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217-084
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, October 3, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1H-118 KUPARUK RIV UNIT 1H-118 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/03/2025 1H-118 50-029-23578-00-00 217-084-0 W SPT 3731 2170840 1500 1104 1101 1100 1099 90 90 90 90 4YRTST P Josh Hunt 8/22/2025 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1H-118 Inspection Date: Tubing OA Packer Depth 530 2010 1990 1985IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250822130504 BBL Pumped:1.2 BBL Returned:1.1 Friday, October 3, 2025 Page 1 of 1 WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďLJĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϮϭϳϬϴϰϬ Ͳ^Ğƚ͗ϯϲϮϲϴJRBy Abby Bell at 1:43 pm, Dec 21, 2021 3M-1750029217290000 KRU WLWFLFINAL FIELD24-Apr-213M-1950029217370000 KRU WLLDLFINAL FIELD25-Apr-213H-0150103200840000 KRU WLCHCFINAL FIELD26-Aug-213H-1250103200880000 KRU WLCCLFINAL FIELD23-Sep-213H-1250103200880000 KRU WLCHCFINAL FIELD29-Aug-213H-1250103200880000 KRU WLCUTTERFINAL FIELD23-Sep-213H-1250103200880000 KRU WLCUTTERFINAL FIELD24-Sep-211L-1250029220330000 KRU WLSBHPSFINAL FIELD6-Nov-213G-2450103201450000 KRU WLTBG CORRFINAL FIELD29-Oct-211A-2550029221160000 KRU WL WHIPSTOCKFINAL FIELD12-Oct-211A-2350029221310000 KRU WLRBPFINAL FIELD12-Jun-211R-2050029222070000 KRU WLPPROFFINAL FIELD2-Jun-212M-1150103201590000 KRU WLPPROFFINAL FIELD27-Aug-212M-0750103201780000 KRU WLBACKOFFFINAL FIELD5-Aug-211Y-1950029223910000 KRU WLPPROFFINAL FIELD31-May-212T-3050103202190000 KRU WLLDLFINAL FIELD2-May-211Q-20A50029225890100 KRU WLSET RECFINAL FIELD2-Aug-212M-3350103202400000 KRU WLLDLFINAL FIELD18-Oct-211F-03A50029208530100 KRU WLPERFFINAL FIELD19-Oct-211Q-08A50029212250100 KRU WLIPROFFINAL FIELD30-Apr-211E-3350029227970000 KRU WLPPROFFINAL FIELD26-Mar-211D-13550029228160000 KRU WLLDLFINAL FIELD16-Jul-213F-13A50029214990100 KRU WLGLSFINAL FIELD17-Jul-212N-318 50103203430000 KRU WLSCMTFINAL FIELD12-Nov-211C-12750029230240000 KRU WLIPROFFINAL FIELD17-Nov-213S-24A50103204560100 KRU WLCUTTERFINAL FIELD25-Oct-213S-0350103204580000 KRU WLIBPFINAL FIELD26-Oct-211B-2050029231640000 KRU WLPPROFFINAL FIELD22-Apr-211E-11950029231980000 KRU WLLDLFINAL FIELD26-Jun-212W-1750029233700000 KRU WLPPROFFINAL FIELD28-Aug-211H-11850029235780000 KRU WLIPROFFINAL FIELD4-Nov-211H-11450029235840000 KRU WLIPROFFINAL FIELD23-Jun-211H-11350029235880000 KRU WLWFLFINAL FIELD22-May-21 MEMORANDUM TO: Jim R6• qj� Z� P.I. Supervisor —"(C 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. 1H-118 KUPARUK RIV UNIT 1H-118 Sre: Inspector Reviewed By: P.I. Suprv� Comm Well Name KUPARUK RIV UNIT IH -118 API Well Number 50-029-23578-00-00 Inspector Name: Bob Noble Permit Number: 217-084-0 Inspection Date: 8/2/2021 Insp Num: mitRCN210802132523 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I IH-118�T ype Inj w - TVD 3731 - Tubing 1090 - 1090 - 1090- 1090 PTD 1 2170840 - Type TestSPT, Test psi 1500 - IA 590 1810 1750 - 1730. BBL Pumped: 0.8 BBL Returned: 0.8- OA_, 215 - z1s � 215. 2 - _ Interva� 4vRTST P/F P Notes: Wednesday, August 4, 2021 Page 1 of 1 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: WINJ to WAG 2. Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:N/A 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A KRU 1H-118 Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 8,121 4,088.50 7,861'2201 N/A N/A Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Packers: 7146 MD (3731 TVD) / 7399 MD (3824 TVD) / 7521 MD (3869 TVD) 12. Attachments:Proposal Summary Wellbore schematic 13. W ell Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Stephanie Thomson Contact Name:Stephanie Thomson Staff Petroleum Engineer Contact Email:stephanie.thomson@cop.com Contact Phone: 907-263-4536 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): 3768-3806; 3833-3863; 3881- 3893; 3932-3948; 3976-3993 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 25639 119' 217-084 P.O. Box 100360, Anchorage, Alaska 99510 50-029-23578-00-00 ConocoPhillips Alaska, Inc. Length Size 3,993' PRESENT WELL CONDITION SUMMARY TVD BurstMD x L-80 x 7,950' 119' 1,719' 4,088.5'7" x x 20" 10-3/4" 80' xx 1,679' 8,121' Perforation Depth MD (ft): x x x Perforation Depth TVD (ft):Tubing Size: 1,695' 8,083' Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 10/1/2020 xx 3-1/2" Halliburton multi-feedthrough packers; No SSSV x 7246-7348; 7424-7504; 7554- 7587; 7693-7737; 7815-7861 m n s 66 t G c Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:42 pm, Sep 14, 2020 320-380 Digitally signed by Stephanie Thomson DN: C=US, OU=ConocoPhillips, O=GKA Base Production & Optimization, CN=Stephanie