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Home My WebLink About218-082MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 8, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1H-108B KUPARUK RIV U WSAK 1H-108B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/08/2025 1H-108B 50-029-23608-02-00 218-082-0 W SPT 3781 2180820 1500 642 646 645 645 160 200 200 200 4YRTST P Austin McLeod 8/20/2025 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U WSAK 1H- 108B Inspection Date: Tubing OA Packer Depth 1420 2210 2180 2170IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250823130405 BBL Pumped:0.9 BBL Returned:0.7 Wednesday, October 8, 2025 Page 1 of 1            ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Date: May 27, 2025 FFROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC 700 G Street 333 W.7th Ave., Suite 100 Anchorage AK 99501 Anchorage, Alaska DATA TRANSMITTAL Kuparuk River Unit/Field Well API #PTD #Comments 1H-112 50029237870100 2240320 3B-16A 50029212890100 2231250 2B-03B 50029211510200 2230800 2M-39 50103207950000 2181710 3S-612 50103207770000 2181110 3S-611 50103207740000 2181030 1H-108B 50029236080200 2180820 1H-110 50029236010000 2180310 1H-116 50029235940000 2180120 2S-06 50103207470000 2160850 2M-37 50103207450000 2160820 1D-39 50029229970000 2002160 1D-40A 50029229690100 2001900 2N-302 50103203800000 2011150 1R-03A 50029214060100 2000210 3H-37 50103208220000 2191940 2S-09A 50103207490100 2161280 T40450 T40451 T40452 T40453 T40454 T40455 T40456 T40457 T40458 T40459 T40460 T40461 T40462 T40463 T40464 T40465 T40466 By Gavin Gluyas at 1:15 pm, May 28, 2025 1H-108 B 50029236080200 2180820 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Colville River Unit/Field Well API # PTD # Comments CD5-31 50103208280000 2210020 CD5-96 50103208110000 2191620 CD4-499 50103208100000 2191610 CD5-26 50103208060000 2191070 CD5-98 50103208030000 2190590 CD5-24 50103207990000 2190060 CD5-23 50103207610000 2171550 CD5-19 50103207600000 2171210 CD5-22 50103207590000 2170890 CD5-316 50103207560000 2170400 CD3-111A 50103205260100 2170040 CD3-198 50103206370000 2110240 CD4-24 50103206020000 2090970 CD4-26 50103206000000 2090490 CD2-15 50103203860000 2011590 CD2-12 50103204550000 2030730 CD4-214 50103205370000 2061450 CD4-17 50103205340000 2061180 CD2-73 50103205900000 2081960 T40467 T40468 T40469 T40470 T40471 T40472 T40473 T40474 T40475 T40476 T40477 T40478 T40479 T40480 T40481 T40482 T40483 T40484 T40487 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Greater Mooses Tooth Unit/Field Well API # PTD # Comments MT7-99 50103208450000 2221020 T40485 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com CAUTION: This email originated from outside the State of Alaska mail system. 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From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1H-108B (PTD 218-082) Report of IA over Operating Pressure Limit Date:Wednesday, April 16, 2025 12:54:42 PM Attachments:1H-108B 90 Day TIO Plot & Schematic.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Wednesday, April 16, 2025 12:03 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Automation, AK Wells <akwellsautomation@conocophillips.com> Subject: KRU 1H-108B (PTD 218-082) Report of IA over Operating Pressure Limit Well Name: 1H-108B Facility: CPF1 PTD: 218-082 Well Type: Inj AA Number (if applicable): N/A Internal Waiver (Yes/No if applicable): No Type of Issue: IA Exceeded OPL Maximum Pressure (if applicable): 2044 psi Date of Occurrence (if applicable): 4/15/25 Chris, KRU 1H-108B (PTD 218-082) was reported by Operations yesterday 4/15/25 to have an IA pressure of 2044 psi. The 7” 26 lb/ft, L-80 has a burst rating of 7240 psi (45% burst rating = 3258 psi). 1H-108B experienced an instrumentation issue that inadvertently opened the choke from 15% to 100% open, resulting in an immediate IA thermal response with the IA increasing from 1150 psi to 2044 psi. The IA was bled and instrumentation techs are working to resolve the issue. Attached is a 90 day TIO plot and wellbore schematic for reference. Please let me know if you have any questions. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By LAST TAG 1H-108B jennalt Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pulled Hanger w/ Gauges 6/17/2019 1H-108B fergusp Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.20 Top (ftKB) 39.0 Set Depth (ftKB) 119.0 Set Depth (TVD) … 119.0 Wt/Len (l… 78.67 Grade B Top Thread Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 40.5 Set Depth (ftKB) 1,834.3 Set Depth (TVD) … 1,767.3 Wt/Len (l… 45.50 Grade L-80 Top Thread Hydril 563 Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 37.8 Set Depth (ftKB) 8,508.9 Set Depth (TVD) … 3,809.0 Wt/Len (l… 26.00 Grade L-80 Top Thread TXP BTC Casing Description SLOTTED LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 8,264.7 Set Depth (ftKB) 13,060.1 Set Depth (TVD) … 4,222.2 Wt/Len (l… 12.60 Grade L-80 Top Thread IBT-m Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 8,264.7 3,786.5 84.78 PACKER Baker HRD-E ZXP 5.0" x 7.00" Liner top packer L-80 5.5" Hyd 521 pin 4.410 8,284.3 3,788.2 85.15 NIPPLE Baker 5.0" "RS" Packoff Seal Nipple 15.5 ppf L-80 Hyd 521 box x box 4.250 8,287.2 3,788.5 85.20 HANGER Baker 5.0" x 7.0" Flex-Lock Liner Hanger L-80 Hyd 521 pin x pin 4.350 8,307.8 3,790.1 85.59 SBE Baker 80-40 Sealbore Extension, 5" L-80 Hyd 521 pin x 4-1.2" Hyd 521 box 4.000 8,327.5 3,791.6 85.43 XO Crossover Pup 4-1/2" L-80 Hyd 521 pin x 4-1/2" IBT pin 3.920 12,250.7 3,923.9 87.78 XO 4-1/2" 12.6#, L-80, IBT-m box x TXP pin X-O pup w/ 5.88" Hydroform 3.950 12,266.6 3,924.6 87.24 SWELL PACKER Baker-- "Swell Packer #2- "C" 5.75" OD SN: 052439-010-3 3.950 12,281.6 3,925.4 86.73 XO 4-1/2" 12.6#, L-80, TXP-m box x IBT pin X-O pup w/ 5.88" Hydroform 3.960 12,381.8 3,934.7 81.91 XO 4-1/2" 12.6#, L-80, IBT-m box x TXP pin X-O pup w/ 5.88" Hydroform 3.950 12,397.7 3,937.1 80.69 SWELL PACKER Baker-- "Swell Packer #2- "B" 5.75" OD SN: 052439-010-1 3.960 12,412.7 3,939.6 79.50 XO 4-1/2" 12.6#, L-80, TXP-m box x IBT pin X-O pup w/ 5.88" Hydroform 3.990 12,759.8 4,058.3 62.44 XO 4-1/2" 12.6#, L-80, IBT-m box x TXP pin X-O pup w/ 5.88" Hydroform 3.950 12,775.7 4,065.7 61.69 SWELL PACKER Baker-- "Swell Packer #1- "A" 5.75" OD SN: 052439-010-4 3.950 12,790.7 4,073.0 60.24 XO 4-1/2" 12.6#, L-80, TXP-m box x IBT pin X-O pup w/ 5.88" Hydroform 3.960 Tubing Strings Tubing Description Tubing - Water Injection String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 33.0 Set Depth (ft… 8,324.3 Set Depth (TVD) (… 3,791.4 Wt (lb/ft) 9.30 Grade L-80 Top Connection Hyd 563 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 33.0 33.0 0.04 HANGER Vetco4-1/2" x 13 1/2" MB228 Tubing hanger w/ parent bowl 13- 7/16" OD 3.900 5,373.5 3,292.9 71.51 NIPPLE HES 2.813 Landing nipple 4½" OD w2.75" No-Go (3294.39' TVD, 72.14°) 2.750 8,272.5 3,787.2 84.93 LOCATOR Baker GBH-22 Locator (OD 5.01") Larger OD above located 2.970 8,273.8 3,787.3 84.95 SEAL ASSY Baker GBH-22 Seal Assembly w/ mule shoe------ below located 2.990 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,537.0 12,251.0 3,811.0 3,924.0 WS D, 1H-108B 8/3/2018 SLOTS 12,423.0 12,547.0 3,941.6 3,974.5 WS D, 1H-108B 8/3/2018 SLOTS 12,636.0 12,760.0 4,005.6 4,058.4 WS D, 1H-108B 8/3/2018 SLOTS 12,861.0 12,990.0 4,109.9 4,182.2 WS D, 1H-108B 8/3/2018 SLOTS 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 2,527.8 2,268.8 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 9/21/2018 2 5,253.5 3,253.5 Camco KBMG 1 GAS LIFT DMY BK-5 8/4/2018 Notes: General & Safety End Date Annotation NOTE: Comment SSSV: NONE 1H-108B, 6/18/2019 7:09:31 AM Vertical schematic (actual) SLOTTED LINER ; 8,264.7- 13,060.1 SLOTS; 12,861.0-12,990.0 SLOTS; 12,636.0-12,760.0 SLOTS; 12,423.0-12,547.0 SLOTS; 8,537.0-12,251.0 INTERMEDIATE; 37.8-8,508.9 SEAL ASSY; 8,273.8 LOCATOR; 8,272.5 GAS LIFT; 5,253.5 GAS LIFT; 2,527.8 SURFACE; 40.6-1,834.3 CONDUCTOR ; 39.0-119.0 XO Reducing (Tubing); 76.2 HANGER; 33.0 KUP INJ KB-Grd (ft) 38.89 Rig Release Date 8/5/2018 Annotation LAST WO: End Date 1H-108B H2S (ppm) Date... TD Act Btm (ftKB) 13,080.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292360802 Wellbore Status INJ Max Angle & MD Incl (°) 91.47 MD (ftKB) 11,321.42 WELLNAME WELLBORE1H-108 MEMORANDUM To: Jim Regg P.I. Supervisor FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 4, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 11-1-10813 KUPARUK RIV U WSAK 1H-10813 Src: Inspector Reviewed By: P.I. Supry j� Comm Well Name KUPARUK RIV U WSAK 1 H- API Well Number 50-029-23608-02-00 Inspector Name: Bob Noble 1088 218-082-0 Ins 8/l/2021 Permit Number: Inspection Date: Insp Num: mitRCN210802093055 Rel Insp Num: Wednesday, August 4, 2021 Page I of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IH -1088 Type Inj W ''TVD 3781 Tubing 760 _ 760 760 - 760 PTD 2180820 Type Test' SPT" Test psi 1500 -� — IA 1430 2200 2160 2150 BBL Pumped: 0 7 BBL Returned: 0.7 OA 150 150 " 150 150 Interval 4YRTS'I' P/F — P -- - - Notes: Wednesday, August 4, 2021 Page I of 1 Originated:Delivered to:8-Jan-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 1A-01 50-029-20590-00 n/a Kuparuk River Packer Setting Record Field- Final 6-Dec-20 0 1 2 1A-01 50-029-20590-00 n/a Kuparuk River Packer Setting Record Field- Final 7-Dec-20 0 1 3 1C-25 50-029-22941-00 906866139 Kuparuk River Packer Setting Record Field- Final 15-Dec-20 0 1 4 1H-108B 50-029-23608-02 906811421 Kuparuk River Water Flow Record Field- Final 12-Nov-20 0 1 5 1H-109 50-029-23595-00 906810847 Kuparuk River Injection Profile Field & Processed 14-Nov-20 0 1 6 1H-111 50-02923581-00 906831134 Kuparuk River Injection Profile Field & Processed 21-Nov-20 0 1 7 1H-115 50-029-23605-00 906832402 Kuparuk River Injection Profile Field & Processed 23-Nov-20 0 1 8 1H-117 50-029-23602-00 906810277 Kuparuk River Injection Profile Field & Processed 20-Nov-20 0 1 9 1J-118 50-029-23337-00 906798402 Kuparuk River Plug Setting Record Field- Final 1-Nov-20 0 1 10 1Y-19 50-029-22391-00 906849383 Kuparuk River Leak Detect Log Field- Final 7-Dec-20 0 1 PLEASE 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 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the 01/08/2021 01/11/2021 Abby Bell PTD: 2180820 E-Set: 34540 21801"2 Originated: 3 197 2 Delivered to: Schlumberger . • 24-Jan-20 24Ja n20 -JW 02 PTS - PRINT CENTER '� .r,T AOGCC 6411 A Street 3 , ? ATTN: Natural Resources Technician II Anchorage, AK 99518 iJ Alaska Oil & Gas Conservation Commision (907)273-1700 main (907)273-4760 fax \' 333 W. 7th Ave, Suite 100 -y Anchorage, AK 99501 8.00 IPROF 1 in-na 50-029-23584.00 DWUJ-00161 KUPARUK RIVER WL �..�•�.�` I-INAL FIELD 15 -Jan -20 1H-119 50-029-23591-00 DWUJ-00162 KUPARUK RIVER WL ]PROF-WFL FINAL FIELD 16 -Jan -20 1 1H-115 50-029.23605-00 DWUJ-00163 KUPARUK RIVER WL ]PROF-WFL FINAL FIELD 17 -Jan -20 1 1H-1086 50-029-23608.02 DWUJ•00164 KUPARUK RIVER WL (PROF-WFL FINAL FIELD 18 -Jan -20 1 1H-116 50-029-23594-00 DWUJ-00165KUPARUK RIVER I WL WFL FINAL FIELD 19-Jan•20 1 IPROF FINAL F]ELD 20-Jan•20 1 7 ✓ ` X ' % ( ATransmittal Receipt signature confirms that package (box, 1\ envelope, etc.) has been received and the contents of the nt Name Signature package have been verified to match the media noted above. The Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this ease return via courier or sign/scan and email a copy t hlumberger and CPA]. point. ska PTSPrmtCenter@slb.com Torn.Osterkarnp2conoco hilli s.com SLB Schlumberger -Private k(�, E(, i a4-1Gs9 P,Nn- ztrot�z.C: Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Sunday, November 24, 2019 7:57 AM To: Regg, James B (CED) Cc: Thomson, Stephanie; Braun, Michael (Alaska); CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1 &2 Ops Supt; NSK West Sak Prod Engr Subject: LPP/SSV Returned to Service on CPAI Well 1 H -108B (PTD# 218-082) Jim, ;/ The low-pressure pilot (LPP) on well 1H-10813 (PTD# 218-082) was returned to service and removed from the "Facility Defeated Safety Device Log" yesterday evening, 11/23/2019, as the injection pressure increased above the LPP setpoint after a sustained injection period. The well is currently injecting 500 BWPD at 560 psi wellhead pressure. The LPP had been defeated on 11/16/2019 due to low injection pressure after an extended shut-in period. This notification is in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Thank you, Sydney Autry for Toon Changklungdee / Marina Krysinski West Sak Production Engineer Office: (907) 659-7234 Pager: (907) 659-7000 pp 497 Kf-u ( 6�-(0e,C, PrD '2-(LC/6 Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Saturday, November 16, 2019 4:34 PM� To: Regg, James B (CED) 1 Cc: Thomson, Stephanie; Autry, Sydney; Braun, Michael (Alaska); CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1 &2 Ops Supt; NSK West Sak Prod Engr Subject: LPP/SSV Defeated on CPAI Well 11-1-108 on 11/16/2019 Jim, The low pressure pilot (LPP) on well (PTD# 218-082) was defeated today, 11/16/2019 after the well is returned to injection following an extended shut in period. The well is currently injecting at 500 BWPD with a wellhead pressure of 315 psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility i Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Thank you, Toon Toon Changklungdee / Marina Krysinski WestSak Production Engineer Office: (907) 659-7234 Pager: (907) 659-7000 pp 497 Conoco a D D o PS Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 6, 2019 Commissioner Hollis French Alaska Oil & Gas Commission 333 West 7h Avenue, Suite 100 Anchorage, AK 99501 Commissioner Hollis French: CW E-032 ECEN MAY 0 8 2010 AOGCC 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 5/6/2019 1J & 1H Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal U-180 50029233290000 2061500 20'9" 2.80 115" 5/4/2019 5 5/5/2019 111-101 50029235850000 2171380 2'10" 0.70 9" 5/4/2019 2.2 5/5/2019 1H-102 50029235800000 2170970 2'9" 0.65 8" 5/4/2019 1.7 5/5/2019 1H-103 50029235930000 2180030 2'2.5" 1 0.45 9" 5/4/2019 2.2 5/5/2019 111-104 50029236100000 2180840 2'.5" 0.40 9" 5/4/2019 2.2 5/5/2019 1H-1086 50029236080200 2180820 3'8" 0.80 10" 5/4/2019 2.5 5/5/2019 1H-109 50029235950000 2180130 2'3" 0.40 9" 5/4/2019 2.2 5/5/2019 111-110 50029236010000 2180310 2'6.5" 0.65 8.5" 5/4/2019 2 5/5/2019 1H-111 50029235810000 2171330 2' 0.35 9" 5/4/2019 2.2 5/5/2019 1H-113 50029235880000 2171680 2'1" 0.40 8" 5/4/2019 1.7 5/5/2019 1H-114 50029235840000 2171360 1'11" 0.25 7.5" 5/4/2019 1.8 5/5/2019 11-1-115 1 50029236050000 2180530 22.5" 0.35 8.5" 5/4/2019 2 5/5/2019 1 H-116 50029235940000 2180120 1'7" 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 1H-118 50029235780000 2170840 2'4" 0.508.5" 5/4/2019 2 5/5/2019 1H-119 50029235910000 2171780 3' 0.80 8" i 5/4/2019 1.8 5/5/2019 DATA SUBMITTAL COMPLIANCE REPORT 11/26/2018 Permit to Drill 2180820 Well Name/No. KUPARUK RIV U WSAK 1H-1086 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23608-02-00 MD 13080 TVD 4234 REQUIRED INFORMATION Completion/Date 8/5/2018 Mud Log No ✓ Completion Status WAGIN Samples No ✓ DATA INFORMATION List of Logs Obtained: GR/ RES/ SONIC LW D (Cement Evaluation) Well Log Information: Log/ Electr Data Digital Dataset Log 9 Lo Run Type MedlFrmt Number Name _ Scale Media No ED C 29686 Digital Data ED C 29686 Digital Data ED C 29686 Digital Data ED C 29686 Digital Data ED C 29686 Digital Data ED C 29686 Digital Data ED C 29686 Digital Data ED C 29686 Digital Data ED C 29686 Digital Data ED C 29686 Digital Data ED C 29686 Digital Data ED C 29686 Digital Data ED C 29686 Digital Data AOGCC Page I of Current Status WAGIN UIC Yes Directional Survey Yes V (from Master Well Data/Logs) Interval OH/ Start Stop CN Received Comments 32 1840 9/19/2018 Electronic Data Set, Filename: CPAI 1 H- 10813_Scope_Gamma_Ray_RM_LW D001.las 1743 6192 9/19/2018 Electronic Data Set, Filename: CPAI_1H- 108B_VISION_Resistivity_RM_LW D005.las 6113 8516 9/19/2018 Electronic Data Set, Filename: CPAI 1H- 108B_VISION_Resistivity_RM_LW D_006.las 8380 10725 9/19/2018 Electronic Data Set, Filename: CPAI_1H- 108B_VISION_Resistivity_RM_LW D007.las 10640 13080 9/19/2018 Electronic Data Set, Filename: CPAI_1H- 108B_VISION_Resistivity_RM_LW D008.las 0 13080 9/19/2018 Electronic Data Set, Filename: CPAI_1H- 1088_VI S ION_Resistivity_RM.las 9/19/2018 Electronic File: CPAI _1H- 108_Scope_Gamma_Ray_RM_LW D001.d11s 9/19/2018 Electronic File: CPAI 11-1- 108_Soope_Gamma_Ray_RM_LW D001.html 9/19/2018 Electronic File: CPAI_1H- 108B_VISION_Resistivity_RM_LW D005.dlis 9/19/2018 Electronic File: CPAI_1 H- 108B_VISION_Resistivity_RM_LW D005.html 911912018 Electronic File: CPAI 1H- 108B_VISION_Resistivity_RM_LW D006.dlis 9/19/2018 Electronic File: CPAI_1H- 1086_VISION_Resistivity_RM_LW D006.html 9/19/2018 Electronic File: CPAI-1 H- 108B_VISION_Resistivity_RM_LW D007.diis Monday, November 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 11126/2018 Permit to Drill 2180820 Well Name/No. KUPARUK RIV U WSAK 1H-1086 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23608-02-00 MD 13080 TVD 4234 Completion Date 8/5/2018 Completion Status WAGIN Current Status WAGIN UIC Yes ED C 29686 Digital Data 9/19/2018 Electronic File: CPAI 1H- 108B_VISION_Resistivity_RM_LW D007.html ED C 29686 Digital Data 9/19/2018 Electronic File: CPAI 1H- 108B_VISION_Resistivity_RM_LW D008.diis ED C 29686 Digital Data 9/19/2018 Electronic File: CPAI_1H- 108B_VISION_Resistivity_RM_LW D008.html ED C 29686 Digital Data 9/19/2018 Electronic File: CPAI_1H- 108B_V I SI ON_Resistivity_RM.dlis ED C 29686 Digital Data 9/19/2018 Electronic File: CPAI 1H- 108B_V ISION_Resistivity_RM.html ED C 29686 Digital Data 9/19/2018 Electronic File: CPAI 1H- 108B_V I S ION_Resisitivity_2MD_RM.pdf ED C 29686 Digital Data 9/19/2018 Electronic File: CPAI 1H- 108B_V I S ION_Resisitivity_2T VD_RM.pdf ED C 29686 Digital Data 9/19/2018 Electronic File: CPAI 1H- 108B_V I S ION_Resisitivity_5MD_RM.pdf ED C 29686 Digital Data 9/19/2018 Electronic File: CPAI_1H- 10813_V I SION_Resistivity_5TV D_R M. pdf ED C 29686 Digital Data 9/19/2018 Electronic File: Gyrodata Survey - 1 H-108 - Post SLB SAG.pdf ED C 29686 Digital Data 9/19/2018 Electronic File: 1H -108B NAD27 EOW Compass Surveys [Canvas].txt ED C 29686 Digital Data 9/19/2018 Electronic File: 11-1-10813 NAD27 EOW Compass Surveys [Macro].txt ED C 29686 Digital Data 9/19/2018 Electronic File: 1H-10813 NAD27 EOW Compass Surveys [Petrel].W ED C 29686 Digital Data 9/19/2018 Electronic File: 1H -108B NAD27 EOW Compass Surveys [Surveys].txt ED C 29686 Digital Data 9/19/2018 Electronic File: 11-1-108B NAD27 EOW Compass Surveys.pdf ED C 29686 Digital Data 9/19/2018 Electronic File: 1H -108B NAD83 EOW Compass Surveys [Canvas].txt ED C 29686 Digital Data 9/19/2018 Electronic File: IH -108B NA083 EOW Compass Surveys [Macro].txt ED C 29686 Digital Data 9/19/2018 Electronic File: 11-1-1088 NAD83 EOW Compass Surveys [Petrel].txt AOGCC Page 2 of 3 Monday, November 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 11/26/2018 Permit to Drill 2180820 Well Name/No. KUPARUK RIV U WSAK 1H-1086 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23608-02-00 MD 13080 TVD 4234 Completion Date 8/5/2018 ED C 29686 Digital Data ED C 29686 Digital Data ED C 29686 Digital Data Log C 29686 Log Header Scans Well Cores/Samples Information: Name INFORMATION RECEIVED Completion Report �jY Production Test Information Yv NA Geologic Markers/Tops �Y COMPLIANCE HISTORY Completion Date: 8/5/2018 Release Date: 7/19/2018 Description Comments: Interval Start Stop Completion Status WAGIN Current Status WAGIN UIC Yes 9/19/2018 Electronic File: 1H-1086 NAD83 EOW Compass Surveys [Surveys].txt 9/19/2018 Electronic File: 1H -108B NAD83 EOW Compass Surveys.pdf 9/19/2018 Electronic File: CPAI_11-1- 108B_PrintSuweyLisl. csv 0 0 2180820 KUPARUK RIV U WSAK 1H -108B LOG HEADERS Directional / Inclination Data / Y� Mechanical Integrity Test Information Y/YY// NA Daily Operations Summary , r ) Date Compliance Reviewed By:�— Comments Sample Set Sent Received Number Comments Mud Logs, Image Files, Digital Data Y IQ Core Chips Y / ID I Composite Logs, Image, Data Files O Core Photographs Y l Cuttings Samples Y / Laboratory Analyses Y NA Date: AOOCC Page 3 of 3 Monday, November 26, 2018 K�tc Irl -1089 PTo zr8oE3z� Regg, James B (DOA) From: NSK West Sak Prod Engr <nl638@conocophillips.com> Sent: Friday, September 28, 2018 2:48 PM To: Regg, lames B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; NSK Optimization Engr; Autry, Sydney; Sudan, Hari Hara; Braun, Michael (Alaska); Thomson, Stephanie Subject: LPP/SSV Returned to Service on CPAI Well 1H -108B Jim, The low pressure pilot (LPP) on well 1H -108B (PTD# 218-082) was returned to service and removed from the "Facility Defeated Safety Device Log" this afternoon, 9/28/2018. This injector had a 30 -day pre -production period that caused initial low well head pressure. The LPP had been defeated on 9/22/2018 after the well was put on it's initial injection post -drilling. This notification is in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Courtney Gallo / Marina Krysinski West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Cell: (720) 318- 5762 Pager: (907) 659-7000 #497 `iu IH -108a Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophilIips.c > L1 Sent: Saturday, September 22, 2018 3:38 PMegp I1ZQ16 To: Regg, James B (DOA) (( 1 Cc: CPF1 Ops Supv; CPF1 DS Lead Techs; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1&2 Ops Supt; Autry, Sydney; Thomson, Stephanie; Fox, Pete B; Braun, Michael (Alaska); Sudan, Hari Hara Subject: Defeated LPP/SSV on CPAI well 1H -108B on 9/22/2018 Jim, The low pressure pilot (LPP) on well 1H -108B (PTD# 218-082) was defeated today on 9/22/2018 after the well was brought on initial injection following a 30 -day pre -production period. The well is currently injecting at a wellhead injection pressure of 0 psi and rate of 950 BWPD. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Courtney Gallo /Marina Krysinski West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 21 8082 29 68 6 Schlumberger -Private STATE OF ALASKA Al ARKA nil AMn (:A4 rnNl4Cnvernnnn rnxasm001nr., vus.nvn .�W w LOG CaOMPLETIs[] OR ROther ta. WeIlStalusWEL❑L SPLUG❑ON ❑ECOMPLAbandoned ❑ETIONpREPORendedEJ 1b. T IAIND l Class: 20MC25.1m MAAC25.110 GINJ❑ WIND❑ WAGO WDSPL❑ No. of Completions: 2. Operator Name: 6. Date Comp., Susp., or ConocoPhlllips Alaska, Inc. Abend.: 8/5/2D18 Development ❑ Exploratory ❑ Service P1 Stratigraphic Test EJ 14. Permit to Drill Number I Sundry: 218.082 , 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 7/21/2018 15. API Number. 50-029-23608-D2-00 ' 4a. Location of Well (Governmental Section): Surface: 5231' FNL, 770' FEL, Sec 28, T12N, R10E, UM Top of Productive Interval: 8. Date TD Reached: 8/1/2018 16. Well Name and Number: KRU 1H-10813 9. Ref Elevations: KB:92.62 J 17. Field I Pool(s): 3023' FNL, 673' FEL, Sec 34, T12N, R10E, UM Total Depth: 844' FNL, 1879' FEL, Sec 36, T12N, R10E, UM GL:64 + BF: Kuparuk River FieldAlVest Salk Oil Pool 10. Plug Back Depth MD/TVD: 18. NIA Property Designation: ADL 25639, ADL25638 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 649570.98 y- 6980752.62 Zone- 4 TPI: x- 554975 y- 6977718 Zone- 4 Total Depth: x- 569029 y- 5979928 Zone- 4 11. Total Depth MD/TVD: 19. 13080/4234 DNR Approval Number: 80-261, 931695000 12. SSSV Depth MD/TVD: 20. NIA Thickness of Permafrost MD/rVD: 1685/1635 5. Directional or Inclination Survey: Yes I] (attached) No ❑ Submit eledronic and printed information per 20 AAC 25.050 13. Water Depth, A Offshore: 21. WA (8 MSL)1 Re-drill/Lateral Top Window MD/TVD: 2264/2108 22. Logs Obtained: List all logs ran and, pursuant to AS 31.05.03D aria 20AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res/Sonlc LWD (Cement Evaluation) 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20 94 H40 Surface 119 Surface 119 42 Existing, cement to surface 10.75 45.5 L-80 Surface 1834 Surface 1767 13.5 969 sx 11.0 Gass G, 221sx 7 29.7 L-80 Surface 8509 Surface 3809 8.75 838 sx 15.8 Class G 4.5 11.6 L-80 8265 13060 3786 4222 6.125 Slotted Liner 24. Open to production or injection? Yes [D No ❑ 25. TUBING RECORD If Yes, list each Interval open (MD/rVD of Top and Bottom; Perforation Size and Number; Date Perfd): PERFORATIONS @: SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3112 8324 NIA 8537-12251 MD and 3811-3924 TVD --- 8/3/2018 12423.12547 MD and 3942-3974 TVD...8/3/2018 12636-12760 MD and 4006-4058 TVD ... 8/3/2018 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No 12861-12990 MD and 4110-4182 TVD ... 8I312018 Per 20 AAC 25.283 (i)(2) attach electronic and printed informatlon DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation (Flouring, gas lift, etc.): 9/17/2018 GAS LIFT Date of Test: 9/1/2018 Hours Tested: 12hns Production for Test Period Oil -Bbl: 260 Gas -MCF: 69 Wafer -Bbl: 46 Choke Size: 100 Gas -Oil Ratio: 266 Flow Tubing Press. 301 Casing Press: CalculatedOil-Bbl: our Rata -40, 620 1 Gas -MCF: 138 Water -Bbl: 92 Oil Gravity- API (con): 17 9 I/TL /r/2/!5' Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2Submit ORIGINAL only �y1VJ-16 RBDIlf1S 1/��CST 2 5 2016 / IV, �-- . 8.11 I 11: Guhl, Meredith D (DOA) From: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty- S herrod@contractor.co nocophi llips.com> Sent: Thursday, October 25, 2018 9:44 AM To: Guhl, Meredith D (DOA) Cc: Kanady, Randall B; Thomson, Stephanie Subject: RE: [EXTERNAL]KRU 1H-10813, PTD 218-082, Sundry? Attachments: 1 H-1088 REVISED 10-407 PTD NEW WELL Completionpdf.pdf Meredith, Attached is a revised 10-407 for 1H -108B, updating the completion (page 1) to WAG and Service. Thanks so much for your patience in this matter. Thanks, Ann From: Guhl, Meredith D (DOA) <meredith.guhl@alaska.gov> Sent: Wednesday, October 24, 2018 4:05 PM To: Kanady, Randall B <Randall.B.Kanady@conocophillips.com>; Roby, David S (DOA) <dave.roby@alaska.gov> Cc: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty-Sherrod@contractor.conocophillips.com>; Thomson, Stephanie <Stephanie.Thomson@conocophillips.com> Subject: RE: [EXTERNAL]KRU 1H -108B, PTD 218-082, Sundry? Randy, The 10-407 was submitted with the well designated 1 -Oil and Development, not WAG and Service, hence my confusion at the lack of conversion sundry. You are correct that no sundry is required for wells converted within 30 days. Please provide an updated page 1 to the 30-407 for KRU SH -1088 so the AOGCC database can be updated. Thanks, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.auhl alaska.gov Direct: (907) 793-1235 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 Meredith Guhl at 907-793-1235 or meredith.euhlPalaska eov. From: Kanady, Randall B <Randall.B.KanadV conocophillips com> Sent: Wednesday, October 24, 2018 3:28 PM To: Guhl, Meredith D (DOA) <meredith.guhfiFDalaska.gov>; Roby, David S (DOA) <dave.robvCraalaska.aov> Cc: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Ha¢eerty SherrodCa)contractorconocophillips com>; Thomson, Stephanie <Stephanie.Thomson@conocophillips com> Subject: RE: [EXTERNAL]KRU 1H -108B, PTD 218-082, Sundry? Meredith See the attached email with Dave Roby. This well was permitted as an injector and is currently on injection, but we did pre -produce the injector for 30 days in order to clean the well up after drilling. I understood that if the well is produced for 30 days or less that no conversion sundry is required. Please let us know if this is correct. Thanks You, Randall Kanady P.E. ConocoPhillips Alaska Drilling and Wells Office: 907-263-4126 Cell: 907-575-0742 randall.b.kanady@conocophillips.com From: Guhl, Meredith D (DOA) <meredith.guhlPalaska.eov> Sent: Tuesday, October 23, 2018 11:53 AM To: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty-Sherrod@contractor conocophillips com> Subject: [EXTERNAL]KRU 1H-1086, PTD 218-082, Sundry? Hi Ann, Do you have a sundry report for converter KRU 1H -108B, PTD 218-082 from 1 -Oil to WAG on the docket? The well was apparently converted in September, but no sundry has arrived here yet. Let me know if I should check in with someone else. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.auhl alaska.gov Direct: (907) 793-1235 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 Meredith GuhI at 907-793-1235 or meredith.euhiPalaska.eov. i�IV�ILa V li. STATE OF ALASKA I SEP 0 7 20118 ALASKA OIL AND GAS CONSFRVATInIY cnneknlcclnel WELL COMPLETION OR RECOMPLETION REPORT AN U 1 a. Well Status: Oily Gas❑ SPLUG❑ Other ❑ Abandoned ❑ Suspended El z0A C25.105 20AAC 25.110 GINJ ❑ WINJ❑ WAG❑ WDSPL❑ No. of Completions: 1b. Well Class: Development 0 Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 8/6/2018 14. Permit to Drill Number/ Sundry: 218-082 3. Address: P.O. Box 100360 Anchorage, AK 9951 U360 7. Date Spudded: 7/21/2018 15. API Number: 50-029-23608-02-00 4a. Location of Well (Governmental Section): Surface: 5231' FNL, 770' FEL, Sec 28, T12N, R10E, UM Top of Productive Interval: 3023' FNL, 673' FEL, Sec 34, T12N, R10E, UM Total Depth: 844' FNL, 1879' FEL, Sec 35, T12N, R10E, UM 8. Date TD Reached: 8/1/2018 16. Well Name a Number: KRU 7H 08B 9. Ref Elevations: KB:92.62 GLBF: 17. Field / 001(s): ru Ri:54 Kupaver Field/West Sak Oil Pool 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 25639, ADL25638 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 549570.98 y- 5980752.52 Zone- 4 TPI: x- 554975 y- 5977718 Zone- 4 Total Depth: x- 659029 y- 5979928 Zone- 4 11. Total Depth MD/TVD: 13080/4234 19. DNR Approval Number: 80-261, 931695000 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1685/1635 5. Directional or Inclination Survey: Yes EI (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL)J 21. Re-drill/Lateral Top Window MD/TVD: 2264/2108 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary thi� palC GR/Res/Sonic LAD (Cement Evaluation) 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT HOLE SIZE CEMENTING RECORD GRADE TOP BOTTOM TOP BOTTOM PULLED 20 94 H-40 Surface 119 Surface 119 42 Existing, cement to surface ";' 10.75 45.5 L-80 Surface 1834 Surface 1767 13.5 969 sx 11.0 Class G, 221sx 7 29.7 L-80 Surface 8509 Surface 3809 8.75 838 sx 15.8 Class G 4.5 11.6 L-80 8265 13060 3786 4222 6.125 Slotted Liner 24. Open to production or injection? Yes ❑ ado ❑ If Yes, list each interval open (MD/TVD of Top and/Bottom; Perforation Size and Number; Date Perfd): �� PERFORATIONS @: 8537-12251 MD and 3811-3924 TVD... 8/3/2018 12423-12547 MD and 3942-3974 TVD.-8/3/2018COMPLETIOR, 12636-12760 MD and 40064058 TVD ... 8/3/2018((''yyD TE 12861-12990 MD and 4110-4182 TVD...8/3/2018 -4kh_ VE IED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 31/2 8324 N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes E] No ❑� 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: 8/1712018 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 9H/2018 12hrs Hours Tested:124iHoorRatp oduction for st Period Oil -Bbl: 260 Gas -MCF: 69 Water -Bbl: 46 Choke Size: 100 Gas -Oil Ratio: 265 Flow Tubing Press. 301 Casinq Press:lculated 1408 Oil -Bbl: 520 Gas -MCF: 138 Water -Bbl: Oil Gravitv - API (corr): 17. R SEP 10 2018 Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINIAL only 28. CORE DATA Conventional Corals): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No 21 If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071, 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No El If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface , Permafrost - Base 1685 ' 1635 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 8210 3782 information, including reports, per 20 AAC 25.071. Formation @ TPI - West Sak Ugnu 4630 3042 TD 13080 4234 Formation at total depth: West Sak 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontolooical report. production r well test results, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: G.L. Alvord Contact Name: Madeline Woodard Authorized Tt!W ^Iaska WIling manager Contact Email: madeline.e.woodard co .corn Authorized ,/ Contact Phone: 265$086 Signature: ate: INSTROCTIONS 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 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (IAS 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 sh'owlhe 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 5/2017 Submit ORIGINAL Only n Insulated Con"' Casing, 20", 94# K55 x 34", 0.312", WT@H-120'MD Wellhead / Tubing Hesse! /Tree 111-1O8B Injector r10 -3/4"x4-1/2", S,OOD psi 1 Final Gas Lilt Mandrel, CAMCO Madel KBMG w/ SOOV @ 2,528 MD/ 2,278' TVD (55 deg) 10-3/4',45,5#, L-80, Hyd563 @ 1,834' MD / 1,824' TVD @3l degrees - TD 13.5" bole 3 - Tubing String: 3-1/2", 9.3 #, L-80 HYD 563 x Gas Lift Mandrel, CAMCO Madel KBMG w/ Dummy @ 5,253' MD /3,254' TVD (70 deg) - 1913" XN nipple w/ 2.75" No -Go @ 5,373' MD / 3,294' TVD (72 deg) 12.64, L-80, IBTM Liner, alternating blanks and slots @ 13,060 MD/ 41222' TVD 6.125" OH TD 13,08Y MD/ @86-55 degrees 4,234! TVD _ 4,551' Lined Laural @ 55 degrees gZXP Liner Top packer &Liner Hanger . -,-'ti___________________________________ .............. .......... .. ........... @ 8,265' MD (-244 ft above 7" shoe) �i ----__—__------- __ __ _______________________________________________@ 26#, 48Q TXP, Casing •, __@8,509'MD ?? z /3,809'TVD �._______________„____.__.____._....._,_....___.......____._____, .. @ 86 degrees __,_._____ ,_.. i Baker Swell Peckers, 5.75" OD c m ° TD 8-3/4" hole 4-1/2" Solid Shoe v KUP PROD 1H -108B Cwto4h1II1p5/'"" weAtAttribut Max Angie T TD Fieltl Name TW¢Ilnore APTUWI .11.1 SOL. velar) MD In Act aim iXNBI .Alaska, IRC. WFSTSAN SM1nJOJienAfn m -lase. vrrzmea.wdeaM Last Tag ---_-- Y^'ayenemercl�NM) Annotation IF 11 Orae O m1N(BI La:I M By LAST TAG gzttI'm RANGES. 990 Last Rev Reason ..........._...................................................... _.__. Aonoblmn Ene ome LalMM BY REV REASON fennalt Casing Strings ..................._...................... _..............casing "' Dens ion OD Un) INTERMEDIATE ] ID(..I 628 TOP 8 taxa) set Oepm(nMB) NO CePin (NOL. 37 8,5089 3,809.0 WULen 26.00 O... trees top inrae L-80 P BTC camin90ascri 0-1 O0(in) SLOTTED LINER 4112 Ila (in) 3.96 TOP prem Set Depth(Nea 9N Depth ROD) 8,2647 13060.1 4,222.2 WULen (L.. 1260 Draoe tap T' SO LAr IEP Liner Details SO SaAnry Hisona. 73.2 Top MB) TCP(WD)MB) Topindfl I Ile. per Com Nomina110 (1n) 8,2 3 3,78. 85.15'Upple IRS) Baker5.W'RS"Paco eat Nipple l5.5 pp 4.250 Hyd 521 box x box CONDUCTOR: 99.0-1190 82872 3,]88,5 8520 Hanger Baker 5. "x To' Flex,4-00, Liner Hanger L-60 4.350 521 pin x pin 8.3078 3,790.1 85.59 Be. BE eaBaker 80,10 Sea ore Exampling, 5" LA0 Hyd pin x 4-1.2'Hyd 521 box 4.000 Extension) 1$266.6 3, d6 8].24 well Packer Baker-" wet ackerp - "G" 575"OD 3.950 SVRFPCE; a0.61.04.9� 052439-010.3 12,39771 3,9371W69 Swell Packer Baker -'Swell athero - "e" 575-00 3.960 I 052439-010.1 12A57 4,0657 61.69 Swell Packer Baker -"Swell Packerat-"A"5.]5"OD N'. 3.950 052439-0114 Metra: sTra Tubing Strings Tubing Description Sinn. kxs..1D1m1 Tubing - Water 3112 2.99 TopinN0, 33.0 Set D'.Pm 1X..SNoepM 8.324.3 ROAN 3.]91 0 .WIunMI 9.30 Greta L -BO Top CannMron Hyd 563 Injection GA9U T:59S15 Completion Detalls TaP(ND Topincl Nominal Tap(US.) pass)(°I Ilam Oes Com IO (In) 33.0 33.0 0,04 HANGER et -1l "x 13 ilY'MB228 Tubing argerial parent been l3- 3.900 7116" OD 5373.5 3,292.9 71.51 NIPPLE HES 2.873 Lending Rippe W" ODw JS o 'TVD, 2350 72.14°) 8,2725 3,787. 84.93 ILOCATOR Baker GBH -22 LecMor(OD 501') Larger OD above located 2.970 8.2738 37877 84.95 1SEAL ASSY Baker GBH-22Seal Assembly wl mule shoe—below located 2990 LOCATOR:8,2721 Perforations& Slots snot SFALAURS;kxxrr Top UUMS D. gooBI Tapflvo) Baker arm I've)lsnolNn DKBI Lineal Dab Den ) Tyq Com 8,537-0 12,251. 