 9:06:5 9/252017 11:3D21AM Page 2 COMPASS 500014 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS -NI-S +E/ -W Northing Easting DLS Section (usft) 0 r) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 38.62 0.00 0.00 38.62 -54.00 0.00 0.00 5,98.414.37 1,689,609.08 0.00 0.00 UNDEFINED 67.62 0.19 41.29 6762 -25.00 ON 0.03 5,980.414.40 1,689,609.12 0.66 0.01 GYD-GC-SS(1) 165.90 0.45 132.01 165.90 73.28 -010 0.43 5.98.414.27 1,689.6M 51 0.50 0.41 GYD-GC-SS(1) 258.98 1.01 128.15 258.97 166.35 -0.85 1.34 5,980,413.52 1,689,61043 0.60 1.59 GYD-GC-SS(1) 354.48 3.34 138.19 35440 261.78 -3.44 3.86 5,980.410.95 1,689,612.97 2.46 5.13 GYD-GC-SS(1) 447.17 461 135.26 446.86 354.24 -8.10 8.28 5.980,406.32 1,689817.42 1.39 11.42 GYD-GC-SS(1) 539.82 577 132.42 539.13 446.51 -13.89 14.34 5,980,400.57 1,689,623.51 1.28 1989 GYD-GC-SS(1) 63284 7.61 134.49 631.51 538.89 -21.36 22.19 5,980,393.15 1,689,631 41 1.99 30.39 GYD-GC-SS(1) 725.82 8.77 137.82 723.54 630.92 -30.93 31.34 5.980,383.65 1,689,640.62 135 43.36 GYD-GC-SS(1) 821.24 10.73 141.32 817.58 724.96 -43.25 41.78 5,980,371.39 1,689,651.14 2.15 58.95 GYD-GC-SS(1) 9/252017 11:3D21AM Page 2 COMPASS 500014 Build 85 ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupi Local Co-ordinate Reference: Well Rig: 11-1-102 Project: Kuparuk River Unit TVD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Site: Kuparuk I Pad MD Reference: 1 H-102 actual @ 92.62usft (Doyon 142) Well: Rig: 1H-102 North Reference: True Wellbore: 1 H-102 Survey Calculation Method: Minimum Curvature Design: 1 H-102 Database: OAKEDMP2 Survey 9/25/2017 7130 21 AM Page 3 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD NDSS +NIS +EI -W Northing Easting DLS Section (waft) (1) 0 (usft) (usft) (usft) (usft) (ft) (ft) (-/100-) (ft) Survey Tool Name 914.20 1269 139.61 908.57 815.95 -57.91 53.90 5,980,356.82 1689,663.36 235 77.26 GVD-GC-SS(1) 1,009.26 1469 136.85 1,000.84 908.22 -74.90 69.13 5,980.339.93 1,689,678.70 2.22 99.44 GVD-GC-SS(1) 1050.36 1532 135.96 1,040.49 947.87 $275 76.61 5,980,332.13 1,689,686.23 2.10 110.06 MWD+IFR-AK-CAZ-SG(2) 1,144.89 17.17 134.37 1,131.15 1,038.53 -10172 95.49 5,980,31329 1,689,705.23 1.61 136.37 MWD+IFR-AK-CAZ-SC(2) 1239.16 20.84 134.25 1,220.26 1,127.64 -123.16 11746 5,980,292.00 1,689,727.33 3.89 168.63 MWD+IFR-AK-CAZ-SC(2) 1,334.20 24.71 136.54 1,307.88 1,215.26 -149.38 14324 5,980,265.94 1,689,753.29 4.18 202.75 MWD+IFR-AK-CAZ-SC (2) 1,428.98 27.54 137.49 1,392.97 1,30.35 -179.92 17168 5,980,235.60 1,689,781.92 3.02 243.50 MWD+IFR-AK-CAZ-SC(2) 1,523.25 28.14 137.93 1,476.33 1,383.71 -212.49 201.30 5,980,203.23 1,689,811.75 0.67 286.38 MWD+IFR-AK-CAZ-SC (2) 161809 28.94 137.33 1,55964 1,467.02 -245.96 23184 5,980,169.96 1689,842.51 0.90 330.53 MWD+IFR-AK-CAZ-SC(2) 1,678.04 29.99 135.80 1,611.84 1,519.22 -267.37 252.11 5,98,14869 1,689,662.92 2.15 359.38 MWD+IFR-AK-CAZ-SC (2) 177100 33.38 135.72 1,690.93 1,50,31 -302.34 286.17 5,980,113.94 1,689,897.21 365 40]28 NOT anAcWalSurvey 10 3/4" z 13-1/2" 1,777.33 33.61 135.72 1,696.21 1,603.59 -304.85 28861 5,980,111.45 1,689,899.65 3.65 410.71 MWD+IFR-AK-CAZ-SC(3) 1,801.61 34.53 13479 1716.32 1,623.70 -314.50 298.19 5,980,101.86 1,689,909.30 4.35 42407 MWD+IFR-AK-CAZ-SC(3) 1,886.66 37.81 133.50 1,793.04 170,42 -353.55 33845 5,980,063.08 1,689,949.82 3.54 479.39 MWD+IFR-AK-CAZ-SC(3) 1,991.93 40.86 131.83 186612 1,774.10 -394.45 382.87 5,980,022.48 1,689,994.50 3.39 539.18 MWD+IFR-AK-CAZ-SC(3) 2,086.48 43.97 130.99 1,936.52 1,843.90 436.61 43070 5,979,980.63 1,690,042.60 3.34 602.50 MWD+IFR-AK-CAZ-SC(3) 2,184.36 47.16 129.49 2,05.04 1,912.42 -481.73 484.06 5,979.93567 1,690,096.25 344 672.04 MWD+IFR-AK-CAZ-SC(3) 2,276.23 50.08 128.77 2,065.76 1,973.14 -525.22 537.53 5,979,892.74 1,690,150.00 3.23 740.76 MWD+IFR-AK-CAZ-SC(3) 2,37148 53.12 127.35 2,124.92 2,032.30 -571.22 596.31 5,979,847.13 1,690,209.07 3.40 815.26 MWD+IFR-AK-CAZ-SC(3) 2,464.98 55.35 124.47 2,179.57 2.086.95 -615.68 657.76 5,979,80307 1,690,270.80 3.45 891.09 MWD+IFR-AK-CAZSC(3) 2,559.60 5673 122.73 2,232.43 2,139.81 -659.10 723.12 5,979,76009 1,60,33645 2.11 969.55 MWD+11FR-AK-CAZ-SC(3) 2,653.87 5879 12243 2,28272 2,190.10 -702.03 790.31 5,979,717.61 1,60,40391 2.20 1,049.23 MWD+IFR-AK-CAZ-SC(3) 2,748.30 59.37 121.74 2,331.24 2,238.62 -745.06 858.95 5,979.67503 1,60,47262 0.88 1,130.16 MWD+IFR-AK-CAZ-SC(3) 2,843.07 6140 121A8 2,378.07 2,28545 -788.24 929.11 5,979,63232 1,690,543 26 2.16 1,212.43 MWD+IFR-AK-CAZ-SC(3) 2,937.25 65.11 121.93 2,420.45 2,327.83 -83244 1000.65 5,979,588.0 160,61508 3.96 1,296.41 MWD+1FR-AK-CAZ-SC(3) 3,032.88 69.13 121.16 2,45782 2,365.00 -878.52 1,075.72 5,979,543.02 1,60,69045 4.27 1,384.37 MWD+IFR-AK-CAZ-SC(3) 3,126.86 71.43 121.37 2,489.33 2,396.71 -92443 1,151.34 5,979,49761 1,60,766.35 2.46 1,472.68 MWD+IFR-AK-CAZ-SC(3) 3,221.95 7262 12137 2,51867 2,426.05 -971.51 1,228.56 5,97945104 160,84388 125 1,562.98 MWD+IFR-AK-CAZ-SC(3) 3,316.46 73,03 121.69 2546.58 2,453.96 -1018.73 1,305.53 5,979,404.33 1,60,921.15 0.54 1,653.15 MWD+IFR-AK-CAZ-SC (3) 3,410,86 73.34 122.71 2,573.89 2,481.27 -1,066.89 1,381.99 5,979,356.68 1,60,997.92 1.09 1,743.43 MWD+IFR-AK-CAZ-SC(3) 3,50.07 73.21 122.55 2,60129 2,508.67 -1,116.05 1,458.78 5,979,308.03 1,691,075.02 0.21 1,834.55 MWD+IFR-AK-CAZ-SC(3) 3,601.42 7321 122.70 2,628.83 2,536.21 -1,165.27 1535.66 5,979,259.32 1,691,15222 0.15 1,925.78 MM+IFR-AK-CAZ-SC(3) 3,696.85 73.21 122.29 2,656.40 2,563 78 -1,214.35 1,61272 5,979,210.75 1,691,229.59 0.41 2,047.08 MWD+IFR-AK-CAZ-SC (3) 3,791.46 73.30 120.98 2,68366 2,591.04 -1,261.87 1,689.85 5,979,163.75 1,691,307.03 1.33 2,107.56 MWD+IFR-AK-CAZ-SC(3) 3,886.74 73.14 118.95 - 2,711.17 2,618.55 -1,307.43 1,768.88 5,979,118.71 1,691,38634 2.05 2198.47 MWD+IFR-AK-CAZ-SC(3) 3,981.94 73.09 119.64 2,738.82 2,646.20 -1,352.00 1,848.32 5,979,07466 1.691,466.07 0.70 2,289.17 MWD+IFR-AK-CAZ-SC(3) 4,07641 73.30 119.87 2,765.13 2,673.51 -1,396.88 1.926.84 5,979,030.30 1,691,54467 0.32 2,379.28 MWD+IFR-AK-CAZ-SC(3) 4,171.02 73.17 118.99 2,793.42 2,70.80 -1,441.40 2,005.73 5,978,986.31 1,691,624.05 0.90 2.469.50 MWD+IFR-AK-CAZ-SC(3) 4,266.02 73.M 119.53 2,821.02 2,728.40 -1,485.83 2,085.04 5,978,94241 1,691,70363 0.56 2,560.01 MWD+IFR-AK-CAZ-SC(3) 4,360.46 73.01 119.04 2,846.57 2,755.95 -1,530.01 2,163.83 5,978,898.75 1,691,78270 0.50 2,64994 MWD+IFR-AK-CAZ-SC(3) 9/25/2017 7130 21 AM Page 3 COMPASS 5000.14 Build 85 Company: Project: Site: Well: Wellbore: Design: Survey ConocoPhillips(Alaska) Inc.-Kupl Kuparuk River Unit Kuparuk 1 H Pad Rig: 111-102 1H-102 1H-102 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Rig: 1H-102 1 H-102 actual @ 92.62usft (Doyon 142) 1H-102 actual @ 92.62usft (Doyon 142) True Minimum Curvature OAKEDMP2 Map Map MD Inc Azi TVD TVDSS +Nl-S +E/ -W Northing Seating (usft) (°) (1) (usft) (usft) (usft) (usft) (ft) (ft) 4,455.58 72.90 119.77 2,87645 2,783.83 -1,574.66 2,243.05 5.978.85462 1,691,862.21 4,549.81 72.87 120.06 2,904.19 2,811.57 -1,619.57 2,321.11 5,978,81023 1,691,940.55 4,64452 7320 11840 2.931.82 2,839.20 -1,663.81 2,400.16 5,978,766.52 1,692,019.89 4,73999 7242 114.51 2,960.05 2,867.43 -1,704.44 2,4B1.79 5,978,726.43 1,692,101]8 4,786.24 72.31 110.47 2,974.06 2,881.44 -172129 2,522.51 5,978,70984 1,692,14260 4,833]6 72A8 108.23 2,98844 2,895.82 -1,736.30 2,565.24 5,978,695.12 1692,18542 4,928.09 72.21 10378 3,017,06 2,92444 -176108 2,65162 5,978,67091 1,692,271.95 5,022.87 71.11 10068 3046.89 2,954.27 -1,780.14 2,739.52 5,97B,652.43 1,692,359.97 5,07023 71.27 98.69 3,062.16 2,969.54 -1,787.68 2,783.71 5,978,645.18 1,692,40421 5,116.77 7168 96.97 3,076.95 2,984.33 -1,793.69 2,827.43 5,978,639.46 1,692,44796 5.211.19 72.12 93.77 3,106.29 3.013.67 -1,802.09 2,916.77 5,978,631.65 1692.537.34 5,305.75 71.74 88.59 3,135.64 3,043.02 -1,803.94 3,006.61 5,978,630.38 1,692,627.18 5,400.08 71.70 83.77 3,165.24 3.072.62 -1797.98 3,095.95 5,978,636.93 1.692,71647 5,495.26 72.32 8129 3,194.64 3,102.02 -1,786.21 3,185.70 5,978,64929 1,692,806.13 5,590.01 72.15 76.05 3,223.57 3,130.95 -1768.49 3,274.13 5,978,667.59 1,692,894.44 5,685.45 72.61 70.23 3,252.48 3,159.86 -1,742.11 3,361.14 5,978,694.53 1,692,981.27 5,779.73 73.02 64.52 3,28036 3,18774 -1]0]48 3,444.24 5,978729]1 1,693,064.13 5,874.02 73.87 63.54 3,307.23 3,214.61 -1,667.90 3,525.49 5,978,769.82 1,693,145.11 5,968.69 74.38 63.99 3,333.12 3,240.50 -1,627.64 3,607.17 5,978,81060 1,693,226.51 6,063.17 74.61 63.93 3358.38 3,265.76 -1,587.68 3.688.97 5,978,851.10 1,693,308.04 8168.96 7468 58.30 3,363.23 3,290.61 -1,544.01 3,768.12 5,978,895.29 1,693,38690 6,252.33 7403 54.53 3,408.96 3316.34 -1,493.22 3,844.61 5,978,946.57 1,693,463.05 6,348.97 7268 51.05 3,43608 3,343.46 -1,438.41 3.916.82 5,979,001.85 1,693,53489 6,441.76 72.16 48.05 3,464.71 3,372.09 -1,379.79 3.985.58 5.979,060.91 1,693,60325 6,537.27 73.10 45.02 3,493.23 3,400.61 -1,317.09 4,05112 5,979,124.04 1,693,668.97 8,585.21 73.18 41.30 3,507.14 3.414.52 -1,283.63 4,083.10 5.979.157.70 1,693,700.13 6,632.17 72.64 38.72 3,520.94 3,426.32 -1,249.25 4,111.% 5,979,192.26 1,693,728.76 6,727.59 71.99 32.96 3,549.95 3,45733 -1,175.60 4,165.17 5,979,26626 1,693,781.48 6,822.80 72.62 27.41 3,578.91 3,486.29 -1,097.23 4,210.74 5,979,34492 1,693,826.53 6,915.59 72.83 23.59 3,687.48 3,513.86 -1,017.27 4,248.88 5,979,425.12 1,693,864.14 7,011.34 72.49 19.50 3,635.02 3.542.40 -932.28 4,282.44 5,979,510.32 1,693,897.14 7,10401 73.90 18.M 3,661.82 3,569.20 -848.34 4,311.14 5,979,594.44 1,693,925.28 7,19895 73.27 1349 3,688.66 3.596.04 -760.78 4,336.05 5.979,682 15 1,693.94961 7,293.52 74.08 7.89 3,715.26 3,622.64 -671.64 4,352.87 5,979,771.40 1,693,965.B4 7,38786 74.53 4.10 3.740.79 3,648.17 -581.33 4,362.35 5,979,861,76 1,693,974.73 7,481.81 74.18 4.40 3,766.13 3,673.51 -491.11 4,369.05 5,979,952.01 1,693,980.84 7,576.96 74,34 2.50 3,791.94 3,699.32 -39930 4,374.56 5,980,043.45 1,693,985.75 7,673.24 74.65 2.56 3,817.68 3,725.06 -307.01 4,378.66 5,980,136.15 1,693,969.24 7,768.14 74.30 2.49 3,843.08 3,750.46 -21566 4,382.68 5,980,227.51 1,693,992.66 7,862.66 7462 1.95 3,86840 3,775.78 424.67 4,386.21 5,980,318.52 1,693,995.59 Vertical DLS Section (-1100-) (ft) Survey Tool Name 0.74 2,740.51 MWD+IFR-AK-CAZ-SC (3) 0.30 2,830.26 MWD+IFR-AK-CAZ-SC (3) 1.71 2.920.44 MWD+IFR-AK-CAZ-SC (3) 3.98 3,010.70 MWD+IFR-AK-CAZ-SC(3) 8.33 3,053.79 MWD+IFR-AK-CAZ-SC(3) 4.51 3,09748 MWD+IFR-AK-CAZ-SC(3) 4.50 3,18264 MWD+IFR-AK-CAZ-SC(3) 3.31 3,265.81 MWD+IFR-AK-CAZ-SC (3) 3.99 3,306.45 MWD+IFR-AK-CAZ-SC(3) 361 3,345.84 MWD+IFR-AK-CAZ-SC(3) 325 3,424.13 MWD+IFR-AK-CAZ-SC(3) 522 3,49912 MWD+IFR-AK-CAZ-SC(3) 4.85 3,569.25 MWD+IFR-AK-CAZ-SC (3) 2.56 3,636.41 MWDHFR-AK-CAZ-SC (3) 5.27 3,699.12 MWD+IFR-AK-CAZ-SC(3) 5.83 3,755.73 MWD+IFR-AK-CAZ-SC(3) 5.80 3,804.44 MWD+IFR-AK-CAZ-SC(3) 1.34 3,848.81 MWD+IFR-AK-CAZ-SC(3) 0.71 3,893.16 MWD+IFR-AK-CAZ-SC(3) 0.25 3,937.76 MWD+IFR-AK-CAZ-SC(3) 579 3,97809 MWD+IFR-AK-CAZ-SC(3) 3.87 4,012.18 MWD+IFR-AK-CAZ-SC(3) 3.80 4,040.45 MWD+IFR-AK-CAZ-SC(3) 3.07 4,063.73 MW0+IFR-AK-CAZ-SC(3) 3.18 4,082.53 MWD+IFR-AK-CAZ-SC(3) 7.43 4,089.34 MWD+IFR-AK-CAZ-SC (3) 5.38 4,093.56 MWD+IFR-AK-CAZ-SC (3) 5.79 4,095.50 MWD+IFR-AK-CAZ-SC (3) 5.59 4,088.47 MWD+IFR-AK-CAZ-SC(3) 394 4,074.43 MWD+IFR-AK-CAZ-SC(3) 4.09 4,053.75 MWD+IFR-AK-CAZ-SC(3) 1.99 4,029.68 MWD+IFR-AK-CAZ-SC(3) 4.86 4,000.43 MWD+IFR-AK-CAZ-SC(3) 5.75 3,963.62 MWD+IFR-AK-CAZ-SC(3) 3.90 3,920.11 MWD+IFR-AK-CAZSC(3) 0.48 3,874.36 MWD+IFR-AK-CAZ-SC(3) 1.93 3,826.96 MWD+IFR-AK-CAZ-SC (3) 033 3,777.67 MWD+IFR-AK-CAZ-SC(3) 038 3,729.08 MWD+IFR-AK-CAZ-SC(3) 0.65 3,680.28 MWD+IFR-AK-CAZ-SC (3) 9/2&2017 11:30:21AM Page 4 COMPASS 5000.14 Build 85 Company: ConocoPhillips(Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: Rig: IH -102 Wellbore: 11-1-102 Design: 11-1-102 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Rig: 1 H-102 1H-102 actual @ 92.62usit (Doyon 142) 1H-102 actual @ 92.62usft (Doyon 142) True Minimum Curvature OAKEDMP2 Survey Map Map Vertical MD Inc AN TVD TVDSS -NAS +E/ -W Nordling Easting DLS Section (usft) (I V) (usft) (usft) (usft) (usft) (ft) (ft) (°/loo') (ft) Survey Tool Name 7.957.29 74.34 1.22 $,893.72 3,801.10 -33.52 4.388.73 5,980,40967 1,693,997.52 0.80 3,630.58 MWDHFR-AK-CAZ-SC(3) 8,051.73 7448 030 3,919.10 3,826.48 5743 4,39026 5,980,500.62 1,693,998.44 0.55 3,580.15 MWD+IFR-AKCAZ-SC(3) 8,146.14 74.91 0.36 3,944.02 3,85140 148.49 4.391.10 5,980,59167 1,693,998.69 0.57 3529.11 MWD+IFR-AK-CAZ-SC (3) 8,240.14 79.25 022 3,965.04 3,872.42 240.08 4,39156 5,980,683.26 1,693,998.55 4.62 3,477.45 MWD+IFR-AK-CAZ-SC(3) 8,335.71 83.18 049 3,979.63 3,89701 334.51 4,392.15 5,980,777.68 1,893,998.52 4.12 3,424.28 MWDHFR-AK-CAZ-SC(3) 8430.45 88.01 129 3,986.90 3,894.28 42893 4,39362 5,980,872.10 1,693,999.36 5.17 3,37184 MWD+IFR-AK-CAZ-SC(3) 8,524.31 8865 060 3,98964 3,897.02 522.74 4,395.17 5,980,965.91 1,694,000.29 1.00 3,319.81 MWD+IFR-AK-CAZ-SC(3) 8,533.88 8854 359.99 3,989.87 3,897.25 532.11 4,395.21 5,980,975.27 1,694,000.28 6.61 3,314.53 MWD+IFR-AWCAZ-$C(3) 8,577.06 88.77 359.85 3,990.89 3,898.27 575.47 4,395.15 5,981018.64 1,693,999.94 062 3,289.84 MWD -INC ONLV 4 8,591.00 89.04 359.81 3,991.15 3,898.53 58941 4,395.11 5,981,032.57 1,693,999.80 1.94 3,261 ss NOT an Actual Survey 7-618" x 9-718" 8,67202 90.59 359.55 3,991.42 3,898.80 670.43 4,394.66 5,981,113.57 1,693,99882 1.94 3,235.48 MWD+IFR-AK-CAZ-SC(5) 8,766.40 9041 359.34 3,990.59 3,897.97 764.80 4,393.74 5,981,207.93 1,693,99728 0.29 3,181.11 MWD+IFR-AK-CAZ-SC(5) 8,861.92 89.77 358.56 3,990.44 3,897.82 860.30 4,391.99 5,981,303.41 1,693,99490 1.06 3,125.41 MWD+IFR-AK-CAZ-SC(5) 8,956.32 8961 357.37 3,990.96 3,898.34 954.64 4,38864 5,981,397.71 1,693,99093 1.27 3.069.05 MWD+IFR-AK-CAZ-SC(5) 9,051.14 89.53 357.07 3,991.67 3,899.05 1.049.34 4,384.04 5,981,492.38 1,693.98571 0.33 3,011.46 MWD+IFR-AK-CAZ-SC(5) 9,14623 90.17 358]0 3,991.92 3,899.30 1.144.37 4,380.53 5,981,587.36 1,693,981.58 1.84 2,954.58 MW0+IFR-AK-CAZ-SC(5) 9,240.50 90.03 359.49 3,991.75 3,899.13 1,238.62 4,379.04 5,981,681.80 1,693,97947 0.85 2,899.80 MWD+IFR-AK-CAZ-SC(5) 9,335.07 9168 359.13 3.990.34 3,897.72 1333.17 4,377.90 5,981.776.13 1,693,97771 1,79 2,845.14 MWD+IFR-AK-CAZ-SC(5) 9,43106 91.67 0.46 3,987.53 3,894.91 1,429.12 4.377.58 5,981,872.06 1,693,976.76 1.41 2,790.36 MWD+IFR-AK-CAZ-SC (5) 9,525.17 89.49 0.42 3,986.58 3,893.96 1,523.21 4,378.32 5,981,966.15 1,693,976.88 2.32 2,737.51 MWD+IFR-AK-CAZ-SC (5) 9,620.04 90.18 0.55 3,986.86 3,894.24 1,618.08 4,379.12 5,982,06101 1,693,97706 074 2,684.27 MWD+IFR-AK-CAZ-SC(5) 9,714.68 88.36 0.62 3,988.06 3,89544 1,712.70 4,380.09 5,982,155.63 1,693,97]40 1.92 2,631.30 MWD+IFR-AK-CAZ-SC(5) 9,808.64 86.98 357.22 3,991.88 3,899.26 1,806.55 4,378.32 5,982,249.46 1,693,975.02 3.90 2.576.52 MWDHFR-AK-CAZ-SC (5) 9,900.53 86.57 354.06 3,897.05 3.90443 1,898.02 4,371.34 5,982,340.87 1,693,96745 3.46 2,518.81 MWD+IFR-AK-CAZ-SC(5) 9,991.81 87.19 349.27 4,00202 3,909.40 1,988.18 4,358.13 5,982,430.93 1,693,953.65 5.28 2,456.72 MWD+IFR-AK-CAZ-SC(5) 10,082.70 89.17 345.80 4,004.91 3,912.29 2,076.86 4,338.53 5,982,519.47 1,693,93346 4.39 2,390.20 MWD+IFR-AK-CAZ-SC(5) 10,175.03 9003 34443 4,00556 3,912.94 2,166.09 4,31481 5,982,608.53 1.693,909.16 1.75 2,31998 MM+IFR-AK-CAZ-SC(5) 10,265.69 90.75 343.05 4,004.94 3,912.32 2,253.12 4,28943 5982,695.38 1,693,883.21 172 2,249.65 MWD+IFR-AK-CAZ-SC(5) 10,358.97 8972 347.53 4,004.56 3,911.94 2,343.31 4,265.75 5,982,785.41 1,693,85894 4.93 2,178.92 MWD+IFR-AKCAZ.SC(5) 10,451.29 9D.10 353.55 4,00430 3,912.08 2,434.34 4,250.58 5,982,876.33 1,693,843.18 6.53 2,114.72 MWD+IFR-AK-CAZ-SC (5) 10,543.80 88.55 358.56 4,005.79 3,913.17 2.526.59 4,244.22 5,982,968.53 1,693,83621 5.67 2,057.07 MWD+IFR-AK-CAZ-SC(5) 10,635.34 69.21 1.04 4,00758 3,914.96 2,618.10 4,24390 5,983,060.03 1,693,835.29 2.80 2,004.81 MWD+IFR-AK-CAZ-$C(5) 10,727.85 89.52 1.56 4,00861 3,915.99 2,710.58 4,246.00 5,983,152.51 1,693,83678 0.65 1,953.99 MWD+IFR-AK-CAZ-SC(5) 10,818.96 8924 1.66 4,009.59 3,916.97 2,801.65 4,248.56 5,983,243.58 1,693,838.74 0.33 1,904.35 MWD+IFR-AK-CAZ-SC(5) 10,911.12 