Thomson, E=stephanie.thomson@conocophillips.com Reason: I am the author of this documentLocation: your signing location here Date: 2020-09-14 12:36:53 Foxit PhantomPDF Version: 10.0.0 Stephanie Thomson DLB 9/15/2020 X 10-404 DSR-9/15/2020 X VTL 9/16/20Comm 9/16/2020 dts 9/16/2020 JLC 9/16/2020 RBDMS HEW 9/17/2020 Stephanie Thomson Staff Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501 Phone: (907) 263-4536 September 14, 2020 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 Dear Commissioner, Enclosed please find the 10-403 Application for Sundry Approval for the ConocoPhillips Alaska Inc well KRU 1H-118 (PTD 217-084). The request is for approval to convert this water injector (WINJ) to a water-alternating- gas injector (WAG) for the benefit of enhanced oil recovery. No downhole or surface work is anticipated to complete this conversion. As such, no Proposed Steps are being provided in this Application. If you have any questions regarding this matter, please contact me via the details below. Sincerely, Stephanie Thomson Staff Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501 Phone: (907) 263-4536 Mobile: (832) 414-2377 Attachments: Sundry Application Area of Review Map and Details Well Schematic Well Events Summary Digitally signed by Stephanie Thomson DN: C=US, OU=ConocoPhillips, O=GKA Base Production & Optimization, CN=Stephanie Thomson, E=stephanie.thomson@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-09-14 12:36:36 Foxit PhantomPDF Version: 10.0.0 Stephanie Thomson 1H-118 10-403 Proposal ConocoPhillips Alaska Inc. requests approval to convert West Sak Well 1H-118 (PTD# 217-084) from Water Injection service to Water Alternating Gas Injection service. Area of Review: West Sak well 1H-118 was completed as an injector on 8/8/2017 to provide waterflood support in the D, B, and A West Sak sands to offset producers 1H-101 and 1H-102. The top of the Ugnu C sand was found at 5,260' MD / 3,102' TVD The top of the Ugnu B sand was found at 6,138' MD / 3,353' TVD The top of the Ugnu A sand was found at 6,487' MD / 3,477' TVD The top of the West Sak D sand was found at 7,244' MD / 3,767' TVD The top of the West Sak C sand was found at 7,366' MD / 3,812' TVD The top of the West Sak B sand was found at 7,424' MD / 3,833' TVD The top of the West Sak A4 sand was found at 7,505' MD / 3,863' TVD The top of the West Sak A3 sand was found at 7,613' MD / 3,903' TVD The top of the West Sak A2 sand was found at 7,812' MD / 3,903' TVD Area Map with ¼ mile radius around target injection zone (see attached): The map attached shows that, in addition to the offset producers (1H-101 and 1H-102), there is one additional well (1H-05) that has penetrations in the West Sak interval located within a 1/4 mile radius of the 1H-118 penetrations of the West Sak interval. Mechanical Condition of Well to be Converted: The mechanical condition of West Sak injector 1H-118 is good. The injection tubing/casing annulus is isolated via a Halliburton MFT (multi-feedthrough) packer located at 7,146' MD (3,731' TVD). The last state-witnessed MITIA was performed on October 31, 2017, to 1810 psi. CBL and interpretation of the cement quality: See attached AOR detail for offset well condition. The 20" Conductor was cemented with 5.5 sks of aggregate cement. The 10-3/4" Surface casing was cemented with 232.6 bbls (683 sxs) of LiteCRETE lead cement followed by 60.1 bbls (291 sxs) of Class G tail cement.Observed 24.8 bbls of cement to surface. The 7" production casing was cemented with 59.4 bbls (215 sxs) of Extended G Class lead cement followed by 68 bbls (330 sxs) of Class G tail cement. Conditions for approval (if applicable): 1H-102L21H - 1 0 2 L 4 1 H - 1 0 2 L 3 1H-051H-101L41H-101L21H-101L31H-101L11H-1011H-1021H-102L11H-118ADL025636 ADL025639 27 Document Path: S:\ANC\Longterm\GKA Geoscience\geotech_projects\GKA_Wells\CPF_1_Wells\Well_1H_118\well_1H_118_inj_sundry_10403_8.4.2020.mxd 1H-118 10-403 Sundry 8/6/2020 ¯ 1H-118 Well Trajectory 1H-118 Open Interval 1H-118 OI Quartermile Buffer Q Well Pad Active Well P+A Well CPAI Lease 0 0.25 Miles Q1H ADL025639 ADL025636 ADL025638ADL02563727 22 34 28 21 33 26 35 23 T12N-R10ET12N-R10E 1H-118 Area of Review DetailPTD API WELL NAME STATUSTop of D-sand Oil Pool (MD)Top of D-Sand Oil Pool (TVD)Top of B-sand Oil Pool (MD)Top of B-Sand Oil Pool (TVD)Top of A4-sand Oil Pool (MD)Top of A4-Sand Oil Pool (TVD)Top of A3-sand Oil Pool (MD)Top of A3-Sand Oil Pool (TVD)Top of A2-sand Oil Pool (MD)Top of A2-Sand Oil Pool (TVD)Top of Cement (MD)Top of Cement (TVD)Top of Cement Determined ByReservoir Status Zonal Isolation Cement Operations Summary Mechanical Integrity21713850029235850000 1H-101 Producing 5,545 3,654 5,834 