7,8110 3,924.0 W5 D, 1H-1088 813 18 SLOTS 12,423.0 12,547.0 3,941.6 3,9]45 WS D, 1H-1088 WW21 SLOTS 1,6360 12,7600 4,005.6 4,0584 WSD,1H-1088 8132018 SLOT 12,8610 12,990. 8109.9 4,182.2 WSD.iH-1088 MO SLOT INTERMEDIATE, 97.ea,506e_ Mandrel Inserts 9t an SLOTS; BST1.61].EtO N upMKI r TOP ITVDI (11KB) Make MWeI OD pal RES Type T9ye POlbl. TR�'un Sun pab Lam 5,253.5 3,2535 amCO KBM 1 DMY SLOTS .12429 C T2,5n,O—�� SLOTS: I2,61A012,7000 suffe:12,SM 012,9200 SLOTTEDUNER:e.2641 13,04 1 m Uperations Summary (with Timelog Depths) 114-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time pw (hr) Phase Op Code Activity Code Time P -T -X Operation Start Dep h (XKa) End DepN (flKe) 6/4/2018 6/4/2018 0.75 MIRU MOVE MOB P Move rock washer & pipe shed. 0.0 0.0 00:00 0045 SIMOPS install Amphion/NOVOS upgrade in drillers cab. 6/4/2018 6/4/2018 1.00 MIRU MOVE MOB. P Move power module. Install travel 0.0 0.0 00:45 01:45 tongue on sub. Finish unplugging interconnects f/ pits to sub. SIMOPS install Amphion/NOVOS upgrade in driller cab. 6/4/2018 6/4/2018 1.00 MIRU MOVE MOB P Skid rig floor & raise stompers. 0.0 0.0 01:45 02:45 6/4/2018 6/4/2018 0.50 MIRU MOVE MOB P Latch sub to truck & move off 1H-110 0.0 0.0 02:45 03:15 6/4/2018 6/4/2018 2.25 MIRU MOVE MOB P Move sub towards 1H-108. Set rig 0.0 0.0 03:15 05:30 mats for 1H-108. Spot sub over well. Remove travel tongue & skid rig floor to drill position. 6/4/2018 6/4/2018 0.50 MIRU MOVE MOB P Spot pits complex to sub base. 0.0 0.0 0530 06:00 6/4/2018 6/4/2018 2.00 MIRU MOVE MOB P Spot pumps, power, pipe shed, & rock 0.0 0.0 06:00 08:00 washer. SIMOPS install Amphion/NOVOS upgrade in drillers cab. 6/4/2018 6/4/2018 3.00 MIRU MOVE RURD P Spot cuttings tank, hook up all 0.0 0.0 08:00 11:00 interconnects, lower/secure skate rail & test skate. Complete rig acceptance checklist@ 11:00 hrs. 6/4/2018 6/4/2018 1.00 MIRU MOVE NUND P Torque diverter tee& annular flanges. 0.0 0.0 11:00 12:00 Attach diverter line extension. Swap to shore power at 12:00 hrs. 6/4/2018 6/4/2018 -3 00 MIRU MOVE NUND P Obtain RKB's. Nipple up riser 0.0 0.0 12:00 15:00 extension, riser & mouse hole. Align & secure annular. Hook up kill, choke, & cement lines in interconnects. Secure all tools & housekeeping. As of 15:00 hrs decision was made to perform maintenance as bridge has washed out. Release from 1 H-108 and accept onto summer maintenance. 6/16/2018 6/16/2018 2.75 MIRU MOVE BOPE P Perform Diverter Test, Test witnessed 0.0 0.0 12:00 1445 by AOGCC Rep Guy Cook. - Knife valve open in 7 sec; annular closed in 30 sec; initial system pressure 3050 psi; pressure after closure 1950 psi; 200 psi recharge time 6 sec; full recharge 45 sec; 6 nitrogen bottles avg pressure 2033 psi; test gas, flow, & pit level alarms. 1 - FP change out knife valve hydraulic hoses for fire rated hydraulic hoses. 6/16/2018 6/16/2018 0.50 MIRU MOVE SFTY P Pre -spud meeting held with rig crew, 0.0 0.0 14:45 15:15 SLB directional, MI Rep, & CPAI Rep. 6/16/2018 6/16/2018 2.25 MIRU MOVE BHAH P PJSM, pick up surface BHA 1 as per 0.0 91.0 15:15 17:30 SLB DO to 91' MD. 6176/2018 6116/2018 0.50 MIRU MOVE SEQP P Flood high pressure mud lines to top 91.0 91.0 17:30 18:00 drive. Test high pressure mud lines to 3500 psi, good test. 6/16/2018 6/16/2018 2.00 MIRU MOVE DRLG P Clean out conductor w/ 13-1/2" 91.0 119.0 18:00 2000 surface drilling assembly f/91'-119' MD, 11 9'TVD, 450 gpm, 450 psi on, off 425 psi, FO 32%, 40 rpm, Tq 2K, off 1K, WOB 2K, PU 64K, SO 70K, ROT 66K, MW 8.8ppg, Max Gas 0. Page 1135 Report Printed: 8/10/2018 . Uperations Summary (with Timelog Depths) 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phe" Op Code Activity Code Ttme P -T -X Opembon Start Depth (ftKB) End Depth (ftKB) 6/16/2018 6/17/2018 4.00 SURFAC DRILL DDRL P Directional drill 13-1/2" surface hole f/ 119.0 301.0 20:00 00:00 119'-301' MD, 301' TVD, 450 gpm, 550 psi on, 475 psi off, FO 38%, 50 rpm, Tq on 2K, off 1 K, WOB 9K, PU 64K, SO 70K, ROT 66K, MW 8.8 ppg, Max Gas 0, AST 0, ART 2.56, ADT 2.56, BIT 2.56, Jars 2.56. Total Footage 182' 6/17/2018 6/17/2018 6.00 SURFAC DRILL DDRL P Directional drill 13-1/2" surface hole f/ 301.0 797.0 00:00 06:00 301'-797' MD, 796' TVD, 500 gpm, 1100 psi on, 950 psi off, FO 38%, 60 rpm, Tq on 4K, off 3K, WOB 29K, PU 78K, SO 82K, ROT 79K, MW 9.0 ppg, AST 1.53, ART 2.43, ADT 3.96, BIT 6.46, Jars 3.94. Total Footage 496' 6/17/2018 6/17/2018 6.00 SURFAC DRILL DDRL P Directional drill 13-1/2" surface hole f/ 797.0 1,367.0 06:00 12:00 797'-1367' MD, 1346' TVD, 550 gpm, 1400 psi on, 1150 psi off, FO 40%, 60 rpm, Tq on 5K, off 1 K, WOB 29K, PU 93K, SO 93K, ROT 92K, MW 9.4+ ppg, AST 2.35, ART 2.03, ADT 4.38, BIT 10.86, Jars 8.34. Total Footage 570'. 6/17/2018 6/17/2018 5.00 SURFAC DRILL DDRL P Directional drill 13-1/2" surface hole f/ 1,367.0 1,840.0 12:00 17:00 1367'-1840' MD, 1772' TVD, 550 gpm, 1424 psi on, 1360 psi off, FO 37%, 60 rpm, Tq on 5K, off 1 K, WOB 29K, PU 97K, SO 100K, ROT 96K, MW 9.5 ppg, AST 1.58, ART 1.52, ADT 3.10, BIT 13.96, Jars 11.44. Total Footage 473'. 6/17/2018 6/17/2018 0.75 SURFAC CASING BKRM P BROOH f/ 1840'-1703' MD, 552 gpm, 1,840.0 1,703.0 17:00 17:45 1205 psi, FO 36%, 60 rpm, Tq 2K, PU 97, SO 100, ROT 96K. Shoot final survey on bottom. BROOH w/ 1 BU during 1 stand on drill pipe. 6/17/2018 6/17/2018 0.50 SURFAC CASING OWFF P Monitor well, static. 1,703.0 1,703.0 17:45 18:15 6/17/2018 6/17/2018 —2 75 SURFAC CASING BKRM P BROOH f/ 1703'-850' MD, 554 gpm, 1,703.0 850.0 18:15 21:00 1090 psi, FO 37%, 60 rpm, Tq 2K. 6/17/2018 6/18/2018 3.00 SURFAC CASING BHAH P Rack back 2 stands of HWDP, lay 850.0 32.0 21:00 00:00 down remaining HWDP & BHA 1 f/ 850'-32' MD, as per SLB DD. 6/18/2016 6/18/2018 0.50 SURFAC CASING SHAH P Continue laying down BHA 1. Pull mud 32.0 0.0 00:00 00:30 motor, flush & break off bit (3,2,WT,A,E,1,NO,TD). Clean & clear rig floor. 6/18/2018 6/18/2018 1.50 SURFAC CASING RURD P Rig up casing handling equipment for 0.0 0.0 00:30 02:00 10-3/4" surface casing. PJSM for all personnel involved in running casing. 6/18/2018 6118/2018 0.75 SURFAC CASING PUTB P Make up 10-3/4", 45.5#, L-80, Hydril 0.0 125.0 02:00 02:45 563, dopeless shoe track to 125' MD. First 2 joints centralized with 2 bowspring centralizers at 10' from top & bottom. Centralizer installed on each collar after. Connections BakerLok'd & torque to 19,400 fl/lbs. Check floats, good. 6/18/2018 6/18/2018 4.25 SURFAC CASING PUTB P Continue to run 10-3/4", 45.5#, L-80, 125.0 1,790.0 02:45 07:00 Hydri1563, dopeless casing f/ 125'- 1790' MD, PU 117K, SO 102K, connections torque to 19.41K, centralized on each collar, total centralizers ran 44 & 4 stop rings. Page 2135 Report Printed; 8/1 012 01 8 Uperations Summary (with Timelog Depths) IH -108 .. Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op Code Activity Cotle Time P -T -X Operation Steil Depth (fiKB) End Depth(ftKB) 6/18/2018 6/18/2018 0.50 SURFAC CASING PUTB P Make up Vetco fluted casing hanger & 1,790.0 1,834.0 07:00 07:30 landing joint. Wash down at 3 bpm, 145 psi, FO 16%, PU 117K, SO 112K, land hanger w/ shoe depth at 1834' MD, 1776'TVD. 6/18/2018 6/18/2018 0.75 SURFAC CEMENT CIRC P Circulate & condition mud for 1,834.0 1,834.0 07:30 08:15 cementing, stage up pump to 8 bmp, ICP 145 psi, FCP 130 psi, FO 22%, PU 117K, SO 112K, reciprocate pipe 20'. 6/18/2018 6/18/2018 0.25 SURFAC CEMENT RURD P Rig up cement manifold & cement line 1,834.0 1,834.0 08:15 08:30 to Volant CRT. Blow down the top drive. 6/18/2018 6/18/2018 2.75 SURFAC CEMENT CIRC P Circulate & condition mud for 1,834.0 1,834.0 08:30 11:15 cementing, stage u g g p pump to 8 bmp, ICP 309 psi, FCP 270 psi, FO 22%, PU 117K, SO 112K, reciprocate pipe 20'. 6/18/2018 6/18/2018 3.25 SURFAC CEMENT HOSO P PJSM w/ all involved parties for 1,834.0 0.0 11:15 1430 cementing. Pump 5 bbls of H2O to flood lines. Test cement lines to 3500 psi, good. Pump 40 bbls of CW -100, 5 bpm, 120 psi, FO 13%. Pump 76 bbls of 10.5 ppg Mud Push II w/ red dye, 5 bpm, ICP 152 psi, FCP 130 psi, FO 16%. Drop bottom plug. Pump 328 bbls of 11 ppg Lead Cement, 6 bpm, 171 psi, FO 15%. Pump 65 bbls of 12 ppg Tail Cement, 5-6 bpm, ICP 220 psi, FCP 274 psi, FO 15%, PU 117K, SO 97K. Drop top plug. Kick out plug w/ 10 bbls of H2O. Swap to rig & pump treated 9.6 ppg mud, 7 bpm, ICP 250 psi, FCP 391 psi, FO 17%. Reciprocate casing w/ 20 strokes throughout job & land casing on hanger w/ 1000 strokes pumped by rig pump. Slow pump rate to 3 bpm at 1300 strokes, 250 psi, FO 11%. Bump the plug with 1569 strokes, pressuring up to 750 psi. Hold pressure for 5 minutes, bleed off, & floats holding. CIP @ 14:13 hrs. Total of 84 bbls of cement back to surface. 6/18/2018 6/18/2018 0.75 SURFAC CEMENT PRTS P Pressure test 10-3/4" surface casing 0.0 0.0 14:30 15:15 to 3000 psi for 30 minutes, charted. Pressure up w/ 9.6 ppg mud at 7 spm to 3340 psi in 32 strokes. Shut in & observe pressure for 30 minutes. ISICP 3280 psi, FSICP 3280 PSI, bled back 3 bbis. 6/18/2018 6/18/2018 1.25 SURFAC CEMENT KURD P Rig down / blow down testing & 0.0 0.0 15:15 16:30 cementing equipment. RD cement lines & manifold. Lay down Volant CRT. Pull landing joint. Clear rig floor of casing & cementing equipment. 6/18/2018 6178/2018 0.50 SURFAC CEMENT WWWH P Make up stack washing tool & flush 0.0 0.0 16:30 17:00 surface stack w/ black H2O pill at 866 gpm, 115 psi, FO 35%, 30 rpm, Blown down top drive & lay down stack washing tool. 6/18/2018 6/18/2018 3.00 SURFAC CEMENT -KU-NDP Drain stack, remove 4" conductor 0.0 0.0 17:00 20:00 valves, riser, annular, diverter tee & starting head. Rig down diverter line. Page 3135 Report Printed: 8/10/2018 Uperations Summary (with Timelog Depths) 1111-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tlme End Tme Dur (hr) Phase Op Code Activity Code Time e P -T -X Operaboh Start Depth (ftKB) Ertl Depth(fIKB) 6/18/2018 6/18/2018 3.75 SURFAC WHDBOP NUND P Prep casing hanger & install thread 0.0 0.0 20:00 2345 ring. Set wellhead per GE Rep. Orientation verified by CPA] Rep & pad Operator. Install flanges on well head valves. Install sweeping 90's. Top of cement measured 3' below hanger flutes. 6/18/2018 6/19/2018 0.25 SURFAC WHDBOP NUND P Test seal between casing hanger & 0.0 0.0 23:45 00:00 wellhead to 2000 psi for 10 minutes, witnessed by CPAI Rep. 6119/2018 6/19/2018 3.00 SURFAC WHDBOP NUND P Set spacer spool and stack / TO all 0.0 0.0 00:00 03:00 flanges. set riser and install choke / Kill lines, 6/19/2018 6/19/2018 0.50 SURFAC WHDB-OP KURD P Rlg up to test BOPE 0.0 0.0 03:00 03:30 6/19/2018 6/19/2018 4.50 SURFAC WHDBOP BOPE P Test BOPE equipment. BOPE test 0.0 0.0 03:30 08:00 waived witness by AOGCC Matt Herrera. Test performed at 50 psi low / 3,500 PSI high with 3 1/2" & 7" test joint. choke valves 1-14, Upper and lower IBOP valves. Kill valves on floor, Mez, HCR kill, Man kill, XT 43 TIW and dart. Man /Hyd choke test to 2,500 PSI. w3 1/2" and 4 1/2" test jt with lower VBR's. HCR, and man choke. Koomey drawn down test - ISP = 2,900 PSI, after closure 1,950 PSI, 200 PSI in 12 sec. Full pressure in 42 Sec. 6 tiff average of 1,975 PSI. Test pit level alarms & FO system. H2S / combustible gas alarms. H2S tested audible and light. Passed. 6/19/2018 6/19/2018 1.00 SURFAC WHTOB OP RURD P Pull test plug and install 12 1/4" wear 0.0 0.0 08:00 09:00 bushing. RILDS X2. RD testing equip Ian BD same. 6/19/2618 6/19/2018 2.00 SURFAC CEMENT SLPC P Slip & Cut 73' of 1.375" DL. Calibrate 0.0 0.0 09:00 11:00 Amphion system. 6/19/2018 6/19/2018 2.00 SURFAC CEMENT BHAH P PU/MU drilling BHA#2 to 99' MD. 0.0 388.0 11:00 13:00 Pre job safety meet. Monitor disp via pit 1. 6/19/2018 6/19/2018 0.75 SURFAC CEMENT TRIP P RIH with drilling BHA#2 on 4 1/2" DP 388.0 1,443.0 13:00 13:45 from 388' MD - 1,443' MD. Monitor disp via Pit 1, Up WT = 84K. OWN WT = 82K. 6/19/2018 6/19/2018 0.25 SURFAC CEMENT DHEQ P Shallow hole test MWD, @ 1,443' MD. 1,443.0 1,443.0 13:45 1400 with 500 GPM @ 855 PSI DPP 30 F/O. (PASSED). BD TD. 6/19/2018 6/19/2018 5.50 SURFAC CEMENT OTHR P Comission New NOVIS system. Work 1,443.0 1,443.0 14:00 1930 7" casing in pipe shed / house keeping. 6/19/2018 6/19/2018 0.75 SURFAC ZTE M E -NT TRIP P RIH with Drilling BHA#2 from 1,443' 1,443.0 1,730.0 19:30 2015 MD - 1,730' MD monitoring disp via Pit #1. Up WT=86K DWN WT=83K. Conduct 5 min test on OA valve to 3,000 PSI. (PASSED) 6/19/2018 6/19/2018 2.25 SURFAC CEMENT DDRL P Drill out shoe tract system and 20' new 1,730.0 1,860.0 20:15 22:30 hole. 60 RPM 4K TO, 550 GPM @ 1,040 PSI DPP. C/O to 1,860'. UP W T= 86K, DWN WT = 84K. 6/19/2018 6/19/2018 1.00 SURFAC CEMENT CIRC P Circulate BU X2 for mud conditioning. 1,860.0 1,860.0 22:30 23:30 580 GPM @ 1,100 PSI DPP. recip pipe above shoe while rotating 60 RPM. 9.5+ in 9.5+ out. 6/19/2018 6/20/2018 0.50 SURFAC CEMENT FIT P Perform FIT to 220 PSI - 12 PPG 1,860.0 1,860.0 23:30 00:00 EMW. (PASSED) Page 4/35Report Printed: 8/10/2018 operations Summary (with Timelog Uepths) 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op Cotle Acfivity Code Time P -T -X Operation Start Depth (ftKB) End Depth(ftKB) 6/20/2018 6/20/2018 6.00 PROD1 DRILL DDRL P DDRL from 1,860'MD-2,692'MD 1,860.0 2,692.0 00:00 06:00 2,372' TVD, 650 GPM @ 981 PSI DPP. 29% F/O 140 RPM @ 3K TO. 2 -6K WOB with ECD's 10.24 PPG. Off bottom - 950 PSI, UP WT = 96K, OWN WT=90K. ROT -92K. 2K TO, Max gas = 404 units. ADT - 4, Bit Hrs - 4, Jar hrs. - 48.52 SPRs @ 2,120' MD 2,004' TVD MW = 9.1 Time 0300 hrs MP 1) 30 SPM - 90 PSI 40 SPM - 120 PSI MP 2) 30 SPM - 90 PSI 40 SPM - 120 PSI 6/20/2018 6/20/2018 6.00 PROD? DRILL DDRL -p7-- DDRL from 2,692' MD 2,372TVD - 2,692.0 3,738.0 06:00 12:00 3,738' MD 2,956' TVD. 650 GPM @ 1,257 PSI DPP 30% F/O 140 RPM @ 5K TQ. 14K WOB with ECD's 10.86 PPG. Off bottom - 1,277 PSI, UP WT =111 K, DWN WT=92K. ROT -99K. 3K TO, Max gas = 51 units. ADT - 4.21, Bit Hrs - 8.21, Jar hrs. - 52.73 SPRs @ 2,782' MD 2,427' TVD MW = 9.0 Time 0630 hrs MP 1) 30 SPM - 120 PSI 40 SPM - 160 PSI MP 2) 30 SPM - 120 PSI 40 SPM - 150 PSI 6/20/2018 6/20/2018 6.00 PROD1 DRILL DDRL P DDRL from 3,738' MD 2,956' TVD - 3,738.0 4,403.0 12:00 18:00 4,403' MD 3,216' TVD. 650 GPM @ 1,408 PSI DPP 30% F/O 140 RPM @ 5K Ti 14K WOB with ECD's 10.51 PPG. Off bottom - 1,390 PSI, UP WT =11 OK, DWN WT=90K. ROT -99K. 3K TO, Max gas = 105 units. ADT - 3.22, Bit Hrs - 11.43, Jar hrs. - 55.95 6/20/2018 6/21/2018 6.00 PROD1 DRILL DDRL P DDRL from 4,403' MD 3,216' TVD - 4,403.0 5,332.0 18:00 00:00 5,332' MD 3,575' TVD. 650 GPM @ 1,492 PSI DPP. 30% F/O 140 RPM @ 6K TQ. 14K WOB with ECD's 10.83 PPG. Off bottom - 1,450 PSI, UP WT =117K, DWN WT=93K. ROT - 105K. 5K TO, Max gas = 43 units. ADT - 3.49, Bit Hrs - 14.92, Jar hrs. - 59.44 SPRs @ 4,591' MD 3,291' TVD MW = 9.1 Time 1900 hrs MP 1) 30 SPM - 200 PSI 40 SPM - 240 PSI MP 2) 30 SPM - 200 PSI 40 SPM - 240 PSI Page 5135 ReportPrinted: 8/10/2018 . uperations Summary (with Timelog Depths) 1 H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Our hr) phase Op Cade Acevky Code Time P-T-X Operation Start Depen (eKB) End Depth(N(B) 6/21/2018 6/21/2018 6.00 PRODt DRILL DDRL P DDRL from 5,332'MD 3,575'TVD- 5,332.0 6,208.0 00:00 06:00 6,208' MD 3,916' TVD. 650 GPM @ 1,635 PSI DPP. 30% F/O 160 RPM @ 8K TQ. 10K WOB with ECD's 10.94 PPG. Off bottom - 1,620 PSI, UP WT = 130K, DWN WT= 96K. ROT- 108K. 5K TO, Max gas = 154 units. ADT - 3.55, Bit Hrs - 18.47, Jar hrs. - 62.99 6/21/2018 6/21/2016 1.50 PRODt DRILL DDRL P DDRL from 6,208' MD 3,916' TVD - 6,208.0 6,527.0 06:00 07:30 6,527' MD 4,043' TVD. 650 GPM @ 1,820 PSI DPP. 30% F/O 160 RPM @ 8K TQ. 18K WOB with ECD's 11.04 PPG. Off bottom - 1,760 PSI, UP WT = 130K, DWN WT = 100K. ROT - 108K. 6K TQ, Max gas = 144 units. ADT - 1, Bit Hrs - 19.47, Jar hrs. - 63.99 6/21/2018 6/21/2018 0.75 PROD1 CASING CIRC P Final survey and SPR's, BROOH from 6,527.0 6,497.0 07:30 08:15 6,527' MD - 6,497' MD. at 650 GPM @ 1,760 PSI DPP. 30% F/O, 130 RPM, 6K TO. UP WT = 130K, DWN WT = 1 OOK. ROT= 108K. Total strokes pumped = 3,875 6/21/2018 6/21/2018 0.50 PRODt CASING OWFF P OWFF (Static) 6,497.0 6,497.0 08:15 08:45 6/21/2018 6/21/2018 3.25 PROD1 CASING BKRM P BKRM OOH from 6,497' MD - 5,245' 6,497.0 5,245.0 08:45 12:00 MD with 650 GPM @ 1,790 PSI DPP. with FCP 1,638 PSI DPP 30% F/O 11.08 ECD. 120 RPM 5K TO. UP WT = 95K. 6/21/2018 6/21/2018 6.00 PROD1 CASING BKRM P BKRM OOH from 5,245' MD - 3,170' 5,245.0 3,170.0 12:00 18:00 MD 650 GPM @ 1,374 PSI DPP, 30 % F/O, 120 RPM, 10.80 ECD, 4K TQ, —3 88K UP WT while BKRM. 6/21/2018 6/21/2018 00 PR051 CASING BKRM P BKRM OOH from 3,170'MD - 1,824' 3,170.0 1,824.0 18:00 21:00 MD. 650 GPM @ 1,374 PSI DPP. 30% FIO, 120 RPM With ECD 10.80 —1 PPG. 4K TQ UP WT = 88k. 6/21/2018 6/21/2018 00 PROD1 CASING CIRC P Circulate while recip in shoe @ 700 1,824.0 1,824.0 21:00 22:00 GPM, 1,200 PSI DPP, 110 RPM with UP WT=82K. DWN WT=80K. pump 6,000 STKS. observe well 10 min (Static). 6/21/2018 6/21/2018 1.00 PROW CASING TRIP P POOH from 1,824' MD - 388' MD 1,824.0 388.0 22:00 23:00 rackin gback 4.5" DR Monitor well at HWDP 10 min. 018 018 1.00 PROD1 CASING BHAH P Begin breaking down 8 3/4" BHA 388.0 226.0 23:00 23:00 00:00 00:00 6/22/2018 6/22/2018 1.50 PROD1 CASING SHAH P Continue to LD 8 3/4" drilling BHA. 226.0 0.0 00:00 01:30 Gear and dean rig floor. 6/22/2018 6/22/2018 1.00 PRODt PLUG RURD X RU 3 1/2" handling equipment for 3 0.0 0.0 01:30 02:30 1/2" EUE cement stinger asym. 6/22/2018 622/2018 4.75 PROD? PLUG TRIP X MU and RIH with 1,193.92' of 3 1/2" 0.0 6,250.0 02:30 07:15 9.3# L-80 cement stinger asym for P&A program. PUsh in hoe with 4 1/2" DPto 6,250' MD in preparation for plug program. Page 6/35 Report Printed: 8/10/2018 Uperations Summary (with Timelog bepths) 111-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Stag Depth (ftKB) End Dept (fi 6/22/2018 6/22/2018 2.25 PROD1 PLUG CIRC X Recip pipe from 6,250'MD-6,155' 6,250.0 5,722.0 07:15 09:30 MD Circulating up to 650 GPM ICP - 193 PSI DPP. with FCP - 1,058 PSI DPP. 32% F/O. Pumped 7800 STKS for initial. Spot 50 BBL of 12 PPG high vis pill @ 355 GPM 420 PSI @ 24% F/O. chase with 78 BBLs of LSND @ 355 GPM 542 PSI @ 23% F/O. PUH to 5,722' MD UP WT = 119K OWN WT = 88K. BD Top drive and RU cement manifold / hose. 6/22/2018 6/22/2018 1.50 PROD1 PLUG CIRC X Condition mud and circulate while 5,722.0 5,722.0 09:30 11:00 stage pumps up to 7 BPM ICP = 167 FCP = 420 18% F/O. PJSM for cement program. 6/22/2018 6/22/2018 3.00 PROD1 PLUG CMNT X Begin 1st cement plug testing lines to 5,722.0 5,206.0 11:00 1400 800 - 3000 PSI, Pump 26 BBLS 12.5 PPG mud push @ 3 BPM ICP = 150 PSI DPP, FCP = 50 PSI DPP. cose bag and batch up cement. Open bag and pump 50 BBLS of 15.8 Class G cement @ 3.5 BPM ICP = 50 PSI DPP, FCP = 102 PSI DPP Close bag and drop foam ball. / Open bag to pump 4 BBLS 12.5 PPG mud push, Swap to rig pumps and pump 58 BBLS LSND @ 7 BPM, ICP = 60 PSI DPP, FCP = 300 PSI DPP. catch up to vement after 400 stks away reduce rate to 4 BPM 12% F/O. PUH on elevators at 1300 hrs from 5,722' MD to 5,206' MD. UP WT = 111 K. Stage up pumps to 7 BPM With ICP 196 PSI DPP, FCP - 420 PSI DPP. 18% F/O. pump 3400 stks. 6122/2018 6/2212018 2.25 PROD1 PLUG CMNT X Begin 2nd cement plug pumping 26 5,206.0 4,610.0 14:00 16:15 BBLs 12.5 PPG mud push II. @ 3 BPM with ICP 222 PSI DPP, FCP - 50 PSI DPP. 10% F/O. Close bag and batch up cement. Open bag pump 50 BBLS of 15.8 PPG Class G cement. with ICP 50 PSI DPP FCP 120 PSI DPP. 14% F/O. Close bag drop foam ball, Open bag and pump 4 BBLS 12.5 PPG Mud push it Swap to rig pumps. pump 51 BBLS of LSND @ 7 BPM. ICP = 153 PSI. catch cement @ 260 stks. Reduce rate to 4 BPM FCP = 374 15% F/O. PUH on elevators from 5206'- 4,610' MD. UP WT = 104K. Circulate staging pumps up to 650 GPM @ ICP 1,230 PSI FCP - 600 PSI DPP 31 % F/O, Reduce rate due to contaminated mud returning to surface at 350 GPM. 352 PSI DPP. 22% F/O, 3,575 STKS pumped. 6/22/2018 6/22/2018 2.25 PROD1 PLUG CIRC X Spot 45 BBL 12 PPG hi vis pill at 350 4,610.0 4,132.0 16:15 18:30 GPM 382 PSI DPP. 22% F/O. Chase pill with 56.8 LSND mud at 350 GPM 380 PSI DPP 22% F/O. POUH on elevators from 4,610' MD - 4,132' MD. UP WT = 99K, OWN WT = 80K. Condition mud and circulate pumping 441 GPM 565 PSI DPP, 27% F/O, Reduce rate due to contaminated mud returns to 350 GPM 350 PSI DPP, 23% F/O. 5,580 STKS pumped. Page 7/35 Report Printed: 8/10/2018 Operations Summary (with Timelog Depths) 1 H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log StartTime End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (flKB) 6/22/2018 6/22/2018 2.25 PROD1 PLUG CMNT X Begin 3rd cement isolation plug pump 4,132.0 3,400.0 18:30 20:45 25 BBLS 12.5 PPG Mud push ii. 4 BPM @ 220 PSI, 12% F/0, close bag. Batch up cement. CEMENT WET 1852 HRS. Pump 70.3 BBLS 15.8 PPG class G cement at 4 BPM, 390 PSI DPP. Close bag drop foam ball, Open bag and pump 5 BBLS of 12.5 PPG Mud push II then swap to rig pumps pumping 33 BBLS of 9.3 PPG LSND @ 7 BPM, catch cement at 180 STKS ICP = 300 PSI DPP FCP = 750 PSI. PUH from 4,132' MD - 3,400' MD monitor disp via pit #5, UP WT = 85K. OWN WT = 80K. Break over weight at 119K. 6/22/2018 6/22/2018 1.25 PROD1 PLUG CIRC X Circulate @ 3,400' MD at 450 GPM 3,400.0 3,400.0 20:45 22:00 560 PSI 27% F/O. Total stks 6,600. UP WT = 84K. OWN WT = 79K. 6/22/2018 6/22/2018 0.25 PROD1 PLUG OWFF X BD top drive and OWFF. 3,400.0 3,400.0 22:00 22:15 6/22/2018 6/22/2018 1.25 PROD1 PLUG TRIP X POOH from 3,400'to 1, 190'MD 1,190.0 1,190.0 22:15 2330 standing back DP. Monitor disp via pit 5 6/22/2018 6/23/2018 0.50 PROD1 PLUG TRIP X Stand back 3 1/2" L-80 tubing from 1,190.0 722.0 23:30 00:00 1,190' MD - 722' MD. Monitor disp viat Pit 5. 6/23/2018 6/23/2018 0.75 PROD1 PLUG TRIP X Continue to POOH with 3.5" 9.3# L-80 722.0 0.0 00:00 00:45 cement string standing back in derrick from 722' MD - surface. 6/23/2018 6/23/2018 0.75 PROD1 PLUG WWWH X MU Jhnny Wacker tool and wash 0.0 275.0 00:45 01:30 BOP's. 21 BPM then RIH three stands. 6/23/2018 6/23/2018 17.50 PROD1 PLUG WOC X Wait on cement to cure. SIMOPs 275.0 0.0 01:30 1900 NOVO's troubleshooting / training. 6/23/2018 6/23/2018 2.50 PROD1 PLUG TRIP X MU 3/5" cement muleshoe and RIH 0.0 3,282.0 19:00 21:30 with 3 1/2" 9.3# L-80 cement string. Monitor displacement via pit #1. 6/23/2018 6/23/2018 0.50 PROD1 PLUG CIRC X Circulate bottoms up stage pumps to 3,282.0 3,282.0 21:30 2200 450 GPM @ 480 PSI DPP. 27% FIG, UP WT = 83K, DWN WT 77K, MW in - 9.1 MWOut=9.3VERY CLOBBERISHI 6/23/2018 6/23/2018 0.75 PROD1 PLUG WASH X Wash down from 3,282' MD at 2 BPM 3,282.0 3,402.0 22:00 2245 110 PSI DPP. 7% F/0, tag TOC at 3,402' MD. rotate string 180 Deg and confirm tag at 3,402' MD with 7-8K dwn wt. 6/23/2018 6/23/2018 0.25 PROD1 PLUG TRIP X POOH from 3,402' MD - 2,806' MD UP 3,402.0 2,806.0 22:45 23:00 WT= 75K. OWN WT= 73K. 6/23/2018 6/23/2018 0.50 PROD1 PLUG CIRC X Spot 50 BELS hi vis 13.5 PPG pill and 2,806.0 2,806.0 23:00 23:30 chase with 315 stks -SND. 6/23/2018 6/24/2018 0.50 PROD? PLUG TRIP X POOH from 2,806 MD - 2,334' MD UP 2,806.0 2,334.0 23:30 00:00 1 1 WT=68K. OWN WT=67K. 6/24/2018 6/24/2018 0.25 PROD1 PLUG TRIP X Continue to PUH to 2,267' MD. 2,334.0 2,267.0 00:00 00:15 6/24/2018 6/24/2018 1.00 PRODi PLUG RURD X Blow down top drive and rig up 2,267.0 2,267.0 00:15 01:15 cement equipment. Blow down cement line and hold PJSM for cement program. Page 8135 Report Printed: 8/10/2018 Operations Summary (with Timelog Depths) IH -108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Di (hi Phase on Code Activity Code Time P -T -X Operation inks) End Depth(XKB) 6/24/2018 6/24/2018 1.25 PROD1 PLUG CMNT X Pump kick off plug. Pressure test all 2,267.0 2,267.0 01:15 02:30 lines to 3,500 PSI, Pump 25 BBLs of 12.5# at 3.3 BPM 90 PSI DPP, close bag and batch up cement. pump 50 BBLS of 17# class G cement @ 3.3 BPM 70 PSI, Close bag and drop foam wiper ball. Open bag and pump 4 BBLS 12.5# Mud push II, chase with 1 BBL afresh water to clear surface lines. Swap to rig pumps and displace with 13 BBLs @ 4 BPM 215 PSI. Catch cement at 8 BBLS into displacement. Cement wet at 0138 hrs. Cement in plae 0228 hrs. 6/24/2018 6/24/2018 0.75 PRODI PLUG TRIP X POOH from 2,267' MD to 1,661' MD 2,267.0 1,661.0 02:30 03:15 Monitor displacement via Pit 1 UP WT = 58K, DWN WT = 60K. 6/24/2018 6/24/2018 0.75 PROD1 PLUG CIRC X Circulate three bottoms up while recip 1,661.0 1,661.0 03:15 0400 from 1,661' MD - 1,600' MD. Monitor returns via pit #1. UP WT = 58K, DWN WT = 60K. 450 GPM @ 210 PSI DPP, 26% F/0, total stks pumped =3100. MW in=9.1+MW out =9.2 PPG. 6/24/2018 6/24/2018 3.50 PROD1 PLUG PULD X BD top drive monitor well (static) and 1,661.0 0.0 04:00 0730 POOH from 1,661' MD to surface. Monitor disp via Pit #1. LD all 3.5" L- 80 tubing down sideways from 1,193' MD to surface and kick out. 6/24/2018 6/24/2018 1.50 PROD1 PLUG RURD X Rig down GBR and release. clean rig 0.0 0.0 07:30 0900 Floor. 6/24/2018 6/25/2018 15.00 PROD1 PLUG WOC X Wait on cement to cure. Crews 0.0 0.0 09:00 0000 performing maintenance / cleaning / paint / training. 6/25/2018 6/25/2018 7.00 PROD1 PLUG WOC X Continue to WOC. Sim ops rig 0.0 0.0 00:00 07:00 maintenance. 6/25/2018 6/25/2018 0.25 PROD1 PLUG SFTY X PJSM 0.0 0.0 07:00 0715 6/25/2018 6/25/2018 1.25 PROD1 PLUG BHAH X MU Drilling BHA#3 as per SLB rep. to 0.0 379.0 07:15 0830 379' MD. Monitor disp via pit#1. 6/25/2018 6/25/2018 1.00 PROD1 PLUG TRIP X Continue to RIH from 379' MD to 379.0 1,625.0 08:30 09:30 1,625' MD running 4 1/2" DP out of derrick. UP WT=81 K. DWN WT= 84K. Monitor disp via pit #1. 6/25/2018 6/25/2018 0.25 PROD1 PLUG DHEQ X Shallow hole test @ 525 GPM, 785 1,625.0 1,625.0 09:30 09:45 PSI SPP. 29% F/O test good. 6/25/2018 6/25/2018 1.25 PROD1 PLUG CIRC X Condition mud and circulate @ 650 1,625.0 1,625.0 09:45 11:00 GPM, 1,025 PSI DPP @ 30% F/O, Total stks 10,075. 6/25/2018 6/25/2018 0.50 PROD1 PLUG WASH X Wash down from 1,625' MD to 1,772' 1,625.0 1,772.0 11:00 11:30 MD TOC. Set 5K DWN. UP WT = 81 K, DWN WT = 84K, ROT - 81 K. 6/25/2018 6/25/2018 0.50 PROD1 PLUG DRLG X Drill cement from 1,772' MD- 1,817' 1,772.0 1,817.0 11:30 1200 MD with 520 GPM @ 750 PSI DPP 31 % F/Q, 60 RPM, 2-4K TO 4K WOB, Off BTM Press 743 PSI, ECD 10.18, UP WT=81K, DWN WT= 84K, rotation WT = 84K. 6/25/2018 6/25/2018 2.00 PROD? PLUG DRLG X Drill cement form 1,817 MD - 1,900' 1,817.0 1,900.0 12:00 14:00 MD W 520 GPM @ 750 PSI DPP. 31 % F/0, 60 RPM, 2-4K TO, 4K WOB. Off BTM = 743, ECD = 10.18, UP WT = 81 K, DWN WT = 84K, ROT WT = 84K Page 9135 Report Printed: 8/10/2018 Operations Summary (with Timelog Depths) 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dm (hr) Phase Op Code Activity Cotle Time P -T -X Operation SW Depth (ftKB) End Depth(ftKB) 6/25/2018 6/25/2018 4.00 PROD2 DRILL DDRL X DDRLfrom 1,900'MD-2,181'MD 1,900.0 2,181.0 14:00 1800 2,060 TVD, 550 GPM @ 38% F/O, 100 RPM 3K TO, 4K WOB, ECD = 10.07 Off Stm = 670 PSI, UP WT = 90K, DWN WT = 84K, ROT- 87K, Max Gas = 5 units, ADT - 1.98, Bit Hrs - 1.98, Jar hrs - 65.99 SPR's @ 2,000' MD 1,911' TVD MW = 9. PPG Time 1545 hr MP1) 30 SPM 80 PSI 40 SPM 110 PSI MP2) 30 SPM 80 PSI 40 SPM 110 PSI 6/25/2018 6/26/2018 6.00 PROD2 DRILL DDRL X DDRL from 2,181'MD 2,060 TVD- 2,181.0 3,159.0 1800 0000 3,159' MD 2,586' TVD, 650 GPM @ 29% F/O, 140 RPM 4K TO, 5K WOB, ECD = 10.25 Off Btm = 1,020 PSI, UP WT = 99K, DWN WT = 85K, ROT - 89K, Max Gas = 170 units, ADT - 3.37, Bit Hrs - 5.35, Jar hrs - 69.36 SPR's @ 2,298' MD 2,148' TVD MW = 9.2 PPG Time 1835 hr MP1) 30 SPM 80 PSI 40 SPM 120 PSI MP2) 30 SPM 80 PSI 40 SPM 120 PSI 6/26/2018 6/26/2018 6.00 PROD2 DRILL DDRL X DDRL from 3,159'MD 2,586'TVD- 3,159.0 4,153.0 00:00 06:00 4,153' MD 2,821' TVD, 650 GPM @ 1,180 PSI DPP 29% FIG, 140 RPM 6K TO, 13K WOB, ECD = 10.61 Off Btm = 1,170 PSI, UP WT = 108K, DWN WT= 78K, ROT 89K, 4K TO Max Gas = 20 units, ADT - 3.26, Bit Hrs - 8.61, Jar hrs - 72.62 6/26/2018 6/26/2018 6.00 PROD2 DRILL DDRL X DDRL from 4,153' MD 2,821' TVD - 4,153.0 5,022.0 06:00 12:00 5,022' MD 3,099' TVD, 650 GPM @ 1,180 PSI DPP 29% F/O, 140 RPM 6K TO, 8K WOB, ECD = 10.61 Off Btm = 1,170 PSI, UP WT= 108K, DWN WT= 78K, ROT -89K, 4K TO Max Gas = 20 units, ADT - 3.48, Bit Hrs - 12.09, Jar hrs - 76.10 SPR's @ 4,198' MD 2,831' TVD MW = 9.2 PPG Time 0620 hr MP1) 30 SPM 160 PSI 40 SPM 200 PSI MP2) 30 SPM 160 PSI 40 SPM 190 PSI 6/26/2018 6/26/2018 6.00 PROD2 DRILL DDRL X DDRL from 5,022' MD 3,099' TVD 5,022.0 5,725.0 12:00 18:00 5,725' MD 3,362' TVD, 650 GPM @ 1,450 PSI DPP 29% F/O, 140 RPM 7K TO, 1 OK WOB, ECD = 10.04 Off Btm = 1,400 PSI, UP WT = 122K, DWN WT = 83K, ROT- 99K, 8K TO Max Gas = 112 units, ADT - 3.89, Bit Hrs - 15.98, Jar hrs - 79.99 Page 10135 ReportPrinted: 8/1 012 01 8 Uperations Summary (with Timelog Lepths) 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time 6/26/2018 End Time 6/27/2018 Cur(hr) 6.00 Phase PROD2 Op Cptle Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth(ftKB) 18:00 00:00 DRILL DDRL X DDRL from 5,725' MD 3,362' TVD - 5,725.0 6,550.0 6,550' MD, 650 GPM @ 1,565 PSI DPP 27% F/O, 150 RPM 9K TO, 20K WOB, ECD = 10.69 Off Btm = 1,560 PSI, UP WT= 136K, DWN WT= 90K, ROT- 106K, 7K TO Max Gas = 70 units, ADT - 3.45, Bit Hrs - 19.43, Jar hrs - 83.44 SPR's @ 5,726' MD 3,362" TVD MW = 9.2 PPG Time 1800 hr MPI) 30 SPM 160 PSI 40 SPM 210 PSI MP2) 30 SPM 170 PSI 40 SPM 210 PSI 6/27/2018 00:00 6/27/2018 6.00 PROD2 DRILL DDRL X DDRL from 6,550MD 3,701' TVD - 6,550.0 7,439.0 06:00 7,493 MD 4,033' TVD, 650 GPM @ 1,790 PSI DPP 29% F/0, 140 RPM 9.5K TQ, 15K WOB, ECD = 10.92 Off Btm = 1,780 PSI, UP WT = 148K, DWN WT= 88K, ROT -111 K, 7K TO Max Gas = 180 units, ADT - 3.69, Bit Hrs - 23.12, Jar hrs - 87.13 Drilled 350' w/NOVO's 6/27/2018 6/27/2018 6.00 PROD2 DRILL DDRL X DDRL from 7,493 MD 4,033' TVD - 7,439.0 8,076.0 06:00 12:00 8,076' MD 4,066' TVD, 650 GPM @ 1,678 PSI DPP 30% F/0, 100 - 150 RPM 9.5K TQ, 12-16K WOB, ECD = 10.87 Off Btm = 1,649 PSI, UP WT = 143K, DWN WT = 79K, ROT- 105K, 9K TO Max Gas = 317 units, ADT - 4.15, Bit Hrs - 27.27, Jar hrs - 91.28 Drilled 350' w/NOVO's SPR's @ 7,435' MD 4,-051" TVD MW = 9.2+ PPG Time 0600 hr MP1) 30 SPM 240 PSI 40 SPM 280 PSI MP2) 30 SPM 240 PSI 40 SPM 280 PSI 6/27/2018 6/27/2018 6.00 PROD2 DRILL DDRL X DDRL from 8,076' MD 4,066' TVD - 8,076.0 8,741.0 12:00 18:00 8,741' MD 3,948' TVD, 650 GPM @ 2,000 PSI DPP 29% F/0, 150 RPM 11K TO, 12K WOB, ECD = 10.81 Off Btm = 1,995 PSI, UP WT = 138K, DWN WT = 73K, ROT- 101 K, 8K TO Max Gas = 236 units, ADT - 3.96, Bit Hrs - 31 .23, Jar hrs - 95.24 6/27/2018 18:00 6/27/2018 4.00 PROD2 DRILL DDRL X DDRL from 8,741' MD 3,948' TVD - 8,741.0 9,245.0 j4 22:00 9,245' MD 3,787' TVD, 650 GPM @ 2,135 PSI DPP 28% F/O, 150 RPM 12K TQ, 13K WOB, ECD = 11.12 Off Btm = 2,130 PSI, UP WT = 132K, DWN WT = 60K, ROT- 95K, 9K TO Max Gas = 220 units, ADT - 2.76, Bit Hrs - 33.99, Jar hrs - 98 Page 11/35 Report Printed: 8/10/2018 Operations Summary (with Timelog Depths) 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time Dur (hr) Phase Op Code AMity Code Time P -T -X Operation Star) Depth (MS) End Depth(flK8) 6/27/2018 6/27/2018 1.00 PROD2 SI CANG CIRC X Cycle pipe from 9,146' MD to 9,245' 9,245.0 9,146.0 22:00 23:00 MD while circulating bottoms up @ 650 GPM, 28% FIG, 12 RPM, 8K TO, 10.8 ECD. UP WT= 127, DNW WT= 55K, ROT 96K. 6/27/2018 6/27/2018 0.50 PROD2 CASING OWFF X OWFF (Static) 9,146.0 9,146.0 23:00 23:30 6127/2018 6/28/2018 0.50 PROD2 CASING BKRM X BKRM OOH from 9,146' MD -9,016 9,146.0 9,016.0 23:30 00:00 UP WT = 90K, 645 GPM @ 2,053 PSI DPP, ECD - 10.79 gas 27 units. 6/28/2018 6/28/2018 3.00 PR0D2 CASING BKRM X Continue to BKRM OOH from 9,016' 9,016.0 7,822.0 00:00 0300 MD - 7,822' MD. UP WT = 140K, DWN WT = 82K. 650 GPM @ 1,875 PSI DPP. 140 RPM with 8K TQ. ECD = 10.64 6/28/2018 6/28/2018 1.50 PROD2 CASING CIRC X Circulate bottoms up with a high vis 7,822.0 7,628.0 03:00 0430 sweep. 7,822' MD - 7,628' MD. UP WT = 143K, DWN WT = 83K. pumped 11,500 STKS, with a MWI 9.2 MWO = 9.3 10.45 ECD, 650 GPM @ 28% F/O, 150 RPM with 8K TQ, 6/28/2018 6/28/2018 0.50 PROD2 CASING TRIP X POOH on elevators from 7,628' MD - 7,628.0 7,477.0 04:30 0500 7,477' MD. Swabbing and 25K overpull. go back to BKRM 6/28/2018 6/28/2018 7.00 PROD2 CASING BKRM X BKRM OOH from 7,477' MD - 4,777' 7,477.0 4,777.0 05:00 12:00 MD. 650 GPM @ 1,526 PSI DPP. 28% F/O, 140 RPM, 5K TO, ECD = 10.62 UP WT = 91K w/pump, DWN WT=81 K. 6/28/2018 6/28/2018 8.75 PROD2 CASING BKRM X BKRM OOH from 4,777' MD - 1,736' 4,777.0 1,736.0 12:00 2045 MD. Rale of BKRM = 750 FT/HR - 500 FT/HR. 650 GPM @ 1,525 - 1,030 PSI DPP. F/028%. 140-100 RPM. UP WT 83-88K, DWN WT = 84K. Slow down for coal areas 3,541' - 3,066'/ 3,066 - 2400'. Recip pipe while pumping high vis sweep at shoe. 6/28/2018 6/28/2018 0.50 PROD2 CASING OWFF X OWFF (dropped 2"). Service TD sim 1,736.0 1,736.0 20:45 21:15 1 op 6/28/2018 6/28/2018 0.50 PROD2 CASING CIRC X Pump slug to surface then BD top 1,736.0 1,736.0 21:15 21:45 Drive. 6/28/2018 6/28/2018 1.00 PROD2 CASING TRIP X POOH from 1,736' MD - 379' MD. 1,736.0 379.0 21:45 22:45 Monitor disp via TT. 6/28/2018 6/28/2018 0.25 PROD2 CASING OWFF X OWFF. Dropped 1". 379.0 379.0 22:45 23:00 6/28/2018 6/29/2018 1.00 PROD2 CASING BHAH X LD BHA frin 379' - 94' MD as per DD. 379.0 94.0 23:00 00:00 Monitor well via TT 6/29/2018 6/29/2018 1.25 PROD1 CASING BHAH X Continue to lay down BHAfrom 94' As 94.0 0.0 00:00 01:15 per SLB. Monitor disp via TT. Clear and clean rig floor, 6/29/2018 6/29/2018 0.75 PROD1 PLUG RURD X RU to run 3 1/2" cement string. Bring 0.0 0.0 01:15 02:00 GBR to rig floor. Spot equip. PJSM 6/29/2018 6/29/2018 2.00 PROD2 PLUG PULD X MU 3 1/2" Cement string BHA of 3 0.0 1,225.0 02:00 0400 1/2" 9.3# EUE from surface to 1,225' MD 6/29/2018 6129/2018 3.25 PROD2 PLUG TRIP X RIH with 41/2" DP from 1,225' MD- 1,225.0 8,000.0 04:00 07:15 8,000' MD. Monitor disp via TT. UP WT = 129K, DWN WT = 83K. 6/29/2018 6/29/2018 1.50 PROD2 PLUG CIRC X Cir bottoms up while recip from 7,925' 8,000.0 8,000.0 07:15 08:45 MD - 8,000' MD. 308 GPM @ 430 PSI DPP. 20% F/O, Pump 5,427 STKS. Page 12/35 ReportPrinted: 8/10/2018 . Operations Summary (with Timelog Depths) 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Sten Time End Time Dur(hr) Phase Op Code Acb,ody Code Time P -T -X Operaton (fIKB) End Dept(fIK8) 6/29/2018 6/29/2018 0.50 PROD2 PLUG CIRC X Spot 48 BBL pill of 12# Hi Vis spacer 8,000.0 8,000.0 08:45 09:15 and chase with 102.5 BBLS 6/29/2018 6/2912018 0.50 PROD2 PLUG TRIP X PUH from 8,000' MD - 7,497' MD. 8,000.0 7,497.0 09:15 09:45 Monitor disp via pit #1. 6/29/2018 6/29/2018 0.75 PROD2 PLUG CIRC X RU cement manifold and circ 284 7,497.0 7,497.0 09:45 1030 GPm @ 450 PSI DPP. 18% F/O, PJSM for cement job with SLB/MI/DDI. 6/29/2018 6/29/2018 1.50 PROD2 PLUG CMNT X Pump tat stage of cement plug 7,497.0 7,497.0 10:30 12:00 program @ 7,497' MD. Flood all lines and PT to 3,500 PSI. Close bag and take all returns thru choke. Pump 27 BBLS 12.5# MP2 @ 4.2 BPM 100 PSI. Batch and pump 48.3 BBLS 15.89 cement at 4.5 BPM, 100 PSI. drop wiper ball and pump 3 BBLS of MP2. Swap to rig for displacement with 82.7 BBLS LSND. Pump 4 BPM @ 220 PSI, @ 772 stks reduce rate to 2 BPM, 197 PSI. Cement wet at 1112 HRS 6/29/2018 6/29/2018 0.75 PROD2 PLUG TRIP X PUH from 7,497' MD - 7,000' MD. 7,497.0 7,000.0 12:00 12:45 1,500 FPH pulling speed. Monitor disp via Pit #1. UP WT = 129K, DWN WT = 79K. 6/29/2018 6/29/2018 1.00 PROD2 PLUG CIRC X Circulate bottoms up while recip from 7,000.0 7,000.0 12:45 13:45 6,930' MD - 7,000' MD. Stage up pumps to 650 GPM @ 1,380 PSI. 29% F/0. 6/29/2018 6/29/2018 0.50 PROD2 PLUG CIRC X Spot 40 BBL pill of 12# Hi Vis spacer 7,000.0 7,000.0 13:45 14:15 and chase with 89.8 BBLS LSND. 892 STKS @ 239 GPM 300 PSI, 13% F/O. 6/29/2018 6/29/2018 0.75 PROD2 PLUG TRIP X PUH from 7,000' MD to 6,580' MD. 7,000.0 6,580.0 14:15 15:00 MU 10' PUPjt. UP WT= 129K, DWN W T= 81 K. Monitor disp via Pit #1. 