88:33 1.79 4,011.55 3,918.93 2,89335 4,251.33 5,983,335.69 1,693.84091 1.00 1,854.31 MWD+IFR-AK-CAZ-SC(5) 11,004.59 88.16 1.56 4,014.41 3,921.79 2.987.13 4,254.06 5,983,429.08 1,693.84303 0.31 1,803.50 MWD+IFR-AK-CAZ-SC(5) 11,095.59 86.50 0.54 4,01865 3,926.03 3,07802 4,255.73 5,983.519.96 1,693,844.10 2.14 1,753.23 MWD+IFR-AK-CAZ-SC(5) 11,187.29 85.96 358.54 4,024.68 3,932.06 3,169.51 4,255.00 5,983,611.44 1,693,842.76 2.25 1,700.64 MW0+IFR-AK-CAZ-SC (5) 11,282.17 85.88 356.05 4,03143 3,938.81 3,264.04 4,250.53 5,983,705.93 1,693,83768 2.62 1,643.26 MWD+IFR-AK-CAZ-SC(5) 11,373.43 86.69 355.12 4,037.18 3,944.56 3,354.84 4,243.52 5,983,796.68 1,693,830.07 1.50 1,585.90 MVM+iFR-AK-CAZ-SC (5) 9/25/2017 11: 30: 21AM Page 5 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Rig: 1H-102 Wellbore: 1H-102 Design: 1H-102 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Rig: 1 H-102 1 H-102 actual @ 92.62usft (Doyon 142) 1 H-102 actual @ 92.62usft (Doyon 142) True Minimum Curvature OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/.W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,465.69 88.59 35442 4,040.82 3,948.20 3,446.64 4,235.12 5,983.88841 1,693,82106 1.99 1,526.82 MWD+IFR-AK-CAZ-SC(5) 11,556.63 89.94 355.12 4,041.99 3,949.37 3,537.19 4,226.83 5,983,97890 4,693,812.18 1.67 1,468.55 MWD+1FR-AK-CAZ-SC(5) 11,649.60 92.35 355.70 4,040.13 3,94751 3,629.84 4,219.39 5,984,07148 1,693,804.14 2.67 1,409.79 MWD+IFR-AK-CAZ-SC(5) 11,741.18 9245 359.34 4,036.29 3,943.67 3,721.24 4,21543 5,984,162.84 4,693,799.58 3.97 1,35461 MWD+1FR-AK-CAZ-6C(5) 11,834.01 91.19 0.11 4,033.35 3,94073 3,814.02 4,214.99 5,984,255.61 1,693,798.52 1.59 1,301.53 MWD+IFR-AK-CAZ-SC(5) 11,926.28 91.63 359.99 4,031.08 3,938.46 3.905.26 4,21507 5,984,34764 1,693,798.00 0.49 1,249.18 MWD+IFR-AK-CAZ-SC(5) 12,018.18 92.17 1.66 4,028.03 3,93541 3,998.10 4,216.39 5,984,43968 1.693,79832 1.91 1,198.09 MWD+1FR-AK-CAZ-SC(5) 12,111.54 91.70 091 4,024.88 3,932.26 4,091.38 4,218.48 5984,53296 1,693,800.20 0.95 1,146.81 MWD+IFR-AK-CAZ-SC(5) 12,199 78 91.11 0.45 4,022.71 3,93009 4,179.58 4,219.53 5,984.62116 1693,800.66 0.85 1,097.56 MWD+IFR-AK-CAZ-SC(5) 12,291.94 9099 1.00 4,02102 3,928.40 4,271.72 4,220.69 5,984,713.30 1,693,801.22 0.61 1,046.17 MWD+1FR-AK-CAZ-SC(5) 12,382.53 W61 3.23 4,019.76 3,927.14 4,362.23 4,224.04 5,984,803.82 1693,80397 2.50 99149 MWD+IFR-AK-CAZ-SC(5) 12,475.25 8987 2.12 4,019.37 3,926.75 4,454.85 4,228.36 5,984,896.66 1,693,807.69 1.44 94843 MWD+IFR-AK-CAZ-SC(5) 12,568.48 89.77 2.90 4,019.66 3,927.04 4,547.99 4,232.45 5,984,98961 1,693,811.16 0.84 898.87 MWD+IFR-AK-CAZ-SC(5) 12,659.86 90.34 0.13 4,019.58 3,926.96 4,639.33 4,234.86 5,985,080.95 1,693,812.98 3.09 848.96 MWD+IFR-AK-CAZ-$C (5) 12,75268 89.21 358.67 4,019.94 3.927.32 4,732.14 4,233.89 5,985,17375 1,693,81140 1.99 795.43 MWD+IFR-AK-CAZ-SC(5) 12,790.00 8925 358.44 4,020.44 3,927.82 4,769.44 4,232.95 5,985,21104 1,693,81021 0.62 773.45 NOT an Actual Survey 4.1124 x 6-314" 12,86488 89.30 358.11 4,021.14 3,928.52 4,824.29 4,231.30 5,985,26587 1,693,80820 0.62 740.94 MWD+IFR-AK-CAZ-SC 15) 12,899.09 89.30 358.62 4,021.80 3,929.18 4,878.48 4,229.75 5,985,32D.04 1,693,806.30 0.94 708.88 MWD+IFR-AK-CAZ-SC (5) 12.96000 89.30 358.62 4,022.55 3.929.93 4,93937 4,228.29 5,965.380.91 1,693.804.43 000 673.08 PROJECTED to TD Final Definitive Survey Verified and Signed -off All targets and/or wolf posildon objectives have been achieved. Yes ❑ No 1 have checked to the best of my ability that the following data is correct: D Surface Coordinates P1 Declination & Convergence E) GRS Survey Corrections E] Survey Tool Codes Brandon Ternple mmh r§w by 9.W. SLB DE: nec 391709,9 tauszmno Hallford "`�� amMraaanng Client Representative: Kelsey Date: 09/27/2017 92512017 11:30.21AM Page 6 COMPASS 5000.14 Build 85 RECEIVED Originated: Schlumberger OCT Z o Zo�7 PTS- PRINT CENTER A`'�OGCC 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: Makana K Bender Natural Resources Technician 11 r Alaska Oil & Gas Conservation Commission t '.V "1` Ave. Sure I00 Anchorage. AK 99:101 J DATA LOGGED 0 IVW20l ? M.K.BENDER zi 7097 28 722 WELL NAME 2G-08 API It 50-029.21125-00 SERVICE ORDER fj�giijii DSOS-00066 NAME DESCRIPTION KUPARUK RIVER SERVICE WL DELIVERABLE DESCRIPTION Tubing DATA TYPE FINAL FIELD DATELOGGED 5 -Oct -17 Color Prints 1 CD's 1 143-05 50-029.20908-00 DM87-00131 KUPARUK RIVER WL IPROF FINAL FIELD 11 -Oct -17 1 1 1H-04 50-029-20770-00 DM87.00132 KUPARUK RIVER WL IPROF FINAL FIELD 12 -Oct -17 1 1 214-09 50-103.20050-00 DM87.00133 KUPARUK RIVER WL PPROF FINAL FIELD 13 -Oct -17 1 1 2V-01 50-029-2103400 DM87-00134 KUPARUK RIVER WL Caliper FINAL FIELD 14 -Oct -17 1 1 2W-12 50-029-21240-00 DM87-00135 KUPARUK RIVER WL PPROF FINAL FIELD 15 -Oct -17 1 1 1H-118 50-029-23578-00 DM87-00136 KUPARUK RIVER WL RST,WFL FINAL FIELD 16 -Oct -17 1 1 1H-102 50-029-23580-00 DM87-00137 KUPARUK RIVER WL USIT FINAL FIELD 18.Oct-17 1 1 1 8 8 Transmittal Receipt A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the X package have been verified to match the media noted above. The Print Name Signature Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this Please return via courier or sign/sca)t and email a copy to Schlumberger. point. Originated: Schlumberger PTS - PRINTCENTER 6411 A street Anchorage, AK 99518 (907) 273-1700main RECEIVED SEP 0 7 2017 AOGCC (907)273-4760 fax Delivered to: �MakanaK Bender Natural Resources Technician 11 Alaska Oil & Gas Conservation Commission Av.--;1!11E� 11)11 �1fi�":u+1-�=1E AK 0e TRANSMITTAL DATE TRANSMITTALN - DATA LOGGED c1 /12/201-7 id. K. BENDER 1E-168 50-029-23230-00 SER NCE ORDER DSOS-00051 FIELD NAME KUPARUK RIVER SERVICE DESCRIPTION DELIVERABLE WL DESCRIPTION FBHPS DATA FINAL FIELD DATELOGGED 14 -Aug -17 Color Prints — CD's 1J-162 50-029-23360-00 DOUJ-00013 KUPARUK RIVER Memory Coil Flag FINAL FIELD 21 -Aug -17 1 1 lQ-11 50.029-21216-00 DM87-00122 KUPARUK RIVER WL Caliper FINAL FIELD 24 -Aug -17 3K -08A 50-029-21621-Ot DWH3-00001 KUPARUK RIVER WL Caliper FINAL FIELD 25 -Aug -17 1 1 3K-11 50-029-21654-00 DWH3-00003 KUPARUK RIVER WL Caliper FINAL FIELD 28 -Aug -17 1 1 3K-25 50-029-22881-00 DWH3-00004 KUPARUK RIVER WL Caliper FINAL FIELD 30 -Aug -17 1 1 1L-24 50-029-22170-00 DSOS-00053 KUPARUK RIVER WL LDL FINAL FIELD 31 -Aug -17 1 1 3F-08 50-029-21464-00 DSOS-00054 KUPARUK RIVER WL IPROF FINAL FIELD 1 -Sep -17 1 1 1H-10250-029-23580-00 DSOS-00055 KUPARUK RIVER WL USIT FINAL FIELD 3 -Sep -17 1 1 1B-09 50-029-20655-00 DSOS-00056 KUPARUK RIVER WL Caliper FINAL FIELD 5 -Sep -17 1 1 1B-09 50-029-20655-00 OSOS-00056 KUPARUK RIVER WL Plug FINAL FIELD 5 -Sep -17 1 1 11 11 3nsmittal Receipt A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the X —package have been verified to match the media noted above. The nt Name Signature Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this !ase return via courier or sign/scan and email a copy to Schlumberger. point. THE STATE GOVERNOR BILL WALKER Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1H-102 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-097 Surface Location: 40.52' FNL, 764.65' FEL, Sec. 33, T12N, R10E, UM Bottomhole Location: 557.7' FNL, 1796.3' FEL, Sec. 27, T12N, R10E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development 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, Hollis S. French p\� ; Chair DATED this vday of July, 2017. STATE OF ALASKA Al! �A, OIL AND GAS CONSERVATION COMM( ON PERMIT TO DRILL 20 AAC 25.005 RECEIVED JUN 2 12017 1a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas L] Service - WAG Service - Disp E]1 c. Specifyfor: Drill ❑� � Lateral ❑ Slraligraphic Test ❑ Development - Oil ❑� Service - Winj El Single Zone ❑� , Coalbed Gas El Gas Hydrates El Redrill El Reentry F-11 Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket 1 Single Well ! 11. Well Name and Number: ConocoPhillips Bond No. 59-52-180 r U�' KRU iH-102 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 12526 TVD: 4015 Kuparuk River Field ' West Salk Oil Pool , 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 40.52' FNL, 764.65' FEL, Sec 33, T 12N, R010E, UM ADL025639 ' Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 4899.9' FNL, 1669.5' FEL, Sec 27, T 12N, R010E, UM LO/NS 80-261 8/1/2017 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 557.7' FNL, 1796.3' FEL, Sec 27, T 12N, R010E, UM 2560 SHL - 4515'; BHL - 584' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 93 15. Distance to Nearest Well Open Surface: x-549577.46 y- 5980662.56 Zone- 4 GL / BF Elevation above MSL (ft): 54 . to Same Pool: 1112 16. Deviated wells: Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91.42 degrees Downhole: 1746 psi • Surface: 1348 psi 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling Length MD TVD MD TVD (including stage data) 42" 20" 94# H40 Welded 80 Surface Surface 80 80 Existing, cement to surface 13.5" 10.75" 45.5# L-80 H563 1794 Surface Surface 1794 1700 914 sx 11.0 Lead, 145 sx 12.0 Tail 9.875" 7.625" 29.7# L-80 H563 8325 Surface Surface 8325 4004 644 sx 15.8 Class G 6.75" 4.5" 11.6# L-80 IBTM 4051 8475 4012 12526 4015 N/A: Un -cemented slotted liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes El No ❑� 20. Attachments: Property Plat ❑ BOP Sketch Divertter Sketch Drilling Program v. Depth lot Shallow Hazard e Sea ed Report B DrillingeFluid Program B 20 AAC 25.050 requiremlents 8✓ 21. Verbal Approval: Commission Representative: Date A a ✓( `1" 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be Kelsey Hanford deviated from without prior written approval. Contact Name: Authorized Name: G. Alvord Contact Email: kelsey.hallford@conocophillips.com Authorized Title: Alaska Drilling Manager Contact Phone: 1-907-265-1577 Authorized Signature:. W\ Date: 20 -Jun -17 Commission Use Only Permit to D JAPI Number: Permit Approval See cover letter for other Number: Q 50- Q - S Q ' QQ -QQ Date: '-i - l�f -\ -j requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: Rip r`- f� Samples req'd: Yes ❑ No[V Mud log req'd: Yes E] No� (l P fl nsiu6ar kjs f -k Z�7�H3S measures: Yes Rf No El Directional svy req'd: Yes [?f No �pr!✓6va F5/ L ❑ Spacing excep n req'd: Yes ❑ No Inclination -only svy req'd: Yes No Post initial injection MIT req'd: Yes ❑ No Hr APPROVED BY pJ't �] t Approved by: COMMISSIONER THE COMMISSION Date: T 0n/11 ^1 n 1 Submit Form and 10-401 Revised 5/2077 T r1>]�`e RVA y1al'd\�rlQylrl[.onths from he d to 0 approval per 20 AAC 25.005(g) Attachments in Duplicate Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone(907)265-1577 Email: kelsev.hallford(cDconocoohillips.com June 20, 2017 Alaska Oil and Gas Conservation Commission 333 West 7s' Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED JUN 2 12017 At%-J.�CC Re: Application for Permit to Drill, West Sak Producer, 111-102 Dear Commissioner: Application for Permit to Drill, Well 11-1-102 Saved: 20 -Jun -17 b'� ConocoPhillips ConocoPhillips Alaska, Inc. hereby applies for a permit to drill a grass roots onshore producer, a penta-lateral horizontal well in the West Sak A2, A3, A4, B and D sands. The expected spud date for this well is August 1, 2017. It is planned to use rig Doyon 142. A 13-1/2" surface hole will be drilled on diverter & 10-3/4" surface casing will be run to total depth and cemented to surface. The remaining intervals will utilize Doyon 142's 13-5/8" x 5000 psi BOP stack with required ram installations and tested on a 14 day cycle in accordance with COP and AOGCC policy. The intermediate hole section will drill a 9- 7/8" hole with 7-5/8" casing run to total depth & cemented in place. The first 1H-102 6-3/4" production lateral will be geo-steered in the West Sak A2 sand and lined with 4-1/2" slotted liner. The subsequent production laterals will again be drilled with 6-3/4" hole and lined with 4-1/2" slotted liner in the following order: West Sak A3, A4, B and D sand. A separate PTD application will be submitted for each lateral: 1H-102, 1H-IO2LI, 1H-IO2L2, 1H -102L3, and 1H -102L4 laterals. Please rind attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Kelsey Hallford at 265-1577 (kelsev.ballford(a�conocophillips.com) or Chip Alvord at 265-6120. Sincerely, � 6sey Hal d ' G Drilling Engineer Application for Permit to Drill Document Kuparuk Well 1H-102 Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as 1H-102 Location Summary Requirements of 20 AAC 25.005(c)(2) u,panied by each of the, following Items. except for an deur already on file ivith the commission and .ea r,hd rho ,q.ph.un..u. (?t ar plat idem )rng the pi uper it and the pr'operty's miners and shovvtog (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation. and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the ewrface. referenced to the state plane coordinate system for this state as maintained by the National Geodetic Sun ey in the National Oceanic aid Annospheric Achninism'allow (C) the proposed depth of the well at dee top of each objective formation and at total depth: Location at Surface 40.52' FNL, 764.65' FEL, Sec 33, T 12N, ROIOE, UM ' NGS Coordinates Northings: 5980662.56' Eastings: 549577.46' Total Vertical Depth, SS. 3911' RKB Elevation 93' AMSL ` Pad Elevation 54'AMSL• Location at Surface Casing 349.45 FNL, 466.77 FEL, See 33, TI2N, ROI OE, UM NGS Coordinates Northings: 5980355.65' Eastings: 549878.04' Measured De th, RKB: 1794' Total Vertical De th, RKB: 1700' Total Vertical Depth, SS: 1607' Location at Intermediate Casing 4743.15' FNL, 1667.16' FEL, Sec 27, T12N, ROME, UM NGS Coordinates Northings: 5981270.1' Eastings. 553949.3' Measured De th, RKB: 8325' Total Vertteal Depth, RKB: 4004' Total Vertical Depth, SS. 3911' Location at Total De th 557.7' FNL, 1796.3' FEL, See 27, T12N, ROIOE, UM NGS Coordinates Northings: 5985454.01' Eastings: 553783.2' Measured De th, RKB: 12526' Total Vertical Depth, RKB: 4015' Total Vertical Depth, SS 1 3922' and (D) other information required by 20 AAC 25:050(6): Requirements of 20 AAC 25.050(6) and. the application for a Permit to Drill (Form 10-401) nnm ft inJnd. .r pial. d0.m... nablescale. shmvtmg the path ofthe proposed wellbore. including all adfacenuelibores within 200feet ofanypovion of the in veli: Please see Attachment: Directional Plan And (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators gfthose hvells. to the extent that those names a, a known or discoverable in public records. and shmv that each named opermor has been fimnished a copy ofthe application by cerli%rod mail: ar d;, ,,i, than the applicant is the only gjfeeled owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) n applicalior for a Permit m Drill must be accompanied hp each of the follmring heuts. evicept for an new already on file with the eommiss(or and identified in the applicmion: (3) a diagram and description a/ the blowout prevention equipment (BOP6) as required hr 20 AAC 25.035. 20 AAC 25.036. or 20 if, 4C 25.017. as applicable: Please reference BOP schematics on file for Doyon 142. Due to lower reservoir pressure in the West Sak a fixed stack ram placement will be utilized to fulfill all barrier requirements during well construction operations, graphic attached. Drilling Hazards Information Reauirements of 20 AAC 25.005 (c)(4) An applicmion for a Permit in Drill must be accoagxated by each of the follai•ing items, except for nth item already on file a ah the commission and identified in the application: (4) information on drilling hazards. Including (A) the n aximan, downhole pressure Meitner), he encountered. criteria used to determine U. and maximum potential surface pressure based on a rnedmnegradient; The maximum potential surface pressure (MPSP) while drilling I H-102 is calculated using an estimated maximum reservoir pressure of 1746 psi (based on 1 H -05A pressure at a 4005.2' TVD reference datum), a gas gradient of 0.10 psi/ft, and the estimated depth of the West Sak A2 sand at 3979' TVD: A2 Sand Estimated. BHP = 1,746 psi tv.v�i A2 Sand estimated depth = 3,979' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 397.9 psi (3,979' TVD * 0.10 psi/ft) MPSP = BHP — gas column = 1,348 psi (1,746 psi — 397.9 psi) (B) data on potential gas sones: The wellbore is not expected to penetrate any shallow gas zones. i And (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata- lost circulation cones, and zones not have a propensity for differential slicking: See attached 1H-102 Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill mist be act unnpanied by each of the follorving items. except for an idem already on file with the commission and identified in the application: (5) a desn'iplion of the procedure for Conducting formation integr'its, tests. as required aider 20, LIC 25.030(l): A procedure is on file with the commission for performing FIT/LOT'S. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An upl t io Drill must be accompanied by each of the folloring items. except for an iter, already on file with the commission and ide»op.,�:r- ,, .....:m. (6) a complete pr-opnsed caring and cementing program as required by 20 AAC 25.030, and a description of air) slated liner, pre -perforated liner at screen to he installed Casing and Cement Program 18. Casing ogram Specifications Top - Setting Depth -Bottom Cerrent Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length rvU ND MD ND (including stage data) 42" 20" 94#H40 Wakled 80 Surface Surface 80 80 Existing, cerrent to surface 13.5" 10.75" 45.5# L-80 H583 1794 Surface Surface 1794 1700 914 sx 11.0 Lead, 145 sx 12.0 Tail 9.875" 7.825" 29.70 L-80 H563 8325 Surface I Surface 1 8325 1 4004 1644 sx 15.8 Gass G 6.75" 4.5" 11.6# 1 L-80 18TH r 4051 8475 1 4012 1 12526 1 4015 1 WA: Un-cernented slotted liner Diverter System Information Requirements of 20 AAC 25.005(c)(7) Jo applualion lma Permit to Drill nova he accompanied by each of dm follmning items. except far an hent ab'eado on file wGh the commission and identified ht the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 15035(h)(2), Please reference attachment for diverter schematic. Drilling Fluid Program Reauirements of 20 AAC 25.005(c)(8) An applicalion for a Peretti to Ordl nmsl he acrotnpoined by each of dte follmving items. except jor an item already on file it hh the co ....ntoon and idenlifted in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25 033,' Mud Program Summary 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 Reauirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Reauirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Reauirements of 20 AAC 25.005 (0(11) N/A - Application is not for an offshore well. Surface Intermediate Production 13-1/2" Hole 9-718" Hole 6-314" Hole 10-314" Casing 7-5/8" Casing 4-112" Liner . Mud System Spud WBM LSND WBM FlowPro WBM Density 8.8-9.5 9.0-9.5 9.0-9.5 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 7-11 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 Reauirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Reauirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Reauirements of 20 AAC 25.005 (0(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) Jn up J camw for o J""'. r '. i., i .r he acrornpumed bieach of the )ollo,ring items. except for' an deal ah-eadp onftle with rhe m...wAsion and idengffed ut the upphealmn: The proposed drilling program follows. Please refer to attachment for proposed well schematic. 1. Move in / rig up Doyon Rig 142. Install 21-1/4" Annular with 16" diverter line and function test. 2. Spud and directionally drill 13-1/2" hole to casing point as per directional plan. Survey & log with MWD, GWD, GR/RES. / 3. Run and cement 10-3/4", 45.5#, L80, Hyd-563 casing to surface. Displace cement with mud & check floats upon bumping plug. Perform top job if required after notifying AOGCC. Evacuate top 2 feet of cement from annulus for sealant job (post rig). 4. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP'S to 3500 psi (annular preventer to 2500 psi) high and 250 psi low. Notify AOGCC 24 firs before test. 5. PU 9-7/8" PDC bit and directional drilling assembly, with MWD, Gamma, Resistivity. RIH and clean out to 100' above shoe. Test surface casing to 3000 psi for 30 minutes. � 6. Drill out shoe track between 20' of new formation. Perform FIT to a minimum of 12.5 ppg, maximum of 14 ppg EMW LOT/FIT, record results. 7. Directionally drill to intermediate hole TD landing in the West Sak A2 sand package. 8. BROOH to surface shoe, circulate well clean then POOH on elevators. 9. Laydown intermediate BHA. 10. Run 7-5/8", 29.7 L80, Hydril 563 casing from surface to TD. 11. Pump cement job as per Schlumberger proposal. Top cement to be placed @ +/- 5,893' MD (250' TVD minimum above N Sand formation). 12. Install 7-5/8" packoff & test to 5000 psi. 13. Flush 10-3/4" x 7-5/8" annulus with water, followed by diesel or isotherm to freeze protect. 14. PU 6-3/4" bit, and drilling assembly with MWD, Gamma, Resistivity, and Periscope. / 15. RIH on 4" DP to top of float equipment. Clean out cement to top of float equipment & test casing to 3000 psi for 30 minutes, testing against the annular to accommodate the West Sak fixed stack BOP configuration. ? 16. Drill out shoe track and 20' of new formation. Perform LOT to a minimum of 12.0 ppg EMW maximum FIT of - 13.0 ppg, recording results. 17. Directionally drill 6-3/4" hole geo-steering through the West Sak A2 sand to TD per directional plan. 18. Circulate 1 BU after TD and BROOH to 7-5/8" shoe CBU to clean casing & POOH on elevators. 19. Lay down Production BHA. 20. PU and run 4-1/2", 11.69 slotted liner w/ ZXP liner hanger & packer. The top of liner will be placed at -8462' MD, allowing for +/-150' of overlap in the 7-5/8" casing & proper spacing for the whipstock assembly. 21. Set liner hanger & packer using MWD to orient hanger. 22. PT liner top packer to 2,500 psi for 10 minutes, chart results. 23. Flow check well for 30 minutes. 24. POOH with liner running tools and lay down. 25. Run & set Baker whipstock system, placing the top of the window at +/-7,789' MD / 3,898' TVD, just below the top of the A3 sand orienting with MWD. 26. Mill 6-3/4" window until top mill across face & clean up window. 27. Perform formation integrity test to minimum of 12.0 ppg, maximum of 13.0 ppg EMW, recording results. 28. POOH with milling BHA. 29. PU 6-3/4" bit, motor, MWD, and magnets to perform a clean out run & land the well. (GR, Res) 30. RIH, orient through window and tag bottom. 31. End 1H-102 PTD & begin IH -102L1 PTD. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An a I t roar to Drill arusm be accompanied by each of the following nems. except for on item already on file virh the commission and identrfted in the apphcation: (14) a general description of hou the operator plans to dispose of drilling nod and matings and a statement of ithither the operator Intends to request atahorization ander 20 AAC' 25.030 for an annular disposal operation in the it ell. Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class 11 disposal well at the 1B Facility. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kupamk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 BOP Ram Placement Attachment 2 Well Schematic Attachment 3 Diverter Layout Diagram Attachment 4 Directional Plan Attachment 5 Drilling Hazards Summary Attachment 6 Cement Summaries Fixed BOP configuration for West Sak Operations f"I f Fixed Blind (� O y} Wellhead /Tubing Head /Tree, Insulemd Con., 13-3/8"x 0.i", 5,000 kai 1H-102 Producer Schematic Cssing.20", 94q, KSS x 0312" DRAFT W.1.� Tubin656ing: 4-t2", 124 b, 480 TXP +I-80'MD Gan Lill Mandrel, 0.12" x I- w/dummy valva M-3/4", 45.5p, Gas LIHMaMm1, 412"eel"w/SOV L-80, Hyd563 Vu' SSD with 3,812" DB Nipple preflo 17W'MD/17W'TVD Peonanens Down Hole Gauge Tubing Seal Assembly ,e ZXP Pecker a z LvWing nipple gofilc 4�—U'D"Send Wiidow s 5 '•,• 0.12", IL6tl L80, 6-3/4"Deand lateral n �„•"• SIodM Liner " e _____________ _____ ___________________ ____________________ _____ __ .......................... ____________ e O •___• ..........................................••___- ..................... 5 .• Li"e"Surd WindowSwellPukers--/a` 6-314"B and lamal� T a 4Stacked Baker Hook Hanger •••,• n' Door, L80 r' Level JJunclion SYsrems ............................................................................. ... ...... .. ............. ............ ................. ................................................... ... �r ZXPPacks L2 "A4" Sand WiMow •, LI"A3"Sand Window ..................... A4 d lamral - 6-3/4" sen Luaal Envy Module•• , '• 4-12" Lim, 116Y L80 _____________ ___________________________________________________________________ 6-31CA3 sand Imcral x Tubing Seal Assembly -----_`_—'—_—' ••................... .................................................................. •, g Lalling nipple ,ofile ' 6-314" A2 anod [.A d-12" U,. l fib L80 Z%Ppacka '� 12526' KID 14015' TVD ------------- W-. ________________________________ •• >v_ _ 7-5/e", 291b, L-80, Hyd563, C,_________ ------------------------ ----- •'� --------- 8325' MD 14004' TVD ........... ........ .............................................................• ��' r 71 I - Drill Site 1 H�� r ConocoPhilhps TITLE: DS1H LAYOUT DRAWING Alaska, Inc. DRAWN BY: ALKET MICI DATE. M-m-zon REV. i 1 H-102wp23 WS Objective 5 T915 _.. _. 5 N 't PFR T 10.314' 13-1n' 0 0 '0 3000 6000 9000 I <� 0 lz000 I Depth Reference: Plan: 54*39 @ 93.1 sU (Doyon 142) i0 10-3/d" x 1&12 Rig: Doyon 142 90 O 0 00reo� 0 75/6" x8-)19" b� o 0 4112" x6-314" � o mqm m m � m i 1500 3000 4500 6000 7500 Horizontal Departure 111 1D3L3wp2t I '. 511 iD�Wi044 ' IH -101L4 28 1H-103ifwoll 1H-101L3wp28 111 1D3wp21 1H103Lbwp21 new INC-ONL1`t00cotle) i H 105 1 1a01L2wp28 I '.. 05 -1 Dt L1wp28 ' 6.Mi 934 Plan Summary I I I r O a_ O 0 CD CD 0 N O 60 " I I I I I I I I I- % i J 0 2000 4000 6000 8000 10000 12000 "a / uo SURVEY PROGRAM epth From 39.00 ]00.00 700.00 Depth To 700.00 1700.00 1)9410 Survey/Plan 1H-102wp23(Plan: 11+102) 1H-402wp23(Plan: 11+102) 1H-102wp23 (Plan: 11+102) Tool GYD-GC-SS MWD MWD+IFR-AK-CAZSC Pad Elevation: 54.00 1]88.6 KOP: Stan LW110O DL6, 136• TF, for 300.31' CASING DETAILS 1794.10 3294.10 1H-102wp23 (Plan: 11+102) MWD 1]94.10 8324.54 1H-102wp23(Plan: 11+102) MWD.IFR-AK-CAZSC TVD MD Name 8324.54 9824.54 11-1-102wp23(Plan: 111-102) MWD 118,00 118.00 2U'x 42" 8324.54 12525.50 11-1-102wp23 (Plan: 1&102) MWD4IFR-AK-CAZSC 1700.37 1794.10 10.304" x 13-1&- 0.00 0.00 0.00 0,00 4003.78 8324.54 7518" x 9-7/8" 2 3oo.00 0.00 0.00 4015.11 12525.50 4-12" x 6-304" 180 39 _ 300 %0 - 480 490 - 6]0 670- No i No - 1040 1040 - 1230 1230 - 141D 410 - WO 1600 - 2050 2060 2600 2500 - 2950 2950 - 3100 3,100 - 3650 me - 4300 4300 - 4750 4750 - 5200 52M- 6120 SIM - 7030 ]030 - 7%0 7%0 -8660 0860 - 9780 970 - 1070 10700- - 1161 11610 - 1 Magnetic Model: BGGM2017 vMarredModel Dole 1.63 Mage Cearaw47.63- To To conM a Magnetic DIaMm to aTrue ,\ Dlretllen, Md 17,63• East 1620.4 PFROST Annotation 1]88.6 KOP: Stan LW110O DL6, 136• TF, for 300.31' T-3 Men 2.6710 DLS, O• TF, for %339 SECTION DETAILS Sec MD IncAa 2008.4 ND +N1 -S +EAW Dleg TFace VSetl Target 1 39,00 0.00 000 39.00 0.00 0.00 0.00 0,00 0.00 2 3oo.00 0.00 0.00 300.00 0,0o o.on D.00 0.00 0TO 3 60D.3'450 1%.00 00.00 -0.49 8.20 1.50 136.0 -B19 Hold for 1]].39' 4 803.]0 12.09 136 %0.00 .19% 30.59 2.0 0.00 J9.% 5 1836.94 34.08 1%.00 15)0.3] -245.53 237.10 3.0 0.00 -245,53 5 1]57.68 34.09 136.00 1670.37 -294.20 284.11 a.TO 0.00 -294.20 Haldfor702Y 1]9460 34.88 134,81 17...37 -308.92 298.59 3.0 55.00 -308.92 _.._ 8 1814.10 34.99 134.81 1]16.76 -317.01 305]2 0.0 0.00 -317.01 9 3141.44 ]1.00 112.1] 2501.02 54599 1197.86 3,07 34.28 -045.99 10 4851.44 ]1.80 112.1] 3035.11 -1450.96 270221 0.0 ON -1458+90 11 5692.63 ]2.00 7238 %00.00 -1489.21 3483.98 4.0 -94.70-1489.21 12 6:92.63 ]2.00 72.38 3358a -1431,% 3656.15 0. W 0.00 -143136 13 5921] 5 ]3.50 ]0.76 338).30 -1422.55 3692,58 5, 72 585]-1422,55 I SB%.]9 ]3.60 ]0.78 3388.]3 4399.16 3758.62 0.0 0.0 -1388.16 15 ]10.95 75.57 0.00 3747.35 534.55 4369.6 5.M -99,21 534.55 16 ]101.01 ]5.5] 0.00 3]52.35 515.12 4%9.05 0.0 0.00 515A2 11+10201.]1 M16178P 11 ]893.04 ]5,5] 0.00 3925,00 155.85 4%9.05 0.0 0.0 155.85 19 a00.00 ]9,03 1,38 3948.33 259,38 437D.31 3.04 21.38 259.39 19 81]].39 ]9.03 1.3a 3982.08 433.48 4374,50 0.00 0,00 433.48 20 8324,54 84.00 0.00 4003.]8 57:.6 43]6.24 3.50 -15.46 5)8,96 1H-1 D2 WT3 OWdl5 BW 21 9344.54 84.00 old 4015.87 598,85 43]6.24 0.0 0.00 599.85 22 8574.81 90.89 OA8 4016.1] 828,55 4377.21 9.00 4.02 329.55 23 091].11 90.a9 OAa 4m D.B4 11]1.01 4380.09 0.00 0.00 W1.01 24 8953.12 88.81 030 401062 1207.01 4%0.36 3.04 -0]4.551207.01 1.10204.T4050d15 BW 25 9%3.13 89.01 0.38 4013.84 2206,90 4%6.88 11.0 0.00 220.98 26 10368.65 e).e] 345.% 40230 2618.30 433]]5 3,0 8]76 Mill 0 27 10574.24 07.87 945.96 4030.01 2817.59 4287.81 O,W 0.00 2817,69 28 10898.93 911.00 0.60 407.94 390.24 4238.67 3.0 01.% 3238.24 11L10207b 090816 KU 29 110)0.00 91.42 0.60 4037.06 3308.30 4239.51 2.0 0.00 930930 30 1185322 81.42 0.68 4%7.63 4092.23 4248.]6 O.W 0.0 4092.23 11+1006T900816 KU 31 1190.)9 90.11 35a.80 4916.1fi 4202.7B 4240.35 2,04 -12646 4202.70 32 12525.5D 90.11 358.901 4015.11 476488 4237.66 0.00 O. W 476438 114102 09,T9 090816 KU 180 39 _ 300 %0 - 480 490 - 6]0 670- No i No - 1040 1040 - 1230 1230 - 141D 410 - WO 1600 - 2050 2060 2600 2500 - 2950 2950 - 3100 3,100 - 3650 me - 4300 4300 - 4750 4750 - 5200 52M- 6120 SIM - 7030 ]030 - 7%0 7%0 -8660 0860 - 9780 970 - 1070 10700- - 1161 11610 - 1 Magnetic Model: BGGM2017 vMarredModel Dole 1.63 Mage Cearaw47.63- To To conM a Magnetic DIaMm to aTrue ,\ Dlretllen, Md 17,63• East 1620.4 PFROST Annotation 1]88.6 KOP: Stan LW110O DL6, 136• TF, for 300.31' T-3 Men 2.6710 DLS, O• TF, for %339 Ran 3°1100' DLS, 0° TF, far 73323' 2008.4 Hold for 120.74 Rad 3-11 Off US, -%• T5 for 36.42' Hold for 2V Rad 3.07°1109 US, -M.25- TF, for 1327.11 HOW for 171V Red 4.51100' DLS,-943-TF for 841,19 Top Pump Tangent: Hold for 210' Bare Pump TangaM: Ran 6.04•/1 W DLS, 505.0 TF, for MAT Hold for 74,04' K-15 Ran 5.73°1100' US, -98.21° T5 for 1185.16- 185.16Hold Hold1.20.06' Adjust TF to 0•, for 02.83' Stan 3.5°1100' DLS, 2136• T5 for 105.16 Hold for 1]].39' Shia 3.5.1106' Us, .15,46- TE for 147.15' Hold for 29 Man 3°110' US. 4.02• TF, I. MOOT HOW for 342.51' 3135.4 Mad 3110V CLS,.174.55° TF for 36' Hdtl for 100' Glad 3.5.110' DLS,-97.78.1'5 for 415.53' VG C - Hold for 20559' Rad 3.61100- DL6, 81,9g° TF, for 24.69 3382a UG B Red 2.110' US, W T5 far 71.07 04e6d- Haldfor702Y UG A for 110.57 Ras 2°1109 U.S.-126.46°TR3610.7 Haldf.561.T No TD: 126255' MD, 4015.11' TVD _.._ By signing this I ackrmwledge that I have been informed of all risks, checked that the date is Wnect ensured it's completeness, and all surrounding wells are assigned to the proper position an I approve Ute scan and sudd a non in, Prepared by: Checked by Accepted by: j Approved by Brij Potnis Huy But Ann Edk Stell Hallforq Phelps 89t ♦V N i3 t 0. iAff GA LL 3)Ob �wnFenwlwelXIW {MmuyilNx�'xNaU1M10tp] II .:% 1 rr, I lo"kl-c- rre .'r mine ... in x ii.0 ' nI ®wwoMYry ASGA �® 4;n, � q D nY [ of u r:A f"e s, i � r j iiavel�eg 11-101 lm Ob(TFO-➢)Cem,, N Centre SepmaLon�usM1� i 1816 1 R-0 R -29L1 1R-25 � 1R-24 1 R-27 1G -12L1 I 1 4L1 '!G-12 H-Ofi rHl, Easting (2500 usfiin) 1H-125wp20 1H-124wp20 1H-123wp20 1H-122wp20 __.._../ 1N -121w l 1H.1-120wP21 I wp2 X-00.1 u>Q7t 1NC-ONLY toolwde) 10 tl�L 2 1H- p21 1H-115wp21 116.p21 -1 9wp21 1H-12 1H-113wp21 -wIRxP21 1H- 9 1p:18�E3� �fl� H-21 gg 1H-108wp2 UH dwp21 IH -15 1 H -104w h Ct 11L 1 Sd- 51§2.1'p C 1C 1H '107W 1 H-106wP21 1C-1 1C -11C-1 1 1H-01 1B-102 1C- _ H- 1C-1 11L -0 C -11L 02 1C 17 1t$ 1 Easting (2500 ustvn) 1C-156wp06 5 �11tC;1;9 �G01 2 0 m H-20 1* -*PB1 1H-14--- 16A 1M-17AL11H- / 1G1H %Hk L11G-10BP611G 1G -12L1 I 1 4L1 '!G-12 H-Ofi rHl, Easting (2500 usfiin) 1H-125wp20 1H-124wp20 1H-123wp20 1H-122wp20 __.._../ 1N -121w l 1H.1-120wP21 I wp2 X-00.1 u>Q7t 1NC-ONLY toolwde) 10 tl�L 2 1H- p21 1H-115wp21 116.p21 -1 9wp21 1H-12 1H-113wp21 -wIRxP21 1H- 9 1p:18�E3� �fl� H-21 gg 1H-108wp2 UH dwp21 IH -15 1 H -104w h Ct 11L 1 Sd- 51§2.1'p C 1C 1H '107W 1 H-106wP21 1C-1 1C -11C-1 1 1H-01 1B-102 1C- _ H- 1C-1 11L -0 C -11L 02 1C 17 1t$ 1 Easting (2500 ustvn) 1C-156wp06 5 �11tC;1;9 �G01 2 0 m 1 H-102wp23 Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 4-1/2" x 6-3/4" - 2525 4500 H-102 09.79 090816 U 1H-102wp23 -12000 11H-102 08.78 090816 U 9000 3000 H-102 07.77 090816 U + 10000 s 0 0 Z 2500- 0 000 co 1 H-102 04.74 050ot15 B 7-5/8" x 9-7/8'-'- _ 00 1 03.T3 05OW5 B 0 ,�O 20" x 42"- 10-3/4" x 13-1/2b� ,tio 00 Mo 0 " o0 1$90®2 01.T1 061617 0 0 h -1500 0 -1500 0 1500 3000 4500 6000 West( -)/East(+) n 700 1 H-102wp23 k 20" x 42" 0. 