3,731 5,966 3,766 6,128 3,808 6,669 3,923 Surface Surface86 good bbls of cement returns to surface during 10-3/4" cement jobSlotter liners open for productionBaker 192-47 Seal Assembly/Locator at 5,448' MD (3,624' TVD).Baker HRD-E ZXP Flex-Lock Liner Top Packer at 6,292' MD (3,852' TVD).Baker 6" OD swell packers at 8,290' MD (3,955' TVD) and 8,649' MD (3,971' TVD).Cement to surface behind 10-3/4" surface casing.20" - 5.5 sxs of aggregate cement10-3/4" - 323.2 bbls (950 sxs) LiteCrete Lead Cement & 59.7 bbls 12.0 ppg LiteCrete Tail Cement7-5/8" - 175.6 bbls (850 sxs) Class G CementConductor cement top job completed 5/5/19. Pumped 0.7 bbls 15.4 ppg AS-1 cement making TOC ~6".21713950029235856000 1H-101L1 Producing 5,545 3,654 5,834 3,731 5,966 3,766 6,128 3,808 6,669 3,923 Surface Surface86 good bbls of cement returns to surface during 10-3/4" cement jobSlotter liners open for productionBaker 190-47 Seal Assembly/Locator at 6,333' MD (3,863' TVD).Baker ZXP Liner Top Packer at 6,127' MD (3,807' TVD).Baker 6" OD swell packers at 6,322' MD (3,849' TVD), 6,825' MD (3,898' TVD), 8,297' MD (3,909' TVD), and 8,482' MD (3,923' TVD).Cement to surface behind 10-3/4" surface casing.20" - 5.5 sxs of aggregate cement10-3/4" - 323.2 bbls (950 sxs) LiteCrete Lead Cement & 59.7 bbls 12.0 ppg LiteCrete Tail Cement7-5/8" - 175.6 bbls (850 sxs) Class G CementConductor cement top job completed 5/5/19. Pumped 0.7 bbls 15.4 ppg AS-1 cement making TOC ~6".21714050029235856100 1H-101L2 Producing 5,545 3,654 5,834 3,731 5,966 3,766 6,128 3,808 6,669 3,923 Surface Surface86 good bbls of cement returns to surface during 10-3/4" cement jobSlotter liners open for productionBaker 190-47 Seal Assembly/Locator at 6,156' MD (3,815' TVD).Baker ZXP Liner Top Packer at 5,929' MD (3,755' TVD).Baker 6" OD swell packers at 6,153' MD (4,419' TVD), 6,461' MD (4,427' TVD), 8,205' MD (4,457' TVD), and 8,308' MD (4,466' TVD).Cement to surface behind 10-3/4" surface casing.20" - 5.5 sxs of aggregate cement10-3/4" - 323.2 bbls (950 sxs) LiteCrete Lead Cement & 59.7 bbls 12.0 ppg LiteCrete Tail Cement7-5/8" - 175.6 bbls (850 sxs) Class G CementConductor cement top job completed 5/5/19. Pumped 0.7 bbls 15.4 ppg AS-1 cement making TOC ~6".21714150029235856200 1H-101L3 Producing 5,545 3,654 5,834 3,731 5,966 3,766 6,128 3,808 6,669 3,923 Surface Surface86 good bbls of cement returns to surface during 10-3/4" cement jobSlotter liners open for productionBaker 190-47 Seal Assembly/Locator at 5,959' MD (3,763' TVD).Baker ZXP Liner Top Packer at 5,656' MD (3,683' TVD).Baker 6" OD swell packer at 5,959' MD (3,755' TVD).Cement to surface behind 10-3/4" surface casing.20" - 5.5 sxs of aggregate cement10-3/4" - 323.2 bbls (950 sxs) LiteCrete Lead Cement & 59.7 bbls 12.0 ppg LiteCrete Tail Cement7-5/8" - 175.6 bbls (850 sxs) Class G CementConductor cement top job completed 5/5/19. Pumped 0.7 bbls 15.4 ppg AS-1 cement making TOC ~6".21714250029235856300 1H-101L4 Producing 5,545 3,654 5,834 3,731 5,966 3,766 6,128 3,808 6,669 3,923 Surface Surface86 good bbls of cement returns to surface during 10-3/4" cement jobSlotter liners open for productionBaker 190-47 Seal Assembly/Locator at 5,686' MD (3,3691' TVD).Baker ZXP Liner Top Packer at 5,439' MD (3,621' TVD).Baker 6" OD swell packer at 5,684' MD (3,681' TVD).Cement to surface behind 10-3/4" surface casing.20" - 5.5 sxs of aggregate cement10-3/4" - 323.2 bbls (950 sxs) LiteCrete Lead Cement & 59.7 bbls 12.0 ppg LiteCrete Tail Cement7-5/8" - 175.6 bbls (850 sxs) Class G CementConductor cement top job completed 5/5/19. Pumped 0.7 bbls 15.4 ppg AS-1 cement making TOC ~6".21709750029235800000 1H-102 Producing 7,367 3,735 7,644 3,810 7,785 3,848 7,941 3,889 8,272 3,970 Surface Surface9 bbls of good cement returns to surface during 10-3/4" cement jobSlotter liners open for productionBaker 192-47 Seal Assembly/Locator at 7,260' MD (3,706' TVD).Baker HRD-E ZXP Flex-Lock Liner Top Packer at 8,228' MD (3,963' TVD).Baker 6" OD swell packers at 8,713' MD (3,991' TVD), 10,968' MD (4,013' TVD), and 11,282' MD (4,031' TVD).Cement to surface behind 10-3/4" surface casing.20" - 5.5 sxs of aggregate cement10-3/4" - 298 bbls (876 sxs) LiteCrete Lead Cement & 61.9 bbls (211 sxs) LiteCrete Tail Cement7-5/8" - 239.3 bbls (1,159 sxs) Class G CementConductor cement top job completed 5/5/19. Pumped 0.65 bbls 15.4 ppg AS-1 cement making TOC ~6".21710050029235806000 1H-102L1 Producing 7,367 3,735 7,644 3,810 7,785 3,848 7,941 3,889 8,272 3,970 Surface Surface9 bbls of good cement returns to surface during 10-3/4" cement jobSlotter liners open for productionBaker 190-47 Seal Assembly/Locator at 8,295' MD (3,935' TVD).Baker ZXP Liner Top Packer at 7,912' MD (3,882' TVD).Baker 