6/29/2018 6/29/2018 0.50 PROD2 PLUG CIRC X From 6,585' circulate bottoms up at 6,580.0 6,580.0 15:00 15:30 630 GPM. 1,290 PSI at 32% F/0. total stks 4,071. 6/29/2018 6/29/2018 1.25 PROD2 PLUG CMNT X PJSM . RU cement hose and 6,580.0 6,580.0 15:30 16:45 manifold, Close arm, open choke and pump cement plug #2. 27 BBPS 12.5# MPII @ 4.2 BPM 50-156 PSI DPP. Close choke and batch up cement. With super choke 1/2 open pump 59.5 BBLS of 15.8# class G cement. 4.7 - 4.2 BPM @ 84-111 PSI DPP. Close super choke to drop wiper ball. Pump 3 BBLS MPII spacer and 1 BBL water. swap to rig pumps and displace at 5 BPM, 220-250 PSI DPP. 4 BPM at 642 stks.340 PSI DPP. 2 BPM from 691 STKS at 232 FCR. 6/29/2018 6/29/2018 0.75 PROD2 PLUG TRIP X PUH to 5,972' MD UP WT= 118K. 6,580.0 5,972.0 16:45 17:30 DWN WT = 83K. Monitor disp via Pit #1. 6/29/2018 6/29/2018 1.25 PROD2 PLUG CIRC X Circulate bottoms up while recip from 5,972.0 5,972.0 17:30 18:45 5,942' MD - 5,972' MD. at 626 GPM 1,400 PSI DPP. 32% F/0. Reduce rate at 2,700 sties due to interface overflowing drag chain system. Increase rate to 633 GPM at 5,400 stks 1,380 PSI. 32% F/O. 7,379 total stks pumped. Page 13/35 ReportPrinted: 8110/2018 Operations Summary (with Timelog Depths) 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur(hn Phase Op Cotle Activity Cotle Time P -T -X Operation Stan Depth (flKB) End Depth (flKB) 6/29/2018 6129/20181.50 PROD2 PLUG CMNT X Pump cement plug # 3 at 5,972' MD. 5,972.0 5,972.0 18:45 20:15 MU cement hose assym and close arm taking returns through super choke and closing chokes with pumps off. Pump 27 BBLS 12.5# MPII. at 4 BPM 850 ICP, 340 FCP, Mix and pump 48.3 BBLS of 15.8#. cmt at 4 BPM. 78 -230 PSI. Stop wiper ball at 160 stks. 4 BPM from 420 stks 500 PSI. reduce to 3 BPM 518 PSI FCP 617 total stks pumped. 6/29/2018 6/29/2018 0.75 PROD2 PLUG TRIP X PUH from 5,972' MD to 5,470' MD. 5,972.0 5,470.0 20:15 21:00 UP WT = 114K, DWN WT = 78K. Swabbing occuring so slow down to 15 FPM. 6/29/2018 6/29/2018 2.75 PROD2 PLUG CIRC X Circulate while recip from 5,440' MD - 5,470.0 5,470.0 21:00 23:45 5,470' MD. stage pumps to 630 GPM @ 1,320 PSI DPP. 34% F/O, total stks pumped 16,690. UP WT = 107. DWN WT=76K. 6/29/2018 6/30/2018 0.25 PROD2 PLUG CIRC X 5,3467' MD spotting 45 BBLS spacer 5,470.0 5,470.0 23:45 00:00 pill and chase with 682 STKS at 5 BPM 328 PSI DPP 15% F/0, 6/30/2018 6/30/2018 0.75 PROD1 PLUG TRIP X PUH and space out with 15' PUP to 5,470.0 5,007.0 00:00 00:45 get on depth at 5,007' MD. UP WT = 107K Monitor lisp via pit #1. 6/30/2018 6/30/2018 0.50 PROD1 PLUG RURD X Flush choke manifold from previous 5,007.0 5,007.0 00:45 01:15 cement plugs. Rig up cement manifold to DP. 6/30/2018 6/30/2018 1.00 PROD2 PLUG CMNT X Pump Cement plug #4 of AS1. Pump 5,007.0 5,007.0 01:15 02:15 27 BELS of 12.7 PPG mud pushll @ 3.7 BPM 170 PSI DPP. Close bag, batch up cement system. Open Annular and pump 67.7 BBLS of 15.7# ASI cement at 4.3 BPM 90 PSI DPP. Close bag and drop wiper ball. Pump 3 BBLS Mud pushl) and one barrel fresh water. Displace cement with rig pumps of LSND at 4 BPM with last 5 BBLS being pumped at 2 BPM, 470 PSI DPP. Was able to catch cement 21 BBLS into displacement. Cement wet at 0213 hrs. 6/30/2018 6/30/2018 1.00 PROD2 PLUG TRIP X PUH from 5,007' MD - 3,980' MD. 5,007.0 3,980.0 02:15 0315 starting at 15 FPM then changed to 30 FPM. Monitor disp via Pit #1. UP WT = 94K, DWN WT = 74K.. 28K OP to move pipe. 6/30/2018 6/30/2018 5.75 PROD2 PLUG WOC X 630 GPM @ ICP of 1,120 PSI DPP 3,980.0 3,980.0 03:15 09:00 FCP 965 PSI DPP. 34°% F/O. 6/30/2018 6/30/2018 1.00 PROD2 PLUG WASH X Wash down from 3,980' MD - 4,298' 3,980.0 4,280.0 09:00 10:00 MD @ 2 BPM 145 PSI DPP. 7% F/O, UP WT = 94K, DWN WT = 78K. Wash thru set down at 4,272' MD - 4,280' MD. 6/30/2018 6/30/2018 1.75 PROD2 PLUG WASH X Wash down and circulate with 4,280.0 4,513.0 10:00 11:45 reciprocations from 4,280' MD -4,513' MD @ 2 BPM with ICP of 145 PSI, FCP of 210 PSI. 9% F/O, UP WT = 96K, DWN WT = 78K. 6/30/2018 6/30/2018 2.00 PROD2 PLUG CIRC X CBU while recip from 4,513'4,456' 4,513.0 4,513.0 11:45 13:45 MD treating fluids due to clobbering. Stage up to 660 GPM 1,285 PSI, 33% F/O, 8,830 STKS @ full rate. Page 14135 Report Printed: 8/10/2018 Uperations Summary (with Timelog Depths) TAT.. IH -108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log St Sam Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Stan Depth (ttKB) End Dept (RKB) 6/30/2018 6/30/2018 0.75 PROD2 PLUG WASH X Continue to wash down to tag depth of 4,513.0 4,714.0 13:45 14:30 4,714' MD. Tagged three times and witnessed by Jeff Jones with AOGCC. UP WT = 96K, OWN WT = 78K. Tagged with 2 BPM and 10K DWN WT. 6/30/2018 6/30/2018 1.25 PROD2 PLUG CIRC X CB U while recip from 4,714' MD - 4,714.0 4,714.0 14:30 15:45 4,641' MD Staging pumps up to 630 GPM @ ICP 1,380 PSI DPP, FCP = 1,080 PSI. 5,964STKS. 6/30/2018 6/30/2018 1.50 PROD2 PLUG TRIP X POOH from 4,714' MD - 2,784' MD. 4,714.0 2,784.0 15:45 17:15 Monitor disp via Pit#1. UP WT = 100K, DWN WT=80K. 6/30/2018 6/30/2018 0.25 PROD2 PLUG CIRC X Pump 48.35 BBL spacer pill Hi -Vis 2,784.0 2,784.0 17:15 1730 monitoring disp via Pit 1. chase with 218 siks. 6/30/2018 6/30/2018 0.50 PROD2 PLUG TRIP X PUH from 2,784' MD - 2,282 'M 2,784.0 2,282.0 17:30 1800 monitoring disp via Pit 1, UP WT = 72K, DWN wT=71K, 6/30/2018 6/30/2018 0.75 PROD2 PLUG CIRC X Circulate while recip from 2,282' MD - 2,282.0 2,282.0 18:00 1845 2,189' MD, 630 GPM @ 820 PSI DPP 32% F/O. UP WT = 69K. DWN WT = 71 K. Total strokes pump = 3,900. 6/30/2018 6/30/2018 1.25 PROD2 T7LUG CMNT X RU cement head and pump KO plug. 2,282.0 2,282.0 18:45 20:00 PUmp 27 BBLS of 12.5# MP @ 4.8 BPM54 PSI DPP> close bag and batch cement. Open bag and pup 51 BBLS of AS1 15.7# cement at 4.6 BPM 100-421 PSI DPP close bag and drop ball. Pump 3 BBLS Mud Push II and 1 BELS fresh water behind ball then wsap to rig pumps for displacement of 11.47 BBLS LSND at 4 BPM, 35 PSI with last 5 BBLS at 2 BPM 42 PSI. Cement wet at 1920 hrs. CIP @ 1946 hrs. 6/30/2018 6/30/2018 1.00 PROD2 PLUG TRIP X PUH from 2,282' MD - 1,684' MD. 15 2,282.0 1,684.0 20:00 21:00 FPM @ 62K UP WT, 59K DWN WT. Monitor disp via TT. 6/30/2018 6/30/2018 0.50 PROD2 PLUG CIRC X Circulate while recip form 1,684' MD - 1,684.0 1,684.0 21:00 21:30 1,602'MD. UP WT=62K DNW WT= 59K. 630 GPM @ 760 PSI DPP FCP = 681 PSI DPP. 018 6/3012018 0.25 PROD2 PLUG OWFF X OWFF BD TD. 1,684.0 1,684.0 21:30 21:30 21:45 6/30/2018 6/30/2018 0.75 PROD2 PLUG PULD X POOH laying down 4 1/2" DP from 1,684.0 1,225.0 21:45 22:30 1,634' MD - 1,225' MD. Monitor disp via pit #1. 6/30/2018 6/30/2018 0.50 PROD2 PLUG KURD X RU GBR handling equipment for 3 1,225.0 1,225.0 22:30 23:00 1/2" 9.3# tubing. 6/30/2018 7/1/2018 1.00 PROD2 PLUG TRIP X POOH with 3 1/2" L-80 tubing 1,225.0 540.0 23:00 00:00 standing back in derrick. C/O seal rings on the fly. Monitor disp via Pit #1. 7/1/2018 7/1/2018 1.50 PROD2 PLUG TRIP X Continue to stand back in derrick 3 540.0 0.0 00:00 01:30 1/2" L-80 - 8 mcl EUE tubing while replacing seal rings. Monitor disp via Pit 1. Clear and clean rig floor. 7/1/2018 7/1/2018 0.75 PROD2 TLUG PLUGWWWH X MU Johnny wacker and wash 930 0.0 0.0 01:30 02:15 GPM @ 160 PSI. wellhead/BOP'S from post cement programs. Pull Wer busing and service. Page 15/35 Report Printed: 8/10/2018 operations Summary (with Timelog Depths) 1 H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Deem(ftKm 7/1/2018 7/1/2018 0.50 PROD2 PLUG BOPE X Install test plug / flood stack with fresh 0.0 0.0 02:15 02:45 water and test blind rams to 250 / 3500 PSI. 5/5 charted (Passed) UII test plug / install wear bushing. 7/1/2018 7/1/2018 1.25 PROD2 PLUG BHAH X M/U BHA for cleanout using 97/8" 0.0 285.0 02:45 04:00 Generic rock bit. Monitor disp via Pit .1 7/1/2018 7/1/2018 0.75 PROD2 PLUG TRIP X TIH from 285' MD- 1,616' MD. 285.0 1,616.0 04:00 0445 Monitor disp via Pit 1. 7/1/2018 7/1/2018 0.25 PROD2 PLUG CIRC X Circulate bottoms up at 630 GPM 1,616.0 1,661.0 04:45 0500 650 PSI DPP. 60 RPM with 2K TO. Recip pipe. 7/1/2018 7/1/2018 0.75 PROD2 PLUG WASH X Wash down from 1,661' MD to 1,661.0 1,750.9 05:00 0545 1,750.89' MD at 2 BPM 105 PSI DPP, 7% F/O, tag cement at 1,750.89' MD. with 15K DWN WT. UP WT = 77K, DWN = 80K. 7/1/2018 7/1/2018 0.25 PROD2 PLUG DRLG X Drill cement from 1,750.89' MD - 1,750.9 1,765.0 05:45 0600 1,765' MD. 800 GPM @ 875 PSI DPP. 34% F/O, 60 RPM with 2K TO. 1K SOB. , 7/1/2018 7/1/2018 0.75 PROD2 PLUG CIRC X Circulate BU while rotating and recip 1,765.0 1,765.0 06:00 0645 from 1,765' MD - 1,705' MD. 807 GPM @ 880 PSI DPP. 34% F/O, 60 RPM 1.51K TO. 6,500 STKS pumped. UP WT=80K. DWN WT=-80K. 7/1/2018 7/1/2018 1.75 PROD2 PLUG PRTS X RU and perform a casing pressure 1,765.0 1,765.0 06:45 08:30 test against TOC. 1,500 PSI = 300 PSI bleed off over charted 30 min test. Bleed off and rig dwn test equip. 7/1/2018 7/1/2018 0.25 PROD2 PLUG DRLG XT Drill cement from 1,765' MD - 1,784' 1,765.0 1,784.0 08:30 0845 MD at 802 GPM 850 PSI. 34% F/O, 60 RPM, 2K TO, 5K WOB. 7/1/2018 7/1/2018 0.75 PROD2 PLUG CIRC XT Circulate bottoms up while recip from 1,784.0 1,799.0 08:45 09:30 1,784' MD - 1,799' MD. @ 802 GPM, 805 PSI DPP 34% F/O, 60 RPM 1.5K TO. 3535 total stks pumped. UP WT = 82K, DWN WT = 80K. Tag cement with 11K DWN WT. 7/1/2018 7/1/2018 2.50 PROD2 PLUG PRTS XT MU test equip and test / chart cmt plug 1,799.0 1,799.0 09:30 1200 to 1,500 PSI. Pressure dropped on initial test from 1,500 PSI - 570 PSI. Pumped 1.8 BBLS to obtain 1500 PSI. Check all surface equip and repeat test X 3 with pressure leveling off at 850 PSI, then droppping to 500 PSI after isolating casing. RD test equip B/D same. test witnessed by Jeff Jones with AOGCC. 7/1/2018 7/1/2018 4.25 PROD2 PLUG PULD X L/D std @16 from string in hole to 1,799.0 1,708.0 12:00 16:15 1,708' MD. Cont to LD stds from derrick via mousehole. LD total of 47 stds. Off bottom UP WT = 80K. DWN WT = 80K. 7/1/2018 7/1/2018 0.75 PROD2 PLUG TRIP XT POOH racking back DP in derrick. 1,708.0 285.0 16:15 1700 Monitor disp via Pit 1. 7/1/2018 7/1/2018 0.25 PROD2 PLUG OWFF X OWFF/pre job LD BHA 285.0 285.0 17:00 1715 7/1/2018 7/1/2018 2.25 PROD2 PLUG BHAH X----FCD BHA monitor disp via Pit 1. Clean 285.0 0.0 17:15 1930 rig floor / jet flow line and clean floor pan. 7/1/2018 7/1/2018 0.50 PROD2 PLUG SVRG X Service top drive / Blocks / crown. 0.0 0.0 19:30 20:00 Page 16135 Report Printed: 811012018 -, operations Summary (with Timelog Depths) 1 H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our(hr) Phase Op Cotle Activity Cotle Time P -T -X Opmabon Start DepRN (kK8) End Depth(fiKB) 7/1/2018 7/1/2018 1.25 PROD2 PLUG TRIP X Make up Baker 10 3/4" N-1 cement 0.0 1,726.0 20:00 21:15 retainer and RIH to 1,726' MD. Monitor disp via Pit 1. UP WT = 73K. OWN WT= 70K. 7/1/2018 7/1/2018 1.00 PROD2 PLUG CIRC X Fill pipe and RIG to tag TOC. Tag at 1,726.0 1,786.0 21:15 22:15 1,786' MD. Pick up T and circ 1.5 S/S # 6 BPM, 285 PSI 16% F/0, total stks pumped 2,350. UP WT = 73K. OWN WT=71 K. 7/1/2018 7/1/2018 1.00 PROD2 PLUG MPSP X Set cement retainer as per BOT REP. 1,786.0 1,782.0 22:15 23:15 Top of retainer at 1,782' MD. PU and RU to test retainer to 1,500 PSI for 30 MIN (PASSED). 7/1/2018 7/2/2018 0.75 PROD2 PLUG DISP X Displace well over to sea water at 10 1,782.0 1,782.0 23:15 0000 BPM 240 PSI DPP 20% F/0, UP WT = 73K, OWN WT = 72K. 7/2/2018 7/2/2018 1.75 PROD2 PLUG PRTS X RU and test cement retainer with sea 1,782.0 1,782.0 00:00 01:45 water to 1,500 PSI charted 30 min. (PASSED) 7/2/2018 7/2/2018 0.50 PROD2 PLUG OWFF X OWFF and monitor same. BD top 1,782.0 1,782.0 01:45 02:15 drive / equip 7/2/2018 7/2/2018 1.50 PROD2 PLUG PULD X POOH laying down singles from 1,782' 1,782.0 0.0 02:15 03:45 MD Monitor disp via TT. 7/2/2018 7/2/2018 0.50 PROD2 PLUG WWWH X Make up Johnny Wacker and wash 0.0 0.0 03:45 04:15 WH / pull wear bushing. 7/2/2018 7/2/2018 0.75 PROD2 PLUG RURD X RU to RIH with 3 1/2" find EUE 9.3#. 0.0 0.0 04:15 0500 for a kill string. 7/2/2018 7/2/2018 5.50 PROD2 PLUG PUTB X RIH with 9.3# L-80 8rnd EUE kill 0.0 1,783.9 05:00 1030 string. from surface to tag of cement retainer at 1,783.9'MD. DOWN WT= 58.5K UP WT = 54K. Space out and pick up hanger. Damaged hanger when picking up. Replace with new from warehouse. 7/2/2018 7/2/2018 1.00 PROD2 PLUG THGR X Make up new hanger and landing jt. 1,783.9 1,781.9 1030 11:30 Orient hanger profile and land. Top of retainer at 1,783.9' MD. Bottom of kill string at 1,781.89' with space out. Verify alignment via tubing port and RILDS. 7/2/2018 7/2/2018 0.50 PROD2 PLUG THGR X PT hanger seals to 5,000 PSI 1,781.9 1,781.9 11:30 1200 witnessed- LD landing joint and pu dry rod., 7/2/2018 7/2/2018 1.00 PROD2 WHDBOP MPSP X Install BPV and test from beloow with 1,781.9 0.0 12:00 13:00 sea water to 1,500 PSI. charted for 10 min (PASSED). BD/RD. 7/2/2018 7/2/2018 3.00 PROD2 WHDBOP NUND X Pull riser and mousehole. NO BOPE 0.0 0.0 13:00 16:00 Secure same. 7/2/2018 7/2/2018 1.25 PROD2 WHDBOP NUND X Clean well head pick and set tree. NU 0.0 0.0 1600 17:15 istall test dart. 7/2/2018 7/2/2018 1.25 PROD2 WHDBOP PRTS X TEst Bonnet seals to 5,000 PSI 0.0 0.0 17:15 18:30 witnessed. Fill tree with diesel with 5 gal buckets and test to 250 / 5000 PSI (Charted). PASSED 7/2/2018 7/2/2018 0.50 PROD2 WHDBOP MPSP X Drain tree and pull test dart ?BPV. 0.0 0.0 18:30 1900 7/2/2018 7/2/2018 2.25 PROD2 WHDBOP FRZP X RU LRS and tiger tank test return line 0.0 0.0 19:00 21:15 then pump lines. Freeze protect IAX TBG with 180 BBLS deise) at 4 BPM. ICP 350 PSI, FCP 350 PSI. Diesel returns to surface @ 165 BBLS away. BD RD. Page 17135 Report Printed: 811012018 operations Summary (with Timelog Depths) 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Cotle Activity Cotle Time P -T -X Operation Start Depth (RKB) End Depth ntKB) 7/2/2018 7/2/2018 1.25 PROD2 WHDBOP MPSP X RU lubricator and set BPV / test to 0.0 0.0 21:15 22:30 1,500 PSI, Good. LD lubricator via Beaver slide. 7/2/2018 7/3/2018 1.50 DEMOB MOVE TURD X Install flanges and jewlery on tree. 0.0 0.0 22:30 00:00 Clean and secure wellhead . Install well sign. TBG / IA 0/0 press. Swap to generator power, disconnecting electrical interconnect. Rig release to move to IH -115 @ 2359 hrs 7/2/2018. 7/19/2018 10:00 7/19/2018 8.00 MIRU MOVE MOB X Released rig F/1H-115 at 10:00 1,834.0 1,834.0 1800 Moved rig over 1 H -108B, Rigged up and completed rig acceptance check list. Rig accepted at 18:00 hrs. 7/19/2018 7/19/2018 1.50 MIRU MOVE TURD X Rig up to circulate out diesel to tiger 0.0 0.0 18:00 19:30 tank 7/19/2018 7/19/2018 3.00 WI -RU WHDBOP VPSP X Monitor well pull BPV. Re -install BPV 0.0 0.0 19:30 22:30 ( Rig waiting on vis. Brine decision made to reinstall BPV) lest BPV 250 low- 2,500 psi high. (Charted) N/D tree, Install blanking plug, Set install plate on lop of hanger and torque. 7/19/2018 7/20/2018 1.50 VIRU WHDBOP NUND X Set spacer spools, Set BOP stack, 0.0 0,0 22:30 00:00 Install choke and kill lines. Install flow riser. 7/20/2018 7/20/2018 1.50 MIRU WHDBOP NUND X Complete torquing all flanges on 0.0 0.0 00:00 01:30 BOPE. Install mouse hole 7/20/2018 7/20/2018 2.50 MIRU WHDBOP CIRC X Pull blanking plug -&BPV, Install 0.0 0.0 01:30 04:00 landing joint. Rig up to reverse circulate out diesel freeze protect to tiger tank. Pump 6 bpm, 600 psi. 1,800 strokes until brine visable at tiger tank. 7/20/2018 7/20/2018 7.00 MIRU WHDBOP BOPE X Install BPV & blanking plug. Witness 0.0 0.0 04:00 11:00 of test waived by AOGCC Insp Adam Earl. Test w/ 3.5", 4.5" and 7" test its. Test 250 psi low and 3500 psi high, 5 min each.lnstall BPV & blanking plug. Test Super & manual choke T/2,500 psi. Test all other 250-3,500 psi. Test choke valves 1-14. Test mud manifold, Mezzanine, HCR & manual kill valves. Manual & HCR choke, Annular W/7"- 3 -1/2' test its. 4 1/2" XT43 and 4" XT39 TIW & dart Valves, Test Upper & lower top drive IBOP's. Lower VBRS. W/3- 1/2" & 4-1/2" test its. Upper rams W/7" test it. Perform koomey draw down test- Initial system psi 3,000, After closure 1,750 psi, 200 psi attained 7 sec. Full psi- 48 sec. 6 nitrogen bottles average psi 1,975. Test pit levels, flow out alarm, H2S & Combustable gas audible & light alrams. 7/20/2018 7/20/2018 1.00 MIRU WHDBOP RURD X Rig down testing equipment, Blow 0.0 0.0 11:00 12:00 down all lines. 7/20/2018 12:00 7/20/2018 1.00 PROD2 PLUG PULL X PJSM/ F/ Laying down 3-1/2" EUE 9.3 1,781.0 1,750.0 13:00 ppf. tubing and hanger. Pick up landing joint make upto hanger, Make up cement hose T/ Circulate, Pull hanger W/62k up. Pull hanger to floor. 7/20/2018 13:00 7/20/2018 0.50 PROD2 PLUG CIRC X Circulate @ 523 gpm, 12 bom, 327 1,750.0 1,750.0 1330 psi, 27% flow out. Total strokes pumped - 3,030. Sim -Ops R/U GBR Page 18/35 Report Printed: 8/10/2018 e operations Summary (with Timelog Depths) .. 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time 7/20/2018 End Time 7/2012018 Dur (hr) 3.25 PhaseOp PROD2 Code Anvey Code Time P -T -X Operation Stan Depth ftKB End Depth 10.0) 13:30 16:45 PLUG PULL X L/D hanger & Landing Joint. Lay down 1,750.0 55 joints & 2, pups of 3-1/2 EUE 9.3 ppf tubing. Up wt. 60k Dn wt. 59k. Monitor via trip tank. 7/20/2018 7/20/2018 1.00 PROD2 PLUG RURD X Rig Down GBR. Clear and clean rig 0.0 0.0 16:45 17:45 floor. 7/20/2018 7/20/2018 0.50 PROD2 PLUG RURD X Mobilze saver sub & BHA to rig floor 0.0 0.0 17:45 18:15 7/20/2018 7/20/2018 1.25 PROD2 PLUG SVRG X Change out XT -43 saver sub in top 0.0 0.0 18:15 19:30 drive. 7/20/2018 7/2012018 1.25 PROD2 PLUG S_LPC X Slip &Cut 63 of Drill line, Calibrate 0.0 0.0 19:30 20:45 block height 7/20/2018 7/20/2018 0.50 PR0D2 PLUG SVRG X Service Top Drive, Blocks & Crown Crow 0.0 0.0 20:45 21:15 7/20/2018 7/20/2018 0.50 PROD2 PLUG TURD X set 12-3/8" ID- Wear ring. Obtain 0.0 0.0 21:15 21:45 measurements 7/20/2018 21:45 7/20/2018 2.00 PROD2 PLUG BHAH X P/U CIBP & Cement drill out BHA - 0.0 482.0 23:45 T/482' MD. Monitor displacement via pit # 1 7/20/2018 23:45 7/21/2018 00:00 0.25 PROD2 PLUG TRIP X Trip in picking up 4-1/2" XT -43 482.0 703.0 drillpipe. F/482'MD - T/ 703' MD. Monitor displacement via pit # 1 7/21/2018 00:00 7/21/2018 1.25 PR0D2 PLUG TRIP X Continue RIH P/U 4-1/2" XT -43 -703 0 1,777.0 01:15 Drillpipe F/703' MD - T/1,77T MD. Monitor displacement via pit # 1. Up wt, 92k, Dn wt, 87k, Rot wt. 90k 7/21/2018 01:15 7/21/2018 01:45 0.50 PROD2 PLUG CIRC X Fill Pipe, Obtain Slow Pump Rates 1,777.0 1,782.0 Wash down and tag at 1,782' MD 7/21/2018 01:45 7/21/2018 4.25 PROD2 PLUG COCF X Drill/ CIBP & Cement F/1,782' MD - 1,782.0 1,809.0 06:00 T/1.809' MD. 800 gpm,415 psi, 29% flow out, 70 rpm, 1-10K torque. 20-40k bit wt. up wt. 98k. Dn wt. 87K. Rot wt. 90K. 7/21/2018 06:00 7/21/2018 -3 00 PROD2 PLUG COC- X DrillI CIBP&Cement F/1,809. MD- 1,809.0 1,836.0 09:00 T1i.836' MD. 567 gpm,400 psi, 29°/ flow out, 70 rpm, 1-10K torque. 20-40k bit wt. up wt. 98k. Dn wt. 87K. Rat wt. 90K. 7/21/2018 09:00 7/21/2018 0.50 PROD2 PLUG CIRC X Wash & Ream F/1,830' MD -T/1,800 1,836.0 1,830.0 09:30 MD. 700 gpm, 423 psi, 34% flow out 70 rpm, 3K. Torque, Up wt. 98K. Dn Wt. 87K. Rot. Wt. 90K. -0 Total strokes pumped - 3,330 7/21/2018 09:30 7/21/2018 50 PROD2 PLUG DISP X Displace well F/ viscosifed brine - T/ 1,830.0 1,830.0 10:00 9.0 ppg. LSND. Pump 30 bbl. spacer followed by 9.0 ppg LNSD. Rotate & Reciprocate F/ 1,830' MD - T/1,800' MD. 700 gpm, 423 psi, 34% flow out, 3K torque. Up wt. 98k Dn wt. 87k. Rot wt. 90k. Total strokes pumped - 5,358 7/21/2018 7/21/2018 0.50 PROD2 PLUG CIRC X Obtain slow pump rates 1,830.0 1,810.0 10:00 10:30 MP#1) 30 spm -60 psi 40 spm - 70 -psi MP#2) 30 spm -60 psi 40 spm - 70 -psi Rack back stand # 15, OWFF- static 7/21/2018 10:30 7/21/2018 1.50 PROD2 PLUG TRIP X Pump dry job ,TOOH-F/1,810'MID - 1,810.0 300.0 12:00 T/300' MD. Pulling on elevators. Monitor via trip tank. 7/21/2018 7/2 12:00 1/2018 1.00 PROD2 PLUG BHAH X L/D Cleanout BHA F/300' MD 300.0 0.0 13:00 Monitor via trip tank Page 19/35 ReportPrinted: 8/10/2018 Operations Summary (with Timelog Depths) 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op Code Activily Code Time P -T -X Coniston Starl Depth (WB) End Depth(flKB) 7/21/2018 7/21/2018 0.50 PROD2 PLUG BHAH X Clear and Clean rig floor 0.0 0.0 13:00 13:30 7/21/2018 7/21/2018 0.75 PROD2 PLUG BHAH X Pick up Drilling assembly with 0.0 368.0 13:30 14:15 Milltooth bit T/386' MD. Ran in with BHA F/ Derrick F/ 86' MD - T/368' MD. Drill collars, HWDP & Jars Up wt. 59k. Dn wt. 64k. Monitor displacement via trip tank. 7/21/2018 7/21/2018 1.50 PROD2 PLUG TRIP X TIH, F/368' MD -T/1,794' MD. Picking 368.0 1,794.0 14:15 1545 up 4-1/2" XT -43 drillpipe F/Pipeshed. Shallow pulse test downhole tools W/550 gpm, 776 psi. 37% Flow out at 1,794' MD. 7/21/2018 7/21/2018 0.75 PROD2 PLUG REAM X Wash & Ream down F/1,794' MD - 1,794.0 1,836.0 15:45 1630 T/1,836' MD. W/587 gpm, 816 psi. 30% flow out. 60 rpm. 3k. torque Up wt. 85k. On wt. 82k. Rot wt. 82k. 7/21/2018 7/21/2018 1.50 INTRMI DRILL DDRL X Dril 8-3/4" hole F/1,836' MD -T/1,884' 1,836.0 1,884.0 16:30 1800 MD. 1,813' TVD. 560 gpm,770 psi,28% Flow out,60 rpm,2K torque, 5k. WOB, Up wt. 85k. On wt. 82k. Rot wt. 82k, 1 k. Torque off bottom, Off bottom psi -764. Max gas units 17 ADT- .96 Bit Hrs..96, Jar hrs. = 59.4 Sidetrack not confirmed at this depth. Indications good. 7/21/2018 7/21/2018 4.50 INTRMI DRILL DDRL X Drill 8-3/4" hole F/1,884' MD - T/2,264' 1,884.0 2.264.0 18:00 2230 MD, 2,119' TVD. 550 gpm,830 psi. 30% flow out, 60 rpm, 3k. torque 20k. Bit wt. ECD's 9.8. Off bottom psi = 820. Up -89k. Down -86k. Rot -87k. 1.5k. torque off, Max gas 40 units. ADT- 3.61 Bit hrs. 4.57. Jar hrs. 63.01 7/21/2018 7/21/2018 0.50 INTRMI DRILL CIRC X Circulate 2 times bottoms up Rot & 2,264.0 2,170.0 22:30 2300 recip F/2,264' MD - T/2,170' MD. 600 gpm, 930 psi.29% flow out, 60 rpm, 1.5k. torque off. Total strokes 3,300. MW in 9.0 MW out 9.1. Up 88k, Down 87k. Rot 87k. 7/21/2018 7/21/2018 0.25 INTRMI DRILL OWFF X Monitor well for 10 minutes fluid level 2,170.0 2,170.0 23:00 23:15 dropped 3" 7/21/2018 7/22/2018 0.75 INTRMI DRILL TRIP X POOH on elevators, F/2,170' MD - 2,170.0 1,604.0 23:15 0000 T/1,980' MD. Swabbing- Kelly up & pump out at 5 bpm, 220 psi. 13% flow out. F/1,980' MD - T/ 1,790' MD. Pulling spped 40 fpm. POOH on elevators F/1,980' MD - T/1,604' MD. Up -80k. Down 78k. SPR's @ 2,264' MD - 2,119' TVD MW - 9.0 ppg. Time 23:00 Pump #1= 30 spm 90 psi, 40 spm 120 psi. Pump #2= 30 spm 90 psi, 40 spm 120 psi. 7/22/2018 7/22/2018 0.50 INTRMI DRILL TRIP X LOCH F/1,604'MD - T/ 367'MD. 1,604.0 367.0 00:00 0030 Monitor via trip tank, Up 63k. Down 66k. 7/22/2018 7/22/2018 1.00 INTRMI DRILL BHAH X Rack back HWDDP, Jars, Drill collars, 367.0 0.0 00:30 01:30 Lay down BHA components. Down 62k. Hole fill monitored via trip tank. 7/22/2018 7/22/2018 1.25 INTRMI DRILL BHAH X Make up BHA# 7. Per directional 0.0 381.0 01:30 02:45 driller T/381' MD. Displacement monitored via trip tank. Up 87k. Down 83k. Page 20/35 Report Printed: 8/10/2018 Uperations Summary (with Timelog Depths) 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur(hn Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth(ftKB) 7/22/2018 7/22/2018 0.75 INTRMI DRILL TRIP X Run in hole with drillpipe from Derrick 381.0 1,813.0 02:45 0330 T/1,813' MD. Displacement monitored via trip. Up 87k. Dwon 83k. 7/22/2018 7/22/2018 2.50 INTRMI DRILL DHEO X Shallow pulse test tools, (Good test) 1,813.0 2,264.0 03:30 0600 MADD pass F/1,813' MD - T/2,264' MD. 600 gpm, 800 psi, 30% flow out. MADD pass at 350 fph. 7/22/2018 7/22/2018 6.00 INTRMI DRILL DDRL X Drill 8-3/4" Intermediate section F/ 2,264.0 2,820.0 06:00 1200 2,264' MD - T/2,820' MD, 2,418' TVD. 605 gpm,864 psi,30 % Flow out Off bottom psi = 560. ECD's - 9.72 ppg. Max gas 89 units. Up 98k. Down 82k. Rot 87k. 3k. Torque. ADT -3.35, Bit hrs. 3.35, Jar hrs. 66.36 SPR's @ 2,286' MD, 2,131' TVD, MW 9.2 ppg MP#1) 30 SPM- 90 psi. 40 SPM- 120 psi. MP#2) 30 SPM- 90 psi. 40 SPM- 120 psi. 7/22/2018 7/22/2018 1.50 INTRMI DRILL DDRL X Drill 8-3/4" Intermediate section F/ 2,820.0 2,983.0 12:00 13:30 2,820' MD - T/2,983' MD. 605 gpm, 846 psi. 30% flow out.max gas 53 units. off bottom psi = 850. ECD's 9.72 ppg. Rot 120 rpm, 3.5k. Torque, 2k. bit wt. Up 98k. Dwon 82k. Rot 87k. Observed 200 psi packoff. 7/22/2018 7/22/2018 4.00 INTRMI DRILL DDRL X Drill coal section F/2,983' MD. - T/ 2,983.0 3,030.0 13:30 17:30 3,030' MD. 2,505' TVD. 420-481 gpm, psi 460- 517. Flow out 29% 80 rpm, 3.5k. Torque 1-3 bit wt. 7/22/2018 7/22/2018 0.50 INTRMI DRILL DDRL X Drill 8-3/4" Intermediate section, 3,030.0 3,050.0 17:30 18:00 F/3,030' MD. - T/3,050' MD. 2,505' TVD. 605 gpm,870 psi, 30%, Flow out. ECD's 9.7 ppg. Off bottom psi- 863. Gas 57 units. 3.5k. torque Bit wt4k. max gas 57 units. 140 rpm. 3k. torque, off bottom. Up 98k. Down 82k. Rot 87k. ADT- 2.46 hrs. Bit hrs. 5.81 Jar hrs - 68.82. 7/22/2018 7/23/2018 6.00 INTRMI DRILL DDRL X Drill 8-3/4" Intermediate section, 3,050.0 4,100.0 18:00 0000 F/3,050' MD. - T/4,100' MD. 2,875' TVD. 700 gpm,1320 psi, 33%, Flow out. ECU's 10.33 ppg. Off bottom psi - 1,315. Gas 95 units. 6k. torque Bit wt 14k. max gas 95 units. 140 rpm. 3.5k. torque, off bottom. Up 109k. Down 83k. Rot 94k. ADT- 4.2 hrs. Bit hrs. 10.01 Jar hrs - 73.02. Pump Hi -Vis weighted sweeps every 500' MP#1) 30 SPM- 100 psi. 40 SPM- 140 psi. MP#2) 30 SPM- 10 psi. 40 SPM- 140 psi Page 21/35 Report Printed: 8/10/2018 Uperations Summary (with Timelog Depths) IH -108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dm (hr) Phase Op Code Adivity Cade Time P -T -X Operabon Smil Depth (flKB) End Depth (XKB) 7/23/2018 7/23/2018 6.00 INTRMI DRILL DDRL X Drill 8-3/4" Intermediate hole, F/4,100' 4,100.0 5,180.0 00:00 06:00 MD - T/ 5,180' MD, 3,228' TVD. 700 gpm, 1,530 psi, 33% flow out, 140 rpm, 6k torque, bit wt. -7k. ECD's 10.57, Off bottom -1,540 psi,Up 116k, Down 85k, Rot 99k, 5k torque off, Max gas 60 units. ADT - 4.1, Bit hrs.- 14.11, Jar hrs. - 77.12 7/23/2018 7/23/2018 6.00 INTRMI DRILL DDRL X Drill 8-3/4" Intermediate hole, F/5,180' 5,180.0 5,845.0 06:00 12:00 MD - T/ 5,845' MD, 3,409' TVD. 748 gpm, 1,406 psi, 32% flow out, 130 rpm, 6.5k torque, bit wt. -2k. ECD's 10.13, Off bottom -1,407 psi,Up 119k, Down 87k, Rot 100k, 5k torque off, Max gas 201 units. ADT - 4.03, Bit hrs.- 18.14, Jar hrs. - 81.15 SPR's- 5,237' MD, TVD - 3,247' MW - 9.0 ppg MP # 1) 30 SPM - 240 psi. 40 SPM - 280 psi. MP # 2) 30 SPM - 240 psi. 40 SPM - 290 psi. No losses 7/23/2018 7/2312018 3.50 INTRMI DRILL DDRL X Drill 8-3/4" Intermediate hole, F/5,845' 5,845.0 6,191.0 12:00 15:30 MD - T/ 6,191' MD, 3,463' TVD. 720 gpm, 1,745 psi, 32% flow out, 140 rpm, 7 k torque, bit wt. -12 k. ECD's 10.35, Off bottom -1,740 psi,Up 120 k, Down 85 k, Rot 100 k, 5k torque off, Max gas 90 units. ADT - 2.57, Bit hrs.- 20.71, Jar hrs. - 79.69. Xceed tool problem, Discontinue drilling. 7/23/2018 7/23/2018 2.25 INTRMI DRILL CIRC XT Rot & Reciprocate pipe 6,189' MD - 6,191.0 6,191.0 15:30 17:45 6,099'10D. 771 gpm, 1,848 psi, Flow out 34%, 100 rpm, 6 k torque. Up 120 k. Down 85 k. Rot 100 k. Total strokes pumped 9,050 SPR's- 6,186' MD, TVD - 3,463' MW - 9.1+ ppg MP # 1) 30 SPM - 160 psi. 40 SPM - 210 psi. MP # 2) 30 SPM - 170 psi. 40 SPM - 210 psi. 7/23/2018 7/23/2018 0.50 INTRMI DRILL OWFF XT Observe well for flow, Fluid level 6,191.0 6,191.0 17:45 18:15 dropped 6" Idown Sim -Ops- Service wash pipe, Blow topdrive 7/23/2018 7/23/2018 0.75 INTRMI DRILL TRIP XT Pull out of hole F/6,189' MD - T/ 5,816' 6,191.0 5,816.0 18:15 1900 MD. Up 129k. down 77k. 20-30k Overpull, well swabbing. 7/23/2018 7/24/2018 5.00 INTRMI DRILL BKRM XT Back Ream Out of Hole, F/5,816' MD- 5,816.0 3,531.0 19:00 00:00 T/3,531' MD. 700 gpm, 1,420 psi, 33% Flow out, 140 rpm, 5k. Torque, ECD's 10.54 ppg. Up. 103k. Down 83k. 7/24/2018 7/24/2018 4.25 INTRMI DRILL BKRM XT Back Ream Out of Hole, F/3,531' MD - 3,531.0 1,809.0 00:00 04:15 T/1,809' MD. 600 gpm, 925 psi, 32% Flow out, 140 rpm, 3k. Torque, ECD's 10.03 ppg. Up. 86k. Down 84k. Page 22135 Report Printed: 8/10/2018 ,.. Uperations Summary (with Timelog Depths) IH -108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op Code Activity Cotle Time P -T -X Operation Start Depth (flKB) End Dept (ftKB) 7/24/2018 7/24/2018 0.25 INTRMI DRILL CIRC XT Circulate bottoms up Rotating and 1,809.0 1,809.0 04:15 04:30 reciprocating drillstring. F/ 1,809' MD - T/ 1,728' MD. 700 gpm, 1,100 psi, 33% flow out. 100 rpm, 1.8k Torque. 9.69 ECD's. Total strokes pumped = 1,700 018 7/24/2018 0.25 INTRMI DRILL OWFF XT Monitorwell (Static) Pump 15 bbl. dry 1,809.0 1,809.0 04:30 04:30 04:45 job 10.3 ppg. 7/24/2018 7/24/2018 0.75 INTRMI DRILL TRIP XT POOH F/1,809' MD - T/ 381' MD. (At 1,809.0 381.0 04:45 05:30 BHA) Monitor hole fill via trip tank 7/24/2018 7/24/2018 1.50 INTRMI DRILL SHAH XT Rack back HWDP, Jars, Stand DC's. 381.0 0.0 05:30 07:00 Lay down Xceed tool and bit. (Per D. D,) 7/24/2018 7/24/2018 0.50 INTRMI DRILL GLEN XT Clear and Clean Rig Floor. - Sim Ops, 0.0 0.0 07:00 07:30 PM Service on drawworks. 7/24!2018 7124/2018 1.00 INTRMI DRILL BHAH XT Make up BHA# 8, Run NM Drill collar, 0.0 383.0 07:30 08:30 HWDP & Jars F/Derrick. F/ 95'MD. - T/383' MD. Up 61 k. Down 67k. Monitor displacement via trip tank. 7/24/2018 7/24/2018 3.25 (NTRMI 'DRILL TRIP XT Continue to RIH with BHA#8 with 4.5" 383.0 6,102.0 08:30 11:45 DP from derrick. 383' MD - 6,102' MD. UP WT=120K. DWN WT=78K. Monitor disp via TT Shallow hole pulse test at 1,810' MD (GOOD). 569 GPM @ 888 PSI DPP. 31% F/O. Taking 15K DWN WT @ 2,374' MD. and 5,850' DM. 7/24/2018 7/24/2018 0.75 INTRMI DRILL WASH XT Wash down from 6,102' MD to 6,187' 6,102.0 6,187.0 11:45 12:30 MD while staging up pumps to 550 GPM ICP 160 PSI DPP FCP' 1,225 PSI DPP. 31°/ F/O. 70 RPM with 6K TO. UP WT=120 K. DWN WT= 78K. ROT WT - 97K. take SPR's. SPR's 6,188' MD 3,463' TVD MW = 9.2 PPG hrs 12:30 SPM 1) 30 SPM - 180 PSI 40 SPM - 220 PSI SPM 2) 30 SPM - 180 PSI 40 SPM - 220 PSI 7/24/2018 7/24/2018 5.50 INTRMI DRILL DDRL X DDRL 8 3/4" hoE 87' MD to 6,187.0 6,880.0 12:30 18:00 6,880' MD 3,51t 646 GPM 1,694 PSI DPP., 140 RPM8K TO, with 15CD - 10.38,Off bottom 1,65WT = 132K,DWN WT= 78K102K. Maxgas = 122 units,7 Bit hrs3.57, Jar hrs 83 7!24!2018 7/25/2018 6.00 INTRMI DRILL DDRL X DDRL 8 3/4" hole from 6,880' MD 6,880.0 7,620.0 18:00 00:00 3,510' TVD - 7,620' MD 3,697' TVD. at 646 GPM 1,950 PSI DPP 32% F/O, 140 RPM 8K TO, with 19K WOB. ECD - 10.72, Off bottom 1,940 PSI. UP WT = 136K, DWN WT = 78K. ROT - 102K. 8K TO Max gas = 30 units, ADT - 3.93 Bit hrs 7.5, Jar hrs 87.19 SPR's 7,140' MD 3,612" TVD MW = 9.0+ PPG hrs 1920 SPM 1) 30 SPM - 180 PSI 40 SPM - 240 PSI SPM 2) 30 SPM - 180 PSI 40 SPM - 230 PSI Page 23135 Report Printed: 8/10/2018 Uperations Summary (with Timelog Depths) 114-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our(hn Phase Op code Activity Coda Time P-T-X Operation Stan Depth I (ftKB) End Depth(ftKB) 7/25/2018 7/25/2018 6.00 INTRMI DRILL DDRL X DDRL 8 3/4" hole from 7,620' MD 7,620.0 8,296.0 00:00 06:00 3,697' TVD - 8,286' MD 3,791' TVD. at 646 GPM 1,745 PSI DPP. 31% F/O, 140 RPM 9K TO, with 4K WOB. ECD - 10.62, Off bottom 1,735 PSI. UP WT =136K, DWN WT=77K. ROT- 106K. 9K TO Max gas = 50 units, ADT - 4.08 Bit hrs 11.58, Jar hrs 91.27 7/25/2018 7/25/2018 3.00 INTRMI DRILL DDRL X DDRL 8 3/4" hole from 8,286' MD 8,296.0 8,517.0 06.00 09:00 3,791' TVD - 8,517' MD 3,809' TVD. at 525 GPM 1,333 PSI DPP. 27% F/O, 80 RPM 10K TO, with 5K WOB. ECD - 10.28, Off bottom 1,909 PSI. UP WT =142K, DWN WT=77K. ROT- 107K. 9K TO Max gas = 137 units, ADT - 2.3 Bit hrs 13.88, Jar hrs 93.57 SPR's 8,451' MD 3,804" TVD MW = 9.2+ PPG hrs 1000 SPM 1) 30 SPM - 190 PSI 40 SPM - 240 PSI SPM 2) 30 SPM - 200 PSI 40 SPM - 250 PSI 7/25/2018 7/25/2018 1.00 INTRMI CASING CIRC X Rotate and recip from 8,517' MD - 8,517.0 8,517.0 09:00 10:00 8,450' MD circulating at 650 GPM, 1,887 PSI DPP. 30% F/O. 140 RPM, 12K TO. 7/25/2018 7/25/2018 0.50 INTRMI CASING OWFF X OWFF. (static). 8,517.0 8,517.0 10:00 10:30 7/25/2018 7/26/2018 13.50 INTRMI CASING BKRM X BKRM OOH from 8,517' MD - 3,517' 8,517.0 3,517.0 10:30 00:00 MD. UP WT = 102K W/pump 140K WO. 7/26/2018 7/26/2018 5.00 INTRMI CASING BKRM X Continue to BKRM OOH from 3,517' 3,517.0 1,811.0 00:00 05:00 MD - 1,811' MD at 650 GPM 1,110 PSI DPP. 32% F/O with 140 RPM @ 3K TO. 9.39 ECD. UP WT=87K. DWN WT = 86K. 7/26/2018 7/26/2018 0.75 INTRMI CASING CIRC X Circulate high vis sweep while recip 1,811.0 1,811.0 05:00 0545 from 1,811'- 1,716' MD. 750 GPM @ 1,350 PSI. 33% F/O with 100 RPM 2K TO. 9.42 ECD. MWI 9.0 MWO 9.0... 4,745 STKS pumped. UP WT = 86K DWNWT=85K. 7/26/2018 7/26/2018 0.25 INTRMI CASING OWFF X OWFF dropped-3". Pump DJ. 1,811.0 1,811.0 05:45 0600 7/26/2018 7/26/2018 1.50 INTRMI CASING TRIP X Continue to POOH from 1,811' MD - 1,811.0 383.0 06:00 0730 383' MD. UP WT = 85K.. DWN WT = 85K. Monitor disp via TT. 7/26/2018 7/26/2018 2.50 INTRMI CASING BHAH X LD HWDP jars and BHA *8. Clean rig 383.0 0.0 07:30 10:00 floor while monitor disp via TT 7/26/2018 7/26/2018 2.00 INTRMI CASING RURD X MU 4 1/2" DP cross over and stack 0.0 0.0 10:00 12:00 flushing tool. flush stack at 900 GPM I simiops bringing GBR tools to rig floor and setting up. Clean rig floor. Pull wear bushing and prep to RIH with 7" casing. 7/26/2018 7/26/2018 0.25 INTRMI CASING SFTY X PJSM for running casing with GBR 0.0 0.0 12:00 12:15 I and rig crew. 7/26/2018 7/26/2018 0.50 INTRMI CASING X MU / Baker Lock Shoe track assym. 0.0 120.0 12:15 12:45 TO TXP connections to 17,700 FT/LB. 1PUTB HYD 563 TO - 9,400 FT / LB. Monitor disp via TT. Page 24/35 Report Printed: 8/1012018 Operations Summary (with Timelog Depths) IH -108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Slav Time End Time Dur (hr) Phase Op Code Activity Cade Time P -T -X Operation Stan Depth (RKB) End Depth(itKB) 7/26/2018 7/26/2018 0.25 INTRMI CASING CIRC X Check floats (Good). staged up 120.0 199.0 12:45 1300 pumps to 8 BPM @ 350 GPM, 85 PSI casing pressure, 26% F/0. 330 stks. 7/26/2018 7/26/2018 1.75 INTRMI CASING PUTB X Continue to RIH with 26# L-80 TXP 7" 199.0 940.0 13:00 1445 casing from 199' MD TQ TXP to 17,700 FT/LB. Monitor disp via Pit 5. 7/26/2018 7/26/2018 1.50 INTRMI CASING EQRP XT GBR hose failure. Shut down for hose 940.0 940.0 14:45 16:15 replacement and troubleshoot. clean up hyd fluid. Spill -1 gal of hed fluid to pad. 7/26/2018 7/27/2018 7.75 INTRMI CASING PUTB X Continue to RIH with 7" 26# TXP L-80 940.0 4,245.0 16:15 00:00 casing from 940' MD -4,245' MD filling every 10. Losses minimal and acceptable. Monitor disp via pit #5. 7/27/2018 7/27/2018 6.00 INTRMI CASING PUTB X Continue to RIH with 7" 26# L-80 TXP 4,245.0 6,672.0 00:00 06:00 casing from 4,245' MD - 6,672' MD. Fill on the fly and top off every ten joints. Monitor disp via pit #5. UP WT =167K. DWN WT=86K. 7/27/2018 7/27/2018 0.75 INTRMI CASING CIRC X Circulate bottoms up while recip from 6,672.0 6,672.0 06:00 06:45 6,672' MD - 6,632' MD. Stage pumps up to 7 BPM @ 305 PSI, 22% F/0. 2,300 STKS pumped MWI = 9.2# MWO=9.2#. 7/27/2018 7/27/2018 4.00 INTRMI CASING PUTB X Continue to RIH with 7" 26# L-80 TXP 6,672.0 8,466.0 06:45 10:45 casing from 6,672' MD - 8,466' MD. Fill on the fly and top off every 10 jts. Monitor disp via Pit #5. UP WT - 204K. DWN WT=94K. 7/27/2018 7/27/2018 0.75 INTRMI CASING HOSO X Make up HNGR assym and wash 8,466.0 8,508.0 10:45 11:30 down to land on depth at 4 BPM 350 PSI with 14% F/O. 7/27/2018 7/27/2018 4.00 INTRMI CEMENT CIRC X RU cement hose and circulate while 8,508.0 8,488.0 11:30 15:30 recip from 8,504' MD - 8,488' MD. Stage up to 7 BPM @ 500 PSI, 23% F/0 with UP WT = 173K (While pumping), DWN WT=84K. Raise rate to 8 BPM and pump a total of 15,120 stks. 7/27/2018 7/27/2018 0.50 INTRMI CEMENT PRTS X RU Schlumberger pump and pump 5 8,488.0 8,488.0 15:30 16:00 BBL of fresh water to PT. Replace 1502 gsket and retest to 4,000 PSI. Page 25135 Report Printed: 811012018 Summary (with Timelog Depths) 1H-108 F6operations Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Star) Tlme Entl TimeDur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (fti(8) End Depth (ftKB) 7/27/2018 7/27/2018 2.75 INTRMI CEMENT CMNT X Drop bottom plug number -1 and pump 8,488.0 8,508.0 16:00 18:45 40.1 BBLS of 12.5# mud push. pumping at 4.1 BPM with 80-177 PSI casing pump pressure. 