1000 PFROST 1400 103/4" xY13-1/2".',"T-3 0x2100K-15 Section View °o ---Na WS—O WS_B WS—A4—Objective 5'0 WS—C WS—A4 WS—A3 WS_A3_Objective o WS A2 ro 7-5/8" x 9-7/8" -- II -1500 -750 0 750 1500 2250 3 Vertical Section at 0.00° 4-1/2" x 6-3/4" N f w ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1 H Pad Plan: 1H-102 (formerly 31) Plan: 1 H-102 Plan: 1 H-102wp23 Standard Proposal Report 19 June, 2017 Database: EDM Production Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Plan: 1 H-102 (formerly 31) Wellbore: Plan: 1H-102 Design: 1H-102wp23 SLB Standard Proposal Report Local Co-ordinate Reference: Well Plan: 1H-102 (formerly 31) TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) MD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Sits Kuparuk 1 H Pad Site Position: From: Map Position Uncertainty: 0.00 usft Slot Radius: 0" Well Plan: 1 H-102 (formerly 31) Well Position -N/-S 0.00 usft +E/ -W 0.00 usft Position Uncertainty 0.00 usft Ground Level: 54.00 usft ......_....... _._. Welltlom Plan: 11-4-102 Magnetics Model Name Sample Data Declination Dip Angle Field Strength C1 0 (n7) BGGM2017 8/19/2017 17.63 80.95 57,498 Design 1H-102wp23 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (') 39.00 0.00 0.00 0.00 8/192017 3: 37: 48PM Page 2 COMPASS 5000.1 Build 74 SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan: 1 H-102 (formerly 31) Company: ConowPhillips (Alaska) Inc. -Kupl TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Site: Kuparuk 1H Pad North Reference: True Well: Plan: 1 H-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H-102 (usft) V) Design: 1H-102wp23 Usti (usft) Pian Sections Measured Vertical TVD Dogleg Send Tum Depth Inclination Azimuth Depth System +Nl-S +E/ -W Rate Rate Rete Tool Face (usft) V) (1) (usft) Usti (usft) (usft) (•Mo0usft) (41o0mft) (91o0usi (•) 39.00 0.00 0.00 39.00 -54.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 207.00 0.00 0.00 0.00 0.00 0.00 0.00 600.31 4.50 136.00 600.00 507.00 -8.49 8.20 1.50 1.50 0.00 136.00 903.70 12.09 136.00 900.00 807.00 -39.96 38.59 2.50 2.50 0.00 0.00 1,636.94 34.09 136.00 1,570.37 1,477.37 -245.53 237.10 3.00 3.00 0.00 0.00 1,757.68 34.09 136.00 1,670.37 1,577.37 -294.20 284.11 0.00 0.00 0.00 0.00 1,794.10 34.99 134.91 1,700.37 1,607.37 -308.92 298.59 3.00 2.47 -3.00 -35.00 1,814.10 34.99 134.91 1,716.76 1,623.76 -317.01 306.72 0.00 0.00 0.00 0.00 3,141.44 71.80 112.17 2,501.02 2,408.02 -845.99 1,197.86 3.07 2.77 -1.71 -34.28 4,851.44 71.80 112.17 3,035.11 2,942.11 -1,458.98 2,702.21 0.00 0.00 0.00 0.00 5,692.63 72.88 72.38 3,300.00 3,207.00 -1,489.21 3,483.98 4.50 0.13 4.73 -94.70 5,892.63 72.88 72.38 3,358.88 3,265.88 -1,431.36 3,666.15 0.00 0.00 0.00 0.00 5,921.75 73.50 70.76 3,367.30 3,274.30 -1,422.55 3,692.59 5.72 2.11 -5.56 -68.57 5,995.79 73.50 70.76 3,388.33 3,295.33 -1,399.16 3,759.62 0.00 0.00 0.00 0.00 7,180.95 75.57 0.00 3,747.35 3,654.35 -534.55 4,369.05 5.73 0.18 -5.97 -99.21 7,201.01 75.57 0.00 3,752.35 3,659.35 -515.12 4,369.05 0.00 0.00 0.00 0.00 7,893.84 75.57 0.00 3,925.00 3,832.00 155.85 4,369.05 0.00 0.00 0.00 0.00 8,000.00 79.03 1.38 3,948.33 3,855.33 259.39 4,370.31 3.50 3.26 1.30 21.38 8,177.39 79.03 1.38 3,982.08 3,889.08 433.48 4,374.50 0.00 0.00 0.00 0.00 8,324.54 84.00 0.00 4,003.78 3,910.78 578.96 4,376.24 3.50 3.38 -0.94 -15.46 8,344.54 84.00 0.00 4,005.87 3.91287 598.85 4,376.24 0.00 0.00 0.00 0.00 8,574.61 90.89 0.48 4,016.13 3,923.13 828.55 4,377.21 3.00 2.99 0.21 4.02 8,917.11 90.89 0.48 4,010.84 3,917.84 1,171.01 4,380.09 0.00 0.00 0.00 0.00 8,953.12 89.61 0.38 4,010.62 3.917.62 1,207.01 4,380.36 3.00 -2.99 -0.28 -174.55 9,953.12 89.81 0.38 4,013.94 3,920.94 2,206.96 4,386.99 0.00 0.00 0.00 0.00 10,368.65 87.87 345.96 4,022.38 3,929.38 2,618.38 4,337.75 3.50 -0.47 -3.47 -97.76 10,574.24 87.87 345.96 4,030.01 3.93701 2,817.69 4,287.91 0.00 0.00 0.00 0.00 10,998.93 90.00 0.68 4,037.94 3944.94 3,238.24 4,238.67 3.50 0.50 3.46 81.96 11,070.00 91.42 0.68 4,037.06 3,944.06 3,309.30 4,239.51 2.00 2.00 0.00 0.00 11,853.22 91.42 0.68 4,017.63 3,924.63 4,092.23 4,248.76 0.00 0.00 0.00 0.00 11,963.79 90.11 358.90 4,016.16 3,923.16 4,202.78 4,248.35 2.00 -1.19 -1.61 -126.46 12,525.50 90.11 358.90 4,015.11 3,922.11 4,764.38 4,237.56 0.00 0.00 0.00 0.00 6/192017 3: 37 48P Page 3 COMPASS 5000.1 Build 74 4 Database: EDM Production Company: ConocoPhillips (Alaska) Inc. -Kupi Project: Kuparuk River Unit Site: Kupamk I Pad Well: Plan: 11-1-102 (formerly 31) Wellbore: Plan: 11-1-102 Design: iH-102wp23 SLB Standard Proposal Report Local Co-ordinate Reference: Well Plan: 1 H-102 (formerly 31) TVD Reference: Plan: 54+39 @ 93.00usft(Doyon 142) MD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey DLS Vert Sectlon (usft) -54.00 Measured 0.00 0.00 Vertical 0.00 0.00 Depth Inclination Azimuth Depth TVDss +N/ -S (usft) (') (') (usft) usft (usft) 39.00 0.00 0.00 39.00 -54.00 0.00 100.00 0.00 0.00 100.00 7.00 0.00 118.00 0.00 0.00 118.00 25.00 0.00 20" x 42" 38.59 2.50 -39.96 54.24 3.00 200.00 0.00 0.00 200.00 107.00 0.00 300.00 0.00 0.00 300.00 207.00 0.00 KOP: Start 1.5°/100' DLS, 136' TF, for 300.31' 3.00 -193.29 400.00 1.50 136.00 399.99 306.99 -0.94 500.00 3.00 136.00 499.91 406.91 -3.77 600.00 4.50 136.00 599.69 506.69 -8.47 600.31 4.50 136.00 600.00 507.00 -8.49 Start 2.6'/100' DLS, 0' TF, for 303.39' -351.93 344.68 700.00 7.00 136.00 699.18 606.18 -15.67 800.00 9.50 136.00 798.14 705.14 -25.99 900.00 12.00 136.00 896.38 803.38 -39.40 903.70 12.09 136.00 900.00 807.00 -39.96 Start 3°1100' DLS, 0- TF, for 73323' 1,000.00 14.98 136.00 993.61 900.61 -56.17 1,100.00 17.98 136.00 1,089.49 996.49 -76.57 1,200.00 20.98 136.00 1,183.76 1,090.76 -100.55 1,300.00 23.98 136.00 1,276.15 1,183.15 -128.05 1,400.00 26.98 136.00 1,366.42 1,273.42 -158.99 1,500.00 29.98 136.00 1,454.31 1,361.31 -193.29 1,600.00 32.98 136.00 1,539.58 1,446.58 -230.85 1,636.94 34.09 136.00 1,570.37 1,477.37 -245.53 Hold for 120.74' 1,697.35 34.09 136.00 1,620.40 1,527.40 -269.88 PFROST 1,700.00 34.09 136.00 1,622.60 1,529.60 -270.95 1,757.68 34.09 136.00 1,670.37 1,577.37 -294.20 Start 3-/100' DLS, J6' TF, for 36.42' 1,794.10 34.99 134.91 1,700.37 1,607.37 -308.92 Hold for 20'- 10-3/4" x 13.1/2" 1,800.00 34.99 134.91 1,705.20 1,612.20 -311.30 1,814.10 34.99 134.91 1,716.76 1,623.76 -317.01 Start 3.071100' DLS, -34.28' TF, for 1327.34' 1,900.00 37.19 132.45 1,786.17 1,693.17 -351.93 1,903.05 37.27 132.37 1,788.60 1,695.60 -353.17 T-3 2,000.00 39.81 129.90 1,864.43 1,771.43 -392.87 2,100.00 42.48 127.61 1,939.74 1,846.74 -434.01 2,195.08 45.06 125.64 2,008.40 1,915.40 -073.22 K-15 2,200.00 45.19 125.54 2,011.87 1,918.87 475.25 2,300.00 47.94 123.66 2,080.62 1,987.62 -516.45 +E/ -W DLS Vert Sectlon (usft) -54.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.91 1.50 -0.94 3.64 1.50 -3.77 8.18 1.50 -8.47 8.20 1.50 -8.49 15.13 2.50 -15.67 25.10 2.50 -25.99 38.05 2.50 -39.40 38.59 2.50 -39.96 54.24 3.00 -56.17 73.94 3.00 -76.57 97.10 3.00 -100.55 123.66 3.00 -128.05 153.54 3.00 -158.99 186.66 3.00 -193.29 222.93 3.00 -230.85 237.10 3.00 -245.53 260.62 0.00 -269.88 261.65 0.00 -270.95 284.11 0.00 -294.20 298.59 3.00 -308.92 300.99 0.00 -311.30 306.72 0.00 -317.01 343.32 3.07 -351.93 344.68 3.07 -353.17 390.19 3.07 -392.87 441.51 3.07 -434.01 494.30 3.07 -473.22 497.13 3.07 -475.25 556.91 3.07 -516.45 6/192017 3:37:48PM Page 4 COMPASS 5000.1 Build 74 SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan: 1 H-102 (formerly 31) Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Site: Kuparuk 1H Pad North Reference: True Well: Plan: 1 H-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 111-102 usft (usft) Design: 1H-102wp23 2,400.00 Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/ -S +FJ -W DLS Vert Section (usft) (_) (1) (usft) usft (usft) (usft) 2,052.80 2,400.00 50.71 121.94 2,145.80 2,052.80 -557.51 620.66 3.07 -557.51 2,500.00 53.51 120.35 2,207.21 2,114.21 -598.30 686.20 3.07 -598.30 2,600.00 56.32 118.87 2,264.69 2,171.69 -638.71 759.34 3.07 -638.71 2,700.00 59.16 117.49 2,318.06 2,225.06 -678.62 833.88 3.07 -678.62 2,800.00 62.00 116.18 2,367.18 2,274.18 -717.92 911.60 3.07 -717.92 2,900.00 64.86 114.94 2,411.91 2,318.91 -756.50 992.28 3.07 -756.50 3,000.00 67.73 113.76 2,452.11 2,359.11 -794.24 1,075.69 3.07 -794.24 3,100.00 70.61 112.63 2,487.67 2,394.67 -831.04 1,161.59 3.07 -831.04 3,141.44 71.80 112.17 2,501.02 2,408.02 -845.99 1,197.86 3.07 -845.99 Hold for 1710' 3,200.00 71.80 112.17 2,519.31 2,426.31 .866.98 1,249.37 0.00 -866.98 3,300.00 71.80 112.17 2,550.54 2,457.54 -902.83 1,337.35 0.00 -902.83 3,400.00 71.80 112.17 2,581.78 2,488.78 -938.67 1,425.32 0.00 -938.67 3,500.00 71.60 112.17 2,613.01 2,520.01 -974.52 1,513.30 0.00 -974.52 3,600.00 71.80 112.17 2,644.24 2,551.24 -1,010.37 1,601.27 0.00 -1,010.37 3,700.00 71.80 112.17 2,675.48 2,582.48 -1,046.22 1,689.24 0.00 -1,046.22 3,80D.00 71.80 112.17 2,706.71 2,613.71 -1,082.06 1,777.22 0.00 -1,082.06 3,900.00 71.80 112.17 2,737.94 2,644.94 -1,117.91 1,865.19 0.00 -1,117.91 4,000.00 71.80 112.17 2,769.18 2,676.18 -1,153.76 1,953.17 0.00 -1,153.76 4,100.00 71.80 112.17 2,800.41 2,707.41 -1,189.61 2,041.14 0.00 -1,189.61 4,200.00 71.80 112.17 2,831.65 2,738.65 -1,225.46 2,129.11 0.00 -1,225.46 4,300.00 71.80 112.17 2,862.88 2,769.88 -1,261.30 2,217.09 0.00 -1,261.30 4,400.00 71.80 112.17 2,894.11 2,801.11 -1,297.15 2,305.06 0.00 -1,297.15 4,500.00 71.80 112.17 2,925.35 2,832.35 -1,333.00 2,393.04 0.00 -1,333.00 4,600.00 71.80 112.17 2,956.58 2,863.58 -1,368.85 2,481.01 0.00 -1,368.85 4,700.00 71.80 112.17 2,987.81 2,894.81 -1,404.69 2,568.98 0.00 -1,404.69 4,800.00 71.80 112.17 3,019.05 2,926.05 -1,440.54 2,656.96 0.00 -1,440.54 4,851.44 71.80 112.17 3,035.11 2,942.11 -1,458.98 2,702.21 0.00 -1,458.96 Start 4.6°1100' DLS, -94.7° TF, for 841.19' 4,900.00 71.63 109.68 3,050.35 2,957.35 -1,475.52 2,745.25 4.50 -1,475.52 5,000.00 71.38 105.14 3,082.08 2,989.08 -1,504.04 2,835.66 4.50 -1,504.04 5,100.00 71.25 100.39 3,114.14 3,021.14 -1,524.97 2,928.01 4.50 -1,524.97 5,166.08 71.22 97.25 3,135.40 3,042.40 -1,534.56 2,989.84 4.50 -1,534.56 UG_C 5,200.00 71.23 95.64 3,146.32 3,053.32 -1,538.16 3,021.74 4.50 -1,538.16 5,300.00 71.34 90.89 3,178.42 3,065.42 -1,543.55 3,116.27 4.50 -1,543.55 5,400.00 71.56 86.15 3,210.25 3,117.25 -1,541.09 3,211.01 4.50 -1,541.09 5,500.00 71.90 81.42 3,241.62 3,146.62 -1,530.80 3,305.38 4.50 -1,530.80 5,600.00 72.36 76.72 3,272.32 3,179.32 -1,512.76 3,398.79 4.50 -1,512.76 5,692.63 72.88 72.38 3,300.00 3,207.00 -1,489.21 3,483.98 4.50 -1,489.21 Top Pump Tangent: Hold for 200' 5,700.00 72.88 72.38 3,302.17 3,209.17 -1,487.08 3,490.69 0.00 -1,487.08 5,800.00 72.88 72.38 3,331.61 3,238.61 -1,458.15 3,581.77 0.00 -1,458.15 5,892.63 72.88 72.38 3,358.88 3,265.88 -1,431.36 3,666.15 0.00 -1,431.36 Base Pump Tangent Start 5.721/100' DLS,.68.57° TF, for 29.12' 6119/2017 3:37:48PM Page 5 COMPASS 5000.1 Build 74 Database: EDM Production Local Co-ordinate Reference: Company: ConomPhillips (Alaska) Inc. -Kupl TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1 H Pad North Reference: Well: Plan: 1H-102 (formerly 31) Survey Calculation Method: Wellbore: Plan: 1H-102 Vert Section Design: 1H-102wp23 (1 Planned Survey SLB Standard Proposal Report Well Plan: 1H-102 (formerly 31) Plan: 54+39 @ 93.00usft (Doyon 142) Plan: 54+39 @ 93.00usft (Doyon 142) True Minimum Curvature Measured Vertical Depth Inclination Azimuth Depth TVD" +N/ -S +El -W DLS Vert Section (usft) (1) (1 (usft) usft (usft) (usft) 3,266.04 5,900.00 73.03 71.97 3,361.04 3,268.04 -1,429.20 3,672.86 5.72 -1,429.20 5,921.75 73.50 70.76 3,367.30 3,274.30 -1,422.55 3,692.59 5.72 -1,422.55 Hold for 74.04' 5,975.61 73.50 70.76 3,382.60 3,289.60 -1,405.54 3,741.35 0.00 -1,405.54 UG -13 5,995.79 73.50 70.76 3,388.33 3,295.33 -1,399.16 3,759.62 0.00 -1,399.16 Start 5.73.1100' DLS, -98.21° TF, for 1185.16' 6,000.00 73.46 70.52 3,389.53 3,296.53 -1,397.82 3,763.43 5.73 -1,397.82 6,100.00 72.63 64.59 3,418.72 3,325.72 -1,361.33 3,851.79 5.73 -1,361.33 6,200.00 71.98 58.62 3,449.13 3,356.13 -1,316.06 3,935.56 5.73 -1,316.06 6,300.00 71.52 52.61 3,480.48 3,387.48 -1,262.46 4,013.89 5.73 -1,262.46 6,319.91 71.45 51.41 3,486.80 3,393.80 -1,250.84 4,028.77 5.73 -1,250.84 UG_A 6,400.00 71.24 46.57 3,512.43 3,419.43 -1,201.07 4,086.01 5.73 -1,201.07 6,500.00 71.16 40.52 3,544.68 3,451.68 -1,132.49 4,151.20 5.73 -1,132.49 6,600.00 71.28 34.48 3,576.90 3,483.90 -1,057.42 4,208.80 5.73 -1,057.42 6,700.00 71.58 28.44 3,608.78 3,515.78 -976.60 4,258.24 5.73 -976.60 6,706.09 71.61 28.08 3,610.70 3,517.70 -971.51 4,260.98 5.73 -971.51 Na 6,800.00 72.08 22.44 3,639.98 3,546.98 -890.85 4,299.03 5.73 -890.85 6,900.00 72.76 16.47 3,670.21 3,577.21 -801.01 4,330.76 5.73 -801.01 7,000.00 73.62 10.56 3,699.15 3,606.15 -707.98 4,353.10 5.73 -707.98 7,100.00 74.63 4.70 3,726.53 3,633.53 -612.69 4,365.85 5.73 -612.69 7,180.95 75.57 0.00 3,747.35 3,654.35 -534.55 4,369.05 5.73 -534.55 Hold for 20.06' 7,200.00 75.57 0.00 3,752.10 3,659.10 -516.10 4,369.05 0.00 -516.10 7,200.81 75.57 0.00 3,752.30 3,659.30 -515.31 4,369.05 0.00 -515.31 WS_D 7,201.01 75.57 0.00 3,752.35 3,659.35 -515.12 4,369.05 0.00 -515.12 Adjust TF to 0°, for 692.83' 7,300.00 75.57 0.00 3,777.02 3,684.02 -419.26 4,369.05 0.00 419.26 7,388.62 75.57 0.00 3,799.10 3,706.10 -333.44 4,369.05 0.00 -333.44 WS_C 7,400.00 75.57 0.00 3,801.94 3,708.94 -322.41 4,369.05 0.00 -322.41 7,468.87 75.57 0.00 3,819.10 3,726.10 -255.71 4,369.05 0.00 -255.71 WsLa 7,500.00 75.57 0.00 3,826.86 3,733.86 -225.57 4,369.05 0.00 -225.57 7,600.00 75.57 0.00 3,851.78 3,758.78 -128.72 4,369.05 0.00 -128.72 7,607.72 75.57 0.00 3,853.70 3,760.70 -121.24 4,369.05 0.00 -121.24 W5 A4 7,677.14 75.57 0.00 3,871.00 3,778.00 -54.01 4,369.05 0.00 -54.01 WS A4 Objective ' 7,700.00 75.57 0.00 3,876.70 3,783.70 -31.88 4,369.05 0.00 -31.88 7,786.29 75.57 0.00 3,898.20 3,805.20 51.70 4,369.05 0.00 51.70 WS_A3 7,800.00 75.57 0.00 3,901.62 3,808.62 64.97 4,369.05 0.00 64.97 6/1912017 3.37.48PM Page 6 COMPASS 5000.1 Build 74 Database: EDM Production Local Co-ordinate Reference: Company: ConowPhillips (Alaska) Inc. -Kupl TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk I Pad North Reference: Well: Plan: 111-102 (Formerly 31) Survey Calculation Method Wellbore: Plan: 1H-102 Azimuth Design: 1H-102wp23 +N/ -S SLB Standard Proposal Report Well Plan: iH-102 (formerly 31) Plan: 54+39 @ 93.00usft (Doyon 142) Plan: 54+39 @ 93.00usft (Doyon 142) True Minimum Curvature Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W OLS Vert Section (usft) (1) V) (usft) usft (usft) (usft) 3,832.00 7,893.84 75.57 0.00 3,925.00 3,832.00 155.85 4,369.05 0.00 155.85 Start 3.51100' DLS, 21.38° TF, for 106.16' 7,900.00 75.77 0.08 3,926.52 3,833.52 161.82 4,369.06 3.50 161.82 7,976.46 78.26 1.08 3,943.70 3,850.70 236.31 4,369.81 3.50 236.31 WS_A3_ObjecOve 8,000.00 79.03 1.38 3,948.33 3,855.33 259.39 4,370.31 3.50 259.39 Hold for 177.39' 8,100.00 79.03 1.38 3,967.36 3,874.36 357.53 4,372.67 0.00 357.53 8,165.94 79.03 1.38 3,979.90 3,886.90 422.24 4,374.23 0.00 422.24 WS A2 8,177.39 79.03 1.38 3,982.08 3,889.08 433.48 4,374.50 0.00 433.48 Start 3.5°1100' DLS, -15.46° TF, for 147.15' 8,200.00 79.60 1.16 3,986.23 3,893.23 455.71 4,374.99 3.50 455.71 8,300.00 83.17 0.23 4,001.04 3,908.04 554.58 4,376.19 3.50 554.58 8,324.54 84.00 0.00 4,003.78 3,910.78 578.97 4,376.24 3.50 578.97 Hold for 20' - 7-6/8" x 9-78" 8,344.54 84.00 0.00 4,005.87 3,912.87 598.85 4,376.24 0.00 598.85 Start 3.1100' DLS, 4.02° TF, for 230.07' 8,400.00 85.66 0.12 4,010.87 3,917.87 654.09 4,376.29 3.00 654.09 8,500.00 88.65 0.33 4,015.83 3,922.83 753.95 4,376.68 3.00 753.95 8,574.61 90.89 0.48 4,016.13 3,923.13 828.55 4,377.21 3.00 828.55 Hold for 342.51' 8,600.00 90.89 0.48 4,015.74 3,922.74 853.94 4,377.42 0.00 853.94 8,700.00 90.89 0.48 4,014.19 3,921.19 953.93 4,378.26 0.00 953.93 8,800.00 90.89 0.48 4,012.65 3,919.65 1,053.91 4,379.11 0.00 1,053.91 8,900.00 90.89 0.48 4,011.10 3,918.10 1,153.90 4,379.95 0.00 1,153.90 8,917.11 90.69 0.48 4,010.84 3,917.84 1,171.01 4,380.09 0.00 1,171.01 Start 3°1100' DLS, -174.56° TF, for 36' 6,953.12 89.81 0.38 4,010.62 3,917.62 1,207.01 4,380.36 3.00 1,207.01 Hold for 1000' 9,000.00 89.81 0.38 4,010.78 3,917.78 1,253.89 4,380.67 0.00 1,253.89 9,100.00 89.81 0.38 4,011.11 3,918.11 1,353.89 4,381.34 0.00 1,353.89 9,200.00 89.81 0.38 4,011.44 3,918.44 1,453.89 4,382.00 0.00 1,453.89 9,300.00 89.81 0.38 4,011.77 3,918.77 1,553.88 4,382.66 0.00 1,553.88 9,400.00 89.81 0.38 4,012.10 3,919.10 1,653.88 4,383.33 0.00 1,653.88 9,500.00 89.81 0.38 4,012.43 3,919.43 1,753.88 4,383.99 0.00 1,753.88 9,600.00 89.81 0.38 4,012.77 3,919.77 1,853.87 4,384.65 0.00 1,853.87 9,700.00 89.81 0.38 4,013.10 3,920.10 1,953.87 4,385.32 0.00 1,953.87 9,800.00 89.81 0.38 4,013.43 3,920.43 2,053.87 4,365.98 0.00 2,053.87 9,900.00 89.81 0.38 4,013.76 3,920.76 2,153.87 4,386.64 0.00 2,153.87 9,953.12 89.81 0.38 4,013.94 3,920.94 2,206.98 4,386.99 0.00 2,206.98 Start 3.5°/100' DLS, -97.7W TF, for 415.53' 10,000.00 89.59 358.75 4,014.16 3,921.18 2,253.86 4,386.64 3.50 2,253.86 10,100.00 89.12 355.29 4,015.31 3,922.31 2,353.70 4,381.44 3.50 2,353.70 10,200.00 88.65 351.82 4,017.26 3,924.26 2,453.04 4,370.22 3.50 2,453.04 6119/2017 3:37.48PM Page 7 COMPASS 5000.1 Build 74 Database: EDM Production Local Co-ordinate Reference: Company: ConocoPhillips(Alaska) Inc.