6" OD swell packers at 8,181' MD (3,934' TVD), 10,993 MD (3,966' TVD), and 11,180' MD (3,983' TVD).Cement to surface behind 10-3/4" surface casing.20" - 5.5 sxs of aggregate cement10-3/4" - 298 bbls (876 sxs) LiteCrete Lead Cement & 61.9 bbls (211 sxs) LiteCrete Tail Cement7-5/8" - 239.3 bbls (1,159 sxs) Class G CementConductor cement top job completed 5/5/19. Pumped 0.65 bbls 15.4 ppg AS-1 cement making TOC ~6".21710150029235806100 1H-102L2 Producing 7,367 3,735 7,644 3,810 7,785 3,848 7,941 3,889 8,272 3,970 Surface Surface9 bbls of good cement returns to surface during 10-3/4" cement jobSlotter liners open for productionBaker 190-47 Seal Assembly/Locator at 7,945' MD (3,883' TVD).Baker ZXP Liner Top Packer at 7,718' MD (3,830' TVD).Baker 6" OD swell packers at 8,295' MD (3,878' TVD), 10,929' MD (3,902' TVD), and 11,175' MD (3,921' TVD).Cement to surface behind 10-3/4" surface casing.20" - 5.5 sxs of aggregate cement10-3/4" - 298 bbls (876 sxs) LiteCrete Lead Cement & 61.9 bbls (211 sxs) LiteCrete Tail Cement7-5/8" - 239.3 bbls (1,159 sxs) Class G CementConductor cement top job completed 5/5/19. Pumped 0.65 bbls 15.4 ppg AS-1 cement making TOC ~6".21710350029235806200 1H-102L3 Producing 7,367 3,735 7,644 3,810 7,785 3,848 7,941 3,889 8,272 3,970 Surface Surface9 bbls of good cement returns to surface during 10-3/4" cement jobSlotter liners open for productionBaker 190-47 Seal Assembly/Locator at 7,750' MD (3,827' TVD).Baker ZXP Liner Top Packer at 7,460' MD (3,760' TVD).Baker 6" OD swell packer at 7,777' MD (3,828' TVD).Cement to surface behind 10-3/4" surface casing.20" - 5.5 sxs of aggregate cement10-3/4" - 298 bbls (876 sxs) LiteCrete Lead Cement & 61.9 bbls (211 sxs) LiteCrete Tail Cement7-5/8" - 239.3 bbls (1,159 sxs) Class G CementConductor cement top job completed 5/5/19. Pumped 0.65 bbls 15.4 ppg AS-1 cement making TOC ~6".21710550029235806300 1H-102L4 Producing 7,367 3,735 7,644 3,810 7,785 3,848 7,941 3,889 8,272 3,970 Surface Surface9 bbls of good cement returns to surface during 10-3/4" cement jobSlotter liners open for productionBaker 190-47 Seal Assembly/Locator at 7,491' MD (3,763' TVD).Baker ZXP Liner Top Packer at 7,252' MD (3,704' TVD).Baker 6" OD swell packer at 7,507' MD (3,765' TVD).Cement to surface behind 10-3/4" surface casing.20" - 5.5 sxs of aggregate cement10-3/4" - 298 bbls (876 sxs) LiteCrete Lead Cement & 61.9 bbls (211 sxs) LiteCrete Tail Cement7-5/8" - 239.3 bbls (1,159 sxs) Class G CementConductor cement top job completed 5/5/19. Pumped 0.65 bbls 15.4 ppg AS-1 cement making TOC ~6".18203850029207270000 1H-05 P&A'd 8,311 3,784 8,436 3,854 8,493 3,879 8,550 3,928 8,665 4,005Inside 10-3/4": 2,425' MDOustide 10-3/4": unverifiedInside 10-3/4": 2,214' TVDOustide 10-3/4": unverifiedInside 10-3/4" casing: taggedOutside 10-3/4" casing: unverifiedPlugged & AbandonedTop cement plug (Plug #5) - 240 sxs Arctic Set 1 @ 15.7 ppg. Top (tagged) 2,200' MD - bottom 2,545' MD. Drilled out to 2,425' MD (2,214' TVD) to kick-off point for 1H-105 sidetrack.Plug #4 - 240 sxs Arctic Set II @ 15.7 ppg. Top (tagged) 2,550' MD (2,291' TVD) - bottom 2,715' MD (2,386' TVD).Plug #3 - 260 sxs "G" @ 15.8 ppg, 2% CaCl2, 2% D-46. Top (tagged) 3,979' MD (3,010' TVD) - bottom 4,590' MD (3,350' TVD).Plug #2 - 290 sxs "G" @ 15.8 ppg, 2% CaCl2, 2% D-46. Top (not tagged) 5,100' MD (3,638' TVD) - bottom 5,700' MD (3,971' TVD).Plug #1 - 260 sxs "G" @ 15.8 ppg, 2% CaCl2, 2% D-46. Top (not tagged) 9,825' MD (6,533' TVD) - bottom 10,890' MD (7,178' TVD).30" - 200 sxs10-3/4" - 1,000 sxs Fondu & 250 sxs Arctic Set IINo Known Problems Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:1H-118 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Replace WFRV 4/17/2019 1H-118 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.20 Top (ftKB) 39.1 Set Depth (ftKB) 119.1 Set Depth (TVD) … 119.1 Wt/Len (l… 78.67 Grade B Top Thread Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 40.4 Set Depth (ftKB) 1,719.3 Set Depth (TVD) … 1,694.8 Wt/Len (l… 45.50 Grade L-80 Top Thread Hydril 563 Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 37.7 Set Depth (ftKB) 8,121.0 Set Depth (TVD) … 4,088.5 Wt/Len (l… 26.00 Grade L-80 Top Thread TXP BTC Tubing Strings Tubing Description Upper Completion String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 34.7 Set Depth (ft… 7,950.2 Set Depth (TVD) (… 4,026.0 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 34.7 34.7 0.12 HANGER Vetco 4-1/2" Tubing Hanger 3.958 7,146.2 3,731.4 68.38 PACKER Halliburton Feed Through Packer #3 VAM connection ( Assy #10) SN# SG3542445-01 2.920 7,159.9 3,736.4 68.43 PRESSURE/TE MPERATURE SENSOR SLB DHG #3 EUE 8RD-Mod ( Assy #10) SN# C15GM-0736 2.898 7,176.3 3,742.5 