10-14% F/O, Launch 2nd bottom plug and pump 173.1 BBLS of 15.8PPG class G cement at 3.7 - 5.2 BPM at 50-140 PSI pump pressure. 11-21%F/0. UP WT = 230K. OWN WT = 54K. Launch Top plug and push with 10 BBLS Fresh water prior to switching to rig pumps. On rig pump and displace with 9.2# LSND @ 8 BPM at 2,089 STKS. ICP = 200 PSI, FCP = 737 PSI. 23% F/O, UP WT = 250K, DWN WT = 52K. Lower rate to 5 BPM pump 2,730 STKS with ICP 575 PSI 17% F/O, FCP = 863 PSI, UP WT = 250 K DWN WT = 40K. Land on hanger at 2,230 STKS due to lack of down wt. Reduce rate to 3 BPM with a FCP of 900 PSI 8% F/O. Bump plug at 3,074 STKS. raise pressure to 1,400 PSI and hold for 5 min. Cement in place at 1830 hrs. Bleed off. 7/27/2018 7/27/2018 1.00 INTRMI WHDBOP PRTS X RU and pressure test casing to 3,600 8,508.0 8,508.0 18:45 1945 PSI for 30 charted min. (PASSED) Pumped 6 BBLS and bled back same. Floats holding (PASSED) 7/27/2018 7/27/2018 0.50 INTRMI CEMENT TURD X BD lines and pull landing joint / lay 8,508.0 0.0 19:45 20:15 down same. 7/27/2018 7/27/2018 0.75 INTRMI WHDBOP WWSP X Drain stack and set pack off. RILDS 0.0 0.0 20:15 21:00 and test to 5,000 PSI witnessed by Rock. LD test joint. 7/27/2018 7/27/2018 2.00 INTRMI CEMENT CIRC X C/O saver sub to XT -39 and run 0.0 0.0 21:00 23:00 injection line to OA. Inject 13 BBLS into 10 3/4" X 7" annulus to ensure injectivity at 1 BPM 450 PSI. 7/27/2018 7/27/2018 0.50 INTRMI CEMENT RURD X Test 4" dart valve to 250/3,500 PSI for 0.0 0.0 23:00 23:30 5 min ea. Tested 4" XT39 FOSV to 250 psi / 3500 psi 5 min ea. All tests charted. Set 9" wear bushing. 7/27/2018 7128/2018 0.50 INTRMI CEMENT BHAH X Bring BHA and handling tools to rig 0.0 22.0 23:30 00:00 floor. Hold PJSM for making up PD to bit. 7/28/2018 7128/2018 2.25 INTRMI CEMENT BHAH X Continue to MU BHA from 22' - 22.0 395.0 00:00 02:15 395' MD. 7/28/2618 7/28/2018 2.00 INTRMI CEMENT TRIP X RIH from 395' MD to 1,900' MD. 395.0 1,900.0 02:15 04:15 Monitor disp via pit #1. UP WT = 80K. DWN WT=76K. Fill every ten. 7/28/2018 7/28/2018 0.25 INTRMI CEMENT DHEQ X Shallow hole test MWD at 250 GPM 1,900.0 1,900.0 04:15 04:30 1,330 PSI DPP 18% F/O. 7/28/2018 7/28/2018 1.50 INTRMI CEMENT QEVL X Continue to RIF -logging free pipe from 1,900.0 2,862.0 04:30 0600 1,900' MD to 2,100' MD' MD at 800 FPM. Making up stands in mouse hole. Monitor disp via pit#1. UP WT = 90K. DWN WT=78K. Page 26/35 ReportPrinted: 8/10/2018 Operations Summary (with Timelog Depths) 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stag Time End Time our (hr) Phase Op Code ACivity Cotle Time PT-X Operation Stan Depth (IKB) End Depm(fiK8) 7/28/2018 7/28/2018 10.26 INTRM1 CEMENT QEVL X Continue to RIH with BHA#9 from 2,862.0 8,338.0 06:00 16:15 2,862' MD - cement tag at 8,338' MD. Filling pipe every ten and monitoring disp via Pit #l. Log cement quality form 6,001' MD - 8,338' MD at 800 FPH. Simops to flush and freeze protect OA with 89 BBLS of FW and 97 BBLS diesel. SIP after water flush = 460 PSI. After diesel = 600 PSI. Max pressure while injecting 635 PSI, 7/28/2018 7/28/2018 1.75 INTRMI CEMENT DRLG X Drill cement from 8,338'MD - 8,382.8 8,338.0 8,385.0 16:15 1800 MD. at 240 GPM, 1,810 PSI DPP. 21% F/O, 50 RPM with 10K TQ. Tag plugs at 8,382' MD. Drill plugs from 8,383' MD - 8,385' MD. @ 150 -200 GPM, 1,100 PSI DPP 15% F/O 7K WOB. 10K TQ. 7/28/2018 7/28/2018 2.75 INTRMI CEMENT DRLG X Continue to drill shoe track from 8,385' 8,385.0 8,517.0 18:00 2045 MD - 8,517' MD. at 230 GPM 80 RPM, 9.5K TO, 15K WOB, 11.5 ECD, Tag top of shoe at 8,506' MD. Drill out with 6-1 OK WOB. 7/28/2018 7/28/2018 0.25 INTRMI CEMENT DRLG X Drill 6 1/8" hole form 8,517' MD - 8,517.0 8,537.0 20:45 21:00 8,537' MD 3,812' TVD. at 240 GPM 1,900 PSI 17% F/O, 80 RPM 9.5K TO. 12K WOB, ECD's = 11.38, ADT .16. Bit HRS=.16, Jarhrs=.16. 7/28/2018 7/28/2018 1.00 INTRMI CEMENT CIRC X Circulate bottoms up while recip and 8,537.0 8,537.0 21:00 2200 rotating from 8,537' MD - 8,503' MD, 240 GPM @ 1,850 PSI. 18% FIG, 80 RPM wiht 9K TO. UP WT = 175K. DWN WT=56K. ROT =104K. 9.1 PPG MWI/MWO. 2,230 STKS pumped. 7/28/2018 7/28/2018 0.75 INTRMI CEMENT FIT X RU and perform an FIT to 13 PPG 8,537.0 8,537.0 22:00 2245 EMW. 9 stks, to pressure up. .6 BBLS bled back. BD/RD. (PASSED) 7/28/2018 7/29/2018 1.25 PROD3 DRILL DDRL X DDRL 6 1/8" hole form 8,537 MD - 8,537.0 8,597.0 22:45 0000 8,597' MD 3,815' TVD. 250 GPM 1,815 pSl DPP. 17% F/O, 100 RPM, 9.4K TO with 4K WOB. ECD'c - 11.06, Off bottom 1,810 PSI, UP WT = 137K, DWN WT = 75K. ROT = 98K. 9K TO. ADT .68, Bit hrs .84, Jar hrs .84 7/29/2018 7/29/2018 6.00 PROD3 DRILL DDRL X DDRL 6 1/8" hole form 8,597' MD 8,597.0 9,323.0 00:00 06:00 3,815' TVD - 9,323' MD 3,830' TVD. 250 GPM 1,950 PSI DPP. 19% F/O, 150 RPM, 6.5K TO with 3K WOB. ECD'c = 11.5, Off bottom 1,940 PSI, UP AT = 125K, DWN WT = 76K. ROT = 94K. 5K TO. ADT .3.86, Bit hrs 4.7, Jar hrs 4.7 MAx gas = 1,030 units SPR's @ 8,657' MD 3,818' TVD MW = 9.2 PPG hrs 0100 1) 20 SPM 530 PSI 30 SPM - 730 PSI 2) 20 SPM 520 PSI 30 SPM - 720 PSI Page 27135 ReportPrinted: 8/10/2018 Operations Summary (with Timelog Depths) 1 H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time our (hr) Phase Op Code ActivityCode Time P -T -X Operation Stan Depth (ftKB) End Depth (ftKB) 7/29/2018 7/29/2018 6.00 PROD3 DRILL DDRL X DDRL 6 1/8" hole form 9,323' MD 9,323.0 9,798.0 06:00 12:00 3,830' TVD - 9,798' MD 3,840' TVD. 258 GPM 2,105 PSI DPP. 20% F/O, 150 RPM, BAK TO with 10K WOB. ECD'c = 11.3, Off bottom 2,100 PSI, UP WT = 125K, DWN WT = 71 K. ROT = 96K. 5.5K TO. ADT .4.47 Bit hrs 9.17, Jar hrs 9.17 Max gas = 109 units Troubleshooting MWD system while drilling SPR's @ 9,323' MD 3,830' TVD MW = 9.1+ PPG hrs 0600 1) 20 SPM 540 PSI 30 SPM - 750 PSI 2) 20 SPM 530 PSI 30 SPM - 740 PSI 7/29/2018 7/29/2018 2.00 PROD3 DRILL DDRL X DDRL 6 1/8" hole form 9,798' MD 9,798.0 9,876.0 12:00 14:00 3,840' TVD - 9,876' MD 3,842' TVD. 258 GPM 2,100 PSI DPP. 20% F/0, 150 RPM, 8.4K TO with 6K WOB. ECD'c = 11.3, Off bottom 2,100 PSI, UP WT= 125K, DWN WT= 71 K. ROT= 96K. 5.5K TO. ADT 1.0 Bit hrs 10. 17, Jar hrs 10.17 Max gas = 109 units 7/29/2018 7/29/2018 1.50 PROD3 DRILL OTHR XT Troubleshoot MWD. Sporadic 9,876.0 9,876.0 14:00 15:30 communication. 7/29/2018 7/29/2018 1.50 PROD3 DRILL BKRM XT BROOH from 9,876' MD - 9,514' MD 9,876.0 9,514.0 15:30 17:00 @ 240 GPM 1,860 PSI DPP. F/O = 20%, 100 RPM with 5K TQ. UP WT = UP WT = 124K, DWN WT = 97K. 7/29/2018 7/29/2018 1.00 PROD3 DRILL CIRC XT Pump 60 BBL High Vis pill while 9,514.0 9,800.0 17:00 18:00 rotating from 9,514' Md - to 9,800' MD. UP WT = 120K, DWN WT = 74K. Monitor lisp via Pits 1-5. 7/29/2018 7/29/2018 0.50 PROD3 DRILL SVRG X Troubleshoot drawworks shut down. 9,800.0 9,800.0 18:00 1830 7/29/2018 7/30/2018 5.50 PROD3 DRILL DDRL X Ream to bottom and DDRL from 9,800.0 10,465.0 18:30 0000 9,876' MD 3,842 TVD - 10,465' MD 3,885' TVD. @ 250 GPM 2,160 PSI DPP. 18% F/0, 150 RPM 8K TO, 4.5K WOB. ECD's = 11.78 PPG. Off BTM = 2,150 PSI. UP WT = 130K, DWN WT = 68K, ROT = 95K. 7K TO. Max gas = 67 units, ADT = 3.37, Bit hrs = 13.54, Jar= 13.54. SPR's @ 9,895' MD 3,843' TVD MW = 9.1 PPG, hrs = 1915 1) 20 SPM = 550 PSI 30 SPM = 760 PSI 2) 20 SPM = 550 PSI 30 SPM = 780 PSI Page 28135 Report Printed: 8/1012018 Operations Summary (with Timelog Depths) IH -108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Our (hr) Phase Op code Activity Code Time P -T -X Operabn Stan Depth ntKB) End Deplh ^13) 7/30/2018 7/30/2018 4.50 PROD3 DRILL DDRL DDRL from 10,465' MD 3,885' TVD - 10,465.0 10,725.0 00:00 04:30 10,725' MD 3,895' TVD. @ 250 GPM 2,270 PSI DPP. 19% F/O, 150 RPM 7.8K TO, 3K WOB. ECD's = 11.82 PPG. Off BTM = 2,260 PSI. UP WT = 132K, DWN WT = 65K, ROT = 100K. 7K TO. Max gas = 60 units, ADT = 1.97, Bit hrs = 15.51, Jar = 15.51. SPR's @ 10,725' MD 3,895' TVD MW = 9.0 PPG, hrs = 0509 1) 20 SPM = 640 PSI 30 SPM = 840 PSI 2) 20 SPM = 620 PSI 30 SPM = 840 PSI 7/30/2018 7/30/2018 0.50 PROD3 DRILL CIRC XT Circulae bottoms up while 10,725.0 10,725.0 04:30 05:00 reciprocating from 10,724' MD - 10,656' MD. 250 GPM @ 2,270 PSI DPP. 19% F/O, 140 RPM, 7K TO. pumped 2,300 STKs total. POOH to change out smart tools! 7/30/2018 7/30/2018 0.50 PROD3 DRILL OWFF XT Observe well for flow(droped l"). 10,725.0 10,725.0 05:00 05:30 7/30/2018 7/30/2018 6.00 PROD3 DRILL BKRM XT BKRM OOH from 10,725' MD, to 10,725.0 8,468.0 05:30 11:30 8,468' MD @ 250 GPM, 2,067 PSI, 19% F/O. 150 RPM, 5.5K TQ, 11.21 ECD. UP WT=110, DWN WT=65K. 7/30/2018 7/30/2018 1.50 PROD3 DRILL CIRC XT Pump a high vis pill and circulate / 8,468.0 8,468.0 11:30 13:00 recip from 8,468' MD - 8,373' MD. @ 250 GPM, 2,260 PSI 19% F/O, ECD = 111,66,120 RPM 5K TQ. 7/30/2018 7/30/2018 4.00 PROD3 DRILL TRIP XT Monitor well for static (passed), POOH 8,468.0 395.0 13:00 1700 on elevators to BHA after pumping dry job from 8,468' MD - 395' MD UP WT = 118K DWN WT = 79K. 7/30/2018 7/30/2018 1.50 PROD3 DRILL BHAH XT Monitor well and lay down BHA#9 as 395.0 0.0 17:00 1830 per SLB rep. Standing back DC/JArs. Monitor disp via TT. Clean rig floor. 7/30/2018 7/30/2018 1.00 PROD3 DRILL BHAH XT MU BHA# 10 as per SLB rep to 365' 0.0 365.0 18:30 1930 MD. Monitor disp via TT. 7/30/2018 7/30/2018 0.75 PROD3 DRILL TRIP XT Trip in hole from 365' MD - 2,255' MD, 365.0 2,255.0 19:30 2015 UP WT=80K. DWN WT=77K. Monitor disp via TT. 7/30/2018 7/30/2018 0.25 PROD3 DRILL DHEQ XT Shallow hole test MWD @ 240 GPM 2,255.0 2,255.0 20:15 20:30 1,430 PSI, 19% F/O, 40 RPM. (GOOD). 7/30/2018 7/31/2018 3.50 PROD3 DRILL TRIP XT Continue to trip in hole form 2,255' MD 2,255.0 8,913.0 20:30 00:00 - 8,913'MD 85K UP WT/42K DWN WT . Monitor disp via TT. fill pipe every 20 stands. 7/31/2018 7/31/2018 0.75 PROD3 DRILL TRIP XT Continue tripping in hole F/ 8,916' MD 8,913.0 10,626.0 00:00 00:45 - T/ 10,626' MD. Monitor displacement via trip tank Up 138k. Down 74k. 7131/2018 7/31/2018 0.75 PROD3 DRILL REAM XT Wash down F/ 10,626'MD - T/ 10,725' 10,626.0 10,725.0 00:45 01:30 MD 2509pm,2,415 psi. 18% flow out, 100 rpm, 5.7k Torque. 11.6 ECD. SPR's at 10,711' MD 3,897' TVD MW 9.2 MP#1) 20 spm - 680 psi, 30 spm - 880 psi MP#2) 20 spm - 640 psi, 30 spm - 860 psi Page 29135 Report Printed: 8/10/2018 Operations Summary (with Timelog Depths) 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log StartTime End Time Dur (hr) Phase Op Code Activity Code Time P -T-% Opemfon Start Depth (flKB) End Depth(fiKB) 7/31/2018 7/31/2018 4.50 PRODS DRILL DDRL X Drill 6-1/8" Production hole section F/ 10,725.0 11,097.0 01:30 06:00 10,725' MD - T/11,097' MD, 3,896' TVD 250 gpm, 2,460 psi. 18% flow out. 150 rpm, 8.5k Torque, 7.5k bit wt. ECD's 11.88 ppg. off bottom psi=2,450. Up 130k, down 64k, rot 92k. 6k. Torque off bottom,Gas units = 0 ADT - 2.98, Bit hrs. 2.98, jar hrs. - 18.49 7/31/2018 7/31/2018 6.00 PRODS DRILL DDRL X Drill 6-1/8 "Production hole section F/ 11,097.0 11,490.0 06:00 1200 11,097' MD - T/11,490' MD, 3,894' TVD 250 gpm, 2,400 psi. 19% flow out. 150 rpm, 7k Torque, 3k bit wt. ECD's 11.99 ppg. off bottom psi=2,400. Upl23k,down72k, rot 94k.6kTorque off bottom,Gas units = 0 ADT - 4.2, Bit hrs. 7.18, jar hrs. - 22.69 SPR's at 11,283' MD 3,901' TVD MW 9.2+ MP#1) 20 spm - 740 psi, 30 spm - 960 psi MP#2) 20 spm - 700 psi, 30 spm - 930 psi 7/31/2018 7/31/2018 6.00 PROD3 DRILL DDRL X Drill 6-1/8" Production hole section F/ 11,841.0 12,318.0 12:00 18:00 11,841' MD - T/12,318' MD, 3,925' TVD 250 gpm, 2,630 psi. 18% flow out. 150 rpm, 11 k Torque,20k bit wt. ECD's 12.09 ppg. off bottom psi=2,580. Up141 k,down 65k, rot 100k.7.5 k, Torque off bottom,Gas units = 30 ADT - 4.36, Bit hrs. 16.33, jar hrs. - 31.84 12,068' MD drilled through fault stayed in zone, SPR's at 11,957' MD 3,917' TVD MW 9.1+ MP#1) 20 spm - 720 psi, 30 spm - 930 psi MP#2) 20 spm - 720 psi, 30 spm - 400 psi 7/31/2018 8/1/2018 6.00 PRODS DRILL DDRL X Drill 6-1/8" Production hole section F/ 11,490.0 11,841.0 18:00 0000 11,490' MD -T/11,841' MD, 3,914' TVD 250 gpm, 2,387 psi. 19% flow out. 150 rpm, 8k Torque, 3k bit wt. ECD's 11.82 ppg. off bottom psi=2,380. Upl 30k,down65k, rot 92k.6kTorque off bottom,Gas units = 0 ADT - 4.79, Bit hrs. 11.97, jar hrs. - 27.48 Page 30135 Report Printed: 8/10/2018 Summary (with Timelog Depths) isOperations IH -108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time Dur(hn Phase Op Code Activity Code Time P -T -X Operation Stan Depth (RKB) End Depth(flKB) 8/1/2018 8/1/2018 6.00 PROD3 DRILL DDRL X Drill 6-1/8" Production hole section F/ 12,318.0 12,452.0 00:00 0600 12,318' MD - T/12,452' MD, 3,939' TVD 250 gpm, 2,585 psi. 18% flow out. 150 rpm, 8k Torque, 4k bit wt. ECD's 12.19 ppg. off bottom psi=2,580. Up143 k,down73 k, rot 104 k.8.5 kTorque off bottom, Gas units = 60 ADT - 4.86, Bit hrs. 21 .19, jar hrs. - 36.7 8/1/2018 8/1/2018 6.00 PROD3 DRILL DDRL X Drill 6-1/8" Production hole section F/ 12,452.0 12,900.0 06:00 12:00 12,452' MD - T/12,900' MD, 4,128' TVD 250 gpm, 2,765 psi. 18% flow out. 150 rpm, 8 k Torque, 4k bit wt. ECD's 12.60 ppg, off bottom psi=2,755. Up152 k,down 83 k, rot 108 k.8 kTorque off bottom, Gas units = 238 ADT - 4.32, Bit hrs. 25.51, jar his. - 41.02 SPR's @ 12,489' MD 3,949' TVD MW - 9.2+ ppg MP # 1) 20 spm = 810 30 spm = 1,060 MP # 2) 20 spm = 800 30 spm = 1,020 16 bbl. loss this tour. 8/1/2018 8/1/2018 3.25 PROD3 DRILL DDRL X Drill 6-1/8" Production hole section F/ 12,900.0 13,080.0 12:00 15:15 12,900' MD - T/13,080' MD, 4,233' TVD 250 gpm, 2,950 psi. 18% flow out. 150 rpm, 8k Torque, 10 k bit wt. ECD's 12.58 ppg. off bottom psi=2,930. Up164 k,down 89 k, rot 113 k.8 kTorque off bottom, Gas units = 175 ADT - 1.82, Bit hrs. 27.33, jar hrs. - 42.84 MP # 1) 20 spm = 880 30 spm = 1,160 MP # 2) 20 spm = 900 30 spm = 1,170 8/1/2018 8/1/2018 0.25 PROD3 CASING CIRC X Obtain final survey, Take Slow pump 13,080.0 13,080.0 15:15 15:30 rates, Obtain torque and drag data. 8/1/2018 8/1/2018 1 0 PROD3 CASING CIRC X Lay down single drillpipe not in string, 13,080.0 13,040.0 15:30 16:30 Circulate while rotating & reciprocating F/ 13,080' MD - T/ 13,010' MD, 250 gpm, 2,780 psi, 18% flow out, ECD's = 12.39 ppg. 150 rpm, 7 k. torque, 3,144 total strokes pumped. Lay down 2 joints drillpipe not in string. 8/1/2018 8/1/2018 0.50 PROD3 CASING OWFF X Monitor well for flow (Static) 13,040.0 13,040.0 16:30 17:00 8/1/2018 8/1/2018 4.50 PROD3 CASING BKRM X Backream out of hole racking back 13,040.0 11,570.0 17:00 21:30 HWDP and laying down drillpipe to pipeshed. F/13,040'MD - T/ 11,570 MD, 250 gpm,2,390 psi. 17% flow out, ECD's = 11.65 ppg. 150 rpm, 6.5 k torque, up 130 k, Down 70 k. Obtained surveys at pre -determined depths per SLB. Page 31135 Report Printed: 8/10/2018 4_ Uperations Summary (with Timelog Depths) .. 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stag Tme End Time Our (hr) Phase Op Code Activity Cafe Time P-T-X Operation Stan Depth (fiKB) End Depth ^13) 8/1/2018 6/2/2018 2.50 PROD3 CASING BKRM X Continue backreaming out of hole 11,570.0 10,626.0 21:30 00:00 laying down drillpipe to pipeshed. F/ 11,570' MD - T/10,626' MD. 250 gpm, 2,330 psi. 18% flow out, ECD's = 11.62 ppg. 150 rpm, 6 k. Torque, Up 124 k. Down 75 k. SPR's @ 13,080.' MD 4,233' TVD MW -9.2+ ppg MP # 1) 20 spm = 880 30 spm = 1,160 MP # 2) 20 spm = 900 30 spm = 1,170 Mud losses this tour 7 bbls. 8/2/2018 8/2/2018 5.25 PROD3 CASING BKRM X Back ream out of hole F/10,626' MD - 10,626.0 8,500.0 00:00 05:15 T/8,500' MD, 250 gpm,2,085 psi,18e% Flow out. 150 rpm,4.3 k, Torque. ECD's 11.16 ppg. Up 114 k. Down 89 k. 8/2/2018 8/2/2018 1.25 PROD3 CASING CIRC X Circulate at shoe, Rotate & 8,500.0 8,490.0 05:15 0630 Reciprocate F/8,490' MD - T/ 8,435' MD. 250 gpm, 2,085 psi. 17% flow out, 120 rpm, 4 k, Torque. ECD's 11.03 ppg. Up 113 k, Down 89 k. 8/2/2018 8/2/2018 0.25 PROD3 CASING OWFF X Lay down stand #86, Drop 2.0" rabbit 8,490.0 8,442.0 06:30 0645 W/110' wire, Monitor well for 10 min. (Static) 8/2/2018 8/2/2018 1.00 PROD3 CASING TRIP X Pull out of hole on elevators F/8,442' 8,442.0 7,491.0 06:45 0745 MD - T/7,491' MD. Laying down drillpipe to pipeshed. Monitor hole fill via trip tank, Calculated 5.5 bbls. Actual 5.3 bbls. up 113 k, down 87 k. 8/2/2018 8/2/2018 0.50 PROD3 CASING CIRC X Pump 20 bbl. dry job, Blow down 7,491.0 7,491.0 07:45 08:15 topdrive. 8/2/2018 8/2/2018 3.00 PROD3 CASING TRIP X Pull out of hole on elevators, Lay 7,491.0 365.0 08:15 11:15 down drillpipe to pipeshed F/7,491' MD - T/ 7,206' MD. Continue tripping out of hole racking pipe in derrick F/7,206' MD - T/365' MD. Rabbit recovered at top of jars. Monitor hole fill via trip tank. 8/2/2018 8/2/2018 0.75 PROD- CASING BHAH X Monitor well 10 min. (Static) Lay down 365.0 140.0 11:15 12:00 BHA F/ 365' MD - T/140' MD Monitor well via trip tank. 8/2/2018 8/2/2018 1.00 PROD3 CASING BHAH X Lay down remainder of BHA, F/140' 140.0 0.0 12:00 13:00 MD. 8/2/2018 8/2/2018 0.50 COMPZN CASING BHAH X Clear and Clean floor, Drain BOP 0.0 0.0 13:00 13:30 Stack. 8/2/2018 8/2/2018 0.25 COMPZN CASING KURD 'R Pull wear bushing. 0.0 0.0 13:30 13:45 8/2/2018 8/2/2018 1.00 COMPZN CASING WWWH X Make up sub to wash BOP Stack to 4" 0.0 0.0 13:45 14:45 drillpipe, Flush stack at 825 gpm, Lay down wash sub, Blow down topdrive, Drain stack. 8/2/2018 8/2/2018 0.75 COMPZN CASING RURD X Set test plug W/4-1/2" testjoint. Rig up 0.0 0.0 14:45 15:30 test equipment, Flush lines. Page 32/35 ReportPrinted: 8/10/2018 Operations Summary (with Timelog Depths) 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log BIaR Time End Time our (hd Phase Op Cone Activity Code Time P-T-X Operation Stan Depth rIKB) End Depth(ftKB) 8/2/2018 8/2/2018 5.0D COMPZN WHDBOP BOPE X Test BOPE. Tested 250 psi low & 0.0 0.0 15:30 20:30 3,500 psi high 5 min. per test all tests charted. Super and manual operated chokes tested to 2 k. Tested with 3-1/2" & 4-1/2" Test joints. Tested-Annular, lower pipe rams, Blind rams, Choke valves 1-14, HCR & Manual choke & kill, Mezzanine kill line valves, Upper & lower IBOP, 4" XT -39 Dart & TIW, Koomey drawdown initial accumulator pressure-2,900 psi. After function = 1,700 psi. 200 psi build 8 sec, Full system recovery 57 sec. 6 nitrogen bottle average 1,937 psi. Test PVT's & Methane, H2S alarms. Test witnessed by AOGCC rep Austin McLeod. Testing complete 20:30 8/3/2018. 8/2/2018 8/2/2018 0.25 COMPZN WHDBOP ROPE X Pull test plug, Set Wear ring (9" ID) 0.0 0.0 20:30 20:45 8/2/2018 8/2/2018 1.25 COMPZN CASING RURD X R/U to run 4-1/2" Lower completion 0.0 0.0 20:45 22:00 liner, Verify tally. 8/2/2018 8/3/2018 2.00 COMPZN CASING PUTB X Run in hole with 4-i/2" 12.6 ppf L-80 0.0 1,182.0 22:00 00:00 IBT-M liner per detail T/1,182' MD. Monitor displacement visa trip tank, Install 5.88 OD Hyd Centralizers per tally. Up 54 k. down 58 k. 8/3/2018 8/3/2018 4.25 COMPZN CASING PUTB X Continue running in hole with 4-1/2" 1,182.0 4,730.0 00:00 0415 Lower completion per tally, F/1, 182'MD - T/4,730' MD. Install 97 hyd centalizers 5.88 OD, Up 81 k. down 71 k. Monitor displacement via trip tank. 8/3/2018 8/3/2018 1.25 COMPZN CASING OTHR X Make up seal bore assembly and 4,730.0 4,809.0 04:15 05:30 hanger per baker rep. to 4,809' MD Up 83k, down 73k. 8/3/2018 8/3/2018 0.50 COMPZN CASING CIRC X Pick up crossover and i stand 4" 4,809.0 4,809.0 05:30 06:00 drillpipe, Circulate to ensure Flow path clear 4 bpm. - 160 psi. 10% Flow out. 8/3/2018 8/3/2018 0.75 COMPZN CASING RUNL X Run in hole with 4-1/2" Lower 4,809.0 5,854.0 06:00 06:45 completion liner on 4" drillpipe, F/4,904' MD - T/5,854' MD. Down 85k. Displacement monitored via trip tank. 8/3/2018 8/3/2018 0.50 COMPZN CASING SVRG X Service ST-100 Iron Roughneck. 5,854.0 5,854.0 06:45 07:15 8/3/2018 8/3/2018 1.25 COMPZN CASING RUNL X RIH with 4-1/2" Lower completion liner 5,854.0 7,175.0 07:15 08:30 on 4" drillpipe, F/5,854' MD - T/7,175' MD. Displacement monitored via trip tank. 8/3/2018 8/3/2018 0.25 COMPZN CASING CIRC X Fill pipe staging pumps up to 4 bpm. 7,175.0 7,175.0 08:30 08:45 364 psi, 12% flow out, up 103k, down Sok. 8/3/2018 8/3/2018 0.75 COMPZN CASING RUNL X RIH with 4-1/2" Lower completion liner 7,175.0 8,500.0 08:45 09:30 on 4" drillpipe, F/7,175' MD - T/8,500' MD. Displacement monitored via trip tank. 8/3/2018 8/3/2018 0.50COMPZN CASING CIRC X Circulate drillpipe volume staging 8,500.0 8,500.0 09:30 10:00 pump up to 4 bpm. 410 psi,12 % Flow out, 110k up, 79k down 8/3/2018 8/3/2018 2.00 COMPZN CASING RUNL X Run in open hole with 4-1/2" Lower 8,500.0 11,360.0 10:00 12:00 completion liner on 4" drillpipe, F/8,500' MD - T/11,360' MD. Displacement monitored via trip tank. 131 k up 70k down. Page 33/35 Report Printed: 8/10/2018 Operations Summary (with Timelog Depths) 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase on Code Admit, Code Time P -T -X Operation Start Depth (ftKB) End Depth(flKB) 8/3/2018 8/3/2018 2.25 COMPZN CASING RUNL X Run in open hole with 4-1/2" Lower 11,360.0 13,060.0 12:00 1415 completion liner on 4" drillpipe, F/11,360' MD - T/13,082' MD. Space out liner hanger w/Shoe at13,060' MD. 163k up 84k down. Displacement monitored via trip tank. 8/3/2018 8/3/2018 1.00 COMPZN CASING CIRC X Circulate 80 bbls.- drillpipe volume, 13,060.0 13,060.0 14:15 15:15 Stage up to 4 bpm. 789 psi,11 % flow out, 819 total strokes. 8/3/2018 8/3/2018 1.25 COMPZN CASING HOSO X Drop 1.625" setting ball, pump down 13,060.0 13,060.0 15:15 16:30 @ 3 bpm. 610 psi. 12% flow out, reduce to 1 bpm, 390 psi, ball on seat 659 strokes, Set hanger per baker rep increasing pressure to 1,900 psi. Slack off attempt to set hanger twice,lncrease pressure to 2,135 psi. setting hanger with 48k down, increase pressure to 2,400 psi. for 5 min. setting packer, increase pressure to 4,200 psi. releasing HRDE, bleed pressure, pick up 7' up wt. 123k. 4- 1/2" Lower completion slotted liner shoe set at 13,060.14' MD TOL at 8,264.72'. 7" shoe @ 8508.85', 244.13' lap. 8/3/2018 8/3/2018 0.75 COMPZN CASING PRTS X Perform packer test 3,400 psi- 30 min. 13,060.0 13,060.0 16:30 17:15 charted test. Pumped down IA with annular closed and drillpipe open. 8/3/2018 8/3/2018 1.75 COMPZN WELLPR DISP X Pick up additional 6'- pump 30 bbl. 13,060.0 8,239.0 17:15 19:00 spacer, Start displacement over to 9.2 ppg kill wt. brine, at 3 bpm. pump 102 bbl's. and pick up out of liner top to 8,239' MD. Increase pump rate to 12 bom. 3,200 psi. 3,900 total strokes pumped. 8/3/2018 8/3/2018 0.50 COMPZN WELLPR OWFF X Monitor well for flow (Static) 8,239.0 8,239.0 19:00 19:30 8/3/2018 8/3/2018 1.00 COMPZN WELLPR §LPC X Slip and cut 88' of drilling line. 8,239.0 8,239.0 19:30 20:30 8/3/2018 8/4/2018 3.50 COMPZN WELLPR TRIP X TOOH laying down 4" drillpipe to 8,239.0 4,409.0 20:30 00:00 pipeshetl. F/ 8,239' MD - T/4,409' MD. 814/2018 8/4/2078 3.50 COMPZN WELLPR TRIP X TOOH Laying down 4" drillpipe F/ 4,409.0 0.0 00:00 03:30 4,490' MD to surface. 078 8/4/2018 0.25 COMPZN WELLPR BHAH X Lay d baker liner running tool. 0.0 0.0 03:3own 03:30 03:45 8/4/2018 8/4/2018 1.25 COMPZN WELLPR WWWH X Pull wear bushing, Clean BOP stack 0.0 0.0 03:45 05:00 with flushing tool. 8/4/2018 8/4/2018 1.50 COMPZN RPCOMP RURD X Rig up to run 3-1/2" Tubing upper 0.0 0.0 05:00 0630 completion. Verify tubing tally & count. PJSM 8/4/2078 8/4/2018 5.50 COMPZN RPCOMP PUTB X Make up seal assembly, RIH with 3- 0.0 4,492.0 06:30 12:00 1/2" 9.3 ppf. L-80 Hyd 563 upper completion per detail to 4,492' MD. Connections torqued to 2,900 ft/lbs. Disp monitored via trip tank Up 70 k. down 66 k. 8/412018 814/2018 5.00 COMPZN RPCOMP PUTS X RIH with 3-1/2" 9.3 ppf. L-80 Hyd 563 4,492.0 8,223.0 12:00 17:00 upper completion per detail F/4,492' MD - T/8,223' MD. Disp monitored via trip tank Up 84 k. down 61 k. 8/4/2018 8/4/2018 0.50 COMPZN RPCOMP PUTB X RIH with joints 259 through 262, Tag 8,223.0 8,326.0 17:00 17.30 no go at 8,326.51 MD. Lay down joint #262 Page 34135 Report Printed: 8/10/2018 operations Summary (with Timelog Lepths) 1H-108 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T-% Operation Start Depth (ftKB) End Depth(ftKB) 8/4/2018 8/4/2018 1.75 COMPZN RPCOMP CRIH X Make up crossover, Pick up to 8,270' 8,326.0 8,270.0 17:30 19:15 MD, Pump 161 bbl's. corrosion inhibited brine at 3 bpm, 190 psi. 7% flow out. Spot inhibited brine with 82 bbl's 9.2 ppg. brine. 8/4/2018 8/4/2018 1.25 COMPZN RPCOMP HOSO X Lay down 3 joints, (161-159) Pick up 8,270.0 8,324.0 19:15 20:30 space out pups. 3.8579.8479.85'- 1.33' crossover, Joint 4-1/2"Hyd 563 tubing 38.07' pup 3.05 & hanger, Make up to landing joint and land hanger at 8,324.37'10D, 86 k up 61 k down 2.25' off fully located. 8/4/2018 814/20 18 1.25 COMPZN RPCOMP WWSP X Rig up and test hanger seals 5,000 psi 8,324.0 8,324.0 20:30 21:45 upper and lower tests. Test good. 8/4/2018 8/4/2018 1.25 COMPZN RPCOMP PRTS X Rig up and test IA and hanger. 1,500 8,324.0 8,324.0 21:45 2300 psi F/10 min. 21 strokes. Pump up to 2,000 psi F/30 min 25 strokes, Pressure up to 2,787 psi to shear SOV, 32 strokes. 3 bbl's received on bleed back 8/4/2018 8/5/2018 1.00 COMPZN WHDBOP NUND X Remove flow riser, Choke and kill 8,324.0 0.0 23:00 00:00 hoses, Unbolt BOPE flanges. 8/5/2018 8/5/2018 1.00 COMPZN WHDBOP NUND X Set back BOP Stack, Remove Spacer D.0 0.0 00:00 01:00 spools. 8/5/2018 8/5/2018 3.00 COMPZN WHDBOP NUND X Nipple up Tree, Install test dart, Test 0.0 0.0 01:00 04:00 hanger void 5 k. 15 min. Test tree body 5 k. 15 min. (Charted) Remove lest dart and BPV. 8/5/2018 8/5/2018 3.75 COMPZN WHDBOP FRZP X Rig up and pump 93 bbl,. diesel 0.0 0.0 04:00 0745 freeze protect. with Little Red Services. Pump down IA returns up tubing to open top tank holding back pressure with choke skid. Rate .8 bpm, 2,000 psi. Shut in tubing 220 psi. Blow down and rig down. OA = 140 PSI. 8/5/2018 8/5/2018 1.25 DEMOB MOVE RURD X Secure tree and Cellar. OA= 140 psi, 07:45 09:00 IA = 0.0 psi. TBG = 200 psi. Release Rig @ 09:00 Page 35/35 ReportPrinted: 8/10/2018 NADConversion Kuparuk River Unit Kuparuk 1H Pad IH -108B film MO . :-] ConocoPhillips Definitive Survey Report 06 August, 2018 rinal Definitive Survey Verified and Signed -off AM targets and/or wellposkion objectives have been achieved. El Yes [ No 1 have checked to the best of try abft that the following data is correct: Surface Coordinates Declination & Convergence _ GRS Surrey Corrections Survey Tool Codes Brandon Temr� le Digitally signed by Brandon Tern ple SLB DE: p Wte:2018.08A614:5733-0800' Client Representative: Madeline Woodard og'u""Sgrs°b'""'iii.W° d Dm:201808071 t _wao -08'orr Date: VIILVLMN mll ConocoPhillips Conocoftillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 1H-108 Project: Kuparuk River Unit TVD Reference: 1H-1088 92.62usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1 H-1088 (rra 92.62usft (Doyon 142) Well: 11-1-108 North Reference: True Wellbore: 1H -108B Survey Calculation Method: Minimum Curvature Design: 11-1-108B Database: OAKEDMP2 'reject Kuparuk River Unit, North Slope Alaska, United States Lisp System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point gap Zone: Alaska Zone 04 Using geodetic scale factor well 1H-108 Well Position +NIS 0.00 usft Northing: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wallbore 1 H-1086 Magnetics Model Name Sample Date BGGM2018 7/15/2018 Design 11-1-1086 Audit Notes: Version: 1 0 Vertical Section: Data 5,980,752.52 usft Latitude: 549,570.98 usft Longitude: usft Ground Level: Declination Dip Angie Pl (9 17.08 80.92 70° 21'29.515 N 149° 35'50.595 W 54.00 usft Field Strength (nn 57,451 Phase: ACTUAL Tie On Depth: 1,847.94 Depth From (TVD) +N/S +E/ -W Direction ("to (usft) (usft) (1) 38.62 0.00 0.00 95.49 From To Welt) Walt) survey (wellbore) 120.11 1,266.01 1H-108 Srvy 1-SLB_GWD70 (1H-108) 1,361.62 1,749.66 1H-108 Srvy 2 - SLB _MWD+GMAG (1H- 1,847.57 1,847.57 1H-108 Srvy 3 - SLB_MWD+GMAG (1H- 1,888.25 1,986.73 1 H-1088 Srvy 1 - MWD -INC -ONLY (1 H-1 2,037.70 2,258.471H -108B Srvy 2-SLB_MWD+GMAG(1H 2,312.57 6,128.601H-1088 Srvy 3- SLB _MWD+GMAG(iH 6,181.68 8,451.771H-108BSrvy4-SLB_MWD+GMAG(1H 8,551.58 10,664.17 1 H-1088 Srvy 5 - SLB_M WD+GMAG (1 H 10,710.66 13,019.61 1 H-1088 SrW 6 - SLB_M WD+GMAG (1H Tool Name Description Survey Date GYD-GCSS Gyrodata gym single shots 6/16/2018 8:51:- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/16/2018 8:54:-'. MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/19/2018 8:55: - MWD -INC -ONLY MWD -INC _ONLY -FILLER 7/21/2018 9:01: MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/21/2018 9:27' MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 7/21/2018 9:30: MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/24/2018 9:34: MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/28/2018 932! MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/30/2018 8:35: - Survey Map Map Vertical MD Inc Azl TVD TVDSS +W s +FJ -W Northing Easting DLS Section (usft) 11 11 (usft) (usft) (usft) (awl" (it) (it) (°/100') (ft) Survey Tool Name 38.62 0.00 O.OD 38.62 54.00 0.00 0.00 5,980,752.52 549,570.98 0.00 0.00 UNDEFINED 120.11 0.15 315.17 120.11 27.49 0.08 -0.08 5,980,752.60 549,570.90 0.18 -0.08 GYD-GCSS(1) 147.47 0.08 176.35 147.47 54.85 0.08 -0.10 5,980,752.60 549,570.88 0.79 -0.11 GYD-GCSS (1) 239.26 0.20 174.22 239.26 146.64 -0.14 -0.08 5,980,752.38 549,570.90 0.13 4).07 GYD.GCSS(1) 335.83 0.12 174.23 335.83 243.21 -0.41 -0.05 5,980,752.11 549,570.93 0.08 -0.01 GYO-GC-SS(1) 428.89 1.29 146.15 428.88 336.26 -1.38 0.54 5,980,751.15 549,571.53 1.27 0.67 GYD-GC-56(1) 519.25 1.88 132.82 519.21 426.59 -3.23 2.20 5,980,749.31 549,573.20 0.77 2.49 GYD-GCSS(1) arw201B 2:35.911cM Page COMPASS 5000.14 Build 85 I ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 1H-106 Project: Kuparuk River Unit TVD Reference: 1H -08B @ 92.62usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1H-0813 @ 92.62usft (Doyon 142) Well: 1H-108 North Reference: True Wellbore: 1H -108B Survey Calculation Method: Minimum Curvature Design: 1 H-1 08B Database: OAKEDMP2 Survey Map Map vertical MD Inc Azi TVD TVDSS +NIS +&4N Northing Easting DLS Section (ustt) P) (') (uaft) Wt) (waft) (am) (1t) (ft) (-11007 (ft) Survey Toot Name 610.50 2.81 125.22 610.38 517.76 E54 5.12 5,980,747.02 549,576.14 1.07 5.63 GYD-GCSS(1) 700.62 4.86 123.76 700.29 607.67 5.93 10.10 5,980,743.66 549,581.14 2.28 10.91 GYD-GCSS(1) 791.11 7.14 120.25 790.28 697.66 -13.90 18.15 5,980,738.75 549,569.21 2.55 19.39 GYD-GCSS(1) 686.04 10.45 122.90 BB4.08 791.46 -21.55 30.47 5,980,731.18 549,601.59 3.51 32.39 GYD-GC-SS(1) 981.23 12.58 121.52 977.35 884.73 -31.66 46.55 5,980,721.18 549,617.74 2.26 49.37 GYD-GCSS(1) 1,076.60 14.17 121.36 1,070.33 977.71 43.19 65,42 5,98,709.T7 549,636.68 1.66 69.25 GYD-GCSS(1) 1,171.28 15.91 122.81 1,161.57 1.WB.95 56.23 86.18 5,980,696.87 549657.52 1.88 91.16 GYD-GCSS(1) 1,266.01 18.99 124.39 1,251.93 1,159.31 -71.97 109.82 5,980,681.28 549,681.26 3.29 116.20 GYD-GCSS(1) 1,361.62 21.79 123.25 1,341.54 1,248.92 410.49 137.50 5,980,662.95 549,709.06 2.96 145.52 MWD+IFR-AK-CAZSC (2) 1,421.83 23.55 123.41 1,397.09 1,304.47 -103.24 156.89 5,9,650.33 549,728.53 2.92 166.04 MWD+IFR-AK-CAZSC (2) 1,515.96 25.66 123.18 1,482.67 1,390.05 -124.76 189.65 5,980,629.03 549,761.43 2.24 200.71 MWD+IFR-AK-CAZ-SC(2) 1,611.61 25.72 122.60 1,568.87 1,476.25 -147.27 224.46 5,980,606.75 549,796.39 0.27 237.52 MWD+IFR-AK-CAZ-SC(2) 1,706.90 26.11 123.45 1.654.57 1,561.95 -169.97 259.38 5,980,564.29 549,831.45 0.57 274.45 MWD+IFR-AK-CAZSC(2) 1,749.66 27.12 123.75 1,692.80 1,600.18 -180.57 275.33 5,980,573.79 549,847.46 2.38 291.34 MWD+IFR-AK-GAZSC (2) 1,847.57 29.90 121.08 1,778.84 1,686+22 -205.57 314.80 5,980,549.05 549,867.10 3.12 333.02 MWD+IFR.AK-CAZSC (3) 1,888.25 30.19 122.17 1,814.05 1,721.43 -216.25 332.14 5,980,536.49 549,904.51 1.52 351.30 MWD -INC -ONLY (4) 1,986.73 33.88 124.56 1,897.52 1,804.90 -245.02 375.72 5,980,510.02 549,948.28 3.96 397.44 MWD -INC -ONLY (4) 2,037.70 36.45 125.64 1,939.19 1,846.57 -261.90 399.73 5,980,493.29 549,972.40 5.19 422.95 MWD+IFR-AK-CAZSC(5) 2,066.27 38.41 127.64 1,977.76 1,865.14 -279.53 423.41 5,980,475.83 549,996.19 4.75 448.20 MWD+IFR-AK-CAZSC (5) 2,132.47 40.28 130.20 2,013.48 1,920.86 -297.93 446.18 5,980,457.57 550,019.08 5.36 472.64 MWD+IFR-AK-CAZSC(5) 2,164.18 41.64 131.92 2,037.43 1,944.81 S11.59 461.85 5,980,444.02 550,034.64 5.57 489.54 MWD+IFR-AK-CAZ-SC(5) 2,195.67 43.04 133.05 2,060.71 1,968.09 -325.92 477.49 5,980,429.80 550,050.57 5.06 506.46 MWD+IFR-AK-CAZ-SC (5) 2,227.18 45.08 133.31 2,083.35 1,990.73 540.91 493.47 5,98,414.92 550,066.64 6.50 523.82 MWD+IFR-AK-CAZ-SC(5) 2,258.47 47.07 134.42 2,105.06 2,012.44 -356.53 509.71 5,98,399.41 550,082.99 6.85 541.48 MWD+IFR-AK-CAZSC(5) 2,312.57 49.98 134.62 2,140.88 2,048.26 384.95 538.61 5,980,371.18 550,112.07 5.39 572.96 MWD+IFR-AK-CAZSC(6) 2,357.88 51.64 134.19 2,169.51 2,076.89 -009.52 563.70 5,980,346.78 550,137.32 3.74 600.29 MWD+IFR-AK-CAZSC(6) 2,418.42 54.00 132.57 2,206.10 2,113.48 -042.64 598.76 5,98,313.90 550,172.60 4.44 636.35 MWD+IFR-AK-CAZ-SC (6) 2,471.47 54.93 132.07 2,236.93 2,144.31 -471.70 630.68 5,980,28505 550,204.70 191 672.91 MWD+IFR-AK-CAZSC(6) 2,513.00 5518 131.95 2,260.54 2,167.92 494.57 656.06 5,980,262.36 550,230.24 2.06 700.36 MWD+IFR-AK-CAZSC(6) 2,570.25 57.47 131.42 2,292.03 2,199.41 526.36 691.77 5,960,230.80 550,266.15 3.05 738.95 MWD+IFR-AK-CAZSC (6) 2,608.64 58.59 131.69 2,312.36 2,219.74 547.