-Kup1 TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1H Pad North Reference: Well; Plan: 1 H-102 (formerly 31) Survey Calculation Method: Wellbore: Plan: 1H-102 Design: 1H-102wp23 Depth SLB Standard Proposal Report Well Plan: 1 H-102 (formerly 31) Plan: 54+39 @ 93.00usft (Doyon 142) Plan: 54+39 @ 93.00usft (Doyon 142) True Minimum Curvature Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W -DLS Vert Section (usft) (^) (I (usft) usft (usft) (usft) 3,927.02 10,300.00 88.19 348.35 4,020.02 3,927.02 2,551.49 4,353.00 3.50 2,551.49 10,368.65 87.87 345.96 4,022.38 3,929.38 2,618.38 4,337.75 3.50 2,618.38 Hold for 206.69' 10,400.00 87.87 345.96 4,023.55 3,930.55 2,648.77 4,330.15 0.00 2,648.77 10,500.00 87.87 345.96 4,027.26 3,934.26 2,745.72 4,305.91 0.00 2,745.72 10,574.24 87.87 345.96 4,030.01 3,937.01 2,817.69 4,287.91 0.00 2,817.69 Start 3.5°/100' DLS, 81.96° TF, for 424.69' 10,600.00 88.00 346.86 4,030.94 3,937.94 2,842.71 4,281.86 3.50 2,842.71 10,700.00 88.49 350.32 4,034.00 3,941.00 2,940.67 4,262.09 3.50 2,940.67 10,800.00 88.99 353.79 4,036.19 3,943.19 3,039.67 4,248.27 3.50 3,039.67 10,900.00 89.50 357.25 4,037.51 3,944.51 3,139.35 4,240.46 3.50 3,139.35 10,998.93 90.00 0.68 4,037.94 3,944.94 3,238.24 4,238.67 3.50 3,238.24 Start 2°1100' DLS, 0° TF, for 71.07' 11,000.00 90.02 0.68 4,037.94 3,944.94 3,239.31 4,238.69 2.00 3,239.31 11,070.00 91.42 0.68 4,037.06 3,944.06 3,309.30 4,239.51 2.00 3,309.30 Hold for 783.22' 11,100.00 91.42 0.68 4,036.31 3,943.31 3,339.29 4,239.87 0.00 3,339.29 11,200.00 91.42 0.66 4,033.83 3,940.83 3,439.25 4,241.05 0.00 3,439.25 11,300.00 91.42 0.68 4,031.35 3,938.35 3,539.21 4,242.23 0.00 3,539.21 11,400.00 91.42 0.68 4,028.87 3,935.87 3,639.18 4,243.41 0.00 3,639.18 11,500.00 91.42 0.68 4,026.39 3,933.39 3,739.14 4,244.59 0.00 3,739.14 11,600.00 91.42 0.68 4,023.91 3,930.91 3,839.10 4,245.77 0.00 3,839.10 11,700.00 91.42 0.68 4,021.43 3,928.43 3,939.06 4,246.95 0.00 3,939.06 11,800.00 91.42 0.68 4,018.95 3,925.95 4,039.03 4,248.14 0.00 4,039.03 11,853.22 91.42 0.68 4,017.63 3,924.63 4,092.23 4,248.76 0.00 4,092.23 Start 2°/100' DLS, -126.46° TF, for 110.57' 11,900.00 90.87 359.92 4,016.70 3,923.70 4,136.99 4,249.01 2.00 4,138.99 11,963.79 90.11 358.90 4,016.16 3,923.16 4,202.78 4,248.35 2.00 4,202.78 Hold for 561.7' 12,000.00 90.11 358.90 4,016.09 3,923.09 4,238.98 4,247.66 0.00 4,238.98 12,100.00 90.11 358.90 4,015.90 3,922.90 4,338.96 4,245.74 0.00 4,338.96 12,200.00 90.11 358.90 4,015.72 3,922.72 4,438.94 4,243.81 0.00 4,438.94 12,300.00 90.11 358.90 4,015.53 3,922.53 4,538.92 4,241.89 0.00 4,538.92 12,400.00 90.11 358.90 4,015.34 3,922.34 4,638.91 4,239.97 0.00 4,638.91 12,500.00 90.11 358.90 4,015.16 3,922.16 4,738.89 4,238.05 0.00 4,738.89 12,525.50 90.11 358.90 4,015.11 3,922.11 4,764.38 4,237.56 0.00 4,764.38 TD: 12626.6' MD, 4016.11' TVD 511912017 3;37:48PM Page 8 COMPASS 5000.1 Bodd 74 SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan: 1H-102 (formerly 31) Company: ConoccPhillips (Alaska) Inc. -Kupl TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Site: Kuparuk 1H Pad North Reference: True Well: Plan: 1H-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 111-102 - plan misses target center by 138.27usft at 10744.01 usft MD (4035.07 TVD, 2984.14 N, 4255.27 E) Design: 1 H-102wp23 1H -10201.T2 05octl5Ab 0.00 0.00 4,024.53 278.94 4,374.27 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E1 -W -Shape (') (I (usft) (osft) (usft) 1H-10201.T105Octi 5 BW 0.00 0.00 3,756.14 -515.12 4,369.05 - plan misses target center by 3.67usft at 7201.96usft MD (3752.59 TVD, -514.20 N, 4369.05 E) - Circle (radius 100.00) IH -102 07 T7 05Oct15 BW 0.00 0.00 4,037.94 3,425.18 4,394.93 - plan misses target center by 154.08usft at 11187.65usft MD (4034.14 TVD, 3426.90 N, 4240.90 E) - Circle (radius 100.00) 1 H-102 06.76 05Oct15 BW 0.00 0.00 4,039.36 3,003.15 4,392.16 - plan misses target center by 138.27usft at 10744.01 usft MD (4035.07 TVD, 2984.14 N, 4255.27 E) - Circle (radius 100.00) 1H -10201.T2 05octl5Ab 0.00 0.00 4,024.53 278.94 4,374.27 - plan misses target center by 71.15usft at 8033.78usft MD (3954.76 TVD, 292.54 N, 4371.10 E) - Point 1 H-102 06 T6 22Decl4 RM 0.00 0.00 4,038.00 3,425.16 4,394.93 - plan misses target center by 154.09usft at 11187.65usft MD (4034.14 TVD, 3426.90 N, 4240.90 E) - Circle (radius 100.00) 1 H-102 02.Pump Tangent 04Decl5AA 0.00 0.00 3,656.00 -815.84 4,326.62 - plan misses target center by 8.99usft at 6881.05usft MD (3664.57 TVD, -818.30 N, 4325.46 E) - Point 1H-10206.76090816 KU 0.00 0.00 4,039.36 2,716.45 4,392.96 - plan misses target center by 78.59usft at 10450.97usft MD (4025.44 TVD, 2698.19 N, 4317.79 E) - Circle (radius 100.00) iH-10203.T3050ctl 5 BW 0.00 0.00 4,003.78 578.96 4,376.24 - plan hits target center - Cimle (radius 100.00) 1H-10202 T2050ctl 5 BW 0.00 0.00 3,981.75 -221.10 4,370.98 - plan misses target center by 146.91 usft at 7542.93usft MD (3837.55 TVD, .183.99 N, 4369.05 E) -Circle (radius 100.00) 1H-10209.T922Dec14 RM 0.00 0.00 4,025.00 4,789.28 4,403.89 - plan misses target center by 168.48usft at 12525.50usft MD (4015.11 TVD, 4764.38 N, 4237.56 E) - Circle (radius 100.00) 1H-102 02.Pump tangent 05Dec15 AA 0.00 0.00 3,556.00 -887.73 4,302.60 - plan misses target center by 81.22usft at 6777.92usft MO (3633.17 TVD, -910.16 N, 4290.79 E) - Point 1H-10208.T8050ctl5 BW 0.00 0.00 4,027.63 3,711.20 4,396.81 - plan misses target center by 152.54usft at 11473.84usft MD (4027.04 TVD, 3712.99 N, 4244.28 E) - Circle (radius 100.00) 1 H-102 02.Base Pump Tangent 04Dec15 AA 0.00 0.00 3,256.00 -1,415.67 3,827.07 - plan misses target center by 148.41 usft at 6010.76usft MD (3392.60 TVD, -1394.33 N, 3773.13 E) - Point 1 H-102 04 T4 050ctl5 BW 0.00 0.00 4,010.62 1,207.01 4,380.36 - plan hits target center - Circle (radius 100.00) 1H-10205. T522Dec14 RM 0.00 0.00 4,039.00 3,003.15 4,392.16 - plan misses target center by 138.25usft at 10744.00usft MD (4035.07 TVD, 2984.13 N, 4255.28 E) -Circle (radius 100.00) 1H- 10210,T10050ctl 5 BW 0.00 0.00 4,024.53 4,789.28 4,403.89 - plan misses target center by 168.45uaft at 12525.50usft MD (4015.11 TVD, 4764.38 N, 4237.56 E) - Circle (radius 100.00) 1H-102 09. T9 090816 KU 0.00 0.00 4,015.11 4,764.38 4,237.56 61192017 3:37:48PM Page 9 COMPASS 5000.1 Build 74 SLB Standard Proposal Report Database: EDM Production Local Coordinate Reference: Well Plan: 1 H-102 (formerly 31) Company: ConomPhillips (Alaska) Inc. -Kup1 TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 54+39 Q 93.00usft (Doyon 142) Site: Kupamk 1H Pad North Reference: True Well: Plan: 1 H-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H-102 - plan misses target center by 32.26usft at 8524.90usft MD (4016.25 TVD, 778.85 N, 4376.83 E) - Point Design: 1H-102wp23 1H-10209.T9050c115 BW 0.00 0.00 4,015.11 4,403.25 4,401.35 - Circle (radius 100.00) 0.00 0.00 4,015.00 4,403.25 1H-10207.T722Dec14 RM 0.00 0.00 4,028.00 3,711.20 4,396.81 - plan misses target center by 152.54usft at 11473.83usft MD (4027.04 TVD, 3712.98 N, 4244.28 E) - Circle (radius 100.00) - Circle (radius 100.00) 20"x42" 1H-10204.T422Decl4 RM 0.00 0.00 4,016.00 2,695.12 4,390.14 - plan misses target center by 69.98usft at 10430.12usft MD (4024.66 TVD, 2677.97 N, 4322.85 E) - plan hits target center - Circle (radius 100.00) 4-1/2 IH -102 07.77 090816 KU 0.00 0.00 4,037.94 3,238.24 4,238.67 - plan hits target center 1H-10200. BasePumpTangent 20150515 BP - Circle (radius 100.00) 4,237.02 1H-10202.T203Mar14 BW 0.00 0.00 3,984.00 778.98 4,377.55 - plan misses target center by 32.26usft at 8524.90usft MD (4016.25 TVD, 778.85 N, 4376.83 E) - Point - Circle (radius 100.00) 1H-10209.T9050c115 BW 0.00 0.00 4,015.11 4,403.25 4,401.35 - plan misses target center by 156.83usft at 12161.29usft MD (4015.79 TVD, 4400.24 N, 4244.56 E) - plan hits target center - Circle (radius 100.00) Tesl1 0.00 0.00 3,256.00 -1,474.97 3,747.33 - plan misses target center by 134.65usft at 5923.13usft MD (3367.69 TVD, -1422.11 N, 3693.84 E) 1H-10205. T505Oct15 BW - Point 4,390.14 1 H-102 08. T8 22Decl4 RM 0.00 0.00 4,015.00 4,403.25 4,401.35 - plan misses target center by 156.83usft at 12161.29usft MD (4015.79 TVD, 4400.24 N, 4244.56 E) 9-7/8 - Circle (radius 100.00) 118.00 20"x42" IH -1020171061617 BP 0.00 0.00 3,752.35 -515.12 4,369.05 - plan hits target center 4-1/2'x6-3/4" 4-1/2 - Circle (radius 100.00) 1,794.10 1,700.37 1H-10200. BasePumpTangent 20150515 BP 0.00 0.00 3,554.47 -756.30 4,237.02 - plan misses target center by 154.25usft at 6875.43usft MD (3662.89 TVD, -823.41 N, 4323.82 E) - Point 1 H-102 08. T8 090816 KU 0.00 0.00 4,017.63 4,092.23 4,248.76 - plan hits target center - Circle (radius 100.00) 1H-10205. T505Oct15 BW 0.00 0.00 4,015.62 2,695.12 4,390.14 - plan misses target center by 70.03usft at 10430.10usft MD (4024.66 TVD, 2677.95 N, 4322.85 E) - Circle (radius 100.00) IH -10203. T322Dec14 RM 0.00 0.00 4,011.00 1,207.01 4,380.36 - plan misses target center by 0.38usft at 8953.12usft MD (4010.62 TVD, 1207.01 N, 4380.36 E) - Circle (radius 100.00) 1 H-102 02. 04 Dec 15 AA Test 0.00 0.00 3,556.00 -515.12 4,369.05 - plan misses target center by 190.06usft at 7150.47usft MD (3739.66 TVD, -564.04 N, 4368.60 E) - Point 1H-10201 T122Decl 4 RM 0.00 0.00 3,754.00 -221.10 4,370.98 - plan misses target center by 71.70usft at 7486.17usft MD (3823.41 TVD, -238.96 N, 4369.05 E) , - Circle (radius 100.00) 8,324.54 4,003.78 7-516'x 9-7/8" 7-5/8 9-7/8 118.00 118.00 20"x42" 20 42 12,525.50 4,015.11 4-1/2'x6-3/4" 4-1/2 6-3/4 1,794.10 1,700.37 10-3/4"x13-1/2' 10-3/4 13-1/2 6/1912017 3:37:48PM Page 10 COMPASS 5000.1 Build 74 SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan: 1H-102 (formerly 31) Company: ConowPhillips (Alaska) Inc. -Kupt TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Site: Kuparuk 1H Pad North Reference: True Well: Plan: 1 H-102 (formerly 31) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H-102 3,898.20 WS -A3 Design: 1H-102wp23 WS -A4 8,165.94 Formations Measured Vertical Vertical Dip Depth. Depth Depth SS Dip Direction Nam (usft) Name Lithology 6,706.09 3,610.70 Na 7,677.14 3,871.00 WS_A4_Objective 2,195.08 2,008.40 K-15 7,786.29 3,898.20 WS -A3 7,607.72 3,853.70 WS -A4 8,165.94 3,979.90 WS -A2 1,697.35 1,620.40 PFROST 7,468.87 3,819.10 WS_B 5,166.08 3,135.40 UG -C 7,200.81 3,752.30 WS_D 7,388.62 3,799.10 WS_C 5,975.61 3,382.60 UG_B 1,903.05 1,788.60 T-3 7,976.46 3,943.70 WS A3_Objective 6,319.91 3,486.80 UG_A Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +FJ -W (usft) (usm (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 136° TF, for 300.31' 600.31 600.00 -8.49 8.20 Start 2.5°/100' DLS, 0° TF, for 303.39' 903.70 900.00 -39.96 38.59 Start 3°/100' DLS, 0° TF, for 733.23' 1,636.94 1,570.37 -245.53 237.10 Hold for 120.74' 1,757.68 1,670.37 -294.20 284.11 Start 3°/100' DLS, -35° TF, for 36.42' 1,794.10 1,700.37 -308.92 298.59 Hold for 20' 1,814.10 1,716.76 -317.01 306.72 Start 3.07°/100'DLS,-34.28° TF, for 1327.34' 3,141.44 2,501.02 -845.99 1,197.86 Hold for 1710' 4,851.44 3,035.11 -1,458.98 2,702.21 Start 4.5'/100' DLS, -94.7° TF, for 841.19' 5,692.63 3,300.00 -1,489.21 3,483.98 Top Pump Tangent: Hold for 200' 5,892.63 3,358.88 -1,431.36 3,666.15 Base Pump Tangent: Start 5.72°/100' DLS, -68.57° TF, for 29.12' 5,921.75 3,367.30 -1,422.55 3,692.59 Hold for 74.04' 5,995.79 3,388.33 -1,399.16 3,759.62 Start 5.73°/100' DLS, -99.21° TF, for 1185.16' 7,180.95 3,747.35 -534.55 4,369.05 Hold for 20.06' 7,201.01 3,752.35 -515.12 4,369.05 Adjust TF to 0°, for 692.83' 7,893.84 3,925.00 155.85 4,369.05 Start 3.5°/100' DLS, 21.38° TF, for 106.16' 8,000.00 3,948.33 259.39 4,370.31 Hold for 177.39' 8,177.39 3,982.08 433.48 4,374.50 Start 3.5°/100' DLS, -15.46° TF, for 147.15' 8,324.54 4,003.78 578.96 4,376.24 Hold for 20' 8,344.54 4,005.87 598.85 4,376.24 Start 3°/100' DLS, 4.02° TF, for 230.07' 8,574.61 4,016.13 828.55 4,377.21 Hold for 342.51' 8,917.11 4,010.84 1,171.01 4,380.09 Start 3°/100'DLS, -174.55°TF, for 36' 8,953.12 4,010.62 1,207.01 4,380.36 Hold for 1000' 9,953.12 4,013.94 2,206.98 4,386.99 Start 3.5°/100' DLS, -97.76° TF, for 415.53' 10,368.65 4,022.38 2,618.36 4,337.75 Hold for 205.59' 10,574.24 4,030.01 2,817.69 4,287.91 Start 3.5°/100' DLS, 81.96° TF, for 424.69' 10,998.93 4,037.94 3,238.24 4,238.67 Start 2°/100'DLS, 0 -TF, for 71.07' 11,070.00 4,037.06 3,309.30 4,239.51 Hold for 783.22' 11,853.22 4,017.63 4,092.23 4,248.76 Start 2°/100' DLS, -126.46° TF, for 110.57' 11,963.79 4,016.16 4,202.78 4,248.35 Hold for 561.7' 12,525.50 4,015.11 4,764.38 4,237.56 TO: 12525.5' MD, 4015.11' TVD 6IM017 3:3748PM Page 11 COMPASS 5000.1 Build 74 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 1 H-102 (formerly 31) Plan: 1 H-102 50103xxxxx00 1 H-102wp23 Clearance Summary Anticollision Report 19 June, 2017 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference] Reference Doeg¢ Kupamk 1H Pad -PIan:1H-102(formerly 31) Plan: 1H-102-tH-10b,23 Well Coordinates: Datum Height: Plan: 54+39@ 93.00usfl (Doyon 142( Scan Range: 0.00 to 12,52550 usk. Measured Depth. Scan Radius is 1,"Bb5 tart. Clearance Factor cutoff is unlimited. Max Ellipse Separation is Unlimited Geodetic Scale FaclorNpplied Version: 5000.1 Build: 74 Scan Type: Scan Type: 25 Olt ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for Plan: 1H-102 (formerly 31) -1 H-102tai Tray. Cylinder North Proximity Scan on Current Sureey Data (North Rerennce) 7272 1,58739 Relerence Design: Kuparak 1H Pad -Plan: 1H-102(formerty fl) -Plan: 111-102-111-102wpg3 1,eci 1.655 Clearance Fader Scan Range: 0.00 to 12,525.50 usit. Measured Depth. 