68.48 NIPPLE Camco 2.812 DS nipple EUE 8RD-Mod ( Assy #9) SN# 3651-4 2.813 7,398.7 3,824.2 68.42 PACKER Halliburton Feed Through Packer #2 VAM connection ( Assy #7) SN# SG3542445-04 2.920 7,412.4 3,829.3 68.45 PRESSURE/TE MPERATURE SENSOR SLB DHG #2 EUE 8RD-Mod SN# C15GM-0739 2.898 7,521.1 3,869.0 68.59 PACKER Halliburton Feed Through Packer #1 VAM connection ( Assy #4) SN# SG3532048-02 2.920 7,534.8 3,874.0 68.57 PRESSURE/TE MPERATURE SENSOR SLB DHG #1 EUE 8RD-Mod SN# C15GM-0728 2.898 7,550.7 3,879.8 68.55 NIPPLE Camco 2.813 X nipple EUE 8RD-Mod ( Assy #3) SN# C15GM- 0728 2.813 7,937.2 4,021.3 68.52 WIV 3 1/2" Baker WIV EUE-MOD 1.000 7,940.4 4,022.5 68.53 CASING BRUSH Baker Trailblazer CSG scrapper / brush / Mag combo ( Assy #1) 3.833 7,946.1 4,024.5 68.53 MULE SHOE 3 1/2" Mule shoe tubing tail 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,246.0 7,348.0 3,768.0 3,805.6 WS D, 1H-118 8/19/2017 6.0 IPERF 7,424.0 7,504.0 3,833.5 3,862.7 WS B, 1H-118 8/19/2017 6.0 IPERF 7,554.0 7,587.0 3,881.0 3,893.1 WS A4, 1H-118 8/19/2017 6.0 IPERF 7,693.0 7,737.0 3,931.9 3,947.9 WS A3, 1H-118 8/19/2017 6.0 IPERF 7,815.0 7,861.0 3,976.5 3,993.3 WS A2, 1H-118 8/19/2017 6.0 IPERF 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 2,529.7 2,325.6 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/28/2017 2 7,182.5 3,744.8 Camco MMGW 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/30/2018 3 7,222.8 3,759.5 Camco MMGW 1 1/2 GAS LIFT WFRV RK 0.297 0.0 10/19/2017 500 BPD 4 7,428.8 3,835.3 Camco MMGW 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/21/2017 5 7,468.9 3,850.0 Camco MMGW 1 1/2 GAS LIFT WFRV RK 0.297 0.0 10/19/2017 500 BPD 6 7,557.4 3,882.2 Camco MMGW 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/21/2017 7 7,597.5 3,896.9 Camco MMGW 1 1/2 GAS LIFT WFRV RK 0.297 0.0 4/17/2019 1340 BPD Notes: General & Safety End Date Annotation 5/27/2018 Note: See mandrels inserts for detail on WFRV's Comment SSSV: NONE 1H-118, 4/18/2019 9:02:47 AM Vertical schematic (actual) PRODUCTION; 37.7-8,121.0 MULE SHOE ; 7,946.1 CASING BRUSH; 7,940.4 WIV; 7,937.2 IPERF; 7,815.0-7,861.0 IPERF; 7,693.0-7,737.0 GAS LIFT; 7,597.5 IPERF; 7,554.0-7,587.0 GAS LIFT; 7,557.4 NIPPLE; 7,550.6 PRESSURE/TEMPERATURE SENSOR; 7,534.8 PACKER; 7,521.1 GAS LIFT; 7,468.9 IPERF; 7,424.0-7,504.0 GAS LIFT; 7,428.8 PRESSURE/TEMPERATURE SENSOR; 7,412.4 PACKER; 7,398.7 IPERF; 7,246.0-7,348.0 GAS LIFT; 7,222.8 GAS LIFT; 7,182.5 NIPPLE; 7,176.3 PRESSURE/TEMPERATURE SENSOR; 7,159.9 PACKER; 7,146.2 GAS LIFT; 2,529.7 SURFACE; 40.4-1,719.3 CONDUCTOR; 39.1-119.1 HANGER; 34.7 KUP INJ KB-Grd (ft) 38.85 Rig Release Date 9/22/2017 Annotation LAST WO: End Date 1H-118 H2S (ppm) Date... TD Act Btm (ftKB) 8,131.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292357800 Wellbore Status INJ Max Angle & MD Incl (°) 75.40 MD (ftKB) 3,515.01 WELLNAME WELLBORE1H-118 1H-118 Water Injector Date Event Summary 08/08/17 Original spud date. 08/22/17 Completion date. 10/09/17 Put on produced water injection. 10/31/17 State-witnessed MIT-IA to 1810 psi (passed). 05/12/18 Put on seawater injection. 05/04/19 Conductor cement top job complete. Pumped 0.5 bbls 15.4 ppg AS-1 cement into conductor. Cement top @ ~6". 05/05/19 Conductor sealant job complete. Pumped 2 gal RG2401 into conductor. Sealant top @ ~4". Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: rt AOGCC ATTN: Natural Resources Tech niclan 11 Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 2 170 84 TRANS M ITTALDATE TRANSMITTAL p COMM NAME 2M-37 3N-09 1A-12 1H-114 1H-118 1H-119 3G-18 3F-03 API It 50-103-20745-00 50.029.21541.00 50-029-20688-00 50-029-23584-00 50.029-23578-00 50-029-23591-00 50-103-20142-00 50-029-21448-00 ORDERSERVICE # EOSH-00096 DWUJ-00125 DWUJ-00128 EDWI.00018 EDWI-00019 EDWI-00020 EDWI-00021 EOSH-00098 FIELD NAMEColor DESCRIPTIONWELL KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL WL WL WIL WL • IPROF LDL Caliper IPROF•WFL IPROF-WFL IPROF•WFL Caliper IPROF DATA TYPE FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD D. 10•Sep-19 15 -Sep -19 18 -Sep -19 19 -Sep -19 20 -Sep -19 21 -Sep -19 23 -Sep -19 25 -Sep -19 1 1 1 1 1 / 1 1 8 Na Signature return via courier or sign/scan and email a copy Date and CPAI. Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. Ca nocoPhillips 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: a 1-7 -6 2q REG I &E� r MAY 0 8 2019 AOGC(-; 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 a 1 n.. u Well Name API# PTD#]1n,Ct,,aM1top of ent Vol. of cement pumped Final top of Cement top off cement dale Corrosion inhibitor Corrosion inhibitor/ sealant date H bbls ft al U-180 50029233290000 2061500 20'9" 2.80 1'5" 5/4/2019 5 5/5/2019 1H-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 1 H-103 50029235930000 2180030 2'2.5" 0.45 9" 5/4/2019 2.2 1 5/5/2019 11-1-104 50029236100000 2180840 2'.5" 0.40 9" 5/4/2019 2.2 5/5/2019 1H -108B 50029236080200 2180820 3'8" 0.80 10" 5/4/2019 2.5 5/5/2019 1 H-109 50029235950000 2180130 2'3" 0.40 9" 5/4/2019 2.2 5/5/2019 1 H-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 1711" 0.25 7.5" 5/4/2019 1.8 5/5/2019 1 H-115 50029236050000 2180530 2'2.5" 0.35 8.5" 5/4/2019 2 5/5/2019 1H-116 50029235940000 2180120 17" 0.25 7" 5/4/2019 1.7 5/5/2019 1H-117 50029236020000 2180320 1'11" 0.35 7"5/4/2019 1.7 5/5/2019 1H-118 50029235780000 2170840 2'4" 0.50 8.5" 5/4/2019 2 5/5/2019 1H-119 50029235910000 2171780 3' 0.80 8" 5/4/2019 1.8 1 5/5/2019 Originated: Seblumbeppri PTS- PRINTCENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: AOGCC `s \ ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 —9&k Anchorage, AK 99501 30500 TRANSMITTAL DATE TRANSMITTAL# � ' 1E-104 50-029-23234.29__LEA77-00006 KUPARUK RIVER WL (PROF INAL FFIELD 20 -Feb -19 1 1A-05 50.029-20627-00 EOSH-00028 KUPARUK RIVER WL 1A-07 50-029-20658-00 EOSH-00029 KUPARUK RIVER [PROF FINAL FIELD 16 -Mar -19 1 1H-118 50.029-23578-00 EOSH-00030 KUPARUK RIVER y�L IPROF FINAL FIELD 17 -Mar -19 1 2A-17 50.103-20193.00 EA77-00009 KUPARUK RIVER yyL IPROF FINAL FIELD 18 -Mar -19 1 2V-04 50-029-21041.00 EA77-00010 KUPARUK RIVER WL Caliper FINAL FIELD 18 -Mar -19 1 1H-114 3C -15A 50-029-23584.00 50-029-21426-01 EOSH-00031 EA77.00011 KUPARUK RIVER KUPARUK RIVER WL WL IPROF (PROF FINAL FIELD FINAL FIELD 19 -Mar -19 19 -Mar -19 1 1 LDL FINAL FIELD 20 -Mar -19 1 REG MAR AG 8 ittal Please via courier or sign/scan and ema Signature and CPAI. Schlumberger -Private ATransmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. • 21 70 84 29119 WELL LOG RECEIVED . MAR u 2 101$ PROACTIVE DIAGNOSTIC SERVICES, INC. AOGCC To: AOGCC Makana Bender 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road uite Anchorage, AK 99518 Fax: (907) 245-8952 1) Injection Profile 26-Jan-18 1H-118 Color Log/CD 50-0239-23578-00 2) Injection Profile 27-Jan-18 1H-105 Color Log/CD 50-029-20727-01 Signed : Date : 3// !s /l j Print Name: M C '_,. PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE((7' MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:Achives\MasterPemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx MEMORANDUM To: Jim Rpe' visor q P.I. Super '\ l ( /( FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, November 02, 2017 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA, INC. IH -118 KUPARUK RIV UNIT IH -118 Src: Inspector Reviewed By: P.I. Supry JQO— Comm Well Name KUPARUK RIV UNIT 1H-118 API Well Number 50-029-23578-00-00 Inspector Name: Lou Laubenstein Insp Num: mitLOL171031133436 Permit Number: 217-084-0 Inspection Date: 10/31/2017 Rel Insp Num: Thursday, November 02, 2017 Page I of I Packer Depth Pretest Initial I5 Min 30 Min 45 Min 60 Min Well IH -118 Type lnj w `TVD 3731 Tubing 1000 10;0 10:0 10 PTD 2170840 Type Testi SPT est pSl 1500 IA 100 810 711= 1.90 BBL Pumped: 08 BBL Returned: 0.7 OA I u, >10 40 Interval INITAL - �PIF P Notes: Initial MITIA for a new well Thursday, November 02, 2017 Page I of I DATA SUBMITTAL COMPLIANCE REPORT 1/10/2018 Permit to Drill 2170840 Well Name/No. KUPARUK RIV UNIT 11-1-118 MD 8131 TVD 4092 REQUIRED INFORMATION Completion Date 8/22/2017 Mud Log No V DATA INFORMATION List of Logs Obtained: GR/RES/CBL I to FLI Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ED C 28541 Digital Data ED C 28541 Digital Data ED C 28541 Digital Data ED C 28541 Digital Data ED C 28541 Digital Data Log C 28541 Log Header Scans Log C 28542 Log Header Scans ED C 28542 Digital Data ED C 28542 Digital Data ED C 28542 Digital Data ED C 28542 Digital Data AOGCC Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23578-00-00 Completion Status 1WINJ Current Status 1WINJ UIC No Samples No Directional Survey Yes 8/23/2017 (from Master Well Data/Logs) Log Log Run Interval OHI Scale Media No Start Stop CH Received 1922 8039 8/23/2017 _Comments _ Electronic Data Set, Filename: CPAI_1 H- 118_SCMT_18Augl7_MainPass_Log_6Up.las , 7744 8044 8/23/2017 Electronic Data Set, Filename: CPAI_1 H- 118_SCMT_18Augl7_RepeatPass_Log_4_Up.la . s 8/23/2017 Electronic File: CPAI_1H- 118_SCMT 18Aug17_MainPass_ConCu_R01_L. 00 Up_SCMT_PSTP_ERS.dlis 8/23/2017 Electronic File: CPAI_1 H- 118_SCMT_18Aug17_RepeatPass_ConCu_R01_• L004U p_SCMT_PSTP_E RS.dlis 8/23/2017 Electronic File: CPAI 1H- 118_SCMT_18Aug17_FieldPdnt.Pdf - 0 0 2170840 KUPARUK RIV UNIT 1H-118 LOG HEADERS 0 0 2170840 KUPARUK RIV UNIT 1H-118 LOG HEADERS 6904 7252 8/23/2017 -Electronic Data Set, Filename: CPAI_1H- 118_Packer_Corr_21Augl7_MainPass_Log_5_U , p.las 8/23/2017 Electronic File: CPAI_1H- 118_Packer_Com 21Augl7_MainPass_ConCu_ R03_L005Up_UPCT_E RS.dlis n 8/23/2017 Electronic File: CPAI_1H- r 118_Packer_Correlation_21Augl7.Pdf' 6904 7252 8/23/2017 Elecstr ', Data t, Filename: inp0 - 1 8 ac er C rr 21Au ainP ss og_5_U Page I of 7 Wednesday, January 10. 