% 716.14 5,980,209.36 550,290.66 2.96 765.27 MWD+IFR-AK-CAZSC (6) 2,703.84 60.44 132.77 2,360.65 2,268.03 503.10 776.88 5,980,154.63 550,351.75 2.18 831.00 MWD+IFR-AK-CAZ-SC (6) 2,799.16 63.47 133.87 2,405.46 2,312.84 -660.82 B38.06 5,980,097.33 550,413.32 3.34 897.43 MWD+IFR-AK-CAZSC(6) 2,894.64 67.33 134.20 2,445.20 2,352.58 -721.15 900.46 5,980,037.41 550,476.11 4.05 965.32 MWD+IFR-AK-CAZSC(6) 2,989.70 70.03 133.23 2,479.76 2,387.14 -782.34 964.47 5,979,976.66 550,540.51 3.00 1,034.88 MWD+IFR-AK-CAZSC(6) 3,065.01 70.58 130.97 2,511.89 2,419.27 542.49 1,031.04 5,979,916.95 550,607.48 2.31 1,106.91 MWD+IFR.AK-CAZSC (6) 3,132.91 71.15 128.77 2,527.59 2,434.97 571.50 1,065.77 5,979,888.18 550,642.39 4.50 1,144.25 MWD+IFR-AK-CAZ-SC (6) 3,179.12 72.08 125.75 2,542.17 2,449.55 598.04 1,100.67 5,979,861.87 550,677.46 6.52 1,181.53 MWD+IFR-AK-CAZSC(6) 3,228.07 71.97 122.73 2,557.28 2,464.66 524.24 1,139.16 5,979,835.93 550,716.12 5.87 1,222.34 MWD+IFR-AK-CAZSC(6) 3,275.0 72.02 120.25 2,571.78 2,479.16 547.55 1,177.21 5,979,812.87 550,754.32 5.03 1,262.45 MWD+IFR-AKCAZSC(6) 87872018 2:35:31PM Page 3 COMPASS 5000.14 Build 85 i ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well iH-108 Project: Kuparuk River Unit TVD Reference: iH-08B @ 92.62usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1 H -08B @ 92.62usft (Doyon 142) Well: 1H-108 North Reference: True Wellbore: 11-1-108B Survey Calculation Method: Minimum Curvature Design: 1 H-1088 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azl TVD TVDSS +N15 +El -W Northing Easting OLS Section (usft) P) r) (usft) (usft) (-ft) (11911) (R) (R) (°/1001 (R) Survey Tool Name 3,323.28 71.75 117.23 2,586.80 2,494.18 -969.61 1,217.49 5,979,791.08 550,794.69 5.97 1,304.61 MWD+IFR-AK-CAZ-SC (6) 3,370.61 71.60 116.27 2,601.68 2,509.6 -989.83 1,257.56 5,979,771.13 550,834.94 1.95 1,346.48 MWD+IFR-AK-CAZ-SC (6) 3,465.87 69.49 116.01 2,633.41 2,540.79 -1,029.40 1,338.19 5,979,732.09 550,915.82 2.23 1,430.52 M AFR-AK-CAZ-SC (6) 3,561.28 69.69 116.11 2,666.68 2,574.6 -1,068.69 1,418.52 5,979,693.35 550,996.40 0.23 1,514.24 MW0+IFR-AK-CAZSC (6) 3,655.31 69.35 115.81 2,699.58 2,606.96 -1,107.25 1,497.72 5,979,655.32 551,075.85 0.47 1,5%.T MWD+IFR-AK-CAZSC(6) 3,750.0 69.37 116.61 2,733.10 2,640.48 -1,146.55 1,577.55 5,979,616.55 551,155.93 0.79 1,680.00 MWD+IFR-AK-CAZ-SC(6) 3,846.59 69.27 117.38 2,767.07 2,674.45 -1,187.40 1,657.74 5,979,576.24 551,236.38 0.76 1,763.72 MWD+IFR-AK-CAZ-SC(6) 3,942.28 69.15 118.65 2,801.03 2,708.41 -1,229.41 1,736.72 5,979,534.74 551,315.62 1.25 1,846.35 MWDAFR-AK-CAZSC(6) 4,036.43 69.12 119.26 2,834.57 2,741.95 -1,272.00 1,813.69 5,979,492.67 551,392.88 0.61 1,927.05 MWD+IFR-AK-CAZSC(6) 4,131.68 69.29 119.83 2,868.38 2,775.76 -1,315.91 1,891.16 5,979,449.28 551,470.62 0.59 2,008.36 MWD+11FR-AK-CAZSC(6) 4,227.08 69.14 121.04 2,902.24 2,809.62 -1,361.09 1,968.6 5,979,404.61 551,547.81 1.20 2,089.23 MWD+1FR-AK-CAZ-SC(6) 4,322.41 69.31 121.09 2,936.05 2,843.43 -1,407.09 2,044.41 5,979,359.13 551,624.46 0.18 2,169.63 MWD+IFR-AK-CAZSC(6) 4,417.20 69.56 122.00 2,969.35 2,876.73 -1,453.52 2,120.04 5,979,313.21 551,700.39 0.94 2,249.36 MW0+IFR-AK-CAZSC(6) 4,512.03 70.35 121.02 3,001.85 2,909.23 -1,500.07 2,195.99 5,979,267.16 551,776.64 1.28 2,329.41 MWD+IFR-AK-CAZ-SC(6) 4,607.53 69.79 119.60 3,039.41 2,941.79 -1,545.38 2,273.50 5,979,222.36 551,854.43 1.52 2,410.90 MWD+IFR-AK-CAZSC(6) 4,702.67 70.20 119.00 3,066.96 2,974.34 -1,589.13 2,351.46 5,979,179.14 551,932.67 0.73 2,492.69 MWD+IFR-AK-CAZSC(6) 4,797.42 70.42 119.01 3,098.88 3,006.26 -1,632.39 2,429.48 5,979,136.40 552,010.97 0.23 2574.49 MWD+IFR-AK-CAZSC (6) 4,892.54 70.21 118.02 3,130.92 3,038.30 -1,675,15 2,508.17 5,979,094.17 552,089.94 1.00 2,656.91 MWD+IFR-AK-CAZ-SC (6) 4,987.23 70.21 117.04 3,162.98 3,070.36 -1,716.33 2,587.18 5,979,053.52 552,169.21 0.97 2,739.50 MWD+IFR-AK-CAZSC(6) 5,082.94 70.26 117.59 3,195.35 3,102.73 -1,757.66 2,667.21 5,979,012.72 552,249.50 0.54 2,823.11 MWD+IFR-AK-CAZSG(6) 5,177.86 69.88 116.81 3,227.70 3,135.08 -1,798.45 2,746.58 5,978,972.46 552,329.13 0.87 2,90602 MWD+IFR-AKCAZSC (6) 5,272.91 70.39 117.75 3,260.00 3,167.38 -1,839.42 2,826.02 5,978,932.02 552,408.84 1.07 2,989.02 MWD+IFR-AK-CAZ-SC(6) 5,367.61 71.37 118.86 3,291.02 3,198.40 -1 WAS 2,904.80 5,978,890.12 552,487.89 1.52 3,071.49 MWDAFR-AK-CAZ-SC(6) 5,463.08 73.64 121.57 3,319.73 3,227.11 -1,927.68 2,983.46 5,978,894.82 552,566.84 3.60 3,154.18 MWD+IFR-AK-CAZ-SG(6) 5,557.98 74.93 123.92 3,345.43 3,252.81 -1,977.09 3,060.29 5,978,795.92 552,643.99 2.74 3,235.38 MWD+IFR-AK-CAZSG(6) 5,653.64 77.41 124.27 3,358.30 3,275.68 -2,029.15 3,137.20 5,978,744.37 552,721.23 2.62 3,316.92 MWD+IFR-AKCAZ-SC(6) 5,74257 77.15 122.52 3,388.98 3,296.36 -2,079.58 3,213.69 5,978,694.45 552,798.05 1.64 3,397.88 MWD+IFR-AKCAZ-SC(6) 5,843.10 79.98 123.80 3,407.92 3,315.30 -2,130.80 3,292.07 5,978,643.76 552,876.75 3.24 3,480.80 MWD+IFR-AK-CAZSC(6) 5,937.94 80.99 124.58 3,423.60 3,330.98 -2,183.36 3,369.43 5,978,591.72 552,954.46 1.34 3,562.84 MWD+IFR-AK-CAZSC(6) 6,032.63 80.72 124.47 3,438.65 3,346.03 -2,236.34 3,446.46 5,978,539.25 553,031.82 0.31 3,644.57 MWD+IFR-AKCAZ-SC(6) 6,128.60 80.70 123.75 3,454.14 3,361.52 -2,289.46 3,524.87 5,978,486.66 553,110.58 0.74 3,727.71 MWD+IFR-AK-CA7-SC(6) 6,181.68 80.70 123.41 3,462.72 3,370.10 -2,318.43 3,568.51 5,978,457.98 553,154.41 0.63 3,773.92 MWDAFR-AK-W-13C(7) 6,222.69 81.79 122.51 3,468.96 3,376.34 -2,340.48 3,602.52 5,978,436.16 553,188.56 3.43 3,809.88 MWD+IFR-AK-CAZSC(7) 6,269.34 80.38 121.17 3,476.19 3,383.57 -2,364.79 3,641.67 5,978,412.11 553,227.86 4.15 3,851.18 MWD+IFR-AKCAZ-SC(7) 6,317.88 81.82 121.41 3,483.70 3,391.06 -2,389.70 3,682.65 5,978,387.48 553,269.00 3.01 3,894.35 MWD+IFR-AK-CAZ-SC(7) 6,413.22 81.07 121.12 3,497.88 3,405.26 -2,438.63 3,763.24 5,978,339.09 553,349.90 0.84 3,979.25 MWDAFR-AK-CAZSC(7) 6,507.97 80.87 120.73 3,512.75 3,420.13 -2,486.72 3,843.51 5,978,291.53 553,430.49 0.46 4,063.76 MWD+IFR-AK-WSC(7) 6,603.35 80.87 120.87 3,527.89 3,435.27 -2,534.94 3,924.40 5,978,243.85 553,511.69 0.14 4,148.89 MWD+IFR-AKCAZ-SC(7) 6,698.55 81.30 121.01 3,542.64 3,450.2 -2,583.29 4,005.07 5,978,196.04 553,592.66 0.47 4,233.81 MWD+IFR-AK-CAZSC(7) 6,793.80 81.30 120.58 3,55205 3,464.43 -2,631.50 4,085.94 5,978,148.38 553,673.85 0.45 4,318.93 MWD+IFR-AK-CAZSC(7) 8Ai4018 2:35:31PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 1 H-108 Project: Kuparuk River Unit TVD Reference: 1 H -08B @ 92.62usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1H-OBB @ 92.62ush (Doyon 142) Well: 1H-108 North Reference: True Wellbore: 1 H-10813 Survey Calculation Method: Minimum Curvature Design: 1 H-1 08B Database: OAKEDMP2 Survey Map Map Vertical ARD Inc AN TVD TVDSS +N/.S +E/ -W Northing Easting DIS Section (usfd P) f°I (usfd Walt) (-t) NO" (ft) Ift) (°/100') (ft) Survey Tool Name 6,888.65 80.66 120.25 3,571.92 3,479.30 -2,678.92 4,166.73 5,978,101.49 553,754.94 076 4,403.88 MWD+IFR-AK-CAZSC(7) 6,983.95 80.77 121.45 3,587.29 3,494.67 -2,727.15 4,247.47 5,978,053.80 553835.99 1.25 4,488.86 MND+IFR-AK-CAZSC(7) 7,079.37 80.60 121.82 3,602.74 3,510.12 -2,776.54 4,327.64 5,978,004.95 553,916.48 0.42 4,573.39 MWD+IFR-AK-CAZSC(7) 7,174.2 80.04 122.21 3,618.65 3,526.03 -2,826.00 4,406.75 5,977,956.02 553,995.91 0.72 4,656.87 MWD+1FR-AK-CAZSC(7) 7,268.88 80.93 120.76 3,634.34 3,541.72 -2,874.86 4,486.53 5,977,907.69 554,076.00 1.78 4,740.96 MWD+IFR-AK-CAZSC(7) 7,319.13 80.84 118.50 3,642.30 3,549.68 -2,899.39 4,529.66 5,977,883.45 554,119.28 4.44 4,786.23 MWD+IFR-AK-CAZSC(7) 7,363.91 79.33 115.68 3,650.01 3,557.39 -2,919.47 4,568.92 5,977,863.63 554,158.68 7.06 4,827.24 MWD+IFR-AK-CAZSC(7) 7,410.45 78.96 113.35 3,658.77 3,566.15 -2,938.44 4,610.51 5,977,844.94 554,200.38 4.98 4,870.45 MWD+IFR-AK-CAZ.SC(7) 7,459.77 79.55 110.07 3.667.97 3,575.35 -2,956.35 4,655.52 5,977,827.32 554,245.51 6.64 4,916.97 MWD+IFR-AK-CAZSC(7) 7,554.48 80.38 105.70 3,684.48 3,591.86 -2,984.99 4,744.25 5,977,799.28 554,334.42 4.63 5,008.03 1AWD+1FR-AK-CAZSC(7) 7,649.47 81.03 101.62 3.699.83 3,607.21 -3,007.12 4,835.32 5,977,777.76 554,425.62 4.29 5,100.80 MND+IFR-AK-CAZSC(7) 7,745.90 80.95 102.04 3,714.93 3,622.31 -3,026.69 4,928.54 5,977,758.85 554,518.96 0.44 5,195.46 MND+1FR-AK-CAZSC(7) 7,840.30 81.55 101.77 3,729.29 3,636.67 -3,045.89 5,019.83 5,977,740.21 554,610.37 0.70 5,288.17 MWD+IFR-AK-CAZSC(7) 7,887.10 81.02 99.08 3,736.39 3,643.77 -3,054.26 5,065.32 5,977,732.14 554,655.91 579 5,334.26 MWD+IFR-AK-CAZSC(7) 7,934.89 80.90 97.02 3,743.90 3,651.28 41,060.87 5,112.05 5,977,725.84 554,702.68 4.26 5,381.40 MND+IFR-AK-CAZSC(7) 8,030.22 81.59 93.73 3,758.41 3,665.79 -3,069.69 5,205.84 5,977,717.69 554,796.52 3.49 5,475.61 MWD+IFR-AK-CAZSC(7) 8,126.01 82.90 89.89 3,771.34 3,678.72 41,072.68 5,300.69 5,977,715.28 554,891.37 4.20 5,570.31 MWD+IFR-AK-CAZSC(7) 8,220.26 83.95 85.70 3,782.14 3,689.52 -3,069.08 5,394.23 5,977,719.50 554,984.87 4.55 5,663.07 MWD+IFR-AK-CAZSC(7) 8,315.38 85.73 84.61 3,790.69 3,698.07 -3,061.08 5,488.62 5,977,728.13 555,079.20 2.19 5,756.26 MWD+IFR-AK-CAZSC(7) 8,410.43 83.34 82.41 3,799.74 3,707.12 -3,050.39 5,582.62 5,977,739.44 555,173.12 3.41 5,848.81 MND+1FR-AK-CAZSC(7) 8,451.77 84.54 83.15 3,804.11 3,711.49 5,045.22 5,623.0 5,977,744.87 555,213.86 3.41 5,888.91 MWD+IFR-AK-CAZ-SC (7) 8,551.58 86.52 82.13 3,811.89 3,719.27 -3,032.47 5,722.08 5,977,758.27 555,312.4 2.23 5,985.92 MWDHFR-AK43AZSC(8) 8,596.99 86.57 80.25 3,814.62 3,722.00 5,025.53 5,766.87 5,977,765.51 555,357.18 4.13 6,029.84 MND+1FR-AK-CAZSC (8) 8,691.91 89.14 76.40 3,818.18 3,725.56 5,006.34 5,859.73 5,977,785.32 555,449.91 4.87 6,120.44 MWD+IFR-AK-CAZSC(8) 8,786.73 89.00 76.95 3,819.72 3,727.10 -2,984.49 5,951.99 5,977,807.77 555,542.01 0.60 6,210.18 MND+1FR-AK-CAZSC (8) 8,881.86 88.79 77.71 3,821.55 3,728.93 -2,963.63 6,044.78 5,977,829.25 555,634.66 0.83 6,300.56 MND+IFR-AK-CAZSC (8) 8,976.55 88.94 79.62 3,823.43 3,730.81 -2,945.02 6,137.61 5,977,848.47 555,727.34 2.02 6,391.17 MND+IFR-AK-CAZSC(8) 9,071.97 88.83 81.43 3,825.28 3,732.66 -2,929.32 6,231.70 5,977,864.79 555,821.32 1.90 6,483.34 MWD+1FR-AK-C ZSC(8) 9,166.56 88.83 81.33 3,827.22 3,734.60 -2,915.14 6,325.20 5,977,879.58 555,914.72 0.11 6,575.05 MND+IFR-AK-CAZSC(8) 9,262.42 88.80 81.15 3,829.20 3,736.58 -2,900.55 6,419.93 5,977,894.80 556,009.34 0.19 6,657.94 MND+IFR-AK-CAZSC (8) 9,356.65 88.79 80.24 3,831.18 3,738.56 -2,885.31 6,512.89 5,97910.65 556,102.19 0.97 6,759.03 MND+IFR-AK-CAZSC(8) 9,451.78 89.18 78.07 3,832.86 3,740.24 -2,867.42 6,606.30 5.977,929.16 556,195.47 2.32 6,850.30 MWD+IFRAK-CAZSC(8) 9,546.64 WS3 75.26 3,834.43 3,741.81 -2,845.55 6,698.59 5,97,951.64 556,287.60 2.97 6,940.06 MWD+IFR-AKLAZSC(8) 9,641.92 89.04 72.60 3,836.12 3,743.50 -2,819.18 6,790.12 5,977,978.61 555,378.95 2.79 7,028.66 MWO+IFR-AK-CAZSC(8) 9,689.60 88.85 69.77 3,837.00 3,744.38 -2,803.80 6,835.24 5,977,994.28 556,423.96 5.95 7,072.10 MWD+IFR-AK-CAZSC(8) 9,736.85 88.03 64.40 3,838.28 3,745.66 -2,785.42 6,878.73 5,978,012.95 556,467.32 11.49 7,113.63 MWD+IFR-AK-CAZSC(8) 9,833.74 87.31 62.38 3,842.22 3,749.60 -2,742.06 6,965.28 5,978,056.88 556,553.57 2.21 7,195.64 MWD+IFR-AK-CAZSC(8) 9,928.33 85.08 65.30 3,848.50 3,755.88 -2,700.45 7,049.98 5,978,099.04 556,637.99 3.88 7,275.97 MWD+IFR-AK-CAZSC(8) 10,021.72 85.88 69.42 3,855.86 3,763.24 -2,664.63 7,135.88 5,978,135.43 556,723.65 4.48 7,358.05 MWD+IFR-AK-CAZ-SC(8) 10,116.75 86.86 71.75 3,861.88 3,769.26 -2,633.10 7,225.32 5,978,167.54 556,812.87 2.66 7,444.07 MWD+1FR-AK-WSC(8) 876/2018 2:35:31PM Page 5 COMPASS WOO.. 14 Build 85 Survey I ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1H-108 Project: Kuparuk River Unit TVD Reference: 1 H -08B @ 92.62usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1 H -08B @ 92.62usft (Doyon 142) Well: 1H-108 North Reference: True Wellbore: 1 H-1 08B Survey Calculation Method: Minimum Curvature Design: 1H -108B Database: OAKEDMP2 Survey Map Map Vertical MD Inc Axl TVD TVDSS +W3 +E/ -W Northing Easting DLS Section (USM r) r) (uslp (usft) (usft) (usft) (M (ft) r11001 (ft) Survey Tool Name 10,211.69 86.36 71.78 3,867.49 3,774.87 -2,603,45 7,315.34 5,978,197.79 556,902.67 0.53 7,630.83 MWD+IFR-AK-CAZSC(8) 10,307.12 86.01 70.71 3,873.84 3,781.22 -2,572.63 7,405.50 5,978,229.0 555,992.62 1.18 7,617.65 MWD+IFR-AK-CAZSC(8) 10,401.72 86.02 71.60 3,880.42 3,787.80 -2,542.35 7,494.81 5,978,260.07 557,081.72 0.94 7,703.64 MWD+1FR-AK-CAZ-SC(8) 10,497.37 85.76 70.77 3,887.27 3,794.65 -2,511.58 7,585.11 5,978,291.43 557,171.81 0.91 7,790.58 MWD+1FR-AK-CAZ-SC(8) 10,546.57 87.34 69.80 3,890.24 3,797.62 -2,495.02 7,631.34 5,978,308.30 557,217.93 3.77 1835.02 MWD+IFRAK-CAZSC(8) 10,592.04 89.53 67.94 3,891.48 3,798.86 -2,478.63 7,673.74 5,978,324.96 557,260.21 6.32 7,875.65 MWD+IFR-AK-CAZSC(8) 10,632.89 88.80 65.21 3,892.07 3,799.45 -2,462.40 7,711.21 5,978,341.45 557,297.57 6.92 7,911.40 MWD+1FRAK-CAZSC(8) 10,664.17 88.17 63.75 3,892.90 3,800.28 -2,448.93 7,739.43 5,978,355.10 557,325.69 5.08 7,938.20 MWD+IFR-AK-CAZ-SC (8) 10,710.66 88.56 61.62 3,894.23 3,801.61 -2,427.60 7,780.72 5,978,376.70 557,366.83 4.66 1977.25 MWD+IFRAK-CAZSC(9) 10,752.18 90.32 60.21 3,694.63 3,802.01 -2,407.42 7,817.00 5,978,397.11 551402.98 5.43 8,011.44 MWD+IFRAK-CAZSC(9) 10,808.27 90.74 55.28 3,894.11 3,801.49 -2,377.50 7,864.41 5,978,427.35 557,450.19 8.82 8,055.78 MWD+IFRAK-CAZ-SC(9) 10,847.11 W0 W 56.18 3,893.56 3,800.94 -2,355.63 7,896.51 5,978,449.43 557,48244 2.35 8,085.63 MWD+1FR-AK-CAZ-SC (9) 10,942.96 89.00 57.99 3,893.64 3,801.02 -2,303.55 7,976.97 5,978,602.03 557,562.24 2.74 8,160.74 MWD+IFRAK-CAZ-SC(9) 11,037.13 88.49 59.64 3,895.70 3,803.08 -2,254.80 8,057.51 5,978,551.31 557,642.45 1.83 8,236.24 MWD+IFR-AK-CAZSC(9) 11,131.84 88.54 58.25 3,898.16 3,805.54 -2,205.96 8,138.61 5,978,600.68 557,723.22 1.47 8,312.31 MWD+IFRAKCAZSC(9) 11,227.05 90.92 54.91 3,898.61 3,805.99 -2,153.53 8,218.06 5,978,653.63 557,802.31 4.31 8,386.38 MWD+IFR-AK-CAZSC(9) 11,321.42 91.47 51.16 3,696.64 3,804.02 -2,096.81 8,293.43 5,978,710.84 557,877.30 4.02 8,455.98 MWD+IFRAK-CAZ-SC (9) 11,416.42 90.40 50.82 3,895.09 3,802.47 -2,037.02 8,367.24 5,978,771.11 557,950.70 1.18 8,523.73 MWD+IFRAK-CAZSC(9) 11,511.18 88.65 50.61 3,895.87 3,803.25 -1,977.02 8,440.58 5,978,831.59 558,023.64 1.86 8,590.99 MWD+IFRAK-WSC(9) 11,603.34 86.30 48.70 3,899.93 3,807.31 -1,917.43 8,510.74 5,978,891.64 558,093.40 3.28 8,655.13 MWD+IFRAK-CAZSC(9) 11,694.90 86.68 49.17 3,905.54 3,812.92 -1,857.39 8,579.65 5,978,952.12 558,161.90 0.66 8,717.98 MWD+IFRAK-CAZ-SC (9) 11,785.94 87.23 49.39 3,910.37 3,817.75 -1,798.09 8,648.55 5,979,011.88 558,230.40 0.65 8,780.89 MWD+IFR-AK-CAZSC(9) 11,876.90 87.84 47.26 3,914.29 3,821.67 -1,737.67 8,716.42 5,979,072.74 558,297.86 2.43 8,842.67 MWDAFRAK-CAZSC(9) 11,929.99 88.35 46.20 3,916.05 3,823.43 -1,701.30 6,755.06 5,979,109.36 558,336.25 2.21 8,677.65 MWD+IFR-AKCAZSC(9) 11,967.79 WW1 42.90 3,916.96 3,824.34 -1,674.37 8,781.56 5,979,136.46 558,362.58 8.85 8,901.46 MWD+IFR-AK-CAZ-SC(9) 12,020.84 89.59 40.05 3,917.65 3,825.03 -1,634.63 8,816.69 5,979,176.43 558,397.44 5.52 8,932.53 MWD+IFRAK-CAZ-SC(9) 12,059.91 89.26 36.50 3,918.04 3,825.42 -1,603.97 8,840.89 5,979,207.25 558,421.43 9.12 8,953.78 MWD+IFRAK-CAZSC(9) 12,151.42 88.75 35.21 3,919.63 3,827.01 -1,529.81 8,894.48 5,979,281.75 558,474.52 1.52 9,000.03 MWD+IFRAK-CAZ-SC(9) 12,208.98 WAS 37.41 3,922.03 3,829.41 -1,483.47 8,928.53 5,979,328.31 558,508.26 5.49 9,029.49 MWD+IFRAKCAZ-SC (9) 12,243.18 88.03 41.22 3,923.67 3,831.05 -1,457.05 8,950.17 5,979,354.87 558,529.72 12.01 9,048.50 MWDAFRA ZAZSC(9) 12,336.32 84.87 43.19 3,929.43 3,836.81 -1,388.20 9,012.61 5,979,424.13 558,591.70 4.00 9,104.07 MWD+IFR-AK-CAZSC(9) 12,384.88 81.71 44.57 3,935.11 3,842.49 -1,353.44 9,046.03 5,979,459.10 558,624.89 7.09 9,134.01 MWD+1FR-AKCAZSC(9) 12,429.25 78.19 45.02 3,942.85 3,850.23 -1,322.44 9,076.80 5,979,490.30 558,655.45 8.00 9,161.68 MWD+IFRAKCAZ-SC(9) 12,477.51 74.91 44.75 3,954.07 3,861.45 -1,289.19 9,109.92 5,979,523.77 558,688.35 6.82 9,19147 MWD+IFRAK-CAZ-SC (9) 12,521.42 72.29 44.80 3,966.47 3,873.85 -1,259.29 9,139.59 5,979,553.% 558,717.81 5.97 9,218.14 MWD+IFRAK-CAZSC(9) 12,613.55 68.69 42.28 3,997.24 3,904.62 -1,196.37 9,199.41 5,979,617.17 558,777.21 4.68 9,271.67 MWD+IFRAKCAZSC(9) 12,703.83 64.32 42.22 4,033.22 3,940.60 -1,135.10 9,255.07 5,979,678.80 558,832.45 4.84 9,321.21 MWD+IFRAKCAZSC(9) 12,772.34 62.02 40.85 4,064.14 3,971.52 -1,089.35 9,295.60 5,979,724.82 558,872.69 3.80 9,357.18 MWD+IFRAK-CAZ.SC (9) 12,796.82 59.65 40.60 4,076.07 3,983.45 -1073.15 9,309.55 5,979,741.10 558,885.52 9.72 9,369.51 MWD+IFR-AK-CAZSC(9) 12,851.70 57.11 39.33 4,104.84 4,012.22 -1,037.34 9,339.57 5,979,777.11 558,916.30 5.03 9,395.97 MWD+1FR-AK-CAZSC(9) 88/2018 2:35:31PM Page 6 COMPASS 500014 Build 85 Company: NADConversion Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: 1 H-108 Wellbore: 1 H-1088 vertical 1H-1 DBB Survey ConocoPhillips Definitive Survey Report Local Coordinate Reference: TVD Reference: MO Reference: North Reference: Survey Calculation Method: Database: Well 1 H-106 1 H -08B ® 92.62usft (Doyon 142) 1 H -08B @ 92.62usft (Doyon 142) True Minimum Curvature OAKEDMP2 8/6/2018 2:35:31PM Page 7 COMPASS 5000.14 Build 85 Map Map vertical MD (asfl) 12,889.11 12,981.65 13,019.61 Inc (') 55.42 56.30 54.99 Azi M 38.04 36.67 36.35 TVD ("it) 4,125.62 4,177.55 4,198.97 TVDSS (usft) 4,033.00 4,084.93 4,106.35 +NIS Wait) -1,013.06 -952.18 -926.99 +PJ -W (wm 9,359.02 9,405.48 9,424.13 Northing (m 5,979,801.51 5,979,862.70 5,979,888.00 Easting (it) 558,935.59 558,981.64 559,000.12 OLS (°11081 5.35 1.55 3.52 Section Survey Toot Naar (it) %413.01 MWD+IFR-AK-SC 9,453.43 MWD+IFR-AK-CA7-SC(9) 9,469.59 MWD+IFR-AK-CAZSC(9) 13,080.00 54.99 36.35 4,233.62 4,141.00 -887.15 9,453.45 5,979,928.03 559,029.17 0.00 9,494.96 PROJECTED 0 TD 8/6/2018 2:35:31PM Page 7 COMPASS 5000.14 Build 85 Cement Detail Report 111-1-108 Job: String: Conductor DRILLING ORIGINAL, 614/2018 00:00 Cement Details Description Conductor Cementing Start Date 11/6/2 10:30 016 CementingEnd Date 11/6/2016 1800 Wellbore Name 1 H-108 Comment 10 yards (5.5 sacks) of aggregate cement poured into backside by AFC. CMT/aggregate ratio of 564/3520 per yard Cement Stages Stage # t Description Conductor Cement ObjectiveTop Depth (ftKB) 39.0 Bottom Depth (ftKB) 119.0 Full Return? No Vol Cement... Top Plug? No Btm Plug? No Q Pump Init (bbl/m... Q Pump Final (bbll...FT.gMeihod Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Conductor Cement Fluitl Description Estimated Top (ftKB) 39.0 Est Btm (ftKB) 119.0 Amount (sacks) 6 Class C Volume Pumped (bbl) 60.0 Yield (ft/sack) 2.13 Mix H2O Ratio (gal/sa... 5.2 Free Water (%) 1 Density (Ib/gal) 15.00 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Page 111 Report Printed: 8/10/2018 Cement Detail Report 11-1-108 • String: Surface Casing Cement Job: DRILLING ORIGINAL, 6/4/2018 00:00 Cement Details Description Surface Casing Cement Cementing Start Date 6/18/2018 11:15 Cementing End Date 6118/2018 14:15 Wellbore Name IH -108 Comment PJSM wl all involved parties for cementing. Pump 5 bbls of H2O to flood lines. Test cement lines to 3500 psi, good. Pump 40 bills of CW -100, 5 bpm, 120 psi, FO 13%. Pump 76 bbls of 10.5 ppg Mud Push 11 wl red dye, 5 bpm, ICP 152 psi, FCP 130 psi, FO 16%. Drop bottom plug. Pump 328 bbls of 11 ppg Lead Cement, 6 bpm, 171 psi, FO 15%. Pump 65 bbls of 12 ppg Tail Cement, 5-6 bpm, ICP 220 psi, FCP 274 psi, FO 15%, PU 117K, SO 97K. Drop lop plug. Kick out plug w/ 10 bbls of H2O. Swap to rig & pump treated 9.6 ppg mud, 7 bpm, ICP 250 psi, FCP 391 psi, FO 17%. Reciprocate casing w/ 20 strokes throughout job & land casing on hanger w/ 1000 strokes pumped by rig pump. Slow pump rate to 3 bpm at 1300 strokes, 250 psi, FO 11 %. Bump the plug with 1569 strokes, pressuring up to 750 psi. Hold pressure for 5 minutes, bleed off, & floats holding. CIP @ 14:13 hrs. Total of 84 bbls of 11 ppg lead cement back to surface. Cement stages Stage # 1 Description Surface Casing Cement ObjectiveTop Depth (ftKB) 43.5 Bottom Depth (ftKB) 1,840.0 Full Return? No Vol Cement... Top Plug? 84.0 Yes BY: Plug? Yes Q Pump Init (bbllm... Q 4 3 Pump Final (bbl/... Q Pump Avg (bbl/... 6 P Pump Final (psi) 240.0 P Plug Bump (psi) 750.0 Recip? Yes Stroke (ft) Rotated? 20.00 No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pump 40 bbls of CW -100, 76 bbls of 10.5 ppg Mud Push II, 328 bbis of 11 ppg Lead Cement, & 65 bbls of 12 ppg Tail Cement. Cement Fluids & Additives Fluid Fluid Type Pre Flush Fluid Description Estimated Top (ftKB) 0.0 Est Btm (ftKB) 0.0 Amount (sacks) ClassVolume 40.0 Pumped (bbl) Yield (ft'Isack) Mix H2O Ratio (gallas... Free Water (%) Density (lb/gal) 33 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Spacer Fluid Description Estimated Top (ftKB) 0.0 Est Bim (ftKB) 0.0 Amount (sacks) Class Volume 76.0 Pumped (bbl) Yield (ft°/sack) Mix H2O Ratio (gaUsa... Free Water (%) Density (Ib/gal) 10.50 Plastic Viscosity (cP) Thickening Time (hr) Cmprstr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 43.5 Eat Btm (ftKB) 1,335.0 Amount (sacks) 969 Class Volume G Pumped (bbl) 328.0 Yield (ft -/sack) 1.90 MixH2O Ratio (gallsa... 6.70 Free Water (%) Density (Iblgal) 11.00 Plastic Viscosity (cP) 100.7 Thickening Time (hr) CmprStr 3.75 1 (psi) Additives Additive Type Concentration Conic Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 1,335.0 Est Btm (ftKB) 1,840.0 Amount (sacks) 221 Class G Volume Pumped (bbl) 65.0 Yield (ft'/sack) 1.65 Mix H2O Ratio (gallsa... 5.47 Free Water (%) Density (iblgal) 1 12.00 Plastic Viscosity (CP) 100.4 Thickening Time (hr) 3.00 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Stage # 2 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? No Vol Cement... I I Top Plug? No I Bim Plug? No Q Pump Init (bbllm... Q Pump Final (bbU... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) I Rotated/ No I Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Page 112 Report Printed: 811012018 Cement Detail Report IH-108 Job: String: Surface Casing Cement DRILLING ORIGINAL, 6141201800:00 Cement Fluids 8 Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 212 ReportPrinted: 8/10/2018 Cement Detail Report r 1H-108 qW String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 6/4/2018 00:00 Cement Details Cementing Start Date Cementing End Date Wellbore Name Description Intermediate Casing Cement 7/27/2018 16:00 7127/2018 18:30 iH-1086 Comment Drop bottom plug number 1 and pump 40.1 BBLS of 12.5# mud push. pumping at 4.1 BPM with 80-177 PSI casing pump pressure. 10-14% F/O, Launch 2nd bottom and pump 173.1 BBLS of 15.8PPG class G cement at 3.7 - 5.2 BPM at 50-140 PSI pump pressure. 11-21% F/O, UP WT = 230K. OWN WT = 54K. ICP = plug Launch Top plug and push with 10 BBLS Freshwater prior to switching to rig pumps. On rig pump and displace with 9.2# LSND @ 8 BPM at 2,089 STKS. 200 PSI, FCP = 737 PSI. 23% F/O, UP WT = 250K, DW N WT = 52K. Lower rate to 5 BPM pump 2,730 STKS with ICP 575 PSI 17% F/0, FCP = 863 PSI, UP WT = 250 K DWN WT = 40K. Landon hanger at 2,230 STKS due to lack of down wt. Reduce rate to 3 BPM with a FCP of 900 PSI 8% F/O. Bump plug at 3,074 STKS. raise pressure to 1,400 PSI and hold for 5 min. Cement in place at 1830 his. Bleed off. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Yes Intermediate Casing Cement 7" casing 3,916.0 8,517.0 Yes 0.0 Yes Cement Q Pump Init (bbl/m... Q Pump Final (bbl/... O Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) No 4 3 4 894.0 1400.0 Yes 20.00 Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (RKB) Drill Out Diameter (in) 61/8 8,338.0 Drill Bit 8,517.0 Comment Drop bottom plug number 1 and pump 40.1 BBLS of 12.5# mud push. pumping at 4.1 BPM with 80-177 PSI casing pump pressure. 10-14% F/0, Launch 2nd - bottom and pump 173.1 BELS of 15.8PPG class G cement at 3.7 - 5.2 BPM at 50-140 PSI pump pressure. 11-21% F/0, UP WT = 230K. DWN WT plug 54K. Launch Top plug and push with 10 BBLS Fresh water prior to switching to rig pumps. On rig pump and displace with 9.2# -SND @ 8 BPM at 2,089 STKS. ICP = 200 PSI, FCP = 737 PSI, 23% F/0, UP WT = 250K, OWN WT = 52K. Lower rate to 5 BPM pump 2,730 STKS with ICP 575 PSI 17% F/O, FCP = 863 PSI, UP WT = 250 K OWN WT = 40K. Land on hanger at 2,230 STKS due to lack of down wt. Reduce rate to 3 BPM with a FCP of 900 PSI 8% F/O. Bump plug at 3,074 STKS. raise pressure to 1,400 PSI and hold for 5 min. Cement in place at 1830 his. Bleed off. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class 4oUl;me Pumped (bbl) Mud push 2,809.0 3,916.0 (psi)Yield (ft /sack) Mix H2O Ratio (gal/sa... Free water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 12.50 Additives Type Concentration Conc Unit label Additive Fluid Fluid Type Fluitl Description Estimated Top (ftKB) Est Btm (kK6) Amount (sacks) Gass Volume Pumped (bbl) 173.2 Intermediate Cement 3,916.0 8,517.0 Yieltl (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic is (CP) Thickening Time (hr) CmprStr t (psi) 11 1.16 5.14 15.80 9,9 4.25 Additives Type Concentration Conc Unit label Additive Page 1/1 Report Printed: 8110/2018 P7—D 2_/8-a82. Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Thursday, August 02, 2018 11:32 AM To: 'Sylte, Hanna' Subject: KRU 1H -108B (PTD #218-082) Packer Setting Depth Waiver Approval Hanna, A waiver is granted to allow the packer to be placed —250' above the 7" intermediate shoe.(20 AAC 25.412(b)) based on the information below and the schematic provided. 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 LoeppicDalaska aov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria LoeooCalaska aov From: Sylte, Hanna<Hanna.Sylte@conocophillips.com> Sent: Thursday, August 02, 2018 11:15 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Woodard, Madeline E <Madeline.E.Woodard@conocophillips.com> Subject: RE: 1H -108B (PTD #218-082) Packer Setting Depth Victoria, For the current well, 1H-1086, we are requesting a variance to set the liner to packer at 8,265' MD, 134' MD higher than the depth stated in the PTD. This will put the packer at ^244' MD above the 7" shoe, but the packer will still be well below the logged top of cement at 3,620' MD. This change is to ensure the packer will be set in clean casing, as cement was tagged at 8,338' inside the 7" casing prior to drilling out the shoe track. I have attached an updated schematic for your reference. Please let me know if you approve this change or have any concerns, we are expecting to begin running liner later this afternoon. Thank you, Hanna Sylte Completions Engineer ATO 1556 Office: (907) 265-6342 Mobile: (713) 449-2197 Insulated Conductor Casing, 20", 94#, K55 x 34", 0.312" -- WT@+/-120'MD f A x 10-3/4",45.5#, L-80, Hyd563 @ 1,834' MD / 1,824' TVD @ 31 degrees TD 13.5" hole Wellbead / Tubing Head / Tree, %— 10-3/4" x 4.1/2", 5,000 psi IH-1O8B Injector (WPO4) Slotted Liner Gas Lift Mandrel, CAMCO Model KBMG w/ SOOV @ 2,500' MD / 2,262' TVD (54 deg) Tubing String: 3-12", 9.3 #, L-80 HYD 563 Gas Lift Mandrel, CAMCO Model KBMG w/ Dummy @ 5,250' MD / 3,253' TVD (70 deg) _ 2.812" XN ripple @ 5,355' MD / 3,291'TVD VD (72 deg) ZXP Liner Top packer & Liner Hanger @ 8,265' MD (-244 ft above 7" shoe) ----i - ------ 7",26#,L-80, TXP, Casing ----_--- @ 8,509' MD / 3,807' TVD @ 85 degrees TD 8-3/4" hole 4-Y,", 12.6#, L-80, IBTM Liner, alternating blanks and slots @ 13,060' MD / 4,198' TVD @ 57 degrees 4,55P Lined Lateral Baker Swell Packers, 5.75" OD J 6.125" OH TD @ 13,080' MD / 4,198' TVD @ 57 degrees ---- ---- ------------- --------------------a-vz•smia shoe .. FrD �;? IR-697- Loepp, 9-o8Z Loepp, Victoria T (DOA) From: Roby, David S (DOA) Sent: Wednesday, August 15, 2018 10:19 AM To: Thomson, Stephanie; Loepp, Victoria T (DOA); Braun, Michael (Alaska); NSK West Salk Prod Engr Subject: RE: [EXTERNAL]RE: 1H -108B Static Bottom -hole Pressure Survey Follow Up Flag: Follow up Flag Status: Flagged Stephanie, Thank you, you're plan for obtaining the required BHP for this well is acceptable. Regards, Dave Roby (907) 793-1232 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 Dave Roby at (907)793-1232 or dave.robv@alaska aov. From: Thomson, Stephanie <Stephanie.Thomson@conocophiIIips.com> Sent: Tuesday, August 14, 2018 4:18 PM To: Roby, David S (DOA) <dave.roby@alaska.gov>; Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Braun, Michael (Alaska) <Michael.Braun@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com> Subject: RE: [EXTERNAL]RE: IH -108B Static Bottom -hole Pressure Survey Hi Dave, The answers to your questions are below. 1. Yes, we will shut the well in after the pre -production period to allow time for piping modifications to configure the well for injection. The well will be shut-in at least 72 hours prior to obtaining the static bottom -hole pressure. 2. We will measure static bottom -hole pressure after a shut-in period consistent with our regular GKA surveillance shut-in times, which is typically at least 72 hours. 3. We are planning on a standard stabilized pressure survey with Spartek gauges on slickline. No pressure build-up will be done at this time. Please let me know if you have any additional questions. Thanks, Stephanie From: Roby, David S (DOA) <dave. roby@alaska.aov> Sent: Tuesday, August 14, 2018 9:59 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov>; Thomson, Stephanie <Stephanie.Thomson@conocophillips.wm>; Braun, Michael (Alaska) <Michael.Braun @conocophillips.cci NSK West Sak Prod Engr<n1638@conocophillips.com> Subject: [EXTERNALJRE: 1H -108B Static Bottom -hole Pressure Survey Stephanie, I have a few questions for you on this matter. 1) After doing the pre -production on the well do you plan to shut it in for a period of time, and if so for how long, prior to obtaining the SBHP? 2) How long does it typically take for a West Sak well to reach stabilized conditions after being shut in? 3) Are you planning on conducting just a plain pressure survey, or a pressure buildup survey? Thanks in advance. Regards, Dave Roby (907)793-1232 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 Dave Roby at (907(793-1232 or dave.robv®alaska.aov. From: Loepp, Victoria T (DOA) Sent: Tuesday, August 14, 2018 9:52 AM To: Roby, David S (DOA) <dave.robV@alaska.gov> Subject: FW: 1H -108B Static Bottom -hole Pressure Survey Dave, Do you see any issue with this information from CPAI on acquiring a SBHP? Do we specify how long the well should be shut in after production before the stabilized SBHP is taken? Let me know. Thanx, Victoria CO 406 Rule 8 Reservoir Pressure Monitoring (a) Prior to regular production or injection an initial pressure survey shall be taken in each well except those equipped with a subsurface pump. (b) A minimum of one bottom -hole pressure survey per producing or injecting governmental section shall be measured annually. Bottom -hole surveys in paragraph (a) may fulfill the minimum requirement. (c) The reservoir pressure datum will be 3500 feet subsea. ( d) Pressure surveys may consist of stabilized static pressure measurements at bottom -hole or extrapolated from surface, pressure fall-off, pressure buildup, multi -rate tests, drill stem tests, and open -hole formation tests. (e) Data and results from pressure surveys shall be reported quarterly on Form 10-412, Reservoir Pressure Report. All data necessary for analysis of each survey need not be submitted with the Form 10-412 but must be available to the Commission upon request. (f) Results and data from special reservoir pressure monitoring tests or surveys shall also be submitted in accordance with part ( e) of this rule. From. Thomson, Stephanie <Stephanie.fhomson@conocophiIIips.com> Sent: Monday, August 13, 2018 4:06 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> Cc: Braun, Michael (Alaska) <Michael.Bra un@conocophillips.com>; NSK West Sak Prod Engr <n 1638@conocophilli ps.com> Subject: 11-1-1088 Static Bottom -hole Pressure Survey Victoria, ConocoPhillips wanted to inform AOGCC that a static bottom -hole pressure survey will be obtained in well 1H -108B (PTD# 218-082-0) after a short pre -production period of up to 30 days, but before the well is placed on injection, as per Rule #8 of the West Sak C0406. In this particular case, there would be no access for slickline to well 1H -108B while the Doyon 142 is drilling 11-1-104, so the well will be pre -produced with slickline work to follow to avoid rig delays. Please let me know if you have any questions. Thanks, Stephanie Thomson Staff Petroleum Engineer —CPF1 Kuparuk GKA Base Production & Optimization I ConocoPhillips Company T: +1907 263 4536 M: +1832 414 2377 1 E: Stephanie.thomsonC@conocophillips.com 700 G St. ATO -1310 Anchorage, AK 99501 USA THE STATE 01ALASKA GOVERNOR BILL WALKER Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, West Sak Oil Pool, KRU 1 H -1 08B ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-082 Surface Location: 5231' FNL, 770' FEL, Sec. 28, T12N, R10E, UM Bottomhole Location: 864' FNL, 1897' FEL, Sec. 35, T12N, R10E, UM Dear Mr. Alvord: 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.aloska.gov Enclosed is the approved application for the permit to redrill 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 Chair �l DATED this t e day of July, 2018. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 "n 4 E`C I V E JUL 0 g 20118 1a. Type of Work: Prposed Well Class: Exploratory - Gas ❑� VService - WAG v Service - Disp ❑ 1c. Specifyif well is proposed for. 11S. Drill ElLateral Eltratigraphic Test ❑ Development p ❑ Service - Winj ❑ Single Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill E ' Reentry ❑ Exploratory -Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple ZoneGeothermal ElShale Gas El2. Operator Name: 5. Bond: Blanket Q Single Well EJ11. Well Name and Number: Co s llips Alaska, Inc. Bond No. 59-52-180 • KRU 1H -108B 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 13,033' ND: 4,203' Kuparak River Field 4a. Location of Well (Governmental Section): 7. Property Designation: West Sak Oil Pool Surface: 5231' FNL & 770' FEL, Sec 28, T12N, R10E, UM ADL025639 & ADL025638 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 2994' FNL & 549' FEL, Sec 34, T12N, R10E, UM 80-261 & 931695000 7/19/2018 Total Depth: 864' FNL 8 1897' FEL, Sec 35, T12N, RICE, UM 9. Acres in Property: 14. Distance to Nearest Property: 2560 & 2560 4416' to ADL025649 41b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 93.0' 15. Distance to Nearest Well Open Surface: x- 549570.98 • y- 5,980,752.52 • Zone- 4 GL / BF Elevation above MSL (ft): 54.0' to Same Pool: 732' to 1C-174 16. Deviated wells: Kickoff depth: 1,900 feet 17. Maximum Poi Pressures in psig (see 20 AAC 25.035 Maximum Hole Angle: 89 d 1egrees Downhole: psi qya-: 1 si % -� f1/1L 18. Casing Program: Specifications Top - Setting Depth - Bottom I Cement Quantity, c.f, or sacks Hole Casing Weight Grade Coupling Length MD ND I MD I (including stage data) 42" 20" 94# 7-40 Welded 180, Surf Surf 119' 119' Existing, cement to surface 13-1/2" 10-3/4" 45.7 L-80 HYD563 1795' Surf Surf 1834 1767' 969 sx 11.0 ppg, 221 sx 12.0 ppg 8-3/4" 7" 26# L-80 TXP 8549' .....Surt Surf 8549' - 3807' 563 sx Class G 15.8 ppg 6-1/8" 4-1/2" 12.6# L-80 IBTM 4624' 8399' 3793 13023' - 4203 N/A 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 9,245' 3,784' Cement Retainer@ 1782' 1782' 17: Casing Length Size Cement Volume MD ND Conductor/Structural 119.00 20" Existing, cement to surface Surface 1,834.00 10-3/4" Existing, 969 sx 11pp9 Lead, 221 sx 12ppg Tail, Circulated 84 bbls cement to surface 3-1/2" tubing 1,781.89' 3-1/2" N/A Perforation Depth MD (ft): Perforation Depth ND (ft): Hydraulic Fracture planned? Yes ❑ No 20. Attachments: Property Plat El BOP Sketch Drilling Program Time V. Dep[h Plot /p, hallow Hazard Analysis Diverter Sketch J Seabed Report Drilling Fluid Program J' 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chip Alvord Contact Name: Madeline Woodard M� Authorized Title: Alaska Drilling Manager Contact Email: madeline.e.woodard co .COm Contact Phone: 907-265-6086 Authorized Signature: i�- aA, -7 / cj I Z,0 I Qj Date: Commission Use Only Permit to Drill 77 Number: �l�-U�` API Number: '5 � Permit Approval See cover letter for other 50 -('`"gyp •-CZE �/ �'" U Date: 0 L requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane as hydrates, or gas contained in shales: Other: 3,'P fc-6 f fo 3�dOr hn y/�QJ- f ✓/�'+ fY� A-$ -{ Samples req'd: Yes ❑ No[Z HzS measures. Yes VNo❑ Directional Mud log req'd: Yes [7;/NoQ svy req'd: Yes [F] No❑ e- /" O Spacing exception req'd: Yes ❑ No�l Inclination U J -only svy req'd: Yes ❑ Nov Post initial injection MIT req'd: Yes 2No❑ APPROVED BY 11� I I Approved by: _ _ _ COMMISSIONER THE COMMIRRlnN n�re �� vr� /ia/iB ORIGINAL 7 o"s Application for Permit to Re -Drill, Well 1H -108B Saved: 9 -Jul -18 July 9, 2018 Alaska Oil and Gas Conservation Commission 333 West Th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Re -Drill Well 1H -108B, a West Sak Sand Injector Dear Commissioner: ConocoPhillips Alaska Inc. hereby applies for a permit to re -drill an onshore grassroots injector pilot well from the 1 H pad utilizing existing 1H-108 surface casing. The expected start date for this sidetrack is July 19th, 2018. It is planned to use rig Doyon 142. 1 H -108B is planned to be a horizontal well through the West Sak sands to provide injection support to the planned 1 H- 104 West Sak Producer. The 10-3/4" surface casing from 1 H-108, set at 1834' MD / 1767' TVD will be utilized. The well will be sidetrack off planned kickoff plug below surface casing shoe and the production section will be drilled with 8-3/4" bit and to ±8,559' MD / 3,807' TVD. The wellbore will be completed with 4-1/2" slotted liner to ±13,023 MD / 4,203' TVD dependent if pay is found across north fault block. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Madeline Woodard at 907-265-6086 (madeline.e.woodard@cop.com) or Chip Alvord at 265-6120. Sincerely, Chip Alvord Drilling Manager July 9, 2018 Alaska Oil and Gas Conservation Commission 333 West Th Avenue, Suite 100 Anchorage, Alaska 99501 Application for Permit to Re -Drill, Well 11-1-10813 Saved: 9 -Jul -18 Re: Application for Permit to Re -Drill Well 1H -108B, a West Sak Sand Injector JUL 18 2013 Dear Commissioner: AO G C C ConocoPhillips Alaska, Inc. hereby applies for a permit to re -drill an onshore grassroots injector pilot well from the III pad utilizing existing 1 H-108 surface casing. The expected start date for this sidetrack is July 19th, 2018. It is planned to use rig Doyon 142. I H -108B is planned to be a horizontal well through the West Sak sands to provide injection support to the planned 1 H- 104 West Sak Producer. The 10-3/4" surface casing from 1 H-108, set at 1834' MD / 1767' TVD will be utilized. The well will be sidetrack off planned kickoff plug below surface casing shoe and the production section will be drilled with 8-3/4" bit and to (8,559' MD / 3,807' TVD. The wellbore will be completed with 4-1/2" slotted liner to ±13,023 MD / 4,203' TVD dependent if pay is found across north fault block. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Madeline Woodard at 907-265-6086 (madeline.e.woodard@cop.com) or Chip Alvord at 265-6120. Sincerely, Chip Alvord Drilling Manager Application for Permit to Drill Document Kuparuk Well 1H -108B Well Name Requirements of 20 AAC 25.005 in The well for which this application is submitted will be designated as KRU 1H -108B Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill nmsi be accompanied by each of the following items, except for an item already on file with the commission and identified it, the application; (2) a plat identifying tire property and the properor's owners andshmoing (A) the coordinates ofthe proposed location oflhe well at the sulfate, at the top of each objective fmniation, and at total depth. referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface. referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration (C) the proposed depth of the well at the tap of each objective formation and at total depth; Location at Surface 5231' FNL & 770' FEL, Sec 28, T12N, R10E, UM NGS Coordinates Northings: 5,980,752.52' Eastings: 549,570.98 RKBElevation 93.0'AMSL Pad Elevation 54.0'AMSL Location at Top of Productive Interval FNL & 549' FEL, Sec 34, NGS Coordinates Northings: 5,977,748.16' Eastings: 555,098.27' Vertical D :l Vertical UM Location at Total Depth 864' FNL & 1897' FEL, Sec 35, T12N, R10E UM NGS Coordinates Northings: 5,979,908.03' Eastings: 559,011.23' Measured De th, RKB: 13,033' Total Vertical De th, RK87 4,203' Total 17— and and (D) other information required by 20 AAC 35.050(b): Requirements of 20 AAC 25.050(b) if a well is to be intentionally deviated, the applica ton for a Perndt to Drill (Form 10401) must (1) include a plat. drown to a suitable scale, showing the path of the proposed u'ellbm'e. including all adjacent it ellbores within 200 feet of any portion of the proposed well: Please see Attachment: Directional Plan And (2) for all wells within 200 feet of the proposed ioellbore (A) list the names of the operators of those wells, to the extent that those names are known or disco enable inpublic records, and shoe that each named operamr has been furnished a copy of the application by certified mail; at (B) state that the applicant is the only affected corner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application fora Permit to Drill must be accompanied by each of the folloring items. ercepi for an item already on file with the commission and identified in the application: (3) a diagram and description of the bloraul prevention equipment (BOPS) as regmired by 20 AAC 25.035, 20 AAC 25.036. m- 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 142 and attachment. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill most he accompanied by each of the following items. except for an item already on file with the commission and identified it, the application (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encomuered. criteria used to determine it, and masinmm potential surface pressure based on a methane gradient: The maximum potential surface pressure (MPSP) while drilling 1H -108B is calculated using an estimated maximum reservoir pressure of 1,863 psi (based on 1 H-105 MDT pressure of 1749 psi, 8.6 ppg equivalent, and corrected to depth), a gas gradient of 0.10 psi/ft, and the estimated depth of the West Sak A2 sand at 4,166' TVD: A2 Sand Estimated. BHP = 1,863 psi A2 Sand estimated depth = 4,166' TVD Gas Gradient — 0.10 psi/ft as per 20 AAC 25.005 (e)(4)(A) Hydrostatic of full gas column = 417 psi (4,166' TVD * 0.10 psi/ft) MPSP = BHP — gas column = 1,446 psi (1,863 psi — 417 psi) (S) data on potential gas :ones; The well bore is not expected to penetrate any shallow gas zones. And (C) data concerning potential causes of hole problems such as about mail), geo-pressured strata, lost circulation =ones, and cones that hai e a propensity jor differential sticking: See attached 1H -108B Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An application fora Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure jor conducting formation integrity tests. as required under 20 AAC 25.030(0: A procedure is on file with the commission for performing LOT'S. Casing and Cementing Program _Requirements of 20 AAC 25.005(c)(6) An application for a Permil to Drill must be accompanied by each of the following items. except jor an item already on file with the commission and identified in the application: (6) it complete p'oposed casing and cementing program as required by 20 AAC 25.030. and a description of any slotted liner. pre-perjm'ated linera- screen to be installed Casing and Cement Program Casing and ementing Program Csg/Tbg OD Hole Sine Weight Grade Conn. Length Top MD/TVD Ban MD/TVD Program (in) gbft) f) 0) (it) 20 42 94 H-40 Welded 80 Surf 119/119 Existing Existing Cement to Surface with 10-3/4 13-1/2 45.5 1.80 HYD563 1,834' Surf 1,834'/ 1,767' 969 sx LiteCRETE Lead 11.0 ppg 221 sx LiteCRETE Tail 12.0 ppg 84 bbls cement circulated to surface 7" 8-3/4"ME 6 L80 TXP 8,549' Surf 8,549'/ 3,807' 563 sx Class G at 15.8 ppg w/ TOC @ 5,414' MD 4-12" 6-1/8" 12.6 L-80 1BTM 4,624' 8,399' 13,023'/4,203' N/A 7" Intermediate casine run to 8.549' MD / 3.807' TVD Single stage slurry is designed to be placed from TD to 5,414' MD, which is 250' TVD above top of West Sak pool (base of Ugnu); 35% excess annular volume. 7" Production Cement Calculations Design: UniSLURRY Class G 15.8 ppg Cement to 250' TVD above Top of West Sak Pool Cement yield = 1.16 1 ft-3/sk I Planned TOC= 5414' MD Shoe Track 80'x 0.0383 bbl/ft x 1.0 (0% excess) 3.1 bbls Shoe to Top of Cement = (8549'- 5414') x 0.0268 bbl/ft x 1.35 (35% excess) 113.3 bbls Total Cement Volume = 116.4 bbls or 1 653.4 ft^3 1 or 563 sks 10 -minute Gel Displacement = (8549' - 80') x 0.0383 bbl/ft= 324.1 bbls Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application jar a Permit to Drill must be accompanied by each of the jollou ing items, except far an item already on file with the commission and identified in the application: (7) a diagram and description of the dh erter system as required by 20 AAC 25.035. unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematic attached. Please note that surface has already been drilled, cased, and cemented off. This is included for reference only as we will not be needing diverter on 11-1-108B. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(81 An application fora Permit io Drill narst be accompmrted by eacli of the follon ing items, except for an item already on file meth the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling f uid system. as required by 20 AAC 25.033: Mold Program Summary Diagram of Doyon 142 Mud System is on file with AOGCC. Intermediate 8-3/4" Hole 7" Casing Production 6-1/8" Hole 4-1/2" Liner Mud System LSND WBM FloPro NT WBM Density 9.0-10.0 9.0 — 9.5 ppg PV ALAP ALAP YP 20-30 15-20 Funnel Viscosity N/A N/A Initial Gel 9-11 7-10 10 -minute Gel <20 8-16 API Filtrate < 6 <6 HTHP Fluid Loss at 160° F <10 <10 pH 9.5-10.0 9.5-10.0 Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(]0) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005 (e)(13) An application fair a Permit to Drill mus( be accompanied by each of lhe_(ollairing items, except for an hear already or file it ith nie coannonon and Identified in the application: The proposed drilling program is included below. Please refer to attachment for proposed well schematic. 1. MIRU Doyon 142 and NU BOP. Secure well. 2. Pull and LD kill string. 3. PU 9-7/8" rock bit and clean out BHA. RIH and tag cement retainer. Displace hole to 9.0 ppg LSND. 4. Drill out cement retainer and kick off plug to surface casing shoe at 1,834' MD / 1,767' TVD. 5. POOH and LD clean out BHA. 6. PU 8.75" bit and 6.75" drilling assembly, with MWD/LWD (gamma ray and resistivity). RIH. 7. Perform sidetrack below surface casing shoe and directionally drill 8-3/4" intermediate hole to TD of 8,559' MD / 3,807' TVD. Note: Successful FIT was performed on 1H-108 surface shoe to 12.Oppg EMW. 8. Run 7" 26# L80, TXP casing to surface. (Top of cement to be 5,414' MD / 3,306' TVD which corresponds to 250' TVD above the top of the West Sak Pool. 9. Install wellhead x 7" packoff and test to 3500 psi. 10. Flush 10.75" x 7" annulus with water, followed by gelled diesel. 11. PU 6.125" PDC Bit and 4.75" drilling assembly with MWD and LWD logging tools (gamma ray, resistivity, and sonic for cement evaluation). RIH, performing MAD pass with sonic tool in memory mode to log cement. 12. Clean out cement to top of float equipment. Test casing to 3500 psi (48.35% of published burst rating) for 30 minutes. 13. Drill out cement and 20' of new hole. Displace hole to lateral drilling Flo -Pro WBM system. Perform shoe test to a minimum of 12.0 EMW LOT/FIT, recording results. 14. Directionally drill 6.125" hole in West Sak D sand to TD at +/- 13,033' MD / 4,203' TVD as per directional plan. 15. Backream out of hole to 7" shoe. Circulate to clean up casing and POOH on elevators. 16. PU and run 4.5" slotted liner. 17. Make up liner hanger running tool. 18. Finish running liner to 13,023' MD if pay found across fault block to north. 19. Set liner hanger @ +/- 8,399' MD, set liner top packer and test. POOH. 20. PU 3.5" tubing as required and TIH to depth. Land tubing. Set BPV. 21. Nipple down BOPE, nipple up tree and test. Pull BPV. 22. Freeze protect well with diesel by pumping into 3.5" x 7" annulus, taking returns from tubing. 23. Set BPV and move off rig. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill nmst be accompanied by each oJ'the following items. escepl Jor an item already on file with the commission and identified in the application: (1 4) a general description of hmr the opermor plans to dispose of drtiling and and cuttings ami a statement ofudrether the operator intends to request authoricalion under 20 AAC 25.080 for an annula disposal operation in the well.,; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class 11 disposal well (DS 113 CRI) or Prudhoe DS -4. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 AOR Attachment 2 Directional Plan Attachment 3 Drilline Hazards Summary Attachment 4 Well Schematic. Current and Proposed Attachment 5 Diverter Layout Diagram Attachment 6 BOP Confieuration Attachment I AOR An Area of Review plot is shown below of the 1H-1086 planned wellpath and offset wells. The included table identifies any of the offset wellbores within (or approximate to) the '/a -mile review. Top of West Well Name Status Sak D Sand TOC TOC DeteBYined Reservoir Zonal Isolation Cement Operations (MD/ (MD/TVD) Status summary TVD) 168 sks 15.84 Class G cement from 7,500' MD / 4050' TVD to 7,000' MD / 3891' TVD. 288 sks 15.8# Class G cement from 1H-108A Abandoned / 4,311 M/ Plugged & 4x abandonment plugs set 6,585' MD / 3,715' TVD to 5,972' MD / 3,464' Sidetrack 3,716 ,716V 'TVD 2,863' TVD Tag Abandoned from 7,500' MD to 4,31 I' TVD. 168 sks 15.8# Class MD / 2,863' TVD G cement from 5,972' MD/ 3,464' TVD to 5,472' MD/ 3,263' TVD. 409 sks 15.74 ASI cement from 5,011' MD / 3,094' TVD to 4,311' MD / 2,863' TVD. Column of IH-104 Proposed Not Yet N/A N//' cement to be Well does not exist yet Well does not exist yet Producer Drilled 250'TVD above pool top. 1H-09 Shut-in Injector 5,301' MD / Surface Circ cement to Shu[-in West Sak behind surface 1260 sks Permafrost "C" & 520 sks Class G. Circ (Kuparuk) ; 706' TVD surface. casing cemented to surface g cement to surface. IH-13 Shut-In Producer 5,328' MD / Surface Circ cement to Shut-in West Sak behind surface 1330 sks Permafrost "E" & (Kuparuk) 3,728' TVD surface. casing cemented to surface. 500 sks Class G. Circ cement to surface. IH-15 Active Producer 5,022' MD / Surface Circ cement to Producing West Sak behind surface 1170 sks Permafrost "E" & (Kuparuk) 3,689' TVD surface. Kuparuk casing cemented to surface. 470 sks Class G. Circ cement to surface. 1 H-1 I Active Producer q 972' MD / Surface Circ cement to Producing West Sak behind surface 1190 sks Permafrost "E" & (Kuparuk) ; 672' TVD surface. Kuparuk casing cemented to surface. 500 sks Class G. Circ cement to surface 930 sks 10.74 ASLite IB-102 Active Injector 7 858' MD / Surface Circ cement to Injecting West Surface casing set in West Class G lead cement, 410 (West Sak) 3,669' TVD surface. Sak Sak and cemented to surface. sks .8# Class G tail cement. Circ cement to surface. 755 sks 10.74 ASLite IC-178L] Active Producer 7,359' MD / Surface Circ cement to Producing West Surface casing set in West Class G lead cement, 281 (West Sak) 3 703, TVD surface. k Sak Sak and cemented to surface. sks 15.8# Class G mil cement. Circ cement to surface. 1167 sks 10.74 ASLite 1C-174 Shut In West 7,101' MD / Surface Circ cement to Shut in Surface casing set in West Class G lead cement, 290 Sak Injector 3,716' TVD surface. Sak and cemented to surface. sks 15.8# Class G tail cement. Circ cement to surface. 551 sks 10.7# ASLite IC-170 Active Producer 5,912' MD / Surface Circ cement to Producing West Surface casing set in West Class G lead cement, 271 (West Sak) 3,753' TVD surface Sak Sak and cemented to surface. sks 15.8# Class G tail cement. Circ cement to surface. 175 sks 15.8# Class G lead IC-150 Activeq 742' MD / Circ cement to Injecting West Intermediate cement from cement to 2,584' MD and Injector 3,766' TVD Surface surface ure Sak 4,905' MD / 3,786' TVD to 431 sks of 15.89 Class G (West Sak) 2,584' MD / 2,468' TVD tail cement from 2,850' MD to 4,905' MD. 4- i 0 0- Jura 29 2018 1 H-1 08B wp04 1250 4500 6750 9000 Measured Depth IH -108 11250 13500 10 10 3/4' 1H- 08 -. 1H-108 actual @ 92.99usft (Doyon 142) o 0 0 -- Equivalent Magnetic Distance - H 1 0 7518"797/8' S 41/2"xG3/4' iFd M v b o f oo t o 0 00 0 s 550800 4.00 PI I I 5739.37 0,00 n 1 H-1088 T02 063018 RP A 5759.01 0.00 0.00 2484.57 S 5934.36 2.50 26852636.11 H 6493.59 0.00 0.00 3113.00 S 6732.50 3.00 -91.183326.81 0 1500 3000 4500 6000 7500 -89.513499.72 9000 10500 748347 0.00 Horizontal Departure 5 767896 0 Oleg TFam VSW IH -108 33733 0.00 0.00 117.34 1H- 08 -. 908.01 - 0 -- Equivalent Magnetic Distance - H 1 0 0.001029 11 S 3101.34 400 22.281116 79 H 451790 0.00 0.00 1630.89 s 550800 4.00 -86.372264.81 11-1-108B T01 M3018 RP H 5739.37 4am 11.0 [aro zrou 2825 315U 33]5 3600 Measured Depth DepthFrom DepOl To SuPrtyIPWn Taol 120.48 1288.30 1H-100 Smy 1 GYD.GC-SS 136199 1750.03 1H-100 SM2 MWDMFR-AK CA2-SC 1847.94 1900.00 1H-108 SM3 MWDHFR�AK-CAZ-SC 1800.00 2050.00 1H-1 We wp04(Plan: 1H-100B)MWO-INCONLY 205000 3550.00 1 H406B,oID4 tPlen: 10-1088) IID 2050.D01303254 1H-1088 wpD4 (Plan: I1+108B) MWD+IFR.AK-CAZ-SC 7 4 +E/ -W Oleg TFam VSW Target A 33733 0.00 0.00 117.34 K 908.01 4.00 2000 236.66 A 1219.12 4.00 -93.00 325.08 H 2878.52 0.00 0.001029 11 S 3101.34 400 22.281116 79 H 451790 0.00 0.00 1630.89 s 550800 4.00 -86.372264.81 11-1-108B T01 M3018 RP H 5739.37 0,00 0.00 2467.37 1 H-1088 T02 063018 RP A 5759.01 0.00 0.00 2484.57 S 5934.36 2.50 26852636.11 H 6493.59 0.00 0.00 3113.00 S 6732.50 3.00 -91.183326.81 1H-1088703063018 RP A 6910.30 3.00 -89.513499.72 H 748347 0.00 0.00 4077.32 5 767896 3.00 -95.12 4282.50 1H -108B T04 063018 RP A 7793.77 3.00 -97.82 4411,27 H 8076.35 0.00 0.00 4736.47 5 819205 3.00 -61.304873.31 1H -108B T05 MM18 RP A 8291.54 3.00 -78.104997.41 H 8627.24 0.00 0.00 5427.15 s 8712.84 3:00 -96.37 5539.42 1 H-1088 T05 063018 RP A 8900.42 3.00 -102.33 5807.82 H 8925.78 0.00 0.00 5846.62 s' 9053.37 4.00 -169,74 6044.42 IH -108B T07 063018 RP A 9365.14 4.00 -179 82 653463 H 9435.57 0.00 0.006645.44 1H -108B T08063018 RP TI All wells pass AC, however it is 16it"Pack very tight drilling past several wells Plan Summa 5000 16000 Magnetic Model & Date: BGGM201815-Jul-18 North is 17.08° East of True North (Magnetic Declination) 20° TF, for 1000' LithDlogy Column .,415.83- 22 28' ,415.83'22.28° TF, for 267.07' w.a -86.37° TF, for 1042.03' T-3 20- ;, 26.85' TF, for 177,69' n -91.18° TF, far 243.88' 2° for 131.32uizio.e� K-15 -81.3° TF, for 138' ccepted by: ', for 124.35' CS DeLapp -96.37° TF, for 112.31' V Osara 83°, for 270.28' oaano DE Name -169.74° TF, for 202.96' 1 � -C "t1Gstc _B "'UG A w Na isAAl x IS -A2 "'V94ASE � � !�•14�i�t„by� 41 Magnetic Model & Date: BGGM201815-Jul-18 North is 17.08° East of True North (Magnetic Declination) 20° TF, for 1000' LithDlogy Column .,415.83- 22 28' ,415.83'22.28° TF, for 267.07' w.a -86.37° TF, for 1042.03' T-3 20- ;, 26.85' TF, for 177,69' n -91.18° TF, far 243.88' 2° for 131.32uizio.e� K-15 -81.3° TF, for 138' ccepted by: ', for 124.35' CS DeLapp -96.37° TF, for 112.31' V Osara 83°, for 270.28' oaano DE Name -169.74° TF, for 202.96' UG 52°, for 542.05' 4202.99' TVD -C "t1Gstc _B "'UG A w Na isAAl x IS -A2 "'V94ASE repared by Checked by: ccepted by: Approved by: CS DeLapp V Osara Erik Sterk DE Name I H-1086 wp04 Section View a 950 I 10 3/4" x 13 1/2" CL 30° K- 5 1900 . _ . - 11 -- - = ---- --- --- > 3$o 0� UG_C od� UG_B 2850 o OG A Na- ---- ta- 1--- - - S -- ----- ---- WS D - B- o I Ca n o. a o G� o b o o SS A4 W 3 COrn 0 CO CO COrn 3800-----_ CO - - -. _.. - J = _ __ _ �o o 41°/ 4750 7 5/8" x 9 7/8" 4 1/2 x 6-3/4" 0 950 1900 2850 3800 4750 5700 ^ 650 7600 Vertical Section at 50.000 1H -108B wp04 Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 1500- 10 3/4" x 13 1/2" y�08 0- o� 4 1/2" x 6-3/4" 3� o + o 2 L o0 ?1500 �" - - 4O o -- O w 00 I D' 00 '200 cq O O -3000- o o I CD OD �jo o ' o o 0 o p; ' o 0 7 5/8" x 9 7/8" -4500- 0 1500 3000 4500 6000 7500 9000 West( -)/East(+) ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad 1 H-108 500292360800 Plan: 11-1-10813 Plan: 1H-10813 wp04 Standard Proposal Report 03 July, 2018 �� ConocoPhillips ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kupanrk River Unit She: Kupawk I Pad Well: 7H-108 Wellbore: Plan: iH-1088 Design: 1H -108B wp04 ConocoPhillips Standard Proposal Report Local Coordinate Reference: Well 11-1-108 TVD Reference: IH -108 actual @ 92.99usft (Doyon 142) MD Reference: 1 H-108 actual @ 92.99usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature Project Kupamk River Unit, North Slope Alaska, United Stales Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor She Kupamk 1H Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.37' Well 11-1-108 Audit Notes: Well Position +N/ -S 781.33 usft Northing: Wrgest Section: +EI -W 378.96 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Tool Name Remarks 1 1,900.00 Wellbore Plan: 1H-1088 MWD -INC ONLY Magnetics Model Name Sample Date Declination (') BGGM2018 7/15/2018 17.08 2,050.00 3,550.00 1H-1088 wp04(Plan: 1 H -108B) Design 1H-108Bwp04 Audit Notes: Version: Phase: Wrgest Section: Depth From (TVD) (usft) (usft) 38.99 Latitude: Longitude: Ground Level: 54.00 usft Dlp Angle Field Strength (') (nn 80.92 57,451 PLAN Te On Depth: 1,900.00 +N/S +E/ -W Direction (usft) (usft) (1) 0.00 0.00 50.00 Plan Survey Tool Program Date 7/3/2018 Depth From Depth To (usft) (usft) survey (Wellbore) Tool Name Remarks 1 1,900.00 2,050.00 1H-1088 wp04(Plan:1H-1088) MWD -INC ONLY MWD -INC ONLY FILLER 2 2,050.00 3,550.00 1H-1088 wp04(Plan: 1 H -108B) MWD MWD - Standard 3 2,050.00 8,560.00 1H -108B wp04(Plan: 1 H-1088) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4 8,560.00 10,060.00 1H -108B wp04(Plan:1H-1088) MWD MWD - Standard 5 8,560.00 13,032.54 1H-108Bwp04(Plan: 11-14086) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/3/2018 11: 19:04AM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Local Coordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: Project Kuparuk River Unit MD Reference: Site: Kuparuk 1H Pad North Reference: Well: 11-1-108 Survey Calculation Method: Wellbore: Plan: iH-108B Dogleg Design: 1H -108B wp04 ConocoPhillips Standard Proposal Report Well 1 H-108 1 H-108 actual @ 92.99usfi (Doyon 142) 1 H-108 actual Q 92.99usft (Doyon 142) True Minimum Curvature Plan Sections Measured Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +N/-8 +El -W Rate Rate Rate TPO (usft) (°) (°) (usft) (usft) Neff) ('1100usft) (9100usft) (°HOOasft) (7 Target 1,900.00 31.20 122.18 1,824.04 -219.45 337.33 0.00 0.00 0.00 0.00 2,900.00 69.98 135.71 2,448.41 -713.95 908.01 4.00 3.88 1.35 20.00 3,315.83 70.00 118.00 2,591.69 -947.15 1,219.12 4.00 0.00 -4.26 -93.00 5,315.83 70.00 118.00 3,275.73 -1,829,47 2,878.52 0.00 0.00 0.00 0.00 5,582.90 79.93 122.09 3,344.96 -1,958.61 3,101.34 4.00 3.72 1.53 22.28 7,281.17 79.93 122.09 3,642.01 -2,847.01 4,517.90 0.00 0.00 0.00 0.00 8,323.20 84.89 80.31 3,785.99 -3,040.86 5,506.08 4.00 0.48 4.01 -86.37 1H -108B 701 063018 8,558.77 84.89 80.31 3,806.99 -3,001.37 5,739.37 0.00 0.00 0.00 0.00 1H -108B T02063018 8,578.77 84.89 80.31 3,808.77 -2,998.02 5,759.01 0.00 0.00 0.00 0.00 8,756.47 88.85 82.32 3,818.48 -2,971.24 5,934.36 2.50 2.23 1.13 26.85 9,320.88 88.85 82.32 3,829.79 -2,895.79 6,493.59 0.00 0.00 0.00 0.00 9,564.77 88.71 75.00 3,834.99 -2,847.87 6,732.50 100 -0.06 -3.00 -91.18 iH-108B T03063018 9,751.63 88.76 69.39 3,839.11 -2,790.78 6,910.30 3.00 0.03 -3.00 -89.51 10,364.12 88.76 69.39 3,852.32 -2,575.28 7,483.47 0.00 0.00 0.00 0.00 10,577.97 88.20 63.00 3,857.99 -2,489.05 7,678.97 3.00 -0.26 -2.99 -95.12 1H-1088 T04 063018 10,709.29 67.67 59.09 3,862.73 -2,425,53 7,793.77 3.00 -0.40 -2.97 -97.82 11,038.90 67.67 59.09 3,876.13 -2,256.38 8,076.35 0.00 0.00 0.00 0.00 11,176.89 88.30 55.00 3,880.99 -2,181.38 8,192.05 3,00 0.46 -2.97 -81.30 1H -108B T05063018 11,301.24 89.07 51.35 3,883.64 -2,106.88 8,291.54 3.00 0,62 -2.94 -78.10 11,731.15 89.07 51.35 3,890.81 -1,838.40 8,627.24 0.00 0.00 0.00 0.00 11,843.47 88.70 48.00 3,892.99 -1,765.75 8,712.84 3.00 -0.33 -2.98 -96.37 1H -108B T06 063018 12,113.75 86.99 40.07 3,903.18 -1,571.75 8,900.42 3.00 -0.63 -2.93 -102.33 12,153.19 86.99 40.07 3,905,25 -1,541.60 8,925.78 0.00 0.00 0.00 0.00 12,356.15 79.00 38.60 3,929.99 -1,385.94 9,053.37 4.00 -3.94 -0.72 -169.74 1H-1088 T07 063018 12,898.19 57.32 38.52 4,130.45 -994.86 9,365.14 4.00 4.00 -0.01 -179.82 13,032.54 57,32 38.52 4,202.99 -906.39 9,435.57 0.00 0,00 0.00 0.00111-1088 708063018 7/3/2018 11:19:04AM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well 1 H-106 Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: 11-1-108 actual @ 92.99usft (Doyon 142) Project: Kupawk River Unit MD Reference: 1H-108 actual @ 92.99usft (Doyon 142) Site: Kupawk 1H Pad North Reference: True Well: 1H-108 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H -108B Design: 1H-1088 wp04 Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth -N1-5 .EI -W Section Rate Rate Rate (usft) (1) C) (usft) (usft) (usft( (usft) ('1100usft) ('H00usft) ('1100usft) 100.00 0.11 315.17 100.00 0.04 -0.04 -0.01 0.00 0.00 0.00 200.00 0.15 174.72 200.00 -0.02 -0.09 -0.08 0.25 0.04 -140.45 300.00 0.15 174.23 300.00 -0.32 -0.06 -0.26 0.00 0.00 -0.49 400.00 0.92 147.26 400.00 -0.91 0.23 -0.41 0.79 0.77 -26.97 500.00 1.75 134.94 499.97 -2.80 1.75 -0.46 0.87 0.83 -12.32 600,00 2.70 125.85 599.89 -5.23 4.70 0.23 1.01 0.95 -9.09 700.00 4.84 123.77 699.68 -8.89 10.03 1.97 2.14 2.14 -2.08 800.00 7.44 120.58 799.10 -14.44 19.08 5.33 2.62 2.60 -3.19 900.00 10.75 122.67 897.81 -22.90 32.58 10.23 3.33 3.32 2.09 1,000.00 12.89 121.49 995.67 -33.78 50.02 16.61 2.15 2.13 -1.18 1,100.00 14.59 121.76 1,092.81 -46.16 70.25 24.15 1.70 1.70 0.27 1,200.00 16.83 123.34 1,189.14 -60,59 92.87 32.20 2.28 2.24 1.59 1,300.00 19.97 123.95 1,283.99 -78.27 119.09 40.92 3.15 3.14 0.61 1,400.00 22.90 123.35 1,377.06 -98.43 149.58 51.31 2.94 2.93 -0.60 1,500.00 25.29 123.22 1,468.30 -120.91 183.77 63.06 2.39 2.39 -0.14 1,600.00 25.71 122.67 1,558.44 -144.47 220.09 75.73 0.48 0.42 -0.54 1,700.00 26.08 123.39 1,648.42 -168.21 256.71 88.53 0.48 0.37 0.71 1,800.00 28.53 122.33 1,737.36 -193.28 294.89 101.66 2.50 2.45 -1.06 1,834.00 29.50 121.43 1,767.10 -201.99 308.89 106.79 3.12 2.85 -2.63 10 3/4" x 13 1/2" 1,900.00 31.20 122.18 1,824.04 -219.45 337.33 117.34 2.64 2.58 1.13 KOP: 4"/100' DLS, 20' TF, for 1000' 2,000.00 34.99 124.56 1,907.80 -249.53 382.88 132.91 4.00 3.78 2.38 2,100.00 38.81 126.53 1,987.76 -284.46 431.69 147.84 4.00 3.82 1.97 2,173.65 41.64 127.79 2,043.99 -313.20 469.58 158.40 4.00 3.85 1.70 K-15 2,200.00 42.66 128.20 2,063.52 -324.08 483.51 162.07 4.00 3.86 1.57 2,300.00 46.53 129.64 2,134.72 -368.21 538.10 175.53 4.00 3.87 1.44 2,400.00 50.41 130.91 2,201.01 -416.61 595.19 188.15 4.00 3.89 1.27 2,500.00 54.31 132.04 2,262.07 -469.06 654.49 199.86 4.00 3.90 1.13 2,600.00 58.22 133.07 2,317.59 525.30 715.73 210.62 4.00 3.91 1.03 2,700.00 62.14 134.01 2,367.31 585,06 778.60 220.37 4.00 3.92 0.94 2,800.00 66.06 134.89 2,410.99 -648.05 842.80 229.06 4.00 3.92 0.88 2,900.00 69.98 135.71 2,448.41 -713.95 908.01 236.66 4.00 3.93 0.82 Adjust TF to -93', for 416.83' 3,000.00 69.83 131.45 2,482.78 -778.67 976.01 247.15 4.00 -0.16 -4.26 3,100.00 69.77 127.19 2,517.33 -838.13 1,048.59 264.53 4.00 -0.06 4.26 3,200.00 69.82 122.93 2,551.88 -892.02 1,125.39 288.72 4.00 0.05 -4.26 3,300.00 69.97 118.67 2,586.27 -940.09 1,206.03 319.59 4.00 0.15 4.26 3,315.83 70.00 118.00 2,591.69 -947.15 1,219.12 325.08 4.00 0.21 -4.25 Hold for 2000' 3,400.00 70.00 118.00 2,620.48 -984.28 1,288.95 354.71 0.00 0.00 0.00 3,500.00 70.00 118.00 2,654.68 -1,028.40 1,371.92 389.91 0.00 0.00 0.00 3,600.00 70.00 118.00 2,688.86 -1,072.52 1,454.89 425.11 0.00 0.00 0.00 3,700.00 70.00 118.00 2,723.08 -1,116.63 1,537.86 460.31 0.00 0.00 0.00 3,800.00 70.00 118.00 2,757.29 -1,160.75 1,620.83 495.51 0.00 0.00 0.00 3,900.00 70.00 118.00 2,791.49 -1,204.86 1,703.80 530.72 0.00 0.00 0.00 4,000.00 70.00 118.00 2,825.69 -1,248.98 1,786.77 565.92 0.00 0.00 0.00 4,100.00 70.00 118.00 2,859.89 -1,293.10 1,869.74 601.12 0.00 0.00 0.00 4,200.00 70.00 118.00 2,894.09 -1,337.21 1,952.71 636.32 0.00 0.00 0.00 4,300.00 70.00 118.00 2,928,30 -1,381.33 2,035.68 671.52 0.00 0.00 0.00 4,400.00 70.00 118.00 2,962.50 -1,425.44 2,118.65 706.72 0.00 0.00 0.00 4,500.00 70.00 116.00 2,996.70 -1,469.56 2,201.62 741.93 0.00 0.00 0.00 7/3/2018 11:19:04AM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Ina -Kupl Project: Kupanik River Unit Site: Kuparuk 1 H Pad Well: 11-1-108 Wellbore: Plan: 1H -108B Design: 1 H -108B wp04 Planned Survey Measured 777.13 0.00 Depth Inclination Azimuth (usft) 812.33 0.00 UG_C 0.00 2,450.53 4,600.00 70.00 118.00 4,700.00 70.00 118.00 4,800.00 70.00 118.00 4,900.00 70.00 118.00 5,000.00 70.00 118.00 5,100.00 70.00 118.00 5,200.00 70.00 118.00 5,300.00 70.00 118.00 5,315.83 70.00 118.00 Start 4°1100' DLS, 22.28' TF, for 267.07' 5,400.00 73.12 119.33 5,500.00 76.84 120.86 5,507.65 77.12 120.98 UG_B 3,032.10 1,091.01 5,582.90 79.93 122.09 Hold for 1698.27' 1,093.44 4.00 5,600.00 79.93 122.09 5,700.00 79.93 122.09 5,800.00 79.93 122.09 5,900.00 79.93 122.09 6,000.00 79.93 122.09 6,100.00 79.93 122.09 6,149.07 79.93 122.09 UG_A 3,365.84 1,212.78 6,200.00 79.93 122.09 6,300.00 79.93 122.09 6,400.00 79.93 122.09 6,500.00 79.93 122.09 6,600.00 79.93 122.09 6,700.00 79.93 122.09 6,789.40 79.93 122.09 Na 0.00 3,699.48 6,800.00 79.93 122.09 6,900.00 79.93 122.09 7,000.00 79.93 122.09 7,100.00 79.93 122.09 7,200.00 79.93 122.09 7,281.17 79.93 122.09 Start 4'M00' DLS, -86.37' TF, for 1042.03' 7,300.00 79.98 121.33 7,400.00 80.26 117.28 7,500.00 80.60 113.24 7,600.00 80.98 109.20 7,700.00 81.40 105.18 7,800.00 81.87 101.16 7,900.00 62.37 97.16 8,000.00 82.92 93.16 8,100.00 83.49 89.18 6,200.00 84.10 85.20 8,300.00 84.73 81.23 8,323.20 84.89 80.31 Vertical Depth (usft) 3,030.90 3,065.10 3,099.31 3,133.51 3,167.71 3,201.91 3,236.11 3,270.32 3,275.73 3,302.35 3,328.27 3,329.99 3,344.96 3,347.95 3,365.44 3,382.93 3,400.42 3,417.92 3,435.41 3,443.99 3,452.90 3,470.39 3,487.88 3,505.37 3,522.86 3,540.35 3,555.99 3,557,84 3,575.34 3,592.83 3,610.32 3,627.81 3,642.01 3,645.29 3,662.46 3,679.09 3,695.11 3,710.43 3,724.99 3,738.70 3,751.51 3,763.35 3,774.16 3,783.89 3,785.99 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: +Nl-S (usft) -1,513.68 -1,557.79 -1,601.91 -1,646.02 -1,690.14 -1,734.26 -1,778.37 -1,822.49 -1,829.47 -1,867.78 -1,916.21 -1,920.04 -1,958.61 -1,967.56 -2,019.87 -2,072.18 -2,124.49 -2,176.80 •2,229.12 .2,254.79 -2,281.43 -2,333.74 -2,386.05 -2,438.36 -2,490.68 -2,542.99 -2,589.75 -2,595.30 -2,647.61 -2,699.92 -2,752.24 -2,804.55 -2,847.01 -2,856.76 -2,904.96 -2,947.03 -2,982.75 -3,011.95 -3,034.49 -3,050.26 -3,059.18 -3,061.20 -3,056.32 -3,044.56 -3,040.86 7/312018 11:19:04AM Page 5 Vertical +El.W Section (usft) (usft) ConocoPhillips Standard Proposal Report Well 1 H-108 1H-108 actual @ 92.99usft(Doyon 142) 1 H-108 actual @ 92.99usft (Doyon 142) True Minimum Curvature Dogleg Build Turn Rate Rate Rate (°1100usft) (°1100ueft) ('MO(lueft) 2,284.59 777.13 0.00 0.00 0.00 2,367.56 812.33 0.00 0.00 0.00 2,450.53 847.53 0.00 0.00 0.00 2,533.50 882.73 0.00 0.00 0.00 2,616.47 917.93 0.00 0.00 0.00 2,699.44 953.13 0.00 0.00 0.00 2,782.41 988.34 0.00 0.00 0.00 2,865.38 1,023.54 0.00 0.00 0.00 2,878.52 1,029.11 0.00 0.00 0.00 2,948.56 1,058.15 4.00 3.71 1.58 3,032.10 1,091.01 4.00 3.72 1.53 3,038.49 1,093.44 4.00 3.72 1.50 3,101.34 1,116.79 4.00 3.73 1.48 3,115.60 1,121.97 0.00 0.00 0.00 3,199.01 1,152.24 0.00 0.00 0.00 3,282.43 1,182.51 0.00 0.00 0.00 3,365.84 1,212.78 0.00 0.00 0.00 3,449.25 1,243.06 0.00 0.00 0.00 3,532.66 1,273.33 0.00 0.00 0.00 3,573.59 1,288.18 0.00 0.00 0.00 3,616.07 1,303.60 0.00 0.00 0.00 3,699.48 1,333.87 0.00 0.00 0.00 3,782.90 1,364.14 0.00 0.00 0.00 3,866.31 1,394.41 0.00 0.00 0.00 3,949.72 1,424.69 0.00 0.00 0.00 4,033.13 1,454.96 0.00 0.00 0.00 4,107.70 1,482.02 0.00 0.00 0.00 4,116.54 1,485.23 0.00 0.00 0.00 4,199.95 1,515.50 0.00 0.00 0.00 4,283.37 1,545.77 0.00 0.00 0.00 4,366.78 1,576.04 0.00 0.00 0.00 4,450.19 1,606.31 0.00 0.00 0.00 4,517.90 1,630.89 0.00 0.00 0.00 4,533.67 1,636.70 4.00 0.26 -4.05 4,619.56 1,671.51 4.00 0.29 -4.05 4,708.72 1,712.77 4.00 0.33 -4.04 4,800.71 1,760.28 4.00 0.38 -4.03 4,895.10 1,813.82 4.00 0.42 -4.02 4,991.41 1,873.11 4.00 0.47 -4.02 5,089.18 1,937.87 4.00 0.51 -4.01 5,187.94 2,007.79 4.00 0.54 -4.00 5,287.19 2,082.52 4.00 0.58 -3.99 5,386.47 2,161.71 4.00 0.61 -3.98 5,485.28 2,244.96 4.00 0.64 -3.97 5,508.08 2,264.81 4.00 0.65 -3.96 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Local Co-ordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kupt TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1H Pad North Reference: Well: 11-1-108 Survey Calculation Method: Wellbore: Plan: 1H -108B Dogleg Design: 1H -108B wp04 Depth Inclination ConocoPhillips Standard Proposal Report Well 1H-108 11-1-108 actual @ 92.99usft (Doyon 142) 1 H-108 actual @ 92.99usft (Doyon 142) True Minimum Curvature Planned survey Measured vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/S +E/.W Section Rate Rate Rate (usft) (^) P) (uaft) (weft) (usft) (usfq C1100ue11t) ('MOOusft) ('MOoturm 8,345.64 84.89 80.31 3,787.99 -3,037.10 5,530.11 2,284.10 0.00 0.00 0.00 W4._D 8,400.00 84.89 80.31 3,792.84 -3,027,98 5,583.48 2,330.85 0.00 0.00 0.00 8,500.00 84,89 80.31 3,801.75 -3,011.22 5,681.67 2,416.83 0.00 0.00 0.00 8,558.77 84,89 80.31 3,806.99 -3,001.37 5,739.37 2,467.37 0.00 0.00 0.00 Adjust TF to 0', for 20'- 7 618" x 9 7/8" 8,578.77 84.89 80.31 3,808.77 -2,998.02 5,759.01 2,484.57 0.00 0.00 0.00 Start 2.5.1100' DLS, 26.86` TF, for 177.69' 8,600.00 85.36 80.55 3,810.58 -2,994.50 5,779.86 2,502.80 2.50 2.23 1.13 8,700.00 87.59 81.68 3,816.73 -2,979,09 5,878.47 2,588.24 2.50 2.23 1.13 8,756.47 88.85 82.32 3,818.48 -2,971.24 5,934.36 2,636.11 2.50 2.23 1.13 Hold for 664.42' 8,800.00 88.85 82.32 3,819.35 -2,965.42 5,977.49 2,672.89 0.00 0.00 0.00 8,900.00 88.85 82.32 3,821.36 -2,952.05 6,076.57 2,757.38 0.00 0.00 0.00 9,000.00 88.85 82.32 3,823.36 -2,938.68 6,175.65 2,841.88 0.00 0.00 400 9,100.00 86.85 82.32 3,825.37 -2,925.32 6,274.74 2,926.37 0.00 0.00 0.00 9,200.00 88.85 82.32 3,827.37 -2,911.95 6,373.82 3,010.86 0.00 0.00 0.00 9,300.00 88.85 82,32 3,829.37 -2,898.58 6,472.90 3,095.36 0.00 0.00 0.00 9,320.88 88,85 82.32 3,829.79 -2,895.79 6,493.59 3,113.00 0.00 0.00 0.00 Start 3.1100' DLS, -01.18' TF, for 243.88' 9,400.00 88.80 79.94 3,831.41 -2,883.60 6,571.74 3,180.71 3,00 -0.06 -3.00 9,500.00 88.75 76,94 3,833.55 -2,863.57 6,669.68 3,268.61 3.00 -0.06 -3.00 9,564.77 88.71 75.00 3,834.99 -2,847.87 6,732.50 3,326.81 3.00 -0.05 -3.00 Adjust TF to -89.61', for 186.86' 9,600.00 88.72 73.94 3,835.78 -2,838.44 6,766.44 3,358.87 3.00 0.03 -3.00 9,700.00 88.75 70.94 3,837.99 -2,808.29 6,861.74 3,451.27 3.00 0.03 -3.00 9,751.63 88.76 69.39 3,839.11 -2,790.78 6,910.30 3,499.72 3.00 0.03 -3.00 Hold for 612.49' 9,800.00 88.76 69.39 3,840.15 -2,773.76 6,955.56 3,545.33 0.00 0.00 0.00 9,900.00 88.76 69.39 3,842.31 -2,738.58 7,049.14 3,639.64 0.00 0.00 0.00 10,000.00 88.76 69.39 3,844.47 -2,703.39 7,142.73 3,733.94 0.00 0.00 0.00 10,100.00 88.76 69.39 3,846.62 -2,668.21 7,238,31 3,828.24 0.00 0.00 0.00 10,200.00 88.76 69.39 3,848.76 -2,633.02 7,329.89 3,922.55 0.00 0.00 0.00 10,300.00 88.76 69.39 3,850.94 -2,597.84 7,423.47 4,016.85 0.00 0.00 0.00 10,364,12 88.76 69.39 3,852.32 -2,575.28 7,483.47 4,077.32 0.00 0.00 0.00 Start 3'/100' DLS, -96.12' TF, for 213.85' 10,400.00 88.67 68.32 3,853.12 -2,562.34 7,516.93 4,111.26 3.00 -0.27 -2.99 10,500.00 88.40 65.33 3,855.68 -2,523.01 7,608.82 4,206.94 3.00 -0.26 -2.99 10,577.97 88.20 63.00 3,857.99 -2,489.05 7,678.97 4,282.50 3.00 -0.26 -2.99 Adjust TF to -97.82', for 131.32' 10,600.00 88.11 62.34 3,858.70 -2,478.94 7,698.52 4,303.98 3.00 -0.41 -2.97 10,700.00 87.71 59.37 3,862.35 -2,430.28 7,785.80 4,402.11 3.00 -0.40 -2.97 10,709.29 87.67 59.09 3,662.73 -2,425.53 7,793.77 4,411.27 3.00 -0.40 -2.97 Hold for 329.61' 10,800.00 87.67 59.09 3,866.42 -2,378.98 7,871.54 4,500.77 0.00 0.00 0.00 10,900.00 87.67 59.09 3,870.48 -2,327.66 7,957.27 4,599.43 0.00 0.00 0.00 11,000.00 87.67 59.09 3,874.55 -2,276.34 8,043.00 4,698.09 0.00 0.00 0.00 11,038.90 87.67 59.09 3,876.13 -2,256.38 8,076.35 4,736.47 0.00 0.00 0.00 Start 3'M00' DLS, -91.3' TF, for 138' 11,100.00 87.95 57.28 3,878.47 -2,224.20 8,128.23 4,796.90 3.00 0.46 -2.97 11,176.89 88.30 55.00 3,880.99 -2,181.38 8,192.05 4,873.31 3.00 0.46 -2.97 Adjust TF to -78.1', for 124.35' 11,200.00 88.44 54.32 3,881.65 -2,168.02 8,210.89 4,896.33 3.00 0.62 -2.94 7/32018 11:19:04AM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Local Coordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kupi TVD Reference: Project: Kupamk River Unit MD Reference: She: Kupamk 1H Pad North Reference: Well: IH -108 Survey Calculation Method: Wellbore: Plan: 11-1-108B Rate Design: 1 H -108B WP04 r) Planned Survey ConocoPhillips Standard Proposal Report Well 11-1-108 1 H-108 actual @ 92.99usft (Doyon 142) 1 H-108 actual C 92.99usft (Doyon 142) True Minimum Curvature Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth -NI-S +El -W Section Rate Rate Rate usft) r) (_) (usft) (usft) (usft) (usft) (*1100usft) ('/100usft) (°/100usft) 11,300.00 89.06 51.39 3,883.82 -2,107.65 8,290.57 4,996.17 3.00 0.62 -2.94 11,301.24 89.07 51.35 3,883.84 -2,106.88 8,291.54 4,997.41 3.00 0.62 -2.94 Hold for 429.91' 11,400.00 89.07 51.35 3,885.44 -2,045.21 8,368.66 5,096.13 0.00 0.00 0.00 11,500.00 89.07 51.35 3,887.06 -1,982.76 8,446.74 5,196.09 0.00 0.00 0.00 11,600.00 89.07 51.35 3,888.68 -1,920.31 8,524.83 5,296.05 0.00 0.00 0.00 11,700.00 89.07 51.35 3,890.30 -1,857.86 8,602.91 5,396.01 0.00 0.00 0.00 11,731.15 89.07 51.35 3,890.81 -1,838.40 8,627.24 5,427.15 0.00 0.00 0.00 Start 3.1100' OLS, .96.37- TF, for 112.31' 11,800.00 88.84 49.30 3,892.06 -1,794.46 8,680.22 5,495.98 3.00 -0.33 -2.98 11,843.47 88.70 48.00 3,892.99 -1,765.75 8,712.84 5,539.42 3.00 -0.33 -2.98 Adjust TF to -102.33°, for 270.28' 11,900.00 88.34 46.34 3,894.45 -1,727.33 8,754.28 5,595.86 3.00 -0.64 -2.93 12,000.00 87.70 43.41 3,897.91 -1,656.52 8,824.79 5,695.39 3.00 -0.64 -2.93 12,100.00 87.07 40.47 3,902.47 -1,582.22 8,891.55 5,794.29 3.00 -0.63 -2.94 12,113.75 86.99 40.07 3,903.18 -1,571.75 8,900.42 5,807.82 3.00 -0.63 -2.94 Hold for 39A4' 12,153.18 86.99 40.07 3,905.25 -1,541.60 8,925.78 5,848.62 0.00 0.00 0.00 Start 4°1100' DLS, -189.74° TF, for 202.96' 12,200.00 85.14 39.73 3,908.46 -1,505.78 8,955.73 5,892.60 4.00 -3.94 -0.72 12,300.00 81.21 39.01 3,920.34 -1,429.04 9,018.71 5,990.16 4.00 -3.94 -0.72 12,356.15 79.00 38.60 3,929.99 -1,385.94 9,053.37 6,044.42 4.00 -3.93 -0.73 Adjust TF to 479.82', for 642.05' 12,400.00 77.25 38.59 3,939.02 -1,352.40 9,080.14 6,086.49 4.00 4.00 -0.01 12,500.00 73.25 38.58 3,964.48 -1,276.83 9,140.44 6,181.26 4.00 4.00 -0.01 12,520.00 72.45 38.58 3,970.38 -1,261.89 9,152.36 6,199.99 4.00 -4.00 -0.01 ws_c 12,598.00 69.33 38.57 3,995.91 -1,204.28 9,198.31 6,272.22 4.00 4.00 -0.01 WS_B 12,600.00 69.25 38.57 3,996.62 -1,202.81 9,199.47 6,274.05 4.00 4.00 -0.01 12,692.00 65.57 38.55 4,031.96 -1,136.41 9,252.41 6,357.29 4.00 4.00 -0.01 WS_A4 12,700.00 65.25 38.55 4,035.29 -1,130.72 9,256.94 6,364.42 4.00 -4.00 -0.02 12,800.00 61.25 38.54 4,080.30 -1,060.89 9,312.57 6,451.92 4.00 4.00 -0.02 12,801.00 61.21 38.54 4,080.78 -1,060.21 9,313.12 6,452.78 4.00 4.00 -0.02 WSf3 12,898.19 57.32 38.52 4,130.45 -994.86 9,365.14 6,534.63 4.00 -4.00 -0.02 Hold for 134.35' 12,900.00 57.32 38.52 4,131.42 -993.67 9,366.09 6,536.12 0.00 0.00 0.00 12,963.00 57.32 38.52 4,165.44 -952.19 9,399.11 6,588.09 0.00 0.00 0.00 WS Jt2 13,000.00 57.32 38.52 4,185.42 -927.82 9,418.51 6,618.60 0.00 0.00 0.00 13,032.54 57.32 38.52 4,202.99 -906.39 9,435.57 6,645.44 0.00 0.00 0.00 TD: 13032.64' MD, 4202.99' TVD 7/3r201811.19:04AM Page 7 COMPASS 5000.14 Build 85 i ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP2 Local Coordinate Reference: Well 1 H-108 Company: ConocoPhillips (Alaska) Inc -Kup1 TVD Reference: 1H-108 actual @ 92.99usft (Doyon 142) Project: Kupawk River Unit MD Reference: 1 H-108 actual @ 92.99usft (Doyon 142) Site: Kuparuk 1 H Pad North Reference: True Well: 11-1-108 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 11-1-108B (usft) 1H-108BT01 OM Design: 1 H-1088 wp04 3,785.99 -3,040.86 Design Targets Measured Target Name Casing Hole Depth Depth -hit/miss target Dip Angle Dip Din TVD +N/S +B/4N -Shape (°) (I (waft) (waft) (usft) 1H-108BT01 OM 0.00 0.00 3,785.99 -3,040.86 5,508.08 - plan hits target center 13,032.54 4,202.69 41/2"x6-3/4° 4-1/2 6-3/4 - Circle (radius 1,320.00) 1H -108B 701063018 RE 0.00 0.00 3,785.99 -3,040.86 5,508.08 - plan hits target center - Circle (radius 100.00) 1H -108B T02063018 R1 0.00 0.00 3,806.99 -3,001.37 5,739.37 - plan hits target center - Cirde (radius 100.00) 1 H-1 08B T03 063018 RF 0.00 0.00 3,834.99 -2,847.87 6,732.50 - plan hits target center - Circle (radius 100.00) 11-1-108B 704063018 R1 0.00 0.00 3,857.99 -2,489.05 7,678.97 - plan hits target center - Circle (radius 100.00) 1H -108B T04 OM 0.00 0.00 3,857.99 -2,489.05 7,678.97 - plan hits target center - Circle (radius 1,320.00) 1H-1088705063018 R1 0.00 0.00 3,880.99 -2,181.38 8,192.05 - plan hits target center -Circle (radius 100.00) 1 H-1 08B T06 063018 R( 0.00 0.00 3,692.99 -1,765.75 8,712.84 - plan hits target center - Circle (radius 100.00) 1H -108B T07063018 RI 0.00 0.00 3,929.99 -1,385.94 9,053.37 - plan hits target center - Circle (radius 100.00) 1 H-1 06B T08 063018 RI 0.00 0.00 4,202.99 -906.39 9,435.57 - plan hits target center - Cirds (radius 100.00) 1H -108B T08 OM 0.00 0.00 4,202.99 -906.39 9,435.57 - plan hits target center - Circle (radius 1,320.