1,585.71 72.87 Scan Radius is 1,448.85 oat. Clearance Factor career is Undraind. Max Ellipse Separation is Unlimited 28.88 1,800.00 Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Sao Nam. Depth Distance Depth Separation Depth Faceor Minimum Separation Waming Comparison Well Name - Wellbore Name -Design just) (left) (unit) Juan) usn Kuparuk 1H Pad 1H45-1H-05-iH-05 1H -05 -1H -105 -IH -105 iH-09-1H-09-111-09 1H -09-1H-09-111-08 1 H-11 -1+11- i H -if 1 H -11 -1+11 -1H -if 1H-12-iH-12-iH-12 111-13.1 H-13 - iH-13 1H -13 -1H -13-1H-13 1H-14 -1H-14 -111-14 1H-14 -1H-14 -1+14 1H -15 -1H45 -1H-15 1H-15 -1H-15 -1H-15 iH-21 -111-21-111-21 1 H -21 -1H -21-1H-21 1 H401(UGNU)-111401-1H401 Plan: 1H-101 (Wholly 103, 29)- Plan: 1 H-101 -1 H-10 Plan: iH-101 (fmmedy 103, 29)- Plan: 1 H-101 -1 H-10 Plan:1 H-101 (formerly 103, 29) - Plan: 1 H-101 Li -1H Plan: t H-101 (fomledy 103,29) - Plan: 1H-101 L1 -1R Plan: t H-101 (formally 103, 29) - Plan: 1H-101 L2 -1H Plan: IH -101 narrowly 1W. 29) -Plan: 1H-101 L2-111 Plan: 1X-101 (fmmerfy 103, 29) -Plan: 1+101 L3 -111 Plan: 1H-101 (rmmady 103, 29) -Plan: 1+101 L3 -1H Plan: 1H-101 (formerly 103, 29)- Plan: 1+101 L4 -1H Plan: 1H-101 (mrmerty 103, 29)- Plan: I Wl01 L4-111 Plana H-103 (fomndy 104, 33) - Plan: 1 H-103-1 H-10 Plan:1 H-103 (fomredy 104, 33) - Plan: 1H-103-1 H-10 1,587.39 7272 1,58739 28,77 1,eci 1.655 Clearance Fader Pass - Major Risk 1,585.71 72.87 1,50511 28.88 1,800.00 1657 Clearance Fedor Pass - Major Risk 4,10329 356.18 4,103.29 226.90 3,750.00 2]55 Centre Distance Paas - Major Risk 4,272.45 359.99 4,272.45 223.47 3,925.00 2,637 Clearance Fedor Pass - Major Risk 2,171.85 486.41 2,17185 430.94 1,95600 6768 Centre Distance Pass - Major Risk 3,178.16 506.83 3,178.16 38686 2,95000 4.115 Clearance Factor Pass - Major Risk 2,040.83 13136 2,04083 78.42 2,000.00 2.481 Clearance Factor Pass -Major Risk 3,481.39 160.59 3,48139 74.44 3,175.00 1791 Centre Distance Pass - Mayr Risk 3,53085 171.87 3,53065 7109 3,250.00 1.707 Clearance Fedor Pau - Major Risk 1,551.51 WAR 1,551.51 303.08 1.500.00 7.825 Centre Distance Pass - Major Risk 1,593.73 348.76 1,593]3 302.42 1,550.00 7.525 Clearance Factor Pass - Major Risk 2,900.43 338.55 2,988.43 230.16 3,150.00 3.124 Centre Demons Pass - Major Risk 3.03096 339.01 3,030.96 229.11 3,20000 3005 Gloater. Factor Pass - Major Risk 2,195.94 377.32 2,195.94 316.84 2,175.00 6.239 Can" Distance Paas - Major Risk 2,214.89 377.65 2,214.89 31657 2,20000 6.183 Clearance Factor Pass - Major Risk 1.19163 81.22 1,19183 52.28 1,27500 2,806 Clearance Fedor Pass - Major Risk 200.00 6007 20000 128.48 20000 16708 Centre Distance Pass - Major Risk 275.00 6067 275.00 55.86 27500 12fi22 Clearance Fedor Pass - Major Risk 200.00 60.07 200.00 56.48 200.00 16.708 Centre Distance Pass - Major Risk 275.00 6667 275.00 55.86 27500 12,622 Clattered Factor Pass -Mapr Risk 200.00 60,07 200.00 5640 200.00 16.708 Centre Distance Pass - Major Risk 27500 60.67 275.00 55.86 27500 12.622 Coater. Factor Pass - Major Risk 20000 60.07 200.00 5648 20000 16.708 Centre Distance Pass - Major Risk 275.00 8067 275.00 55.66 27500 12.622 Clearance Factor Pass - Major Risk 2W.00 80.07 200.00 56.48 200.00 16.708 Centre Distance Pass - Major Risk 27500 60.87 27500 $5.66 275.00 12,622 Clearance Factor Pass - Major Risk 79283 59.59 79263 47.45 800.00 4.907 Centre Distance Pass - Major Risk 1,43103 71.12 1,431.03 42.73 1,450.0 2.505 Clearance Fedor Paas -Mapr Risk 19 Jura, 2017 - 15:39 Peg. 2077 COMPASS Conocol"hillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for Plan: 1 H-102 (formerly 31 ) -1 H-102wp23 792.63 59.59 Tlay. Cylinder North Proximity Son an Cunent survey Data (North Reterencin 4].1] 00000 Reference Dedisn: national, iH Pad -Plan: 1H-1021formetly3lj-PlanaH-102-111402svP23 Pass - Major Risk Plan: IH -103 riarmetly 104, 33) -Plan: 11+103L1-iH Scan Range: too to 12,525.50 and. Measured Depth. 71.12 1,431.03 Scan Radius is 1,448.55 unit. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited 1,450.00 2,618 Clearance Factor Measured Minimum aMenci Ellipse ablessurM Coolant. Summary Based on Site Name Depth Distance Depth Sooner.. Depth Factor Minimum Separation Wareing Comparison Well Name - Wellbore Name - Deal, just) Juan) haat (uaRl waft Plana H-103(lannMy 104, 33)- Plan: 11+1031.1. 111 792.63 59.59 792.63 4].1] 00000 4800 Centre Distance Pass - Major Risk Plan: IH -103 riarmetly 104, 33) -Plan: 11+103L1-iH 1,431.03 71.12 1,431.03 42.07 1,450.00 2,618 Clearance Factor Pass - Major Risk Plan: IH-103(knotedy 104, 33) -Plan: 1&10312-1H 792.63 59.59 792.63 4].1] BW.00 4,800 Centre Distance Pass - Major Risk Plan: 1H-103(frrady 104, 33) -Plan. 11+10312-1H 1,431.03 71.12 1,43103 42.87 1,450.00 2.518 Cloonan Factor Pass - Major Risk Plan: 1 H-103(fomwdy 104, 33) -Plan: 1H -10313-1H 792.63 59.59 79263 47.17 000.00 4.800 Centra Distance Pass - Major Risk Plan: 1 H-103(bmMtly 104, 33) -Plan: 1H -10313-1H 1,431.03 71.12 1,43103 42.87 1,450.00 2.518 Cherance Factor Pass - Major Risk Plan: 1H-1W(formedy 104, 33) -Plan: 1H -1031_4-1H 792.83 59.59 79283 4].1] 80000 4.800 Centre Dstence Pass - Major Risk Plan: 1 H-1 03(fo0nedy 104, 33) -Plan: 1 H-1 WL4-iH 1,43103 ]1.12 1,43103 42.88 1,45000 2.518 Clearance Factor Pass - Major Risk Pon: IH -1 04(formerly 101. 2]) -Plan: 1 H N -1H-10 397.44 119.39 39]44 11260 40000 1]5]2 Centre Distance Pass - Major Risk Plan: i Wl 04(brmerly 101, 27) -Plan: 1H -104-1H-10 494.87 120.21 494.8] 111.96 500.00 14574 Clearance Factor Pass - Major Risk Palo: 1H-f06(brinedy 100, WE, 10]) -Plan: 11-1-106- 300.00 2980 300.00 2446 300.00 5.578 Centre Distance Pass - Major Risk Plan: 111i(lonneM 108. WE, 107) - Man : 1H-106- 475.94 3054 475.94 2272 475.00 3.909 Clearance Factor Pass - Major Risk Plan: 1H-107(formerly 106, 28E, 112) - Plan : 1H-107- 498.62 27.54 49&62 19.46 500.00 3.410 Centre Distance Pass - Major Risk Plan: 1H-107(formedy 1 W. 28E, 112). Plan: 1H-10]- 548.14 27.82 540.14 18.97 550.00 3.142 Clearance Factor Pass - Major Risk Plan: IH-108(bmaly 111, 30D) -Plan: 1N -108-1H-1 300.00 9020 300.00 84.85 300.00 16.084 Centre Distance Pass - Major Risk PIan:1H-f08(fom y111,30D)-Plan:1H-108-1H-1 37366 90.76 373.68 84.22 375.00 13.889 Clearance Factor Pass - Major Risk Plan: 1 H-109 (joinery 110, WC) - Plan: IH -109-1H4 300.00 150.06 300.00 144.72 300.W 28 067 Centre Distance Pass - Major Risk Plana H-109(brmery 110, WC) - Plan: IH -109-11+1 372.81 150.61 37281 144.08 37500 23085 Clearance Factor Pass - Major Risk Plan: 1H-110(formerly 111, 113, 34D) - Pilot : 1H-110- 300.00 180.15 300.00 174.80 300.00 31719 Centre Distance Pass - Major Risk Plan: 1H-110(bnnerly 111, 113, 34D) -Plan: 1H-110- 372.38 18089 372.38 1]4.1] 375.00 2].]18 Clearance Factor Pass - Major Risk Plan, IH-111(lormeM 109, 32D) -Pon: 1 Hi 11-1H-1 3000 210.07 30.00 20473 300.00 39.318 Centre Distance Pass - Major Risk Plan : 1H-111(bri 109,32D) -Palo: 1 H -111-1H-1 3]1.9] 21061 3]1.9] 204.10 375.00 32.332 Clearance Factor Pass - Major Risk Plan. IH- 112(IDnnedy 107,28D, 1 W) -PIan: 1H-112- 300.00 240.19 30.00 23485 300.00 44.957 Centre Dislance Pass - Major Risk Plan. 1 H-112(brmedy 107,28D, 106)-PIan: 1H-112- 37155 240.73 371.55 234.22 375.00 36.985 Clearance Factoi Pass - Major Risk Plan: 1H-113(formaly 412, 34B) -Plan: 11-113-iH-1 3000 27019 300.00 264.85 30.00 50.573 Cookie Distance Pass - Major Risk Pan: 1H-113(knody 112, 34B) -Plan: 11+113-1H-1 371.15 2]0.]3 371.15 264.22 3]500 41.628 Clearance Factor Pam - Major Risk Pen: 111-114(bmledy 308, 116) -Plan: 1H -114-1H-1 299.90 300.14 299.90 294.80 3WA0 56193 Centre Distance Pala -Major Risk Plan: 1H -t 14(lomredy 30B, 116) -Plan: IH -114-1H-1 370.65 30087 37065 294.17 375.00 46.276 Clearance Factor Pas. - Major Risk Plan: 11+115(brmedy 115, 34A, 114) -Plan: 1H-115- 299.90 330.04 299.90 324.69 3W.D0 61.790 Centre Distance Pass - Major Risk Plan: 1H-115(bmredy 115, 34A, 114) -Plan: 1H-115- 41716 330.04 417.16 32372 425.00 46.406 Clearance Factor Pass - Major Risk 19 Jmm. 2017 - 1339 Page 3 a1 ] COMPASS Conocophillips (Alaska) Inc.-Kupi Kuparuk River Unit Anticollision Report for Plan: 1 H-102 (formerly 31 ) -1 H-102wp23 299.90 380.02 Tray. Cylinder North Proximity Scan on Current Survey Data (NMN Reference) 35408 300.00 Reference Design: Kuparuk lH Pact -PIan:111-102(formerly 31) -Plan: iH-102.1114ID2wy23 Pass - Major Risk Pin: H-116(formerly 114, 32B, 115)- Plan: 1H-116- Scan Range: 0.00 to 1;525.50 un. Measured Depth. 360.55 369.87 Scan Radius is 1,443.65 usft. CMarance Factor cutoff is Unlimited. Max Ellipse SepaMBon is Unlimited 375.00 55.574 Clearance Fahr Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on She Name Depth Diclance Depth separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellsore Name - Design (use) (usft) lush) josh) usft Plan. 1H-116 farraidy 114, 328,115) -Plan: iH-116- 299.90 380.02 29990 35408 300.00 67.405 Gene Distance Pass - Major Risk Pin: H-116(formerly 114, 32B, 115)- Plan: 1H-116- 369.87 360.55 369.87 354.06 375.00 55.574 Clearance Fahr Pass - Major Risk Pen: 1H-118(fonnedy 3M. 119) -Pin: 1H-118-IWl 30000 419.82 30000 414.48 30000 78.580 COMM Distance Pass - Major Risk Plan: 1H-118(fomedy 30A,119) -Pin: 1H-118-111-1 369.16 42034 369.18 413.88 375.00 60975 Clearance Factor Pass -Major Risk Plan: 1H-120(Al M, fomle0y, 11]) -Pin: 1H-120-iH 29990 480.10 299.90 47465 30000 88.083 Genus Distance Pass -Major Risk Plan: 1H -120(A1035, formerly ll]) -Plan: 1H -120-1H 36B.33 48062 368.33 474.04 375.00 73.064 Clearance Factor Pass - Major Risk Plan: 1H -121(A1034 formerly 119) -Plan: 1H -121-1H 300.00 51023 300.00 504.]] 300.00 93.585 Centre Distance Pass - Major Risk Plan: I H-1 21 (Al 034, formerly 119)- Plan: 1 H-121-iH 388.05 510.73 WAS 504.10 375.00 ]].931 Clearance Factor Pass - Miller Risk Plana H-122(Al 033. formerly A1040) -Plan: iH-122 300.00 54023 300.00 534.]8 300.00 99.089 Gene Distance Pass - Major Risk Plan, IH -122(A 1033, remedy A1040) -Plan: 11-122 36168 540.74 367.68 534.19 37500 82.544 Clearance Facer Pass - Major Risk Ron :11-123(A1032, fonnedy A1033) -Plan: 11-123 12,302.90 499.63 12,302.90 381.89 7,775.00 4.244 COMM Distance Pass - Major Risk Plan: 1H -123(A1032, fompdy A1033) -Plan: 111-123 12,352.18 503A6 12,352.18 378.25 7,850.00 4.021 Clasi nce Factor Pass - Major Risk Plan: 111-124(A1031, fomgrtyA1036)-Plan: 111-124 300.00 60024 30000 594]8 50000 110.095 Can" Dinner' Para - Major any Plan: 1H-124(Al 031. formerly Al 036) -Plan: 1H-124 344.64 600.55 34484 594.30 350.00 97.395 Clearance Factor Pass - Major Risk Survey 2001 nroani From To SurveylPlan Survey Tool (.art) (usft) 3900 700.00 1H-102wp23 Gy6GCSS 70000 1,700.00 1H -102.P23 MWD 70000 1,791 1H-102.,23 MWD+IFRAK-CAZ-SO 1,794.10 3,294.10 111-102.,23 MWD 1,794.10 8,324.54 1H-102WP23 MWD+IFR-AK-CAZ-SC 0,32054 9,824.54 iH-102"23 am 8,32454 12,525.50 1H-102.,23 MWD+IFR-AK-CAZ-SC 19 Jona, 201 - 15.39 Page 4 of ] COMPASS C000eoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for Plan: 1H-102 (formerly 31) -1 H-102wp23 Ellipse error teems are mneleled across survey tool fie -on points. Cakulated ellipses incorporate sudace mors. Sepumban is the actual distance between ellipsoids. Distance Between centres is the straight line drslanw betuveen wellbore centres. Clearance Factor= Distance Between Perles / (Distance Behreen Pmfles - Ellipse Separation). All station coonina4s were almlated using the Minimum Curvature melhod. 19 June, M7 - 1539 Page S of 1 COMPASS Ladder View 1 H- 1 0 2w p 2 3 The Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. z 4 V 2_ 3 II a «...� S 300 p 6 d 0) N150 U ji O C N ® Ew"IeM Ma9Mrc Disk -u; e 0 2000 4000 5000 9000 10000 12000 Displayed interval could be less than entire we1l:Measured Depth 39.00 To 12525.50 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.00 700.00 1H-102wp23 (Plan: 1H-102) GYD-GC-SS 118.00 118.00 20"x42" 700.00 1700.00 1H-102wp23 (Plan: 1H-102) MWD 1700.37 1794.10 10-3/4" x 13-1/2" 700.00 1794.10 1H-102wp23(Plan:1H-102) MWD+IFR-AK-CAZ-SC 4003.78 8324.54 7-5/8"x9-7/8" 1794.10 3294.10 1H-102wp23 (Plan -11-1-102) MWD 4015.11 12525.50 4-1/2"x 6-3/4" 1794.10 8324.54 1H-102wp23 (Plan.]1H-102) MWD+IFR-AK-CAZ-SC 8324.54 9824.54 1H-102wp23 (Plan:81H-102) MWD 8324.54 12525.50 1H-102wp23 (Plan;1H-102) MWD+IFR-AK-CAZ-SC s g ? r i a s s0 C O l0 d W ' I I d ! 30 __.... ...._ ............. __.... ............. ............. ............. i..... . U I I 0 N Epulvelam Magnnrt Olcunce - C U I o 0 500 1000 1500 2000 2500 3000 3500 Partial Measured Depth IH -10 39.00 To 3, Jun CASING TVD ND 118. Be 118.08 1780.37 1794.10 4083.78 8324.54 4015.11 12525.50 .1. T. ua.za m nz.z° m 2wp23 TFace Tari NO Inc Azi TVD 39.00 0.00 0.00 0.00 39.00 670 12525.50 300.00 0.00 0.00 0.00 300.00 670 - 860 600.31 4.50 136.00 1040 600.00 0.00 903.70 1636.94 12.09 34.09 .35.00 136.00 136.00 900.00 1570.37 1230 e 19 2017 0.00 1757.68 1794.10 34.09 34.99 3.07 136.00 134.91 1670.37 1700.37 1230 1410 DETAILS 0.00 1814.10 3141.44 34.99 71.80 134.91 112.17 -94.70 1716.76 2501.02 Name 28" x 42" 0.00 4851.44 71.80 112.17 5.72 3035.11 10-3/4" x 13-1/2' 1600 5692.63 0.00 72.88 72.38 3300.00 5.73 7-518" x 9-7/8' 5892.63 2050 72.88 0.00 72.38 3358.88 2500 4-112" x 6-3/4' 0.00 5921.75 73.50 70.76 3.50 3367.30 2950 5995.79 7180.95 7201.01 0.00 73.50 75.57 75.57 70.76 0.00 0.00 3388.33 3747.35 3752.35 3.50 wovx, Tw1 n, 3400 7893.84 0.00 75.57 0.00 3925.00 3.00 ^°'� ... 8000.00 3850 79.03 0.00 1.38 3948.33 8177.39 79.03 4300 1.38 0.00 3982.08 8324.54 3.50 84.00 0.00 4750 4003.78 0.00 3.50 0.00 81.96 8344.54 5200 84.00 2.00 0.00 4005.87 6120 7030 0.000.00 -12s.4s 8574.61 1H-102 -0 - IN lG2 -0 1H-111wp21 90.89 7950 0.48 4016.13 1H-110wp21 7950 - 8860 8917.11 90.89 30 0.48 4010.84 1H-105 9953.12 8860 89.81 0.38 4013.94 10368.65 87.87 345.96 tmoo 4022.38 10574.24 10700 87.87 -- 345.96 4030.01 10 1 H-401 10998.93 11970. 90.00 2 0.68 0.68 4037.94 - 11853.1 H -OS 2--- 04,036096 1H-12 --- -60/300 -- -60/300 1 H-104wp21 � -901 1 1 H-107wp21 11963.79 9 12525 -30/3 1 -150/210�w 225 -180/180 1H-101L2wp28 1 H-101 L4wp28 1 H-101wp28 1 H-101 L1 wp28 Dleg TFace Tari 300 490 0.00 0.00 0.00 0.00 490 670 1.50 136.00 2.50 0.00 670 - 860 3.000.00 860 1040 0.00 0.00 3.00 .35.00 1040 1230 0.00 0.00 3.07 -34.28 1230 1410 0.00 0.00 4.50 -94.70 1410 1600 0.00 0.00 5.72 -68.57 1600 2050 0.00 0.00 5.73 -99.21 2050 2500 0.00 0.00 1H-102 01.T1 061617 BP 2500 2950 0.00 0.00 3.50 21.38 2950 3400 0.00 0.00 3.50 -15.46 1H-102 03.T3 050ctl5 BW 3400 - 3850 0.00 0.00 3.00 4.02 3850 4300 0.00 0.00 - 4300 - 4750 0.00 0.08 3.50 -97.76 1 H-13 4750 5200 0.00 3.50 0.00 81.96 1H-102 07.T7 099815 KU 5200 6120 2.00 0.00 - 6120 7030 0.000.00 -12s.4s 1H-102 -0 - IN lG2 -0 1H-111wp21 7030 7950 1H-110wp21 7950 - 8860 30 ' 8860 9780 _6H-113L3wp2l 9780 tmoo --- '// wp21 10700 11610 -- .... 10 12526 150 INC -ONLY Kul us(gin) Easting 12500 Iwp20 1M-120wp21 AC Flipbook ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 1H-102 (formerly 31) 50103xxxxx00 Plan: 11-1-102 Plan: 1 H-102wp23 Error Ellipse Survey Report 19 June, 2017 Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kupamk River Unit Site: Kuparuk 1 H Pad Well: Plan: 1 H-102 (formerly 31) Wellbore: Plan: 1H-102 Design: 1H-102wp23 SLB Error Ellipse Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 1 H-102 (formerly 31) Plan: 54+39 Q 93.00usft (Doyon 142) Plan: 54+39 @ 93.00usft (Doyon 142) True Minimum Curvature 1.00 sigma EDM Production Survey Tool Program Date 8/19/2017 A41mu0 vertical From To VeN4al (usft) (usft) Survey (Wellbore) Tool Name Description 39.00 700.00 1 H-102wp23 (Plan: 1 H-102) GYD-GC-SS Gyrodata gyro single shots 700.00 1,700.00 1 H-1 02WP23 (Plan: 1 H-102) MWD MWD -Standard 700.00 1,794.10 1 H-1 02WP23 (Plan: 1 H-102) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 1,794.10 3,294.10 1H-102Wp23(Plan:1H-102) MWD MWD -Standard 1,794.10 8,324S4 1 H-1 02wp23 (Plan: i H-102) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 8,324.54 9,824.541H-102wp23(Plan: 11-1-102) MWD MWD - Standard 8,324.54 12,525.50 1H-102wp23(Plan: 1H-102) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC Position uncertainty and bias at survey station Meaaoe.N Indina . A41mu0 vertical Highude Labral VeN4al M,nau4e Se.Nnator Semi+ei. Depth Depth Ertor Bus Error aws Error BO. daias Error Ertor A iAh Tool (usft) (1) (1 lusnl (usft) ludo (usm (usft) lu4ft) luml look) luau) lum) (1) 1000 0.00 000 39.00 000 000 0.00 O.0 000 000 000 000 00 000 UNDEFINED 118.00 0.00 0.00 MOO 0.19 090 0.19 000 1.15 000 000 0.19 0.19 000 GYD-GC-SS(1, 1) 300.00 000 0.00 300.00 0.33 Dw 0.33 000 1.15 0.01 001 033 0.33 0.00 GYD-GCW(1, 1) 60,31 4.0 136.00 8000 0.59 0.00 0.60 ODD 1.15 0.04 004 060 060 4500 GYD-GO-5S n. 1) 903.70 1209 13600 900.00 0.72 -0.01 0.94 0.03 1.15 0.09 0.10 0.94 0.76 137.83 MVID(1. 