2018 DATA SUBMITTAL COMPLIANCE REPORT 111012018 Permit to Drill 2170840 Well Name/No. KUPARUK RIV UNIT 1H-118 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029.23578.00-00 MD 8131 TVD 4092 Completion Date 8/22/2017 Completion Status 1WINJ Current Status 1WINJ UIC No ED C 28542 Digital Data 8/23/2017 Electronic File: CPAI_1H- 118_P _ orr_21 g17_ ainP s_Co Gu ' 3 05Up_ ERS.dlis �,�% ED C 28542 Digital Data 8/23/2017 ctroni PAI 1H- "' " \ 1 _P ker_Cor _ tAug� ED C 28632 Digital Data 70 1729 9/22/2017 Electronic Data Set, Filename: CPAI 1H-118, VISION Resistivity_RM_LWD001.1as ED C 28632 Digital Data 1680 8131 9/22/2017 Electronic Data Set, Filename: CPAI 11-1-118 - VISION Resistivity_RM_LWD002.las ED C 28632 Digital Data 70 8131 9/22/2017 Electronic Data Set, Filename: CPAI 1H-118 VISION Resistivity RM.las ED C 28632 Digital Data 70 8131 9/22/2017 Electronic Data Set, Filename: CPAI 11-1- 118_Customer Channel LAS.Ias ED C 28632 Digital Data 9/22/2017 Electronic File: CPAI 111-118 VISION Resistivity. RM LWD001 DLIS.dlis ED C 28632 Digital Data 9/22/2017 Electronic File: CPAI 11-1-118 VISION Resistivity RM LWD001 DLIS.html ED C 28632 Digital Data 9/22/2017 Electronic File: CPAI 11-1-118 VISION Resistivity. RM LWD002 DLIS.dlis ED C 28632 Digital Data 9/22/2017 Electronic File: CPAI 11-1-118 VISION Resistivity RM LWD002 DLIS.html ED C 28632 Digital Data 9/22/2017 Electronic File: CPAI 11-1-118 VISION Resistivity. RM DLIS.dlis ED C 28632 Digital Data 9/22/2017 Electronic File: CPAI 11-1-118 VISION Resistivity RM DLIS.html ED C 28632 Digital Data Electronic File: CPAI 1H - n9/22/2017 Y 118_VISION_Resistivity_2in_MD.PDF ED C 28632 Digital Data 9/22/2017 Electronic File: CPAI _1H- 118_VISION_ Resistivity_2in_TVD.PDF- ED C 28632 Digital Data 9/22/2017 Electronic File: CPAI_11-1- P 118_VISION_Resistivity_5in_MD.PDF , ED C 28632 Digital Data 9/22/2017 Electronic File: CPAI 1H- 119 118_VISION_Resistivity_5in_TVD.PDF ' ED C 28632 Digital Data 9/22/2017 Electronic File: 11-1-118 NAD27 EOW Compass , Surveys [Canvas].W ED C 28632 Digital Data 9/22/2017 Electronic File: 111-118 NAD27 EOW Compass ' Surveys [Macro].txt AOGCC Page 2 of 7 Wednesday, January 10, 2018 DATA SUBMITTAL COMPLIANCE REPORT 1/1012018 Permit to Drill 2170840 Well Name/No. KUPARUK RIV UNIT 1H-118 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23578-00-00 MD 8131 TVD 4092 Completion Date 8/22/2017 Completion Status 1WINJ Current Status 1WINJ UIC No ED C 28632 Digital Data 9/22/2017 Electronic File: 1H-118 NAD27 EOW Compass Surveys [Petrel].txt ED C 28632 Digital Data 9/22/2017 Electronic File: 1H-118 NAD27 EOW Compass Surveys [Plan].txt ED C 28632 Digital Data 9/22/2017 Electronic File: 1H-118 NA027 EOW Compass Surveys.pdf ED C 28632 Digital Data 9/22/2017 Electronic File: 1H-118 NAD83 EOW Compass, Surveys [Canvas].txt ED C 28632 Digital Data 9/22/2017 Electronic File: 1H-118 NAD83 EOW Compass - Surveys [Macro].txt ED C 28632 Digital Data 9/22/2017 Electronic File: 1H-118 NAD83 EOW Compass* Surveys [Petrel].txt ED C 28632 Digital Data 9/22/2017 Electronic File: 1H-118 NAD83 EOW Compass, Surveys [Plan].txt ED C 28632 Digital Data 9/22/2017 Electronic File: 1H-118 NAD83 EOW Compass ' Surveys.pdf ED C 28632 Digital Data 9/22/2017 Electronic File: CPAI_1H-118_SurveyList.csv , Log C 28632 Log Header Scans 0 0 2170840 KUPARUK RIV UNIT 1H-118 LOG HEADERS ED C 28721 Digital Data 6958 7938 10/20/2017 Electronic Data Set, Filename: CPAI_1H- 118_WFL_160ct17_Depth_Confirmation_Log_5_ Up.Ias ED C 28721 Digital Data 43025 43025 10/20/2017 Electronic Data Set, Filename: CPAI 1H - 118_W FL_160ct17_Station_1460B W P D_7512ft_ Slow_Log_19Jas ED C 28721 Digital Data 43025 43025 10/20/2017 Electronic Data Set, Filename: CPAI 1H- 118_WFL_160ct17_Station_1460BWPD_7525ft_ - Slow_Log_18.las ED C 28721 Digital Data 43025 43025 10/20/2017 Electronic Data Set, Filename: CPAI_11H- 118_W FL_ 160017_Station_14606W PD_75351t_ Slow_Log_17.las ED C 28721 Digital Data 43025 43025 10/20/2017 Electronic Data Set, Filename: CPAI 1H - 118_W FL_160d17_Station_1460B W PD_7592ft_- Normal_Log_16.las ED C 28721 Digital Data 43025 43025 10/20/2017 Electronic Data Set, Filename: CPAI_1H- 118_W FL_160ct17_Station_146OBW PD_7592ft_ - Slow_Log_15.las AOGCC Page 3 of 7 Wednesday, January 10, 2018 DATA SUBMITTAL COMPLIANCE REPORT 1/1012018 Permit to Drill 2170840 Well Name/No. KUPARUK RIV UNIT 1W118 