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (waft) (uaft) Name P) f1 1,834.00 1,767.10 10 3/4"x 13 1/2" 10-3/4 13-1/2 8,558.77 3,806.69 7518"x97/8" 7-5/8 9-7/8 13,032.54 4,202.69 41/2"x6-3/4° 4-1/2 6-3/4 7/12018 11:19..04AM Page 8 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Ina -Kup1 Project: Kupamk River Unit Site: Kupawk 1H Pad Well: 1WI08 Wellbore: Plan: 1H -108B Design: 1H -108B wp04 Formations Plan Annotations Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well 1 H-108 1 H-108 actual @ 92.99usft (Doyon 142) 1 H-108 actual @ 92.99usft (Doyon 142) True Minimum Curvature Measured Vertical Local Coordinates Dip Depth Depth +111$ Dip Direction (usft) (usft) Name Lithology 1,876.67 1,803.99 T-3 1,824.04 2,174.05 2,043.99 K-15 0,00 4,538.81 3,008.99 UG_C 0.00 5,509.00 3,329.99 UG_B 0,00 6,150.79 3,443.99 UG_A 0.00 6,791.12 3,555.99 Na 0.00 8,349.01 3,787.99 WS_D 0.00 12,520.00 3,970.08 WS_C 0.00 12,598.00 3,995.61 WS_B 0.00 12,692.00 4,031.66 WS_A4 0.00 12,801.00 4,080.48 WS—A3 0.00 12,963.00 4,165.14 WS—A2 0.00 Measured Vertical Local Coordinates Depth Depth +111$ +El -W (usft( (usft) (usft) (usft) Comment 1,900,00 1,824.04 -219.45 337.33 KOP: 4°/100' DLS, 20° TF, for 1000' 2,900.00 2,448.41 -713.95 908.01 Adjust TF to -93°, for 415.83' 3,315.83 2,591.69 -947.15 1,219.12 Hold for 2000' 5,315.83 3,275.73 -1,829.47 2,878.52 Start 4°/100' DLS, 22.28° TF, for 267.07' 5,582.90 3,344.96 -1,958.61 3,101.34 Hold for 1698.27' 7,281.17 3,642.01 -2,847.01 4,517.90 Start 4°/100' DLS, -86.37° TF, for 1042.03' 8,323.20 3,785.99 -3,040.86 5,508.08 Hold for 235.57' 8,558.77 3,806.99 3,001.37 5,739.37 Adjust TF to O°, for 20' 8,578.77 3,808.77 -2,998.02 5,759.01 Start 2.5°/100' DLS, 26.85° TF, for 177.69' 8,756.47 3,818.48 -2,971.24 5,934.36 Hold for 564.42' 9,320.68 3,829.79 -2,895.79 6,493.59 Start 3°/100' DLS, -91.18° TF, for 243.88' 9,564.77 3,834,99 -2,847.87 6,732.50 Adjust TF to 39.51', for 186.86' 9,751.63 3,839.11 -2,790.78 6,910.30 Hold for 612.49' 10,364.12 3,852.32 -2,575.28 7,483.47 Start Wit 00'DLS,-95.12°TF, for 213.85' 10,577.97 3,857.99 -2,489.05 7,678.97 Adjust TF to -97.82°, for 131.32' 10,709.29 3,862.73 -2,425.53 7,793.77 Hold for 329.61' 11,038.90 3,676.13 -2,256.38 8,076.35 Start 3°1100' DLS, -81.3° TF, for 138' 11,176.89 3,880.99 -2,181.38 8,192.05 Adjust TF to-78.1°,for 124.35' 11,301.24 3,883.84 -2,106.88 8,291.54 Hold for 429.91' 11,731.15 3,890.81 -1,838.40 8,627.24 Start 3°/100' DLS, -96.37° TF, for 112.31' 11,843.47 3,892.99 -1,765.75 8,712.84 Adjust TF to -102.33°, for 270.28' 12,113.75 3,903.18 -1,571.75 8,900.42 Hold for 39.44' 12,153.19 3,905.25 -1,541.60 8,925.78 Start 4°/100'DLS,-169.74°TF, for 202.96' 12,356.15 3,929.99 -1,385.94 9,053.37 Adjust TF to -179.82°, for 542.05' 12,898.19 4,130.45 -994.86 9,365.14 Hold for 134.35' 13,032.54 4,202.99 -906.39 9,435.57 TD: 13032.54' MD, 4202.99'TVD 7/320181 f 19:04AM Page 9 COMPASS 5000.14 Build 85 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 11-1 Pad 11-1-108 Plan: 11-1-10813 500292360800 1 H-1086 wp04 ConocoPhillips Clearance Summary Anticollision Report 03 July, 2018 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 1H Pad -1H -108 -Plan: 1H -10813-1H-1088 wp04 Datum Height: 11-1-108 actual @ 92.99usft (Doyon 142) Scan Range: 1,900.00 to 13,032.64 usft. Measured Depth. Scan Radius is 1,499.36 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 6000.14 Build: 86 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 ConocoPhillips ConocoPhillips Anticollision Report for 1H-108 - 1H-1088 wpO4 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 1H Pad -1H -108 -Plan: iH-108B-1H-1088 wp04 Scan Range: 1,900.00 to 13,032.64 usft. Measured Depth. Scan Radius Is 1,499.36 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Site Name Depth Distance Depth Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) Kuparuk 1B Pad 1 B-102- 1 B-102- i 8-102 Kuparuk 1C Pad 1C-150 -1 C-150 - 1C-150 1C-170 - IC -170 - 1C-170 IC -174 - 1C.174 - 1C-174 1C-178 - 1C-17817 - 1C-1781-1 Kuparuk 1H Pad 1H-05-iH-05-1H-05 1 H-05 -1 H-105 -1 H-106 I H-09 -1 H-09 - 1 H-09 1H -09 -1H -09-1H-09 1 H-101 - i H-101 - 1 H-101 1 H-101 - i H-101 - i H-101 1H -101-1H-101 L1-iH-101 L1 IH -101 -11-1-1011-1 - i H-101 L1 IH -101 -11-1-1011-2- 1 H-101 L2 IH -101 - IH -1011-2- 1 H-101 L2 IH -101 - 11-1-10113 -1 H-1011-3 1H-101 -1 1-1-1011-3 - 11-1-1011-3 11-1-101 -1H-101L4 - 1H-1011-4 11-1-101 -1H-1011-4- 1 H-1011-4 1H-102- 1H-102-1 1-1-102 11-4-102 - 1H-102- i H-102 IH -102 -1 H-10211 -1 1-1-10211 IH -102 -1 H-1021-7 -1 H-1021-1 IH -102 - 11-1-1021-2 -1 1-1-10212 ConocoPhillips (Alaska) inc. -Kupa Kuparuk River Unit Ellipse @Measured Clearance Summary Based on Separation Depth Factor Minimum Separation Warning (usft) usft 7,927.24 727.23 7,927.24 513.56 14,044.00 3.404 Clearance Factor Pass - Major Risk 11,411.45 942.31 11,411.45 782.93 12,898.00 5.912 Clearance Factor Pass - Major Risk 10,523.86 1,104.03 10,523.86 949.50 12,230.00 7.144 Clearance Factor Pass - Major Risk 9,700.00 733.57 9,700.00 474.72 12,485.00 2.834 Clearance Factor Pass -Major Risk 9,064.92 1,007.88 9,064.92 784.48 13,626.00 4.512 Clearance Factor Pass -Major Risk 1,900.00 82.12 1,900.00 36.83 1,950.00 1.813 Clearance Factor Pass- Major Risk 1,916.19 85.34 1,916.19 40.17 1,975.00 1.689 Clearance Factor Pass - Major Risk 4,934.29 213.79 4,934.29 55.47 4,450.00 1.350 Centre Distance Pass - Major Risk 4,982.18 214.26 4,982.18 54.88 4,500.00 1.344 Clearance Factor Paas -Major Risk 1,911.70 337.92 1,911.70 305.59 1,850.00 10.454 Centre Distance Pass - Major Risk 4,516.36 350.22 4,516.36 265.49 4,675.00 4.133 Clearance Factor Pass - Major Risk 1,911.70 337.92 1,911.70 305.59 1,850.00 10.454 Centre Distance Pass- Major Risk 4,516.36 350.22 4,516.36 265.49 4,675.00 4.133 Clearance Factor Pass- Major Risk 1,911.70 337.92 1,911.70 305.59 1,850.00 10.454 Centre Distance Pass- Major Risk 4,516.36 350.22 4,516.36 265.49 4,675.00 4.133 Clearance Factor Pass - Major Risk 1,911.70 337.92 1,911.70 305.59 1,850.00 10.454 Centre Distance Pass - Major Risk 4,516.36 350.22 4,516.36 265.49 4,675.00 4.133 Clearance Factor Pass - Major Risk 1,911.70 337.92 1,911.70 305.59 1,850.00 10.454 Centre Distance Pass- Major Risk 4,516.36 350.22 4,516.36 265.49 4,675.00 4.133 Clearance Factor Pass- Major Risk 3,213.14 124.44 3,213.14 44.84 3,075.00 1.563 Centre Distance Pass- Major Risk 3,283.93 125.92 3,283.93 43.25 3,150.00 1.523 Clearance Factor Pass - Major Risk 3,213.14 124.44 3,213.14 44.84 3,075.00 1.563 Centre Distance Pass - Major Risk 3,283.93 125.92 3,283.93 43.25 3,150.00 1.523 Clearance Factor Pass - Major Risk 3,213.14 124.44 3,213.14 44.84 3,075.00 1.563 Centre Distance Pass - Major Risk 03 July, 2018 - 10:37 Page 2 of 7 COMPASS ConocoPhillips Anticollision Report for 1 H-108 -1 H -108B wp04 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: KuparuklH Pad - IH408 -Plan: 1H-1088-lH-108Bwp04 Scan Range: 1,900.00 to 13,032.54 usft Measured Depth. Scan Radius is 1,499.35 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Wanting Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft 1H -102 -1H -1021-2-1H-1021_2 3,283.93 125.92 3,263.93 43.25 3,150.00 1.523 Clearance Factor Pass - Major Risk iH-1D2-1H-1021-3-iH-1021_3 3,213.14 124.44 3,213.14 44.84 3,075.00 1.563 Centre Distance Pass - Major Risk IH -102 -1H -1021_3-1H-1021-3 3,283.93 125.92 3,283.93 43.25 3,150.00 1.523 Clearance Factor Pass - Major Risk 1H -102 -IH -1021_4-1H-1021.4 3,213.14 124.44 3,213.14 44.84 3,075.00 1.563 Centre Distance Pass - Major Risk 1H -102 -1H -1021.4-1H-1021.4 3,283.93 125.92 3,283.93 43.25 3,150.00 1.523 Clearance Factor Pass - Major Risk 1H-103-1H-103-iH-103 1,916.77 132.16 1,916.77 103.16 1,875.00 4.556 Centre Distance Pass - Major Risk IH -103 -1H -103-1H-103 3,452.75 136.85 3,452.75 30.38 3,325.00 1.285 Clearance Factor Pass -Major Risk 1H-103. 1H -10311-1H-1031.1 1,916.77 132.16 1,916.77 103.16 1,875.00 4.556 Centre Distance Pass - Major Risk 1 H-103 - 1 H-103LI - 1 H-1031_1 3,452.75 136.85 3,452.75 30.38 3,325.00 1.285 Clearance Factor Pass - Major Risk 1H -103 -1H -1031_2-1H-1031-2 1,916.77 132.16 1,916.77 103.16 1,875.00 4.556 Centre Distance Pass - Major Risk IH -103 -1H -1031 -2 -1H -103L2 3,452.75 136.85 3,452.75 30.38 3,325.00 1.285 Clearance Factor Pass - Major Risk 1H -103 -1H -1031.3-1H-1031.3 1,916.77 132.16 1,916.77 103.16 1,875.00 4.556 Centre Distance Pass - Major Risk 1H -103 -1H -1031-3-1H-1031_3 3,452.75 136.65 3,452.75 30.38 3,325.00 1.285 Clearance Factor Pass - Major Risk 1H -103 -1H -1031 -4 -1H -103L4 1,916.77 132.16 1,916.77 103.16 1,875.00 4.556 Centre Distance Pass - Major Risk 1H-103-1H-1031.4-iH-1031-4 3,452.75 136.85 3,452.75 30.38 3,325.00 1.265 Clearance Factor Pass - Major Risk I H-106 -1 H-108 -1 H-108 2,223.87 16.95 2,223.87 2.41 2,225.00 1.165 Clearance Factor Pass - Major Risk 1H-108-iH-1OSA -1H-108A 2,148.81 12.85 2,148.61 2.30 2,150.00 1.217 Centre Distance Pass - Major Risk 1H -108 -1H -108A -1H -108A 2,272.85 17.67 2,272.85 1.46 2,275.00 1.090 Clearance Factor Pass - Major Risk IH-109-1H-109-iH-109 1,908.12 98.06 1,908.12 63.85 1,925.00 2.667 Clearance Factor Pass - Major Risk IH -11 - 11-1-11 - JH -11 3,490.23 520.43 3,490.23 389.21 3,100.00 3.966 Clearance Factor Pass - Major Risk 1H-11-1H-11-iH-11 3,538.01 520.28 3,538.01 399.13 3,150.00 4294 Centre Distance Pass -Major Risk 1H-110-1H-110-iH-110 1,911.61 199.47 1,911.61 156.03 1,925.00 4.591 Centre Distance Pass - Major Risk 1H -110 -1H -110-1H-110 1,935.51 202.96 1,935.51 155.97 1,950.00 4.319 Clearance Factor Pass - Major Risk 1H -110-1H-110. 1H-110 1,911.61 199.47 1,911.61 156.03 1,925.00 4.591 Centre Distance Pass - Major Risk IH -110 -IH -110-1H-110 1,935.51 202.96 1,935.51 155.97 1,950.00 4.319 Clearance Factor Pass - Major Risk 1H -111 -1H -111-1H-111 1,906.45 236.68 1,908.45 201.78 1,950.00 6.783 Clearance Factor Pass - Major Risk 1H -113 -1H -113-1H-113 1,900.96 338.44 1,900.96 302.06 1,950.00 9.303 Clearance Factor Pass - Major Risk 1H-114-1H-114-iH-114 1,909.57 367.18 1,909.57 333.68 2,000.00 10.961 Clearance Factor Pass - Major Risk 1H -12 -1H -12-1H-12 2,460.37 156.12 2,460.37 89.18 2,425.00 2.332 Clearance Factor Pass - Major Risk 1H -12 -1H -12-1H-12 2,478.24 155.52 2,478.24 89.86 2,450.00 2.369 Centre Distance Pass - Major Risk 03 July, 2018 - 10'37 Page 3 of 7 COMPASS ConocoPhillips Anticollision Report for 1H-108 - 1H-1086 wpO4 Tri Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk lH Pad -1H -108 -Plan: IH -108B -IH -1088 wp04 Scan Range: 1,900.00 to 13,032.64 usft. Measured Depth. Scan Radius is 1,499.35 usft. Clearance Factor cutoff Is Unlimited. Max Ellipse Separation is Unlimited ConocoPhillips (Alaska) inc. -Kupl Kuparuk River Unit 03 July, 2018 - 10.37 Page 4 of COMPASS Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on She Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft 1H -13 -1H -13-1H-13 3,500.59 254.79 3,500.59 150.82 3,100.00 2.450 Clearance Factor Pass - Major Risk iH-13-11-1-13-11-1-13 3,568.83 253.09 3,568.83 155.27 3,175.00 2.587 Centre Distance Pass - Major Risk iH-15-1H-15-iH-15 3,460.40 294.82 3,460.40 168.54 3,500.00 2.335 Centre Distance Pass - Major Risk 1H-15-iH-15-IH-15 3,484.29 294.84 3,484.29 168.16 3,525.00 2.327 Clearance Factor Pass - Major Risk 1H-21 - 1H-21 - iH-21 2,678.66 437.59 2,678.66 359.01 2,650.00 5.569 Centre Distance Pass - Major Risk 1H-21 - 1H-21 - 1 H-21 2,695.58 437.61 2,695.58 358.95 2,675.00 5.563 Clearance Factor Pass - Major Risk 11-1-21-1H-21A-1H-21A_wp03 2,678.66 437.59 2,678.66 359.01 2,650.00 5.569 Centre Distance Pass - Major Risk 1H-21-1H-21A-1H-21A_wP03 2,695.58 437.61 2,695.58 358.95 2,675.00 5.563 Clearance Factor Pass - Major Risk 1H-21-1H-21ALl-1H-21AL1_wP02 2,678.66 437.59 2,678.66 359.01 2,650.00 5.569 Centre Distance Pass - Major Risk 1H-21-1H-21ALl-iH-21AL7_wP02 2,695.58 437.61 2,695.58 358.95 2,675.00 5.563 Clearance Factor Pass - Major Risk 1H-21-1H-21AL2-i1-1-21AL2_wp02 2,678.66 437.59 2,670.66 359.01 2,650.00 5.569 Centre Distanx Pass - Major Risk iH-21-1H-21AL2-iH-21AL2_wP02 2,695.58 437.61 2,695.58 358.95 2,675.00 5.563 Clearance Factor Pass - Major Risk 11-1-21-1H-21AL2-01-1H-21AL2-01_wp02 2,678.66 437.59 2,678.66 359.01 2,650.00 5.569 Centre Distance Pass - Major Risk 1H-21-iH-21AL2-01-iH-21AL2-01_wP02 2,695.58 437.61 2,695.58 358.95 2,675.00 5.563 Clearance Factor Pass - Major Risk iH-401(UGNU)-11-1-401. JH401 1,900.00 938.51 1,900.00 898.76 2,575.00 23.607 Clearance Factor Pass - Major Risk Plan: 1H -104 -Plan: 1H-104-1H-104wp26 1,912.96 135.37 1,912.96 101.60 1,900.00 4.009 Clearance Factor Pass - Major Risk Plan: 1H -104 -Plan: 1H-104LI-1HA 04Liwp24 1,912.96 135.37 1,912.96 101.60 1,900.00 4.009 Clearance Factor Pass - Major Risk Plan: 1H -104 -Plan: 11-1-1041-2-1H-104L2wp24 1,912.96 135.37 1,912.96 101.60 1,900.00 4.009 Clearance Factor Pass - Major Risk Plan: 1H -115 -Plan: 1H-115-1H-115wp22 1,908.89 409.16 1,908.89 377.38 2,025.00 12.876 Clearance Factor Pass -Major Risk 03 July, 2018 - 10.37 Page 4 of COMPASS ConocoPhillips Anticollision Report for 1 H-108 - 1 H-1088 wp04 Survey tool program From To Wait) (Usn) 120.48 1,266.38 1,361.99 1,750.03 1,847.94 1,900.00 1,900.00 2,050.00 1H-1088 wp04 2,050.00 3,550.00 1H-1088 wp04 2,050.00 8,560.00 1H -108B wp04 8,560.00 10,060.00 1 H-1 08B wp04 8,560.00 13,032.54 1 H-1 08B wp04 Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Survey/Plan Survey Tool GYD-GC-SS MWD+IFR-AK-CAZSC MWD+IFR-AK-CAZSC MWD-INC—ONLY MWD MWD+IFR-AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC ConocoPhillips (Alaska) Inc. -Kupi Kuparuk River Unit 03 July, 2018 - 10.37 Page 5 of 7 COMPASS 10:42: July 03 3018 2000 1 H-1086 wp04 Ladder View QII�ITII Depth From Depth To Survey/Plan 120.48266.38 1H-108 Srvy 1 (11-1-108) 1361.99750.03 1H-108 Srvy 2 (1H-108) 1847.94 900.00 1H-108 Srvy 3 (1H-108) 1900.0(2050.00 11-1-1086 wp04 2050.00550.00 11-1-10813 wp04 2050.03560.00 1H-1086 wp04 8560.0®060.00 1H -108B wp04 8560.068032.54 1H -108B wp04 M c 0 m` CL m U E030 - U 0 Z 8000 Measured Depth Tool GYD-GC-SS MWD -INC ONLY MWD - MWD+IFR-AK-CA MWD iflus SP 12000 TVD MD Name 3806.69 8558.77 7 5/8" x 9 7/8" 4202.69 13032.54 4 1/2" x 6-3/4" Fi` — - — ---- Equivalent Magnetic Distance0/ 2100 2400 2700 3000 Partial Measured Depth t 3300 . . 120.48 1266.38 GYD-GC-85 1361.99 1750.03 MWD+IFR-AK-GAZ-SC 1847.94 1900.00 MWD+IFR.AK-CAZ-SC 1900.00 2050.00 MWD -INC ONLY 2050.00 3550M MWD 2050+00 8560.00 MWD+IFR-AK-CAZ-SC 8560+00 10060M MWD 8560.00 13032.54 MWD+IFR�AK-CAZ-SC t I vs . 3806 69 8558.77 7 518"�..�J10Fnl�,0 ' ♦ ��1 i =.1�►iI/ ..i esF.� �' ♦ 1 'Q•Vop 1900 it tIP ��,.: �.r. 1900 2090 11��, m fit MA b\i�•��1� �/( \�`rY � ll�� `A,..ssi%/%1 t It yr =-: a•�S;t��i�Q�1�j��!1� 11 1 ..�i►I�.■� ,r fir\IV1��\��`L�/1 ra-� .� �' �.�.a� �0��6�V! d.�w � • 1 • 1 1 ,,8i�%%��g i�� OF Ali- ►.ci;8d�17 M"n..�y�\\ �� '�dal'b�o 1 .1•/ i,\ e .1.1 11 ljp, f�`•e/•FlfiWA`41W.� \`� / i, �i �\ �1liiVl — 7320 i� osn �� <a.,G®�..a■':, .y.� tee:6500 lm,W .l 7320 — 8130 8130 8950 Z AW 8950 9770 10590 11400 11400 12220 %% , oi,, July 03 K Kuparuk 1 H Pad Easting (2500 usftlin) 1H-1011-1_ 1H -102L4 1H -102L3 1H-1031-3 1H -101L2- -1H-10 -- 1H-1021-2 __1H-1031-1 1H -101L3 1H-102 L1 ""---- _.1H -103L4 1H-102 - __1H -103L2 1H-1011-4 - --__ 1H-114 1H- 05 ----1H-103 1H-104wp26 1H -21A _ --1H-104 Ltwp24 _ iH-1D5H1H4 15wp22 1 H-21AL1_wp02 1H-401 _ 1H-109 1H-113 1H-1 jI-21 _ - AFL iH 1H-108 H-15 1H -108A 1C-1 U 16-102 ` iC- H-11 Easting (2500 usftlin) iH-21AL2_wp02 - -1 H-21 AL2 -01 _wp02 1H-1088 wp04 IH -13 1C-150 3 O O O O O C D 0 O 0 0 0 0 0 O O O O O O M O O co O N M O O r- M d- M — O— (0 '14' Ln M 1,- O -.) 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L�ooO OM ON��n aNnOo Z {/� [1M WOM �OOMMOn OI�I�n[O f�MNI�m OQ)�u7 (p�Q�m� u�noo Q OOWo�61�NI�i�a Ml�c0 �6�NQ�NN�Vf��[J �O Ul mm VOOoOo 0o 616 LU NMOJ w(pOV�aI�Q�W(O��MMM(DNN OO��ro WN�n-�N(O t1 (p I�OMrOM��t1�6�M pV mmOoo00 iyo�n0000a UtpN oo p��MMNNMN�I�MU ISM NI�O�MI�W �'-M�O �NMLLJNI�Wp'JNW OOm000`��N��M of m O ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1 H Pad 1 H-108 11FTiliil:6[1Y3-3 Plan: 1H-1086 wp04 Error Ellipse Survey Report 03 July, 2018 Company: ConocoPhillips(Alaska) Inc.-Kupl Project: Kupamk River Unit Site: Kupamk 1 H Pad Well: 1H-108 Wellbore: Plan: IH -108B Design: 11-4-108B wp04 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well IH -108 IH -108 actual Q 92.99usft (Doyon 142) 1 H-108 actual ® 92.99usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kupamk 1H Pad Site Position: Northing: Latitude: From: Map Easgng: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0 " Grid Convergence: 0.37 ° Well 1H-108 From Well Position -NAS 0.00 usft Northing: Latitude: Tool Name +E/ -W 0.00 usft Easting: Longitude: Position Uncertainty 1,361.99 0.00 usft Wellhead Elevation: Ground Level: 54.00 usft Jellbore Plan: 1H-1088 Mgnetids Model Name Sample Date Declination Dip Angle Field Strength f9 (1) (nT) BGGM2018 7/15/2018 17.08 80.92 57,451 Design 1H-108Bwp04 Audit Notes: Version: Phase: PLAN Te On Depth: 1,900.00 Vertical Section: Depth From (TVD) -NAS -E/.W Direction 7 — (usft) (usft) (usft) 38.99 0.00 0.00 50.0.0 0 Survey Tool Program Date 7/3/2018 From To (usft) (usft) Survey(Wellbore) Tool Name Description 120.48 1,266.38 1H-108 Srvy 1 - SLB_GVM70 (1H-108) GYD-GCSS Gyrodata gyro single shots 1,361.99 1,750.03 1H-108 Srvy 2- SLB _MWD+GMAG(1H-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1,847.94 1,900.00 1H-108 Srvy 3-SLB_MWD+GMAG(1 H-1 MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC 1,900.00 2,050.001H-1088 wp04(Plan: i H-1088) MWD-INC_ONLY MWD-INC_ONLY_FILLER 2,050.00 3,550.00 11-1-108B wp04(Plan: 1 H-1088) MWD MWD - Standard 2,050.00 8,560.00 1H -108B wp04(Plan: 1 H-1 08B) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6,560.00 10,060.00 1H-1088 wp04(Plan: 1 H-1088) MWD MWD -Standard 8,560.00 13,032.54 1H -108B wp04(Plan: 1 H-1088) MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC 7/3/2018 10.5E:31AM Page 2 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kupl Project• Kuperuk River Unit Site: Kupawk 1H Pad Well: IH -108 Wellbore: Plan: 11-1-10813 Design: 1 H-1088 wp04 ConocoPhillips Error Ellipse Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Plan Survey Tool Program Date 7/3/2018 Depth From Depth To (us@) (usft) Survey (Wellbore) Tool Name Remarks 1 120.48 1,266.38 1H-108 Srvy 1 - SLB GWD70 (1 GYD-GC-SS Gyrodata gyro single shots 2 1,361.99 1,750.031H-108 Srvy 2-SLB_MWD+GM MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3 1,847.94 1,900.001H-108 Srvy 3 -SLB MWD+GM MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4 1,900.00 2,050.001H-108BWP04(Plan:11-1-10813) MWD -INC -ONLY MWD -INC ONLY FILLER 5 2,050.00 3,550.001H-1088 WP04(Plan: 1 H-1088) MWD MWD - Standard 6 2,050.00 8,560.001H -108B WP04(Plan: 1 H-1088) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7 8,560.00 10,060.001H -108B wpO4(Plan:1H-1088) MWD MWD - Standard 8 8,560.00 13,032.541H-1088 wp04(Plan:1H-1088) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Position uncertainty and blas at survey station Well IH -108 IH -108 actual @ 92.99usil (Doyon 142) IH -108 actual @ 92.99usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Mwured lneNnaeon Ammu111 wmcm HVIlside Lateral VeN al Ma9n6ude S.I.Aw Semiminor Osptll Mtn, Error Binz Error Bias E. Blas &Bias Error error Manu01 Tad W) (p 0 (uae) (uan) (usm lusn) W) ersal tamp (..ft) (ssa) 0-111 p) 100.00 0.11 315.17 Man 0.04 0.00 0.04 0.00 0.85 0.00 0.00 0." 0.04 45.00 GttF S(1, 1) 200.00 0.15 174.72 200.00 0.14 0.00 0.14 0.00 1.15 0.00 0.00 0.14 0.14 45.00 GY6GCSS(1, 1) 300.00 0.15 174.23 300.00 0.27 0.00 e27 0.00 1.15 0.01 0.01 0.27 0.27 45.00 GY GG56(1, 1) 400.00 0.92 147.28 400.00 0.40 0.00 0.40 0.00 1.15 0.01 0.01 0.40 0.10 45.00 GY GGSS (1, 1) Mow 115 134.94 4W.W 0.54 0.00 0.54 0.00 1.15 0.02 0.02 0.51 0.51 4500 GY GC -SS (1, 1) 800.00 2.70 125.85 599,89 0.67 0.00 0.67 0.00 1.15 0.03 0.03 0.87 0.67 45.00 GYD-GOSB (1, 1) 7WAO 4,84 123.77 699.88 0.80 0.00 0.81 0.00 1.15 0.05 0.05 0.81 0.81 14.69 GYINGPM(1, 1) 800.00 7." 120.58 799.10 0." -0.01 0.95 0.00 1.15 0.07 0.07 0.95 0.95 178.92 GYOGCSS (1, 1) 900.00 10.75 122.67 897.81 1.08 4.01 1,11 0.00 1.15 0.09 0.09 1.11 1.10 130.07 GYINGCSS(1. 1) 11000.00 12,89 121.49 995.67 1.22 -0.01 1.28 0.00 1.15 0.11 0.11 110 1.26 127.08 GYD-GCSS(1. 1) 1.100.00 14.58 121.76 1,09291 1.37 4.02 t46 OAO 1.15 0.13 0.13 1.46 1.1 124.75 GYD-G"s0. 1) 1,200.00 16.W 123.34 1,189.14 1.52 Aw 1.65 0.00 1.15 0.16 0.16 1.65 1.57 123." GY GC -SS (1, 1) l'see 0 19.97 123.95 1,283.99 1.64 -0.03 1.83 0.00 1.15 0.19 0.19 1.83 1.71 123.81 MWDHFR-AK-0PZ-SC 0. 2) 100.00 22.90 123.35 1,377.08 1.88 -0.04 1.92 0.00 1.13 0.22 012 1.02 1.77 124.08 MWONFR-M+ -SC (1. 21 1,80000 25.29 123.22 11468.30 1.67 -0.05 1.97 0.00 1.12 an 016 1.97 1.80 125.16 ~+IFR -AK- -SC (1, 2) 1,80eA0 25.71 122.67 1.558." 1.69 4.05 2.06 0.00 1.13 0.28 0.29 2.06 1.82 125.87 MW IFR -MK -SC (1.2) 1,70100 MAS 123.39 1.618.42 1.72 -ow 2.16 0.00 1.14 0+32 0.33 2.16 1.85 128.09 MWSHIFR-AK-C-SC(1.2) 118110.00 28.53 122.33 1,737.36 1.73 4.07 229 ow 1.14 013 137 229 1.98 12629 MW IFR-AK-CAZ4C(1. 3) 1,834.0 29.50 121.3 1,767.10 1.72 -0.8 2.35 0.00 1.13 0.37 0.39 2.35 1.90 12141 MW IFR -AK- -SC (1. 3) 1,900.00 31.20 122.18 1,824.04 1.75 -0.09 2.84 0.00 1.13 0.39 0.41 281 1." 124.n MW INCLONLY(1, 4) 2,000.00 34.99 124.58 1.97.80 1." -0.12 3.03 0.00 1.11 0.43 046 3.83 1.93 124.86 MVr0.1NC_ONLY(1, 4) 7131201810:56.31AM Page 3 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kupt Project: Kuparuk River Unit Site: Kupamk 1H Pad Well: 1 H-108 Wellbore: Plan: 1H -108B Design: iH-108Bwp04 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well 11-1-108 I H-108 actual @ 92.99usft (Doyon 142) 1 H-108 actual @ 92.99usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 M aiiraE Inclination AtlmuM Wwol Hi,hade mewl Ponical Magnitude Semimalor Semiminor Mani W,i h Error Bias E. Blas Error Bias of Bias Error Error Azimuth Tod (um) I'1 1°I (usR) (ues) (usft) (usn) (usft) (ueh) (use) lasso fuss) (usM) (°) 2,100.00 38.01 126.53 1.98],]8 1.65 -0.15 557 0.10 1.0 0.47 0.51 5.57 1.90 12A67 am (1, 5) 2,200.00 42M 120.20 2,063.52 1.64 4.18 5.89 0.32 1.07 0.50 0.64 5.90 2.02 12687 MWD(1. 5) 2.300.00 45.53 129.64 2,134.72 1.0 4.21 6.43 0.58 1.10 0.54 0.83 8.45 2.0 125.40 am (1, 5) 2,400.0 50.41 130.91 2,201.01 1.76 -013 7.19 0.87 1.17 0.57 1.08 711 2.17 126.15 mm (1, 5) 2,500.00 54.31 132.04 2,2132.07 1.88 -037 8.13 1.19 1.29 0.60 1.38 8.15 2.26 127.08 am (1. 5) 2,800.00 58.22 133.07 2,317.59 2.04 4.30 8.22 1.54 1.46 0.62 1.72 9.25 137 127.99 MWD(1, 5) 2,706AO 62.14 134.01 2,367.31 2.22 433 10.42 192 1.67 0.65 2.09 10.48 2.47 12888 sam(1. 5) 2,800.00 66.06 134.89 2,410.99 2.43 -0.37 1133 2.33 1.91 0.67 2.49 11.77 2.57 129.67 MM (1, 5) 2,900,00 69.98 135.74 2,440.41 2.66 .0.42 13.10 2.75 2.19 0.0 2,91 13.15 2.67 130.42 MM (1. 5) 3,000.00 69.83 131AS 2,482.78 2.96 -OAS 14.51 315 2,49 0.70 3.36 14.51 2.75 130.81 MMM. 5) 8100.00 6937 19.19 2,517.33 131 -0.58 15.82 3.75 2.80 0.71 3.82 15.85 282 130.91 MND (1, 5) 3,200.00 69.82 122.93 2,551.88 3.70 4.68 17.11 414 3.11 0.73 4,30 17.25 2.89 130.40 am (1, 5) 3,300.00 69.87 118.67 2,586.9 4.13 4.80 10.34 4.72 3.43 0.75 4.79 18.60 2.96 128.69 am (1, 5) 3,315.83 70.00 118.00 2,591.69 430 -0.82 18.53 4.00 3.48 075 4.87 18.91 2.97 12sS6 MNP (1, 6) 3,400.00 70.00 118.00 2,620.48 4.47 .0.82 19.81 59 3.75 on 5.28 20.16 3.03 128.84 MWD(1, 5) 3,500,00 70.00 118.00 2,654.68 4.79 -0.82 21.37 5.72 4.07 0.78 5.78 2170 3.11 128.07 am (1. 5) 31800.00 Mae 118.00 2,68888 2.78 -0.48 10.02 0.12 2.35 0,80 1.13 10.15 2.52 127.44 MWD+IFR-MK ,iZSC(2, 5) 3,700.00 70.00 118.00 2,723.08 2.94 410 10.52 0.12 2.50 0.82 1.17 10.64 2.55 127.05 MWD+IFR-MK-W(2,5) 3,800.0 70.00 118100 2,757.29 110 4.48 11.03 0.12 2.56 0.83 112 11.15 2.55 12867 MWD+IFR-AWCA2-X(2. 5) 3,900.00 70.00 118.00 2,791A9 3.26 .0.48 11.55 0.12 2.82 0,85 1.27 11.67 2.61 126.32 MWD+IFR-AK-CA2-SC(2,5) 4.000.00 70.00 118.00 2a25.69 3.42 -OA8 12.08 0.12 2.98 0.87 1.32 12.19 2.65 125.99 MWD+IFR-AK-CAZSC(2. 5) 4,100.00 70.00 118.00 2,859.89 3.58 -0.48 12.61 0.12 3.13 0.89 1.37 12.72 2.69 125.68 MND+IFR-AK-CAZ-SO(2.5) 4,200.00 70.00 118.00 2,894.09 3.75 -0.40 13.15 0.12 319 0.91 1.42 1315 2.72 125.39 1JWD+IFR-AK-CA2SCQ, 5) 4,300.00 70.00 118.0 2,928.30 3.91 -0A8 13.69 0.12 3.45 0.93 1.48 13.79 2.76 126.12 MWD+IFR-AWCA24C(2,5) 4,400.00 70.00 118.00 2,982.50 4.08 -0.48 14.24 0.12 3.61 0.95 1.53 14.34 2.80 124.87 MND+IFR-MK CA -SC (2.5) 4,500.00 70.00 118.00 2,988]0 4.25 .0.48 14.79 0.12 3.77 0.97 1.59 14.89 2.84 124.63 MWD+IFR-AK-CA (2, 5) 4,800.00 70.0 11a.00 3,030.90 4.41 -0.48 15.35 812 3.93 0.99 1.64 15.44 288 124.41 MND+1FR-AK-OAZSC (2, 5) 4,700,00 70.00 11500 3,065.10 4.68 -0.48 15.91 0.12 4.10 1.01 1.70 16.00 2.93 124.20 MWD+IFR-AK-CAZSC (2.5) 4,800.00 70.00 118.00 3,099.31 4.75 -OAS 16.0 0.12 4.26 1.03 1.76 18.58 2.97 124.00 MWD+IFR-AK-OAZS0(2.6) 4,900.00 70.00 118.00 3,133.51 4,92 -0.48 17.04 0.12 4A2 1.05 1.82 17.12 3.02 123.82 MW IFR-AK-CAZSC(2, 5) 5,000.0 70.00 118,00 3,167.71 809 AOAs 17.60 0.12 4.58 1.07 1.88 17.69 3.06 123.65 MWD+IFR-MK ii ZSC(2,5) 5,100.00 70.00 118.00 3.201.91 5.28 -OAS 18.17 0.12 4.74 1.09 1s,1 18.25 3.11 123.49 KIM. it -MK iiZSC(2,5) 5200.06 70.00 118.00 3,23511 5.43 -0.48 18.74 0.12 4.90 1.12 2.01 18.82 3.15 123.33 MM+IFR-AR-06(2,5) 5,300.00 70.00 118.00 3,270.32 5.60 .0.48 19.32 0.12 5.06 1.14 2.07 1999 3.20 123.19 14"+IFR-M& -SC (2,51 5,315.83 70.00 118.00 3,95.73 6.83 -0.18 19.41 0.12 5,09 1.14 2.08 19.48 3.21 123.17 MMAFR-AK-0AZ-80 (2.5) 5,400.00 73.12 119.33 3,302.35 5.70 -0.59 19.92 0.08 5.23 tib 2.13 19.88 3.25 123.07 MWD+IFR-AK-C0ZSC(2.5) 5.500.00 76.84 120.80 3,328.9 5.78 -0.72 20.49 0.03 5.39 1.18 219 20.60 3.29 122.0 MWD+IFR-AK-CAZ-SC(2.5) 51582.90 79.93 19.119 3,344.96 5185 -0.84 20.95 -0.01 5.53 1.19 2.24 20.95 3.33 122.96 MWD+IFR-AK-CA2SC(25) 5,600.00 79.83 12209 3,30.95 588 -0.84 21.04 -0.01 595 1.19 2.25 21.01 3,33 19.96 MND+IFR-AK-CAZSCi(2,5) 6,700.00 79.93 19.09 3,365,44 6.05 4.84 21.59 4.01 5.73 1.20 290 21.60 3.36 122.94 MM+IFR-AWCA (2, 5) 5,600.00 79.93 19.09 3,382.93 6.22 -0.84 22.15 4).01 5.90 1.21 2.35 22.15 3.39 122.92 MND+IFR-MX -SC (2. 5) 5,900.00 79.93 12209 3,400.42 6.40 -0.84 9.71 -0.01 6.07 1.9 2.41 2271 3.42 19,90 MNWIFR-AK-CAZSC(2, 5) 6,000.0 79.93 122.09 3,417.82 6.57 -0.64 M.M 4.01 6.24 1.21 246 23.27 3,45 19.89 MM+IFR-AKLAZSC (2, 5) 8,100.00 79.93 122,09 3,43841 6.75 4.84 23.82 -0.01 6.42 114 2.52 23.83 3.48 19.87 04WD+IFR-AK-CAZSC(2.5) 6100.00 79.93 12209 3,452.90 6.83 -0.84 24.38 -ooi 6.59 1.25 2.57 24.39 3.51 19.86 51WD+IFR.AK-CAZ-SC(2, 5) 6,300,00 79.93 122.09 3,00.39 7.10 -084 24.95 4.01 6.76 1.26 2.63 24.0 3.54 122.84 MV IFR-AK-CAZSC(25) 8,400.00 79.93 122.09 3,487.88 Z9 -0.84 25.51 4.01 6.93 1.27 269 25.51 3.57 122.03 MWD+IFR-AK-CAZSCa 5) 6,500.00 79.93 122.09 3,505.37 7.45 -0.84 26.08 Aoi 7.11 1.28 2.74 26.09 3.60 122.82 MW IFR-AK-CAZSC(2,5) 6,500.0 79.93 122.09 3,59.86 7.62 40.84 28.84 -0.01 7.28 1.29 2.80 26.64 1.63 12181 M1IYD+IFR-AKLAZSC(2.5) 6,700.00 79.93 122.09 3,540.35 7.60 4.84 9.21 A.Ot 7.45 1.30 2.86 9.21 3.66 122.80 MVrLI+IFR-MHA -SC (2. 5) Sewoo 79.93 122.011 3.557.84 7.97 -0,84 9.78 4.01 7.0 1.31 2.92 27.75 3.69 122.79 MWD+IFR.MK ,,Z -SG (2, S) 61900.00 79.93 122.09 3,575.34 8.15 -0.84 M.14 4.01 7.80 1.32 2.98 28.35 3,72 122.78 MWD+IFR-A3( -06(2,5) 7,000.00 79.93 122.09 3.592.83 8.32 -0.84 28.91 4.01 7.97 193 1104 28.92 3.75 19.77 MWDNFR-AR-CAZ-SC(2.5) 71100100 79.93 12109 3.810.32 550 -0.84 29.48 4.01 8.15 1.35 3.10 29A9 3.78 122]6 MWD+IFR-AK4AZSC(2, 5) 7MO18 10:56'31AM Page 4 COMPASS 5000.14 Build 85 Company. ConocoPhillips (Alaska) Inc. -Kupl Project Kupawk River Unit Site: Kupawk 1H Pad Well: iH-108 Wellbore: Plan: 1H-1088 Design: 1 H-1088 wp04 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well 11-1-108 iH-108 actual @ 92.99usft (Doyon 142) 1 H-108 actual @ 92.99usft (Doyon 142) Two Minimum Curvature 1.00 sigma OAKEDMP2 Position uncertainty and bias at survey station Measured Inclination Aa1muM Wr6cal HI9Mi6e Lateral venlcal Magnitude Beinmalor SeMminw OepN cape E. BMs Error Bus Enor Blas WBMs Ermr Erts iasnif Taal (Yan) (') cl (Yea) (Yam) (.an) (.lift) (-aft) (.01) (.Sa) (-aft) (usn) (.aft) V) 7,200.00 79.93 122.09 3,627.81 8.68 -0.84 30.05 -0.01 B.32 1.36 3.16 30.06 3.81 12.75 MW IFR-AK-CAZ-WW2, 5) 7.01.17 79.93 122.09 3,812.01 8.62 -0.64 30.52 -0.01 8.416 1.37 3.21 30.52 3.84 122.74 MW IFR-AK-CAZSC(2, 5) 7.3(10.00 7BW 121.33 3,84529 8.86 -0.84 30.81 0.03 8.49 1.37 3.23 30.62 seal 122.74 M4 IFR-M(-CAZSC(2, 5) 7.400.00 8018 117.28 3.652.418 9.08 -0.86 31.01 024 8.67 1.38 3.29 31.15 3.07 122.69 MWDcIFR-Al(-CAZSC(2. 5) 7,500.00 W.60 113.24 3,679.09 9.30 -0.88 31.26 OA5 8.04 1.39 3.35 31.67 3.93 12257 MW IFR-AK-CAZ4C(2, 5) 7,800.00 BOW 109.211 3,895.11 9.52 4.91 31.38 0.66 9.01 1.40 3.41 32.19 10 122.39 MWDNFR-AK-CAZSC(2, 5) 7,700.00 81.40 105.18 3,710.43 9.74 -0.94 31.33 0.87 9.19 1.41 3.0 32.70 3.96 122.15 MW IFR -AK -C 2-50(2.5) 7,000.00 8187 101.16 3.724.99 9.95 4.97 31.09 1.0 sw 1.42 3.53 3320 3.99 121.86 MW IFR -MC -A2 -SC (2r 5) 71900.00 8237 97.16 3.7U.70 10.15 -1.01 30.73 180 9.53 1.43 3.59 33.68 4.02 121.52 UMcIFR-AK-CA2-SC(2,5) 8,00080 82.92 0.16 3,751,51 10.34 -1.06 30.21 1.51 9.71 1.44 3.64 34.14 4.08 421.13 MW IFR-AK-CA2-SC(2, 5) 8,100.00 83.49 89.18 3.763.35 10.51 -1.10 29.55 1.72 9.09 1.44 3.69 34.50 4.10 120.71 MW IFR-AK-CAZSC(2. 