21 1,63894 3409 136,00 187037 165 -0.08 5.33 064 1.17 0.30 0.71 5.33 174 136.80 MWD(1. 2) 1,697.35 3409 136.00 1,62040 178 -008 591 0.74 1.21 0.32 0.81 5.91 1.84 136]8 NIM (1. 2) 1.757.60 34.09 138.00 1.670.37 1.45 -0.08 2.94 000 1.14 033 0,38 295 1.55 140.45 MM+IFR-AK-CAZ-W(2,2) 1,794.10 34.99 134.91 1.70037 147 -0.09 3.07 003 1.13 035 0.37 308 1.59 140.23 MM (2.3) 1,814.10 34.99 13491 1,716]6 1A7 -0.09 3.14 0.07 1.13 0.35 0.39 3.15 1.60 13997 MWD(2,3) 1,90305 37.27 13297 1,78860 1.57 -0.14 4.28 044 1.15 0.42 063 129 1.69 136.68 MM (2,3) 2,195.08 4506 12564 2,008AO 1.84 -0.22 6.14 0.95 126 0.48 10B 6.19 189 13311 MWD(2.3) 3,141.44 7160 112.17 2,01.02 4.05 -0.88 19.07 4.80 3.31 072 4.85 19.35 3.08 122.11 MM (2.3) 4,851.44 7180 112.17 3,035.11 5.13 -OA9 1805 0.13 4.60 1.00 178 18.13 309 117.84 MWD+IFR-AK-CAZ-W(3,3) 5110.08 7122 97.25 3,13540 625 -051 18.M 0.57 5.17 1.07 1.99 19.84 3.28 116.84 MWD+IFR-AK-OAZ-W(3.3) 5,692.63 72.88 72.36 3.300.00 7.89 -087 1568 120 5.98 1.17 226 2183 367 113.27 MM+IFR-AK-CAZ-SC(3,3) 589263 7288 72.38 3.358 88 BIB -067 17,76 1.20 6.29 1.21 2.37 2266 3.81 111,45 MWO+IFR-AK-CAZ-W(3,3) 5,921]5 73.50 7076 3.367.30 821 -070 17.50 125 634 121 239 22.76 3.05 11122 MwD1IFR-AK-CAZ-SC(3.3) 5.975.61 73.50 7076 3.382.0 8.32 -070 17,87 1.25 646 1,23 243 2304 3.94 110.61 MM+IFR-AK-CAZ-SC(3,3) 5.995.79 73.50 70.76 3,35.33 832 -0.70 17.87 1.25 846 1.23 2A3 23.04 3.84 11061 IAWD+IFR-AK-CAZ-SC(3,3) 6,319.91 71.45 51A1 3,486.0 10.35 -O.M 1241 1.88 7.12 1.32 2.83 24.09 4.64 107.4 MWD -IFR -MX AZ -SC (3.3) 8,708.09 71.61 28.08 3,81070 11.12 -1.14 6.69 2.30 775 1.41 270 2446 591 104.88 MWD+IFR-AWCr1Z-&C(3,3) 7,180.95 7557 000 3,747.35 1044 -1.44 9.39 2.44 8.37 1,49 286 2440 7.53 10392 MWD+IFR-ML -SC (3,3) 7,20081 75.57 000 3,752.30 1045 -1A4 943 2.0 8.40 1 S 288 24.40 7.0 ION MwD+IFR-A1(-CAZSC(3,3) 7201.01 75.57 OOD 3,75235 1046 A.40 943 2.44 8.40 1.50 2.86 24,48 760 103.90 VY IFR-A4(-0AZ-SC(3,3) 7,M862 75.57 000 3,799.10 10.75 4'" 968 2.44 373 153 289 24.44 8.06 10345 MWD+IFR-AK-CAZ-SC(3, 3) 7,468.87 7557 0.00 3.819.10 10.09 -1611 9.85 2.86 8.89 1.55 290 24,42 833 10324 M IFR-AR-CAZ-SC(3, 3) 7.07,72 75.57 DOC 3,53]0 11.18 -1.114 10.28 2A4 922 159 2.94 24.38 8.95 102.87 MWD+IFR-A1(-CAZ-BC(3, 3) 7,677.14 75.57 000 3,871.00 11.18 -144 10.28 2A4 922 158 2.94 24.38 8.95 10207 MWD+IFR-AK-CAZ-SC(3,3) 7786.29 75.57 0.00 3.898.20 11.32 -1 A4 10.53 244 929 161 296 24.37 929 102.69 MW IFR-AK-CAZ-W(3,3) 7,893.84 75.57 000 3,925.0 11AB -144 10.79 2.44 9.54 1.63 2.9B 24.35 9.63 102.54 MVVD+IFR-AK-CAZ-S0(3,3) 7.976.46 7326 108 3.943.70 10.99 -1.49 1072 2.42 9.72 1.64 3.01 24.33 9.86 102.18 MM+IFR-AK-CAZ-W(3,3) 8100.00 7903 138 3,94833 10.88 -1.49 10.72 242 9.72 1.64 3.01 24.33 986 102.18 1AWD+IFR-AK-CAZ-5C(3,3) 5165.94 79.03 138 3.979.90 1127 -1.49 1124 2.42 1002 1.67 3.05 24.5 105 10114 MWD+IFR-AK-CAZ-SC(3,3) 8,17739 790 138 3.982.08 11.27 -1.49 1124 2.42 10.02 1.67 3.05 2430 1053 101.74 MWDHFR-AKLA -SC (3,3) 8.324.54 84.00 0.00 4,03]8 io.J AM 12.07 244 1027 1.88 3.09 2428 11.28 10163 MWD (3,4) 8,344.54 84.00 00 4,05.07 1078 -1.59 12.14 2.43 1028 169 3.08 24AO 1142 101.01 MM (3.4) 8.57461 Was 046 4,016.13 10.28 -171 13.0 2.02 10.32 1.69 2.82 2418 1286 98.83 MWD(3,4) 8,917.11 90.89 0.48 4,010.84 1OA6 -1.71 15.84 1.44 1050 169 2.52 24.09 15.02 88.16 MWD(3, 4) 8.953.12 88.81 0.38 4.010.62 10.53 -1.69 16.12 1.38 10.52 1.69 249 24.11 1808 87.02 NIM (3,4) 5/192017 3+53:52PM Page 2 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kupamk River Unit Site: Kuparuk 1H Pad Well: Plan: 11-1-102 (formerly 31) Wellbore: Plan: 11-1-102 Design: 1H-102wp23 SLB Error Ellipse Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: survey Calculation Method: Output errors are at Database: Well Plan: 1H-102 (formerly, 31) Plan: 54+39 @ 93,00usft (Doyon 142) Plan: 54+39 @ 93.00usft (Doyon 142) Tme Minimum Curvature 1.00 sigma EDM Production Position uncertainty and bias at survey station Meeapol Inclination A ptuth Vertical Hi9haide lateral Vertical Me9niluda semieni a, Semi+ninir Depth Depth Ermr Bias Error Bias Ertor Shea aBias ERar Error AaimNh Taol (usft) (9 19 (usft) lasft) I-10 Iu9ft) (use) hart) (use) (use) lusft) (waft) (1) 9,95312 9981 0.38 4,013.94 1069 -169 1593 244 10.68 1.69 3.44 24.11 15.92 9182 M1VDHFR-AK-CA-SC(4,41) 10,360.65 8787 34596 4,022.38 10.99 -1.65 17.19 2.82 10.91 1.70 3.54 24.02 16.83 87.00 VM+IFR-AKCAZ-W(4, 4) 10.57424 8787 34596 4,030.01 11.11 -165 1793 2.82 11.03 ll0 3.59 23.94 1760 80.16 MM.IFR-AKCAZ-W(4,4) 10.99893 90.00 0.60 4,03794 11.33 -170 1877 2.34 11.33 170 372 23.95 18.80 $0.0 1,WDaIFR-AK-CAZ-SC(4,4) 11,070.00 9142 0.60 4.03706 11.34 -176 19.08 2.34 11.39 170 3.74 23.98 1507 79.69 MM-IFR-AK-CAZ-SC(4,4) 11,053.22 91.42 0.68 4,017.63 1201 416 2271 2.M 12.06 1.69 399 24.97 21.46 55.03 MVJDHFR-AKCAZ-W(4.4) 11,96379 90.11 358.90 4.016.16 12.16 -170 2285 2.42 12.16 1.69 403 25.15 2152 52.63 MM-IFRAK-CAZSC(4,4) 12.525.50 90.11 358.90 4,015.11 12.72 -170 25.57 2.42 12.73 1.69 424 27.01 22.32 33.82 MWD-IFR-AK-CPZSC(4,4) 6/192017 3: 53 52P Page 3 COMPASS 5000. 1 Build 74 Pool Report I1H-102wp23 Surface Location [M CPAI Coordinate Converter 4 From: Datum: NAD83 Region: alaska '.. C Latitude/Longitude Decimal Degrees f-` UTM Zone:3 r South d-` State Plane Zone: q • Units: us ft Legal Description [NAD27 only) Starting Coordinates: ------- ----------- ---------I X: Ii689609.08 Y: 15980414.37 To - Datum: (NAD27 Region: alaska t` Latitude/Longitude Decimal Degrees�m v 7;1 i r UTM Zone: True i- South r State Plane Zone: q Units: us -ft f Legal Description (NAD27 only) - Ending Coordinates. --- - -- -- ---- X: F519177 Y: 1 5980662.56352101 T ............Transform........... _ Quit Help 1 H -102w 23 Surface Location N. CPAi Coordinate Converter o^" From: Datum: NAD83Region: lalaska r Latitude/Longitude jDacimalDegrees t- UTM Zone: "'" South r State Plane Zone: 4 Units: us -ft . r Starting Coordinates: X 1689609.08 Y: 15980414.37 To. Datum: NAD27 -1Region: alaska I' Latitude/Longitude Decimal Degrees • r UTM Zone: True r- South r State Plane Zone: q Units: us -ft . C Legal Description (NAD27 only) - Legal Township: 012 f -N 7, Range: 010 E . Meridian: U Section:33 FNL I 40.519229 IFEL 1764.65061 Transform Quit Help 1H -102w 23 Surface Casing M CPA! Coordinate Converter o i CI 5 ;... From: ` -- _ ...... .. To: Datum: NAD83 Rcgion: alaska . Datum: NAD27 Rcgion: alaska i Latitude/Longitude Decimal Degrees I r Latitude/Longitude IDecimal Degrees I r UTM Zone: " ` r South ( UTM Zone: True South I T? State Plane Zone: 4 - Units: us -ft I r State Plane Zone: q Units: us -ft r Legal Description (NAD27 only) r Legal Description (NAD27 only) Starting Coordinates --- X: 1689909.67 Ending Coordinates: --- --- --- X 549878.038975245 _ y 15980107.45 i I Y: 5980355.64507016 ..........._.._..._._.. . .............. ........ ..... .Transform Quit Help 1 H -102w 23 Surface Casing n. CPAiCoordinate Con, er:zr - o I From. _... _. To. Datum: Region: NAD83 9 alaska i Datum: NAD27 Region: alaska r Latitude/Longitude Decimal Degrees �Wv Latitude/Longitude Decimal Degrees { r UTM Zone: J"` South r UTM Zone: True i South "' State Plane Zone: q Units: us -ft i i` State Plane Zone: 4 �. Units: us -ft r Legal D,rrir!i,:n fFiA'r) 7 only) r Legal Description (NAD27 only) Starting Coordinates:- - Legal Description ------------- X: 1689909.67W�� Township: 012 N Range: 010 it �1 5980107.45 Meridian: �� Section: 33 ......._. --....._..--_Y.- - ,,.....__._._-._.._......._.. ... - - -. -------------------------- FNL 349.44826 FEL 466.76527 Transform Quit Help I1H-102wp23 Top of Production s M. GPA[Coardinate Converter From Datum: NAD83 Rcgion: alaska i" Latitude/Longitude Decimal Degrees j f— UTM Zone: d' South t-- State Plane Zone: q Units: us -ft t` Legal Description (NAD27 only) w_-- --- Starting Coordinates ------- ------ ---- X: 1693980.02 Y: 15980865,29 Datum: fNa15�7 Region: alaska - Latitude/Longitude Decimal Degrees r UTM Zone: True r South fi State Plane Zone: r4 Units: us -ft r Legal Description (NAD27 only) Ending Coordinates: X: f 553948.33248081 Y: f 5981113.39013898 .Transform Quit Help 11 H-102wp23 Top of Production M, CPA1 Coordinate Converter - From. _.. _.. _. Datum: INAD83 I Region: alaska C` Latitude/Longitude IDecimal Degrees W (UTM Zone: J— South {# r State Plane Zone: q Units: us -ft r- Starting Coordinates: -- ------r X: 11693980.02 Y: 159BOO65.29 _—�— To Datum: NAD27 -j Region: alaska Latitude/Longitude IDecimeDegrees UTM Zone: True C` South f— StatePlane Zone:r4 Units: us -ft f? Legal Description (NAD27 only) - Legal Township: 012 N . Range: olo E Meridian: U Section:27 FNL .j 4899.8536 FEL 11669.5289 Transform Quit Help 11H-102wp23 Intermediate Casing I M . CPAi Coordinate Cartverter From: Datum: NAD83 + Rcgion: Pala ks a — (` Latitude/Longitude Decimal Degrees I- UTM Zone: South State Plane Zone: q +- Units:us-ft + C' Legal Description (NAD27 only) Starting Coordinates. ------------------ --------- X: 11693981.00 __.m... y 15981022.00 -To. Datum: NAD27 . Rcgion: alaska Latitude/Longitude Decimal Degrees 1 f UTM Zone: True i South r State Plane Zone: 14 1 Units: usft I Legal Description (NAD27 only) Ending Coordinates: --------- ----- --� X: 553949.313576726_ t i Y: 5981270.0964028 Transform Quit Help 1H -102w 23 Intermediate Casing I C'1 CPA] Caordinate Corn arer j K" -From. Datum: jNXDB3� I Region: lalaska C Latitude/Longitude Decimal Degrees _.. r UTM Zone: f F South t: State Plane Zone: q , Units: us -ft . C' Legal Descrvirn NAD27 ord,(j r Starting Coordinates: ---- X: 11693981.00 ...� Y: 5981022.00 Datum: NAD27 .. Region: alaska . d" Latitude/Longitude Decimal Degrees t" UTM Zone: True F South f` State Plane Zone: Iq M Units: us -ft X- Legal Description (NAD27 only) Township: 012 [-N--,l Range: 010 1` J Meridian: U Section:27 FNL 4743.1451 FEL 1667.1637 Transform Quit Help 1 H-102wp23 TD n. CPA! Coordinate Converses I , �." 2 .-. From ---._..._.._ ___-- Datum: NAD 83 Region: alaska (' Latitude/Longitude IDecimalDegreas C` UTM Zone: f— (- South 0' State Plane Zone: q T Units: Fu s -f T . ?' Legal Description (NAD27 only) Starting Coordinates: --------- ------ X: 11693814.85 _ Y- 15985206.01 To: Datum: FNA 277 _�-j Region: alaska . i" Latitude/Longitude Decimal Degrees f- UTM Zone: True r- South C•` State Plane Zone: 14 Units: us -ft ' Legal Description (NAD27 only) ------------- Ending -- Ending Coordinates ----- ----------------7 X 553783195512971 Y: 5985454.01034606 I .................TransForm.................) Quit Help 1 H -102w 23 TD N . CPAS Coordinate Converter From. Datum: INAD83 Region: alaska I- Latitude/Longitude IDecimal Degrees t` UTM Zane: )"" South tt� r- State Plane Zone:q Units: f- t.r,gai iii....;. i- Starting Coordinates: ---- X: 11693814.85 Y: 15985206.01 --To. _... _..... -. _..._ Datum: .NAD27 Region:alaska f " Latitude/Longitude Decimal Degrees !" UTM Zone: True F South State Plane Zone: 4 Units: us -ft f: Legal Description (NAD27 only) .... 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W5Ct3 n VV��/-/s V tive �Obje WS A3_ bjective ' 3800 .r .: S_ Ws - 00f O , c 00 OO W °' j 4000 m 7-518" 9-7/8 o 4-1/2"$6-3/4" N F- 0 o n 0 4200- 2004400-800 4400- -8000 800 1600 2400 3200 4000 4800 5600 Vertical Section at 0.00° Tollerable Collision Risk Worksheet As -built 1 12/05/0q MRT I CC I IRev. Per K05014ACS 12 102/01 1 JAH I LGM I Rev. Per K170005ACS 29 2�, 1 26 29 2 2� N I G - - A JR KC32 3-1 .�4 35 36 + TI AM-, 1 OF CIV 2 1 3 0120 AIA ................ C ASP GRID NORTH 011912 CpF1 10 1 0118 11 0117 12 0116 0115 0114 IE • 0113 LEGEND *112 IF 0 AS -BUILT CONDUCTOR 0111 2a 19 2j 21 2 2, 1 silo VICINITY MAP 0 EXISTING CONDUCTOR 0109 SCALE: 1" = 2 MILES 0104 0108 0103 28 2T07 7 .,3 34 0102 0106 0101 NOTES 1. BASIS OF LOCATION AND ELEV. IS DS1H MONUMENTATION PER LOUNSBURY & ASSOC. DS1 H 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES ARE NAD 27. 3. ELEVATIONS ARE B.P.M.S.L. 9UGNU 01 4, ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTIONS 28 AND 33, :14 5 TOWNSHIP 12 NORTH, RANGE 10 EAST, o20 o12 UMIAT MERIDIAN, ALASKA. 019 *22 ell 5. DATES OF SURVEY: 12-26-16 THRU *17 010 1-31-17 FIELD BOOKS 1_16-35, 1_16-40, 06 L17-02 & 1_17-03. 916 921 e15 *13 6. ALL DISTANCES SHOWN ARE GROUND. 01 09 *2 07 03 *18 GRAPHIC SCALE 0 100 200 400 08 04 1 inch = 200 ft. SEE SHEET 2 & 3 FOR COORDINATE TABLE LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS P"NNERS AREA: 1H MODULE: XXXX UNIT: DI ConocoPhillips DSlH WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CADD FILE NO. DRAWING NO. PART: REV. LK6108d31 2/05/05 1 CEA—D1HX-6108D31 1 1 OF 3 1 1 1 102/01/171 JAH I LGM I (Create Per K170005ACS I I I CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 28, T. 12 N.. R. 10 E.. UMIAT MERIDIAN Well No. NAD 27 ASP Coordinates NAD 27 Geo ra hic Coordinates Section Offset. Elev. Y X Lot. Long. F.S.1- F.E.L. O.G. I PAD *103 5,980,722.55' 549,573.20' N 70' 21' 29.220" W 149' 35' 50.536" 19' 768' 48.0' 54.1' *104 5,980,782.43' 549,568.74' N 70' 21' 29.809" W 149' 35' 50.655" 79' 772' 48.0' 54.1' *108 5,980,752.52' 549,570.98' N 70' 21' 29.515" W 149' 35' 50.595" 49' 770' 48.0' 54.0' *109 5,980,812.20' 549,566.50' N 70' 21' 30.102" W 149' 35' 50.714" 109' 774' 48.0' 54.0' *110 5,980,842.21' 549,564.40' N 70' 21' 30.398" W 149' 35' 50.770" 139' 776' 48.0' 54.0' *111 5,980,872.05' 549,562.21' N 70' 21' 30.691" W 149' 35' 50.828' 169' 778' • 48.0' 54.1' *112 5,980,902.08' 549,559.94' N 70' 21' 30.987' W 149' 35' 50.889" 199' 780' 48.0' 54.0' *113 5,980,932.00' 549,557.76' N 70' 21' 31.281" W 149' 35' 50.947" 229' 782' 48.0' 54.0' *114 5,980,961.86' 549,555.50' N 70* 21' 31.575" W 149' 35' 51.006" 259' 784' 48.0' 54.1' *115 5,980,991.68' 549,553.43' N 70' 21' 31.868" W 149' 35' 51.062" 289' 786' 48.0' 54.1' *116 5,981,021.61' 549,551.58' N 70' 21' 32.163" W 149' 35' 51.110" 319' 787' 48.0' 54.1' *117 5,981,051.73' 549,548.80' N 70' 21' 32.459" W 149' 35' 51.185" 349' 790' 48.0' 54.0' *118 5,981,081.22' 549,546.95' N 70' 21' 32.750" W 149' 35' 51.234" 378' 791' 48.0' 54.0' *119 5,981,111.42' 549,544.52' N 70' 21' 33.047" W 149' 35' 51.299" 408' 794' 48.0' 54.2' *120 5,981,141.33' 549,542.48' N 70' 21' 33.341" W 149' 35' 51.353" 438' 795 48.0' 54.1' * CONDUCTOR ASBUILT THIS SURVEY ' 49th '. AH F. CORNELLp LS -12663 ".•i i .......... �P?��•� SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION ARE CORRECT AS OF JANUARY 31, 2017. LOUNSBURY k ASSOCIATES, INC. RIEYORS ENGINEERS PLANNERS AREA: 1H MODULE: XXXX UNIT: D1 ConocoPhilli S DS1H WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CADD FILE NO. DRAWNG NO. PART: REV: LK6108d31 12/27/16 1 CEA-D1HX-6108D31 1 3 OF 3 1 1 Haagen Dazs Necessary Plan Request (NPR) Initiated by: Kelsey Hallford Well Name'. 11-1-102 As4oui0 available? Yes Rig: Met Inclination Profile: Hontiomal New Hole from: Surface 3393.78 Tablas 351].]3 1ybl6S 3859.35 Tables 3]08.0] Tablss 3]28.15 rvoss ITop of Pool I Production Interval: N Sand 3618.00 Tablfifi Bottom of Pool / ProtluN0. Mterval. Data dby: : 0513111] Contact Information: W7201M Nee0&1111] um, for Even[ Permit PeCK Placeholder Well Name: Bottom Hole Location Name Last Plan Number (poor to this change request): wp 21 As-bui0 attached? Yes sbu sunacaLaalion: 102 YM: Hamas %/E: wan.w Z'. sa.00 NAD: 27 Doyon 142 Air Gap: Distance from Kelly Bushing to PadlGround Pilot Hole?: No Laterals?: Penta Lat CI S r Pump Tangent: Yes Limit Doglegs t0: 0.0 °/100' Limit INC to: Inclination ° Purl Length 200 ft Pump Tangent Depth Selection Cohere Base of regent no shallower than 400' wo show top or n S.uE M -Motor Vex 'ogle_ 6 o I Limit Steerings, this Hole Section?: No I� 7" x 97/8 Number of Hole Sections: 3 Strings Incuramos' BHA C Conductai x Hole memo Da Mn.Vpe M -Motor Max Dogleg: ao HorimrOal By: Limit Steering in this Hole Sectil Yes S Top of Limited Steering: Hao rvuss sudeca mmm Hnramaname limits: Dogleg: 3.0 '/lMP INC: LImhINCm° u r Steering tonin rvbleS Base a permafrost F a f0 L4 x 19111 anon NDB6 M -Motor Vex 'ogle_ 6 o I Limit Steerings, this Hole Section?: No 4112 x 6314 Approved by: Kelsey Hal"& Date: W31117 Contact Information. 