5) 8.200.00 84.10 85.20 3,774.16 10.66 -1A5 28.74 1.92 10.06 1.45 3.74 UAW 4.15 120.25 MWD IMAK-CAZSC(2,5) 8,330,00 841.73 8113 3,783.89 10,79 .1.19 n.79 2,11 10.23 1.416 3.79 35.37 4.21 lien 1AWDHFR-ARCAZSC(2, 5) 8,323.20 041.89 80.31 3,785.99 10.02 -020 27.55 2.16 1027 1.46 3.00 35.416 4.23 119.66 MM.IFR-AK-CAZSC (2, 5) 8400.00 84.89 80.31 3,792.84 10.0 -1.20 27.93 2.18 10,41 1.4 3.84 35.75 41.28 119.28 MM11FR-AK-CA C(2,5) 8,500.00 04.89 80.31 3801.75 11.13 -120 28.44 2.16 1088 1.47 3.09 36.14 4.35 118.75 MMcIM-AK13AZ-SC(2, 5) 8,55837 84.89 80.31 3,806.99 11.23 -1.20 28.74 2.16 10.69 1.47 3.91 38.38 4.40 118.45 MWV-IFR-AK-0AZSC(2,5) 8,578.77 64.89 80,31 3,808.77 11.25 -1.20 28.86 2.21 10.69 1.47 3.95 88.51 4.37 118.41 MM (2.6) Baccoo 85.36 80.55 3,810.58 11.18 -1.23 29.10 2.33 10.69 1.47 482 88.62 499 11026 MM (2,6) 8,700.00 8759 81.68 3,016.73 Met -1.35 30.26 2.76 10.70 1.47 4.37 37.19 4.62 117.54 ra"(2, 6) 8756A7 88.05 8282 3,818,48 10,82 -1.41 30.05 3,02 10.72 1A8 4.56 37.53 4.81 117,11 MM (2.6) 8.800.00 88.85 82.32 3,019.35 M83 -4.41 31.31 325 10.73 140 4.75 37.81 4.98 116.77 MM (2.6) 8.900.0 8885 82.32 3.821.36 10.08 -1.41 32.18 3.77 1076 1.48 5.15 3848 5.413 115.95 MWD(2, 6) 9800.40 88.85 82.32 1823,36 10.91 -1.41 33.12 429 10.61 1.48 5.68 39.19 5.93 115.00 1AWD(2,6) 9,100.00 89.85 82.32 3,825.37 10.97 -1.41 341.11 4.82 40.87 1.48 6.02 39.95 6.416 114.17 MM (2, 6) 9,2WA0 8885 82.32 3,827.37 11.041 -1.41 35.15 5,34 10,94 148 6.47 4076 7.01 113.24 MWM(2,6) 9,300.00 08.85 0232 3,829.37 11.12 -1,41 3825 886 11.02 1.48 6.94 41.61 7.88 112.28 MWD (2, 6) 9,320.88 88.85 82.32 3,629]9 11.14 AA1 WAS 897 11.04 148 7.03 41.80 7.0 11200 MWD(2,6) 9,400.00 Ssw 79,94 3,831.41 11X1 -1,42 36.52 6,52 11.12 1A8 7,41 42.49 SAO 111.32 MWD(2.6) 9,500.00 88.75 7894 3,833.55 11.33 -1.42 36.53 7.18 1112 1.48 7.88 43.37 8.09 110.31 MWD(2,6) 9661.77 88.71 76.00 3.834.99 11,41 6.42 36.51 7,80 11.30 148 8.19 4384 9.03 109.64 MWD (2,6) 9wom 88.72 73.94 3,835.78 11.46 -1.43 36.50 7.01 1134 1.48 8.35 44.25 9.23 109.26 MWD(96) 9700.00 8835 70.94 3,837.99 11.58 4.44 WA3 8.11 11.47 1.49 8.81 45.13 9.0 108.16 MM (2,6) 9,751.63 88.76 89.39 3,839.11 11.65 4.44 38.38 8.70 11.54 1.49 9,05 45.59 10.15 107.57 MM (2.6) 9,800.00 88.76 69.39 3,841015 11.72 41.44 37.00 0.93 11.61 1.49 9.27 46.2 1OA5 107.02 MWD(26) 91900.00 W.76 69.39 3.842.31 11.88 4M 36.32 9.38 11.75 1,49 9.M 48.0 11.05 105.87 MM(16) 101000.00 0936 6999 3,044.47 12.02 4M 39.65 9.84 11.91 1.49 10.17 47.90 11.65 104.73 1AWD(2.6) 10,100.00 8836 69.39 3,846.62 11.16 -1.42 28.24 2.78 11.04 1.49 4.54 3929 Bw 114.31 MMAFR-AK-CA (3.6) 10,200,00 88.78 69.39 3.848,78 14.20 4A2 28.58 238 11.09 1.49 4.57 39,49 7.07 113.94 IJWDe1FR-AK-CAZ-W(3,6) 10,300.00 09.78 69.39 3,850.94 11.25 .1.42 28.93 2.70 11.13 1.49 4.61 39.70 7.34 113.57 MMAFR-AK-CAZ-SC (3, 6) 101364.12 88.76 Mae 3,852.32 1128 4.42 29.16 2.78 11.17 1.49 4.64 39,84 7.52 113.32 MWDHFR-AK-CAZ-M(3,6) 10,409.00 MA7 6862 3,653.12 11.31 4.42 28.79 2.0 11.19 1.49 4.65 39.91 7.61 113.19 MW0NFR-A CAZ-SC (3.6) 14500.00 W.10 65,33 3,055.68 11.39 -1.10 27.71 3.0 11.24 1.09 4.69 40.11 7.09 112.82 MW IFR -AK -CQ -SC (3. 6) 10,577.97 09.20 6100 3,857.99 11.46 -1,40 26.84 3.15 11.28 1.50 672 1025 am 112.53 MW IFR-AK-CAZ-SC(3,6) 10,600.00 88.11 62.341 3,858.70 11.49 -1.39 26.59 3.19 11.30 1,50 4.73 40.30 8.12 11244 MW IFR-AK-CAZSC(3, 6) 10,700.00 87.71 $9.37 3,862.35 11.60 -1.38 25.43 3.5 11.26 1,50 4.M 40.48 699 11205 MMMFR-AK-CAZSC(3,6) 10,709.29 87.67 59.09 3,832.73 11.61 -1.37 25,32 3.34 11.26 1.W 4.77 40.49 841 112.01 MWDNFR-AK- SC It. 6) 10,000.00 87.67 59.08 3,868.42 11.67 -1.37 25.67 3.38 11.42 1.50 4.09 40.66 6.68 111.63 MM.IFR-AK-CAZSC(3, 6) 10,900.00 87.67 59.09 3,870.48 11.73 -1.09 26,06 3.36 11.48 1.50 4.64 40.64 8.98 111.21 MWDsIFR-AK-CAZSC(3, 6) 11,000.0 87.67 Sew 3,874.55 11.80 -1.37 26.0 3.36 11.55 1.51 4.88 41.0 9.29 110.77 MM+IFR-AK-CA -$C (3. 6) 11,088.90 87.67 59109 3.876,13 11.82 -1.37 2863 3.38 1157 1.51 4.89 41.11 9.41 110.60 MWDHFR-AA-CAZSC(3,61 11,100.00 87.95 5728 3,87BA7 11.0 -1.39 25.94 3.46 11.62 1.51 4.92 41.22 9.59 110.34 MWD.1FR-AK-CAZSC(3.6) 11,176.89 Bsw 55.00 18W.99 11.84 -1.42 25.05 3.59 11.67 1.51 4.94 41.38 9.82 110.00 MW0+1FR-AK-CAZ-SC(3,6) 11,200.00 88.44 54.32 3,881.65 11.84 -1.43 24.78 352 11.69 1.51 4.95 41AO 9.00 109.90 MWD4IFR-AK-CAZSC(3,6) 7/3@01810:56:31AM Page 5 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kupi Project Kupamk River Unit Site: Kupamk I Pad Well: 11-1-108 Wellbore: Plan: 1H -108B Design: 1 H-1089 wp04 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well 1 H-108 1 H-108 actual @ 92.99usb (Doyon 142) 1 H-108 actual @2 92.99usR (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 M...d mdmNion A...h Vs -6.1 Ki9hsiee ",..I wilk.1 Ma9naua 3emlmaiar samlmmor DapN Deieh E., Bias Error Bias E. Bias at Blas Error Error A¢lmuth Tod (Ym) (1 (') rase) (.n) (usft) (uaft) (user (ian) Imft) (..ft) (usn) (usftl P) 11,300.00 89.06 51.39 3.883.82 11.84 4.46 2362 3.77 11.76 1.51 498 41.67 10.19 109.46 MWDHFR-AK-O C(3,6) 11,301.24 89.07 51.35 3,883.54 11.84 -1.46 23.61 3.78 11.76 1.51 4.98 41.57 10.19 109,45 MM-IFR-AK-CAZ-WdiA 8) 11A0.O 89,07 51.35 3,885,44 11.92 -1.46 24.03 3.78 11,64 1.51 5.01 41.74 10.50 109.00 04WD+11`WAK-CAZ-W(3,6) 11,500,0 89.07 5tm 3.007.08 12.00 -146 24.47 3.78 11.91 1.51 5,5 41.91 low 108.53 MWD+IFR-AK--5C(3,6) 11,600,0 89.07 $1.36 3,606.68 12.08 -1.46 24.91 3.78 11.99 1.51 5.08 42.09 11.14 108.0 MWD+IFR-M-CQS0 p. 6) 11]0.0 89,07 5185 3,89030 12.16 -1.46 2$.38 3.70 12.08 1.51 5.11 42.27 11.47 107.58 NWD+IFR-AK-C0Z-SC(3, 8) 11,731.15 89.07 61.35 3,890.01 12.18 -1A6 25.50 3.78 12.10 1.51 5.12 42.33 11.57 107.43 MWD+IFR-AKCQ-X(3,6) 11,80,0 68.84 4830 3,892.0 IZ27 -1AS 24.71 3.89 12.16 1.52 5.14 42.45 11]7 107.11 MWD+IFR-M(-CQ-SCp,6) 11,843.47 88.70 48.0 3,692.99 12.32 -1,45 24.20 3,0 12,20 1.52 5.16 42.52 11.88 106.0 MM+IM-AK4:AZSC(3, 6) 11,90.0 68.34 46.34 3,894.45 12.41 -1.43 23.54 4.04 12.25 1.52 5.17 42.61 12.03 10,0 MWDHFR-AK-CAZSC (3,6) 12,00.00 07.70 43.41 3,897.91 12.59 -1A1 22.39 4.18 1233 1.52 5.21 42.75 12.29 106.2214WD+IFR-AK-CAZ-W(3,6) 12,10.00 87.07 40.47 3,902.47 1277 -1.39 21.25 4.31 12.12 1.52 5.24 42.00 12.56 105.77 MWD+IFR-AKCAZ-W(3,6) 12,113.75 Sam 40.07 3,903.18 12.80 -1.39 21.09 4.33 12.44 1,52 5.24 42.90 12.60 105.71 MWD -IFR -A 4- 5C(3,6) 12,153.19 86.99 40.07 3.905.25 12,84 -1.39 21.26 4.33 12.7 1.52 5.25 42.0 12.71 105.52 MWTI+IFR-AK-CAZSC(3, 8) 12,20.00 MA4 39.73 3.9OA6 13.24 410 21.26 4.35 12.52 1.53 5.27 4101 12.81 10.33 04%,10+1FR-AK-CAZSC(3,6) 12,30.0 0121 39.01 3,92084 14.41 -1.12 21.16 4.38 1261 153 5.30 43.11 12.93 104.90 MW0+IFR-AK-CAZ-SC(3,6) 12,356,15 79.0 3880 3.929.99 15.21 -1.02 21.11 4.40 12,66 1.54 5.33 43.17 13.01 104.78 MM+IFR-Ar(-Cil-Wp,6) 12,40.00 0.25 30.59 3,939.02 15.90 4.93 21.9 4.40 12.70 1,55 5.35 43.21 13.0 M4.83 MWD+IFR-AK Q4iCp,6) 12,500.0 73.25 38.58 3,964.48 17.62 4.73 21.50 4,40 12.60 1.57 5.40 43.31 13.19 Hale MWD+IFR-AKC 4C(3,6) 12,800.0 69.25 38.57 3,90.62 19.47 4.51 21.7 4.40 12.89 1.61 5.46 43AI 1383 103.95 MMAFR-AWCAZSC(3, 6) 12+70.0 6525 38.55 4,03529 21.38 -0.28 am 4.40 12.98 1.0 5.53 43.51 13.49 10161 MWD+IFR-AK-CAZ.S0(3, 6) 12,800,00 81.25 38,54 4,000.30 23.32 -0.04 22.33 4.40 110 1.71 5.61 43.61 13.64 10327 MWD+IFR-AK-CAZ-X(3, 6) 12,898.19 57.32 38.52 4,13045 2530 0.20 22.60 4.40 13.14 1.78 5.89 43.71 13.80 102.95 MWD+IFR-AK-CQSC(3, 6) 12,900.0 57.32 38.52 4,131.42 25.20 0.20 22.61 4A0 13.15 1.78 5.0 43.71 13.81 102.94 MWD+IFR-AK-CAZ-SC(3,6) 1100.0 57.32 38.52 4,185.42 2524 0.20 am 4.40 13.22 1.0 5.79 43.83 13,99 10256 MWD+IFR-AK-CQ-SC(3,6) 13.03154 57.32 38.52 4,202.99 259 030 9,04 4.40 13.25 1.89 SB2 43.87 14.04 102.44 MW IFR -MCA (3,6) 7/3!1018 10:56:3IAM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips Error Ellipse Report Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Coordinate Reference: Well 1 H-108 Project: Kupamk River Unit TVD Reference: 1 H-108 actual @ 92.99usft (Doyon 142) Site: Kupamk 1 H Pad MD Reference: 1H-1 D8 actual @ 92.99usft (Doyon 142) Well: 11-1-108 North Reference: True Wellbore: Plan: 1H-1088 Survey Calculation Method: Minimum Curvature Design: 1FF-1088 WP04 Output errors are at 1.00 sigma 0.00 0.00 Database: DAKEDMP2 Design Targets Measured Target Name Casing Hofe Depth Depth -hit/miss target Dip Angle Dip Dir. TVD aNFB +E/ -W -Shape M 0 (usft) (w1t) (usft) iH-108B Tot 063018 RI 0.00 0.00 3,785.99 -3,040.86 5,508.08 - plan hits target center 13,032.54 4,202.69 41/2"x6-314" 4-112 6-3/4 - Circle (radius 100.00) IH -1086702063018 RI 0.00 0.00 3,806.99 -3,001.37 5,739.37 - plan hits target center - Circle (radius 100.00) 1H -108B 703063018 RI 0.00 0.00 3,834.99 -2,847.87 6,732.50 - plan hits target center - Circle (radius 100.00) iH-108B T04 063018 Rf 0.00 0.00 3,857.99 -2,489.05 7,678.97 - plan hits target center - Circle (radius 100.00) 1H-1088 705063018 RI 0.00 0.00 3,880.99 -2,181.38 8,192.05 - plan hits target center - Circle (radius 100.00) 1 H -108B T06 063018 RI 0.00 0.00 3,892.99 -1,765.75 8,712.84 - plan hits target center - Circle (radius 100.00) 1H -108B 707063018 RI 0.00 0.00 3,929.99 -1,385.94 9,053.37 - plan hits target center - Circle (radius 100.00) iH-1086 T08063018 Rf 0.00 0.00 4,202.99 -906.39 9,435.57 - plan hits target center - Circle (radius 100.00) Casing Pointe Measured Vertical Casing Hofe Depth Depth Diameter Diameter (waft) lust) Name Cl 1"1 1,834.00 1,767.10 10 3/4" x 13 1/2" 10-3/4 13-1/2 8,558.77 3,806.69 7 5/8" x 9 718" 7-5/8 9-7/8 13,032.54 4,202.69 41/2"x6-314" 4-112 6-3/4 7/3/2018 10:56:31AM Page 7 COMPASS 500014 Build 85 company: ConocoPhillips (Alaska) Inc. -Kup1 Project Kuparuk River Unit Site: Kuparuk 1 H Ped Well: 1H-108 Wellbore: Plan: iH-108B Design: 11-1-108B wp04 ConocoPhillips Error Ellipse Report Local Coordinate Reference: TVD Reference: MD Reference: Norm Reference: Survey Calculation Method: Output errors are at Database: Well 11-1-108 1 H-108 actual @ 92.99usft (Doyon 142) 1 H-108 actual Q 92.99usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Formations Vertical Local Coordinates Measured Vertical +N14 Dip Depth Depth (usft) Dip Direction (usft) (usft) Name Litholon 1,876.67 1,803.99 T-3 2,900.00 2,166.04 2,037.99 K-15 Adjust TF to 43°, for 415.83' 4,495.88 2,994.99 UG_C 1,219.12 5,247.29 3,251.99 UG_B -1,829.47 5,624.81 3,351.99 UG_A 3,344.96 6,236.55 3,458.99 Na 7,281.17 7,237.06 3,633.99 WS_D Start 4.1100' DLS, -86.37° TF, for 1042.03' 7,532.01 3,683.99 WS_C 5,508.08 7,679.10 3,706.99 WS_B -3,001.37 7,942.76 3,743.99 WS—A4 3,808.77 8,382.66 3,790.99 WS—A3 8,756.47 10,969.00 3,872.99 WSf2 Hold for 564.42' 12,557.92 3,981.99 WS_Ai 6,493.59 12,781.05 4,070.99 WS—BASE -2,847.87 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N14 +E/4M (usft) (usft) (usft) (usft) Comment 1,900.00 1,824.04 -219.45 337.33 KOP: 4°/100' DLS, 20° TF, for 1000' 2,900.00 2,448.41 -713.95 908.01 Adjust TF to 43°, for 415.83' 3,315.83 2,591.69 -947.15 1,219.12 Hold for 2000' 5,315.83 3,275.73 -1,829.47 2,878.52 Start 4.1100' DLS, 22.28° TF, for 267.07' 5,582.90 3,344.96 -1,958.61 3,101.34 Hold for 1698.27' 7,281.17 3,642.01 -2,847.01 4,517.90 Start 4.1100' DLS, -86.37° TF, for 1042.03' 8,323.20 3,785.99 -3,040.86 5,508.08 Hold for 235.57' 8,558.77 3,806.99 -3,001.37 5,739.37 Adjust TF to 0", for 20' 8,578.77 3,808.77 -2,998.02 5,759.01 Start 2.5°1100' DLS, 26.85° TF, for 177.69' 8,756.47 3,818.48 -2,971.24 5,934.36 Hold for 564.42' 9,320.88 3,829.79 -2,895.79 6,493.59 Start 3°/100' DLS, -91.18° TF, for 243.88' 9,564.77 3,834.99 -2,847.87 6,732.50 Adjust TF to -89.51', for 186.86' 9,751.63 3,839.11 -2,790.78 6,910.30 Hold for 612.49' 10,364.12 3,852.32 -2,575.28 7,483.47 Start 3°/100' DLS, -95.12° TF, for 213.85' 10,577.97 3,857.99 -2,489.05 7,678.97 Adjust TF to -97.82°, for 131.32' 10,709.29 3,862.73 -2,425.53 7,793.77 Hold for 329.61' 11,038.90 3,876.13 -2,256.38 8,076.35 Start 3°/100' DLS, -81.3° TF, for 138' 11,176.69 3,880.99 -2,181.38 8,192.05 Adjust TF to -78.1', for 124.35' 11,301.24 3,883.84 -2,106.88 8,291.54 Hold for 429.91' 11,731.15 3,890.81 -1,838.40 8,627.24 Start 3°/100' DLS, -96.37° TF, for 112.31' 11,843.47 3,892.99 -1,765.75 8,712.84 Adjust TF to -102.33°, for 270.28' 12,113.75 3,903.18 -1,571.75 8,900.42 Hold for 39.44' 12,153.19 3,905.25 -1,541.60 8,925.78 Start 4°/100'DLS,-169.749 TF, for 202.96' 12,356.15 3,929.99 -1,385.94 9,053.37 Adjust TF to -179.82°, for 542.05' 12,898.19 4,130.45 -994.86 9,365.14 Hold for 134.35' 13,032.54 4,202.99 -906.39 9,435.57 TD: 13032.54' MD, 4202.99' TVD Checked By: Approved By: Date: 7/3/2018 10..56:31AM Page 8 COMPASS 5000.14 Build 85 11:02, JWY 03 2013 1H-10813 wp04 Quarter Mile View 14 1H -11L2 ;,�.1:W40Q 102L2 --. 1 H--/01�3� - 11 f -T01 H ski 05i 1 139 -B 1H-iO3 4500 1H-1 101L4 38 1H-104wp26 0 9 _ 36 1H-102 1H-104L1wp24- - 8 H -102L1 3000 41 6 8 ,IH-104L2wp24 3 1s 1 07AP 7 ¢`. 0IH- 4 1H-105 1-115wp22 1H- ld 8 40 1 H-07 P _ 7 7 1 H- 6 � p9 —1 H-40 g -_. a,-'.O"o1 0H-12 �1 H-113 3 1 H-1py< 0 o' 0 7- rn ,cz"-to-''°b 1 H-110 _ +3kH- 1 30 1H-111 1H-1086 wp04 C 38 38 1 1H-1 0 0 �' °j M 1H-13 u 4 1/2" x 6-3/4" 15018 - O � o - M� 9 o1H-15 - M 1H -168A -3000 1H-22 — - CC tC-150 5/8" x 9 7/8 7 1C-170 1B -10210-178L1 1H-01 1H-18 IH -11 i H-09 -4500 0 1500 3000 4500 6000 7500 9000 10500 12000 13500 West( -)/East(+) (1500 usfUin) 11:09. MY 03 2018 1H-10813 wp04 Quarter Mile View 4500 -- 1H-104wp26 1H-104L1wp24 1 H-104L2wp24 3000 -_ - -- — -- - 1500-- 500 -0 0- + -__ -..-_ _. 1H-110 .. - r z 1H-108 t w po OQ s� 1H-1986 wp04 o 1500 10 3/4" x 13 1/2" g�2 , rn i m Lo 19 4 1/2" x 6-3/4" M M M v 1H -108A -3000 - MD Mr w co 7 5/8" x 9 7/8" -4500- 0 1500 3000 4500 6000 7500 9000 10500 12000 13500 West( -)/East(+) (1500 usft/in) IH -10 4L2 -p24] 6 WDU4 I 3_n IIH-108Bwp04 Surface Location ,a CPAI Coordinate Converter Datum: NAD837 Region: alaska C Latitude/Longitude IDecimalDegrees f UTM Zone: I — F South f• State Plane Zone:q Units: us.g r Legal Description (NAD27 only) -IMIJI Datum: INAD27 Region: alaska r Latitude/Longitude IDecimal Degrees fi UTM Zone: True r South r State Plane Zone: I' ---�-:] Units: F7771 r Legal Description (NAD27 only) Starting Coordinates: Ending Coordinates: X: 11689602.6 X: 1549570.976245029 Y: 15980504.33 Y: 15980752.52152466 r..............._...................._.............._.., .Transform j Quit I Help I1H-108Bwp04 Surface Location Datum: NAD83 Region: [-a-la,-k;---- r Latitude/Longitude IDecimal Degrees C UTM Zone:F— — r South r State Plane Zone: F-3- Units: us -f C Legal Description (NA.D27 only) Starting Coordinates: X: 11689602.6 Y: 5960504.33 - 1012<j FTo: Datum: NAD27 w Region: alaska r Latitude/Longitude IDecimalDevees, T UTM Zone: True r South C State Plane Zone: q . Units: us -ft w t% Legal Description (NAD27 only) - �egei Township: 012 N Range: 010 Meridian: U Section:28 FNL + 5230.4878 FEL - 770.33475 Transform ; quit Help 1H-108Bwp04 Surface Casing ,a CPAI Coordinate Converter Datum:NAD83 Region: alaska C Latitude/Longitude IDecimalDegrees C UTM Zone: r— F South C•' State Plane Zone: Iq�—] Units: us -it E !- Legal Description (NAD27 only) Starting Coordinates: X: 11689912.79 Y: 15980304.39 - 1131J Datum: NAD27 Region: alaska r Latitude/Longitude IDecimal Degrees —� r UTM Zone True r South G State Plane Zone: r4 ----,l Units: us -ft r Legal Description (NAD27 only) Ending Coordinates: X 549881.160223707 Y: 5980552.56037005 (..._..._..__TransForm _, ( Quit I Help 1: p1 Surface Casing ■. CPAI Coo nate Converter Datum: NAD83 v Region: alaska f^ Latitude/Longitude IDecimalDegrees, C UTM Zone:I _ r South F State Plane Zone: F-----] Units: us -ft t- Legal Description (NAD27 only) Starting Coordinates: X: 11689312.79 Y: 15900304.39 Datum: NAD27 Region: alaska r Latitude/Longitude Decimal Degrees r UTM Zone: True r South [" State Plane Zone:q El Units: us -(t f• Legal Description (NAD27 only) Township: 012 I" J Range: 010 Meridian: U Section:33 FNL 152.51391 FEL 1461.89888 Quit Help •;. CPAI Coordinate Converter Datum: NAD83 _ Region: alaska Zj C Latitude/Longitude IDecimalDegtees C UTM Zone: I — r South r- State Plane Zone: F7-:1 Units: Fus-173- r Legal Description (NAD27 only) Datum: NAD27 Region: alaska r Latitude/Longitude IDecimalDegrees r UTM Zone: True r South r State Plane Zone: q Units: usft r Legal Description (NAD27 only) =L! XI Starting Coordinates: Ending Coordinates: X: 1168994133 X: 549909.699676337 Y 5980287.12 Y: 5980535.31023751 C_777.7. ..._.._.___..ransform__....._...._. t Help T 1H-108Bwp04 Kick-off Point ■_ CPAI Coordinate Converter Datum: NAD83 - Region: lalaska r Latitude/Longitude Decimal Degrees f UTM Zone: 1 - r South * State Plane Zone: F -7-H] Units: us -ft r Legal Description (NAD27 only) Datum:NAD27 Region: alaska C Latitude/Longitude IDecimalDegrees r UTM Zone: True r South F State Plane Zone: F-3- Units us -ft r Legal Description (NAD27 only) Starting Coordinates: Ending Coordinates: X: 11689941.33 X: 1549909.699676337 Y 5980287.12 Y: 5980535.31023751 Transform ... ...... _..._.._................................_....� Quit I Help 1 H-108Bwp04 Top of Production Datum:NAD83 Region: alaska + C Latitude/Longitude IDecimal Degrees + C UTM Zone: F—r South * State Plane Zone:q Units: us -ft + C Legal Description (NAD27 only) Starting Coordinates: X: 11695130 Y: 15977500 Datum: NAD27 Region: alaska + r Latitude/Longitude IDecimalDegrees + * UTM Zone: True r South F State Plane Zone: F --H] Units: FUS ft + r Legal Description (NAD27 only) -Ending Coordinates: X: 555098.270711043 Y: 15977740.15835257 I TransformQuit Help 1 H-108Bwp04 Top of Production Datum: NAD83 Region: alaska + • Latitude/Longitude IDecimaiDegrees + • UTM Zone: r South r State Plane Zone:q + Units: us -ft + C Legal Description ITJP.D27 rrd,J Starting Coordinates: X: 11695130 Y: 15977500 JoJ X1 Datum: NAD27 Region:alaska + (' Latitude/Longitude IDecimalDegrees + r UTM Zone:True r South C State Plane Zone: I' - Units: us -ft + ' Legal Description (NAD27 only) -Legai Township: p12 FN--,—] Range: 010 E + Meridian: Section: 34 FNL 2993.6947 FEL + 549.26325 .._......__._......_......_._..f Transiotm j Quit Help 1 H-108Bwp04 Intermediate Casing I 1% CPAI Coordinate Converter —101X1 From: To: Datum: NAD63 Region: alaska Datum: NAD27 Region: alazka C Latitude/Longitude IDecimalDegrees r Latitude/Longitude IDecimalDegrees r UTM Zone: I — r South r UTM Zone: True F South r State Plane Zone:] Units: us-ft - G State Plane Zone: F----3 Units: us-ft r Legal Description (NAD27 only) r Legal Description (NAD27 only) Starting Coordinates: Ending Coordinates: X: 11695361 X: 555329.26743056 Y: 15977541 Y: 5977789.15303049 ( Transform Quit Help 1H-108Bwp04 Intermediate Casing 1 Coordinatein CPA] _101X1 From: ------ To: — — -� Datum: NAD83 Region: alaska Datum: NA� Region: alaska * Latitude/Longitude Decimal De rees g r Latitude/Lon itude �— 9 Decimal Degrees f UTM Zone: r South C UTM Zone: True r South f• State Plane Zone: q Units: us-ft f State Plane Zone: Iq --:w:l Units: us-ft r Legal Description (NAD27 only) i% Legal Description (NAD27 only) Starting Coordinates: Legal Description X: 11695361 Township: 012 N Range: 010 E Y: 15977541 Meridian: U Section:34 FNL - 2954.3917 FEL 317.88558 r....._._................................_......._.__ tTransform Quit Help ................._........... 1 H-108Bwp04 TD I% CPAI Coordinate Converter IMI X1 From: To: --- – ----- Datum: NAD83 Region: alaska . Datum: NAD27 Region: alaska r Latitude/Longitude IDecimalDegrees, r Latitude/Longitude IDecimalDegrees C UTM Zone: F— r South r UTM Zone: True r South r State Plane Zone: q - Units: us -ft f• State Plane Zone: q � Units: us -ft r Legal Description (NAD27 only) r Legal Description (NAD27 only) Starting Coordinates: Ending Coordinates: X 1699043 X: 559011.226910056 Y: 15979660 Y: 5979908.03301083 ( Transform Quit Help 1 H-108Bwp04 TD imt, CPAI Coordinate Converter J oJJ From: To: Datum: NAD63 Region: alaska Datum: NA� Region: alaska T Latitude/Longitude IDecimaiDegrees r Latitude/Longitude iDecimaiDegrees r UTM Zone: F— j– South (- UTM Zone: True r South C• State Plane Zone: I" J Units: us -k ( State Plane Zone: �� Units: us -ft r Legal Description (NAD27 only) G Legal Description (NAD27 only) Starting Coordinates: Legal Description X: 11699043 Township: 012 [F_] Range: 010 Y: 5979660 Meridian: F--':-] Section:35 FNL - 863.47020 FEL 1896.9934 Quit Help REVI DATE I BY I CK I APP I DESCRIPTION I REV I DATE 7 BY I ..K I APP DESCRIPTION 1 2/05/0 MRT I CC I Rev. Per K05014ACS 2 02/01/11 JAH I LGMI Rev. Per K170005ACS N 25 30 29 21 7 25 G � 36 31 16 1 KCS 32 33 34 35 36 T1 211 OE Ti JOE 1 6 5 4 3 2 0120 1A ASP GRID NORTH *119 2 CPFI o 0 ��Hf 011 8 e 9 t i 0117 t 2 40 0116 0115 18 2 16 15 14 13 0114 ,s LEGEND 0113 TF 1n 24 0112 24 19 20 21 2 23 0 AS BUILT CONDUCTOR 0111 0110 VICINITY MAP • EXISTING CONDUCTOR 0109 SCALE: 1" = 2 MILES 0104 0108 0103 28 27 C-07 33 + 34 0102 0106 0101 NOTES: 1. BASIS OF LOCATION AND ELEV. IS DS1H MONUMENTATION PER LOUNSBURY & ASSOC. DS1H 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. •UGNU 01 4. ALL CONDUCTORS ARE LOCATED WITHIN •14 PROTRACTED SECTIONS 28 AND 33, •5 TOWNSHIP 12 NORTH, RANGE 10 EAST, 920 •12 UMIAT MERIDIAN, ALASKA. 019 922 •11 5. DATES OF SURVEY: 12-26-16 THRU 017 010 1-31-17 FIELD BOOKS L16-35, L16-40, 06 L17-02 & L17-03. •16 •21 •15 013 6. ALL DISTANCES SHOWN ARE GROUND. •1 •9 •2 •7 03 •18 GRAPHIC SCALE 0 100 200 400 • g •4 1 inch = 200 ft. SEE SHEET 2 & 3 FOR COORDINATE TABLELOUN;BURY & ASSOc is. INC. TUTS 'i WRRWYORS RN FiLi 1i3 AREA: IH MODULE: XXXX UNIT: 51 ConocoPhilli S DS1H WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CADD RLE N0. DRAWING N0. PART: REV: Li 8d31 2 Os 05 CEA—I)M-6108D31 1 OF 3 1 2 1 1 102/01/171 JAH I LGM I (Create Per K170005ACS I I I I 1 CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 28, T. 12 N., R. 10 E., UMIAT MERIDIAN Well NAD 27 549,566.50' NAD 27 Section Elev. No. ASP Coordinates Geociroohic Coordinates Offset. 549,564.40' N 70' 21' 30.398" Y I X Lot. 48.0' I Long. F.S.L F.E.L. O.G. PAD •103 5,980,722.55' 549,573.20' N 70' 21' 29.220" W 149' 35' 50.536"19' 5,980,902.08' 768' 48.0' 54.1' *104 r,QRn 7R9 A.'S' 54Q.5riR 74' M 7n• 91' 90 Ano"' W 1 AW iR' Rn RSR^ 70' 1 -1 . , W 149' 35' 50.947" 229' *108 5,980,752.52' 549,570.98' N 70' 21' 29.515" W 149' 35' 50.595" 49' 1 770' 1 48.0' 1 54.0' *109 5,980,812.20' 549,566.50' N 70' 21' 30.102" W 149' 35' 50.714" 109' 1 774' 48.0' 1 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 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 ......0 DONE BY ME OR UNDER MY DIRECT SUPERVISION AND aor THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION ARE CORRECT AS OF JANUARY 31, 2017. LOUNSBURY dt ASSOCIATES, INC. .""ORS ENGINEERS PWNNERS AREA: IH MODULE: XXXX UNIT: D1 ConocoPhilli S DS1H WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CALK6 08d31 12/27/16 oRAwNc No. CEA-D1HX-6108D31 PART: 3 OF 3 REV: 1 _ — _— — _ - = Insulated Conductor Casing, 20", 94#, K55 x 34", 0.312" WT@+/-120'MD 10-3/4", 45.5#, L-80, Hyd563 Wellhead / Tubing Head / Tree, j10-3/4"x4-1/2",5,000psi 1H-108B Injector (WP04) Slotted Liner Gas Lift Mandrel, CAMCO Model MMG w/ SOV @ 2,000' MD / 1,908' TVD (35 deg) @ 1,834' MD / 1,824' TVD F @ 31 degrees n TD 13.5" hole m s Tubing String: 3-1/2', 9.3 #, L-80 HYD 563 0 ao � Gas Lift Mandrel, CAMCO 2 Model MMG w/ Dummy g' a 5,250' MD / 3,253' TVD (70 deg) 0 .. 2.812" XN nipple @ 5,364' MD / 3,291' TVD (72 deg) VW% 12.6#, L-80, IBTM Slotted Liner @ 13,023' MD / 4,203' TV D @ 57 degrees 6.125" OH TD @ 13,033' MD / 4,203' TVD 4,465' Lined Lateral @ 57 degrees '• 4,475' Lateral ZXP Liner Top packer &Liner Hanger•________________________________________________ @ 8,399' MD (-150 ft above 7" shoe)------� ----------------------------------------_________________ •• ;. -------------------------------------------------------- 7", 26#, L-80, TXP, Casing •, @ 8,549' MD/3,807 TVD•-____________________________________________________________________________________________ o @ 85 degrees Y 2 TD 8-3/4" hole 4-IY2" Solid Shoe IH -10813 Drilling Hazards Summary 8-3/4" Open Hole / 7" Casing Interval Hazard Risk Level Mitigation Strategy Running sands and gravels Low Maintain planned mud parameters, increase mud weight, use weighted sweeps Stuck pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight. Abnormal reservoir pressure Low BOP training and drills, increased mud weight. Lost circulation Moderate Reduced pump rates, mud rheology, add LCM. Differential sticking Moderate Follow mud program, keep pipe moving when able. Anti -collision Moderate Follow real time surveys very closely. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out or back reaming. Getting casing to bottom Moderate Utilize proper drilling and hole cleaning practices, follow mud program. Fault crossings and concretions Moderate Use developed best practices for concretion drilling. 6-1/8" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Mitigation Strategy 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, add LCM. Differential sticking Moderate Follow mud program, keep pipe moving when able. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out or back reaming. Getting liner to bottom Moderate Utilize proper drilling and hole cleaning practices, follow mud program. Fault crossings and concretions Moderate Use developed best practices for concretion drilling. 1H-1088 Ddlling Hazards.docx 7/9/2018 l A3tl 9'0 Spry "vo BIW 131I1V ONIMV80 imAVI HISO :31111 A9 NMVaa 1 :177 -oul."SelV sd!II!4do:)ouoD Attachment 5 BOP Confieuration The following ram configuration will be utilized for the West Sak wells. Further details regarding the BOPE specifications can be found with the Doyon 142 documentation on file with the State. Loepp, Victoria T (DOA) From: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Sent: Wednesday, July 18, 2018 10:40 AM To: Loepp, Victoria T (DOA) Cc: Woodard, Madeline E; Brunswick, Scott A; Rohlfing, Jenaya J; Tolman, Ben V Subject: RE: [EXTERNAL]RE: KRU 1H-1088 PTD(218-082) Victoria, I apologize for the error — the pressures listed on the 10-401 form are incorrect and the calculations on the PTD application are correct. The maximum potential downhole pressure for 1H -308B is 1863 psi and the maximum potential surface pressure is 1446 psi. Would you like me to submit a revised 10-401 form? With regards to the attachments being submitted in black and white only, I am in the process of printing out 2 x copies of the attachments in color and will deliver them here shortly. Thanks, Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick. R.LehmanConocoPhillips.com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Wednesday, July 18, 201810:17 AM To: Lehman, Nick R <Nick.R.Lehman @conocophillips.com> Subject: [EXTERNAL]RE: KRU 1H -108B PTD(218-082) Nick, The MPSP and max res pressure in the PTD do not agree with the 10-401 form. Please indicate which is correct. 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.Loepona alaska.aov 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.Loepo@olaska.gov From: Loepp, Victoria T (DOA) Sent: Wednesday, July 18, 2018 10:14 AM To:'Lehman, Nick R' <Nick.R.Lehman@conocophillips.com> Subject: KRU 11-1-108B PTD(218-082) Nick, The entire package (originaI and duplicate) was submitted in B&W. I need two copies of all the attachments in color. Do not include the 10-401 forms. I would like hardcopies as I do not want to print out everything. Bring it to the front desk with directions to deliver to me. Thanx, Victoria From: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Sent: Wednesday, July 18, 2018 9:36 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Subject: RE: [EXTERNAL]RE: 11-1-108B PTD Ok thanks. Nick From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> Sent: Wednesday, July 18, 2018 8:58 AM To: Lehman, Nick R <Nick. R. Lehman@conocophillips.com> Subject: [EXTERNAL]RE: 1H -108B PTD Should be approved this week - From: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Sent: Tuesday, July 17, 2018 5:10 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> Subject: 1H-1088 PTD Good afternoon Victoria, We are currently preparing to run our upper completion for 11-1-115 and are estimating rig release and move to 11-1-108B on Thursday afternoon. I wanted to reach out to you regarding the 11-1-108B permit to drill application and see if you have any questions or if there is anything I can do to help. We appreciate you working with us regarding the recent challenges we've encountered at 11 -1 -pad. Thanks, Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick.R.Lehman@ConocoPhillips.com Loepp, Victoria T (DOA) From: Woodard, Madeline E <Madeline.E.Woodard@conocophillips.com> Sent: Wednesday, July 11, 2018 10:39 AM To: Loepp, Victoria T (DOA) Cc: Davies, Stephen F (DOA) Subject: FW: [EXTERNAL]KRU 11-1-1086 (PTD #218-082) - Question Hi Victoria, Per our phone conversation, we actually will be producing from 1H-1086 for a short period of time to clean up the wellbore. We are uncertain on the timing of when this will begin. I will update you with more information as I get it. Thanks so much. Madeline From: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Sent: Tuesday, July 10, 2018 3:14 PM To: Woodard, Madeline E <Madeline.E.Woodard@conocophillips.com> Subject: [EXTERNAL)KRU 1H-1086 (PTD #218-082) - Question Madeline, One question: KRU 1H-1086 be pre -produced or will the well be produced only for short time to clean up wellbore. Thank you, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. Davies, Stephen F (DOA) From: Woodard, Madeline E <Madeline.E.Woodard@conocophiIli ps.com> Sent: Tuesday, July 10, 2018 3:53 PM To: Davies, Stephen F (DOA) Subject: RE: [EXTERNAL]KRU 1H-1088 (PTD #218-082) - Question Steve, The entire geologic column is expected to be normally pressured and the West Sak sands are all uniformly pressured at 8.6 ppg here. Thanks, Madeline From: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Sent: Tuesday, July 10, 2018 3:39 PM To: Woodard, Madeline E <Madeline. E.Woodard@conocophillips.com> Subject: RE: [EXTERNAL]KRU 1H-1086 (PTD #218-082) - Question Madeline, Three more questions: Is the entire geologic column above the West Sak Sands expected to be normally pressured? Are the West Sak Sands uniformly pressured at 8.6 ppg, or are any of the sands depleted? If so, which sands and what are their approximate pressures? Thank you, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.daviesPalaska.aov. From: Woodard, Madeline E [ma ilto: Made line.E.Woodard@conocophillips.com] Sent: Tuesday, July 10, 2018 3:18 PM To: Davies, Stephen F (DOA) <steve.davies@alaska.aov> Subject: RE: [EXTERNAL]KRU 1H-1088 (PTD #218-082) - Question Steve, No to both. No perforations, just a horizontal injector. Thanks, Madeline From: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Sent: Tuesday, July 10, 2018 3:14 PM To: Woodard, Madeline E <Madeline E Woodard@conocophillips.com> Subject: [EXTERNAL]KRU 1H -108B (PTD #218-082) - Question Madeline, One question: KRU 1H -108B be pre -produced or will the well be produced only for short time to clean up wellbore. Thank you, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.eov. AOGCC PTD No. 218-082 Coordinate Check 10 July 2018 INPUT Geographic, NAD27 DIU SDI 04-26A Latitude: 70 21 29.515 Longitude: 149 35 50.595 OUTPUT Slate Plane, NAD27 5004 -Alaska 4, U.S. Feet 111 NorthinglY: 5 980 752.5 21 EastinglX: 549570.972 Convergence: 0 22 45.07024 Scale Factor: 0.999902791 Remark: Corpscon v6.0.1, U.S. Army Corps of Engineers TRANSMITTAL LETTER CHECKLIST WELL NAME: X�� //--/— /09 -IS PTD: Development • Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: POOL: W< 3'f Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50 - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- -_) from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements / Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, ✓ composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field 8 Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 19 Well Name: KUPARUK RIV U WSAK 1H -108B Program DEV Well bore seg ❑ PTD#:2180820 Company CONOCOPHILLIPS ALASKA INC Initial Class/type DEV/PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31.05.030Q.1.A),(j,2.A-D) _ _ NA 21 1 Permit fee attached _ _ _ _ _ _ ... _ _ _ NA.. 22 2 Lease number appropriate ... _ ... _ _ _ _ . Yes Surface location and top productive interval in ADL 025639; and TD in ADL 025638, 23 3 Unique well name and number _ _ _ _ _ .. _ . _ _ ... Yes 24 4 Well located in defined pool ...... _ _ _ _ _ _ _ _ _ _ Yes Kuparuk River, West Sak Oil Pool - 490150, goverrred by CO 406C 25 5 Well located proper distance from drilling unit bounder)( _ _ ......... Yes CO 4060, Rule 3: no restrictions as to well spacing except that no pay shall be opened in a. well closer 26 6 Well located proper distance from other wells _ .... _ _ _ Yes _ than 50.0 feet to an external_ property line where ownership or landownership changes, 27 7 Sufficient acreage. available in drilling unit _ _ _ Yes As planned, well conforms to spacing requirements... 28 8 If,deviated, is wellbore plat.included _ _ _ _ _ _ _ _ _ _ _ _ _ _ . Yes VTL 7/18/2018 29 9 Operator only affected party. .. _ _ _ _ ... Yes 30 10 Operator hasappropriate bond in force _ _ _ _ . . . . . . . ........ Yes Appr Date 11 Permit can be issued without conservation order. ........... . . Yes 32 12 Permit can be issued without administrative approvel Yes SFD 7/10/2018 Is presence of H2S gas probable.... _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 34 13 Can permit be approved before 15 -day wait _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 35 14 Well located within area andstrata authorized by Injection Order # (put 10# in comments) (For.: Yes Area Injection Order No, 26 36 15 All wells within 1/4. mile area of review identified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ ___ Yes _ KRU 16-102, 1C-150, 1C -170,.1C7174,. 1C -178.-1-C-1 780. 1H-09, 1H-1 08A, 1H-11, 1H-13, and 1H-15 37 16 Pre -produced injector: duration of pre production less than 3 months. (Fpr serv(ce well only) .. Yes _ _ _ (11-1-1041-1, 111-1041-2, 11-1-1041-3, 11-1-1041-4 are proposed, but do not yet exist). SFD 7/10/2018 18 Conductor string_ provided _ _ _ _ _ _ NA ... Conductorsetfor. KRU 1H-108_ Engineering 19 Surface casing_ protects all known USDWs .... .................. NA _ Surface casing set for KRU.1 H-108... Commissioner 20 CMT. vol adequate to circulate on conductor 8 surf csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA Surface casing set and fully cemented _ _ _ _ _ _ ....... 21 CMT vol adequate to tie-in long string to surf csg _ _ _ _ _ _ _ _ NA 22 CMT. will cover all known productive horizons _ _ _ _ _ _ _ _ _ _ _ ______ No. Productive_ interval will be completed with uncemented slotted line[ 23 Casing designs adequate for C, T, B & permafrost.. _ _ _ _ _ _ ....... Yes 24 Adequate tankage or reserve pit _ _ _ _ _ _ .......... Yes Rig has steel tanks: all waste to approved disposal wells 25 If.a_re-drill, has a 10-403 for abandonment been approved _ _ _ _ _ Yes 26 Adequate wellbore separation_ proposed _ _ _ _ _ _ Yes Anti -collision analysis complete; no major risk failures 27 If diverter required, does it meet regulations _ _ _ _ _ _ _ _ _ _ _ _ _ NA Appr Date 28 Drilling fluid. program schematic & equip list adequate. _ _ _ _ . Yes Max formation pressure is 1.863 psig(8.6 ppg EMW); will drill w/ 9.0-9.5 ppg EMW VTL 7/18/2018 29 BOPEs,_do they meet regulation _ ... _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes. 30 BOPE.press rating appropriate; test to (put psig in comments)_ .. _ .. Yes _ MPSP is 1446 psig: will test BOPS to 3500_psig. _ _ .... 31 Choke, manifold complies w/API RP -53 (May 84)_ _ _ _ _ _ . _ Yes 32 Work will occur without operation shutdown..... .... ...... _ _ _ Yes _ 33 Is presence of H2S gas probable.... _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 1-12S measures required_ 34 Mechanical condition of wells within AOR verified (Forservice well only)....... _ Yes _ _ Wells.identifed and mechanical condition verified________ 35 Permit can be issued w/o hydrogen sulfide measures _ _ _ _ _ _ _ _ _ _ _ No.. H2S measures required. Well 1H-102_measured 2Q ppm H2S on. November 20, 2017.... Geology 36 Data. presented on potential overpressure zones.. _ _ _ _ _ _ _ _ _ _ _ Yes .. _ Expected reservoir pressures range from 8,4 to 0.6 ppg EMW; will be drilled with 9.0 - 10.0 ppg mud. Appr Date 37 Seismic. analysis of shallow gas_ zones_ _ _ _ _ _ _ NA SFD 7/10/2018 38 Seabed condition survey (if off -shore) . _ _ _ _ _ _ _ _ _ NA 39 Contact name/phone for weekly progress reports (exploratory only] _ _ NA Geologic Engineering Public Commissioner: Date: Commissioner Date Commissioner Date