90726515]] Geology I Reservoir Contacts: Ryan Phelps Drilling 1 Completion Contacts' Kelsey Hallford / Adam Well Planning Contacts Brij Pont Klein I Sammi Pedant I� 7" x 97/8 n0/rvo Degn TyPe Incuramos' BHA Max Dogleg. Doelao HorimrOal By: above Dam` The 90 ° Lineup with Toe at Heel? NolYea mmm Hnramaname 90' 4112 x 6314 Approved by: Kelsey Hal"& Date: W31117 Contact Information. 90726515]] Geology I Reservoir Contacts: Ryan Phelps Drilling 1 Completion Contacts' Kelsey Hallford / Adam Well Planning Contacts Brij Pont Klein I Sammi Pedant Appendix ■ Tier 1: Standard Section • Intervals without issues noted for Tier 2 or 3 ■ Tier 2: Challenging Orientation • Drilling within 30° of horizontal inclination AND drilling within 30°of magnetic East/West azimuth in extreme northern or southern locations ■ Tier 3: Critical Steering • Driller's Target of 50' Radius or Less • Lease line constraint • Small Geologic Target ■ Failure of Major Risk Rule (Close Approach) • Defined during directional planning, based on the positional uncertainty • Theoretical intersection of the path of the well being planned with an offset well • If HSE risks are eliminated, the Tolerable Collision Risk assessment can be implemented ■ Tier 4: Single section containing both Tier 2 and Tier 3 challenges ■ Tier 1: • Directional interval across which no special mitigations are needed ■ Tier 2: • Increase non-magnetic insulation of MWD tool in the BHA • Take rotational check shots and/or increase survey frequency at the start of a BHA run • Alter well directional plan, if feasible • Consider gyro surveys where feasible ■ Tier 3: • Increase survey frequency across critical interval • Increase correction frequency across critical interval • Take rotational check shots and/or increase survey frequency if the critical interval is at the start of a BHA run • Define escalation based on deviation from plan • Minor Risked close approach intervals with a high financial or scope risk should strongly consider the use of relevant mitigations ■ Tier 4: Consider all Tier 2 & 3 mitigations IH -102 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 Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out Washouts / Hole Sloughing Low Cool mud temperatures, minimize circulating times when possible Anti -Collision Moderate Follow real time surveys very closely, shut in nearby wells that we have collision concerns with, gyro survey to ensure survey accurac . 9-7/8" Open Hole / 7-5/8" Casing Interval Hazard Risk Level Mitigation Strate 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. 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 Intervals Hazard Risk Level Mitigation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud weight. Stuck Pipe Low Good hole cleaning, PWD tools monitoring and analysis, decreased mud weight if possible if pipe does get stuck. Lost Circulation Moderate Reduced pump rates, mud rheology, LCM program, additional fluid stored on location during completion run. Differential Sticking Moderate Follow mud program, keep pipe moving when able. Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out or backreamin . Fault Crossings and Concretions Moderate Use developed best practices for concretion drilling. Anti -Collision Moderate Follow real time surveys very closely, shut in nearby wells that we have collision concerns with. IH -102 only has AC challenges between its laterals, we will be utilizing periscope to maintain eolo ical certain to stay within zone. Casing wear Moderate Maintain low dog legs in the surface interval and utilize super sliders for drilling, milling, and liner running operations to minimize casing wear. Consider logging casing thickness to calibrate casing we model. Getting Liner to Bottom Moderate Properly clean hole on the trip out with the BHA, perform clean out run if necessary, utilize super sliders for weight transfer, monitor torque and drag. Whipstock Retrieval Moderate A dedicated clean out run prior to attempting to pull whipstock can be used to reduce the risk of fishing operations. 05 Attachment- 1H-102 Drilling Hazards Summarydoc 6/20/2017 9:22:47 AM IH -102 Cement Calculations Surface Cement: Surface to 1,794' MD Cement from 8,325' MD to 5,900' MD Capacities: Lead 1.91 ft3 sx of 11.0 / ppg DeepCRETE Capacities XS% for open hole and annulus: Tail 2.28 ft3/ sx of 12.0 DeepCRETE OH 0.177045 Permafrost (PF) depth 1620 ft 13-1/2" x 30-3/4" 0.064783 XS% Lead 250% 20"x 10-3/4" 0.220213 XS% Tail 50% 10-3/4" 0.096175 Tail Cement 1 3.67 bbls Total Length 500 ft bbls 500 x 0.06478288 x 1.5 48.6 Shoe Track 80 ft 80 x 0.09617496 x 1 7.7 Open Hole 10 x 0.17704488 x 1.5 2.7 Total 59 bbl 331 ft3 145 sx Lead Top Tail Cement to Conductor 1294 ft 1294 x 0.06478288 x 3.5 293.4 bbl Conductor Length 80 ft 80 x 0.22021323 17.6 bbl Total: 311 bbl 1746 ft3 914 Sx Intermediate Cement: Slurry: Cement from 8,325' MD to 5,900' MD Capacities: 15.8ppg Class G yielding 1.16f03/sk 9-7/8" x 7-5/8" 0.03825 XS% for open hole and annulus: 40% 9-7/8" OH 0.094731 7-5/8" ST 0.045916 Annulus Cement 2425 x 0.03825044 x 1.4 129.86 bbls Rathole Cement 2 x 0.09473055 x 1.4 0.27 bbls Shoe Track 80 x 0.0459157 x 1 3.67 bbls Total 134 bbls 751 h3 Loepp, Victoria T (DOA) From: Hallford, Kelsey <Kelsey.Hallford@conocophiIli ps.com> Sent: Monday, July 17, 2017 10:35 AM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL] KRU 1H-102(PTD 217-097) Diverter vent line outlet Attachments: Chemical Injection and Piperack Area Classification.pdf Victoria, Attached you will find the area classification drawings. The electrical equipment within the clouds are designed not to be ignition sources. Specifically page 3 will have the same overhead view for comparison along with notes (#5 in upper right hand corner). Regards, Kelsey From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday, July 17, 2017 10:30 AM To: Hallford, Kelsey <Kelsey.Hallford@conocophillips.com> Subject: RE: [EXTERNAL] KRU 1H-102(PTD 217-097) Diverter vent line outlet Kelsey, The facility notes are unreadable. Please provide a drawing blowup of the diverter vent line outlet and the 75' radius area. It appears that the pumps may be within the radius and are an ignition source. See 20 AAC 25.035(c)(2)(C)(i). Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeporrDalaska. gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission IAOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loeoo@alosko.gov From: Hallford, Kelsey [mailto:Kelsey.Hallford@conocophillips.com] Sent: Tuesday, July 11, 2017 3:40 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL] KRU IH-102(PTD 217-097) Diverter vent line outlet Victoria, The facility noted as (6) are the tanks for chemical injection. (5) is the housing for the chemical injection pumps. Kelsey Hallford From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.aov] Sent: Thursday, July 06, 2017 11:09 AM To: Hallford, Kelsey<Kelsey.Hallford@conocophillips.com> Subject: [EXTERNAL] KRU 1H-102(PTD 217-097) Diverter vent line outlet Kelsey, On the diverter layout drawing, what is the facility within the 75' radius of the vent line outlet? Pumps or? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 V ictoria. Loeppoa laska.c ov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)7931247 or Victoria. Loeppdolaska aov Well: KRU 1 H-102 <== Data Input Name: CPAI <_=D—ata Input Mud Weight (ppg) 9.50 <_= Data Input Weak point or LOT - Measured depth (ft) t 794' <== Data Input Weak point or LOT True vertical depth (ft) 1,700' <== Data Input Weak point or LOT - Hole angle (deg) I 34.0° <_= Data Input Weak point or LOT - Hole size (in) 9.875" <== Data Input Weak point pressure or LOT - EMW (ppg) 12.50 <== Data Input Zone of interest - Measured depth (ft) 8,325' <== Data Input Zone of interest - True vertical depth (ft) 4,004' <== Data Input Zone of interest - Hole angle (deg) 84.0° <== Data Input Zone of interest - Hole size (in) 6.750" <== Data Input Zone of interest - Pore pressure EMW (ppg) 8.40 <== Data Input Gas gradient (psi/ft) 0.10 <_= Data Input Bottom hole assembly OD (in) 8.0" <== Data Input Bottom hole assembly length (ft) 151' <== Data Input Drill pipe OD (in) 5.000" <== Data Input BHA annular vol. @ zone of interest (bbl/ft) -0.0179 DP annular vol. @ zone of interest (bbl/ft) 0.0200 DP annular vol. @ weak polnt bbllft 0.0704 Additional safety margin (psi) 0.00 <_= Data Input Weak point pressure (psi): PIO 1,105 psi Weak point pressure - Safety margin: Pmax 1,105 psi Pmax EMW 12.50 pp Max anticipated formation pressure (psi): Pf 1,749 psi Weak Pt to Zone of Interest distance (TVD ft): OH (ND) 2,304 Want w r„ n.ne of IM.Iaef dia+...,-a nun ai. nw Imn t. A FZ1' ax ep erc I ax xxr 5' R MOUND TANK VENT (TTN) 10' DISTANCE FROM TANKS (TMP) /I C10 R MOUND 1 TRUCK FILL 1 V R AROUND TRUCK FILL STATION 10' R AROUND TAN( VENT (TYP) A WEST ELEVATION EED—D1H0-3013 00 NEW LOOKING EAST 5' R AROUND TAN( VENT (TYP) 5' R AROUND DOOR OPENINGS (TYP) S' R AROUND \ VENT MOOD `J (TYP) I 5 R AROUND DOOR OPE14HOS (TYP) 5' R AROUND VENT HOOD (TYP) 10' R AROUND TANK VENT 5' R AROUND TRUCK FILL STATION EED-Dm0-.50T'_' a9, EAST ELEVATION VIEW LOOKING WEST YW 10' DISTANCE FROM TANKS (TYP) 10 R AROUND TRUCK FILL S .a o .en wn J R MW 6 TRUCK FILL STATION 6/ 1 SOUTH ELEVATION EEo-131Me-3613 VIEW LCDIcmc NORTH /-o-,\ NORTH ELEVATION EED-D1H0-5915 06 VIEW LOOKING SOUTH TRUCK FILL STATION N01 w 1. AREA CLASSIFICATION DESIGN AND LAYOUT IS BASED ON API RP S00, SECOND EDITION. NOVEMBER 1997, REAFFIRMED NOVEMBER 2002 AND 2811 NEC ARTICLE 560.5 (8) (1) AND (2). 2. ALL ELECTRICAL EQUIPMENT SHALL HAVE A MAXIMUM TEMPERATURE RATING OF T3. (200' C) 3. INTERIOR OF MODULE IS CUSS 1, DIVISION 2. GROUP D. 4. MODULE SOFFIT AREA IS UNCLASSIFIED, PER CPA[ SPECIFICATION SPC—EE—NS-00201. SECTION 1.16.1. WITH EXCEPTION OF LEAK DETECTION WELL. REFERENCE —3F13/AREA CL SS PLAN DRAWING 5. CLASS 1, DIVISION 2 AREA EXTENDS 10' OUT FROM EACH TANK TO GRADE. w CONSTRUCTION NOTE A. THIS DRAWING SHOWS WORK SCOPE FOR MULTIPLE WORK PACKAGES ANO IS BEING ISSUED PER 2004026410E. ISSUED FOR JUN 19 2015 CONSTRUU i ION IUm ENERGY It COLSTRUCIIDY. Inc AREA: 1H MODULE: IH10 UNIT: D1 DS1H NEWS AREA CLASSIFICATION ELEVATIONS CHEMICAL INJECTION m 0 ®— CUSS 1. DIVISION 1. GROUP D 00 eo ®—CUSS 1, DIVISION 2. GROUP D 1 O 0 K I I 1 — NW CLASSIFIED C> N CONSTRUCTION NOTE A. THIS DRAWING SHOWS WORK SCOPE FOR MULTIPLE WORK PACKAGES ANO IS BEING ISSUED PER 2004026410E. ISSUED FOR JUN 19 2015 CONSTRUU i ION IUm ENERGY It COLSTRUCIIDY. Inc AREA: 1H MODULE: IH10 UNIT: D1 DS1H NEWS AREA CLASSIFICATION ELEVATIONS CHEMICAL INJECTION m TRANSMITTAL LETTER CHECKLIST WELL NAME: LA(, 14- /O 2 PTD: —an -(327 Development _Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: I Q t - POOL: �4llu%ZlW,T Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter Revised 5/2013 IONSEddaaand TEXT FOR APPROVAL LETTER ATERAL permit is for a new wellbore segment of existing well Permit wo digitsAPI inmber ared SO- No. 50- _- _ _. Production continue to be reported as a function of the original API number stated 60-69) . ordance with 20 AAC 25.005(f), all records, data and logs acquired for the Hole 7Dry hole must be clearly differentiated in both well name PH) and API number (50-ecords, data and logs acquired for well. ermit is approved subject to full compliance with 20 AAC 25.055. Approval duce / inject is contin ent u on issuance of a conservation order a rovinxceptiong P Pp g cing exception. (C) Operator assumes the liability of any t to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than Sample 30' sample intervals from below the permafrost orfrom where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: Non- Production or production testing of coal bed methane is not allowed for name of Conventional well until after (Comoanv Name) has designed and implemented a water well Well testing program to provide baseline data on water quality and quantity. (Comoanv Name) must contact the Commission to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) / in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 5/2013 WELL PERMIT PTD#:2170970 Appr Date PKB 6/28/2017 Engineering Appr Date VTL 7/6/2017 Geology Appr Date PKB 6/28/2017 SAK OIL -490150 Well Name: KUPARUKRIV UNIT 1N_192._ 17 Nonconven, gas conforms to AS31.05.030(j.l..A),Q.2.A-D) 1 Permit fee attached 2 Lease number appropriate 3 Unique well. name and number _ 4 Well located in. a defined pool 5 Well located proper distance from drilling unit boundary _ 6 Well located proper distance from other wells. 7 Sufficient acreage. available in drilling unit 8 If deviated, is wellbore plat. included _ 9 Operator only affected party 10 Operator has. appropriate bond in force 11 Permit can be issued without conservation order 12 Permit. can be issued without administrative approval 13 Can permit be approved before 15 -day wait 14 Well located within area and strata authorized by Injection Order # (put 10# in. comments) (For 15 All wells within 1/4 mile area of review identified (For service well only) 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) 18 Conductor string provided 19 Surface casing. protects all. known USDWs 20 CMT. vol. adequate to circulate on conductor & surf esg 21 CMT vol adequate to tie-in long string to surf csg. 22 CMT will cover all known productive horizons 23 Casing designs adequate for C, T, B & permafrost 24 Adequate tankage or reserve pit 25 If a re -drill, has a 10-403 for abandonment been approved 26 Adequate wellbore separation proposed 27 Ifdiverter required, does it meet regulations 28 Drilling Fluid program schematic & equip list adequate 29 BOPEs, do they meet regulation 30 BOPE press rating appropriate; test to (put psig in comments) 31 Choke manifold complies w/API RP -53 (May 84) 32 Work will occur without operation shutdown 33 Is presence of H2S gas probable 34 Mechanical condition of wells within AOR verified (For service well only) 35 Permit can be issued w/o hydrogen sulfide measures 36 Data presented on potential overpressure zones 37 Seismic analysis of shallow gas. zones 38 Seabed condition survey (if off -shore) 39 Contact name/phone for weekly progress reports [exploratory only) NA Yes Yes _ Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes NA NA NA Yes Yes Yes No No Yes Yes NA Yes Yes Yes Yes Yes Yes Yes Yes NA No Yes NA NA NA __Program DEV _ Well bore seg 1-1 160 On/Off Shore 9n___ Annular Disposal n ADL0025639,.entire wellbore. KRU 1 H-102 KUPARUK RIVER, WEST SAK OIL - 490150, governed by Conservation. Order No. 406C. CO 406C contains no spacing restrictions with respect to drilling unit boundaries. CO 406C has no interwell. spacing restrictions... Wellbore will be. more than 500' from an external property line where ownership or landownership changes. 80' conductor set 1794' MD _ 218% excess Productive interval will be completed with slotted liner Rig has steel tanks; all waste to approved disposal wells Anti -collision analysis complete; no major risk failures _ Diverter route acceptable;. chem inj pumps in 75' radius are Class 1,. Div 2 so acceptable. Max formation. pressure is 1746 psig(8.4 ppg EMW); will drill w/ 8.8-9.5 ppg EMW MPSP is 1348 prig; will test BOPs to 3500 prig. _ H2S measures required H2S measures required. Expected reservoir pressure is 8.38 ppg EMW; will be drilled using 8.8 to 9,5. ppg mud. Onshore development well to. be drilled. Geologic Engineering Public Commissioner: Date: Commissioner: DateC i loner Date �7-1�� gIte,1,-