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23578.00-00 MD 8131 TVD 4092 Completion Date 8/22/2017 Completion Status 1WINJ Current Status 1WINJ UIC No ED C 28721 Digital Data 43025 43025 10/20/2017 Electronic Data Set, Filename: CPAI_1H- 118 WFL_160ct17_Station_7708WPD_7196ft_ Slow_Log_14.las ED C 28721 Digital Data 43025 43025 10/20/2017 Electronic Data Set, Filename: CPAI - _1H 118_W FL_ 160ct17_Station_77OB W PD_7375ft_ Slow_Log_13.las ED C 28721 Digital Data 43025 43025 10/20/2017 Electronic Data Set, Filename: CPAI - _1H 118_W FL_160ct17_Station_77OBW PD_7403ft_ Slow_Log_12.las ED C 28721 Digital Data 43025 43025 10/20/2017 Electronic Data Set, Filename: CPAI_1H- 118_WFL_160ct17_Station_770E1WPD_7418ft_ - Slow_Log_11.1as ED C 28721 Digital Data 43025 43025 10/20/2017 Electronic Data Set, Filename: CPAI_1H- 118_W FL_16Oct17_Station_770BW PD_7512ft_ - Slow_Log_10.las ED C 28721 Digital Data 43025 43025 10/20/2017 Electronic Data Set, Filename: CPAI_1H- 118_W FL_160ct17_Station_770B W PD_7525ft_. Slow_Log_9.las ED C 28721 Digital, Data 43025 43025 10/20/2017 Electronic Data Set, Filename: CPAI 1H - 118_W FL_ 160ct17_Station_77OB W PD_7535ft_ Slow_Log_8.las ED C 28721 Digital Data 43024 43025 10/20/2017 Electronic Data Set, Filename: CPAI 1H- 118_WFL_160ct17_Station_770BWPD_7592ft_ Slow_Log_Ties ED C 28721 Digital Data 43024 43024 10/20/2017 Electronic Data Set, Filename: CPAI _1H 118_WFL_160ct17_Station_77OBD_7650ft_ ' WP- Slow_Log_6.las ED C 28721 Digital Data 43024 43024 10/20/2017 Electronic Data Set, Filename: CPAI_1H- 118_W FL_160ct17_Station_770BW PD_7900ft_F ast_Log_4.las ED C 28721 Digital Data 43024 43024 10/20/2017 Electronic Data Set, Filename: CPAI_1H- 118_W FL_160ct17_Station_77OB W PD_7900ft_' Normal_Log_3.las ED C 28721 Digital Data 43024 43024 10/20/2017 Electronic Data Set, Filename: CPAI_1H- 118_W FL_16Oct17_Station_770BW PD_7900ft_. Slow_Log_5.las ED C 28721 Digital Data 10/20/2017 Electronic File: CPAI 1H - 118_W FL_160ct17_Depth_Conftmiation_ConCu _RC1 _LO05Up_RST_PSTP.dlis AOGCC Page 4 of 7 Wednesday, January 10, 2018 DATA SUBMITTAL COMPLIANCE REPORT 1/1012018 Permit to Drill 2170840 Well Name/No. KUPARUK RIV UNIT 11-1-118 MD 8131 TVD 4092 Completion Date 8/22/2017 ED C 28721 Digital Data ED C 28721 Digital Data ED C 28721 Digital Data ED C 28721 Digital Data ED C 28721 Digital Data ED C 28721 Digital Data ED C 28721 Digital Data ED C 28721 Digital Data ED C 28721 Digital Data ED C 28721 Digital Data ED C 28721 Digital Data ED C 28721 Digital Data ED C 28721 Digital Data AOGCC Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23578-00-00 Completion Status 1WINJ Current Status 1WINJ UIC No 10/20/2017 Electronic File: CPAI_1H- 118_WFL_ 160ct17_Station_146OBWPD 7512ft_ Slow_ConCu_RO1 _Sta019_RST_PSTP.dlis 10/20/2017 Electronic File: CPAI_1H- 118_W FL_16Oct17_Station_1460B W PD_7525ft_ Slow_ConCu_ROt_Sta018_RST_PSTP.dlis 10/20/2017 Electronic File: CPAI_1H- 118_WFL_160017_Station 1460BWPD_7535ft Slow_ConCu_RO1 _Sta017_RST_PSTP.dlis 10/20/2017 Electronic File: CPAI_1H- 118_WFL_ 160ct17_Station_146OBWPD 7592ft_ Normal_ConCu_R01_Sta016_RST_PSTP.dlis 10/20/2017 Electronic File: CPAI_1H- 118_W FL_l60ctl7_Station_146OBW PD_7592ft_ Slow_ConCu_R01_Sta015_RST_PSTP.dlis 10/20/2017 Electronic File: CPAI_1H- 118_W FL_l60ctl7_Station_770BW PD_7196ft_ Slow_ConCu_RO1_Sta014_RST_PSTP.dlis ' 10/20/2017 Electronic File: CPAI_1H- 118_WFL_160017_Station 77OBWPD 7375ft Slow_ConCu_Rol _Sta013_RST_PSTP.dlis ' 10/20/2017 Electronic File: CPAI_1 H - 118_W FL_160ct17_Station_77OBW PD_7403ft_ Slow_ConCu_RO1 _Sta012_RST_PSTP.dlis 10/20/2017 Electronic File: CPAI1H- 118_WFL_160ct17__Station 77OBWPD 7418ft Slow_ConCu_RO1_Sta011_RST_PSTP.dlis ' 10/20/2017 Electronic File: CPAI_1H- 118_WFL_160ct17_Station 77OBWPD 7512ft_ Slow_ConCu_RO1 _Sta010_RST_PSTP.dl is 10/20/2017 Electronic File: CPAI_1H- 118_WFL_t6Oct17_Station_770BWPD 7525ft_ Slow_ConCu_ROt_Sta009_RST_PSTP.dlis ' 10/20/2017 Electronic File: CPAI_1H- 118_WFL_160ct17 Station_770BWPD_7535ft_ , Slow_C0nCu_R01 _Sta008_RST_PSTP.dlis 10/20/2017 Electronic File: CPAI_1 H - 118_W FL_160ct17_Station_770BW PD_7592ft_ Slow_ConCu_RO1 _Sta007_RST_PSTP.dl is Page 5 of 7 Wednesday, January 10, 2018 DATA SUBMITTAL COMPLIANCE REPORT 1/10/2018 Permit to Drill 2170840 Well Name/No. KUPARUK RIV UNIT 1H-1118 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50.029-23578-00-00 MD 8131 TVD 4092 Completion Dale 8/22/2017 Completion Status 1WINJ Current Status 1WINJ UIC No ED C 28721 Digital Data 10/20/2017 Electronic File: CPAI_lH- 118_WFL_160ctl7_Station_770BWPD_7650ft_ , Slow_ConCu_R01 _Sta006_RST_PSTP.dlis ED C 28721 Digital Data 10/20/2017 Electronic File: CPAI_1H- 118_WFL_160ctl7_Station_770BWPD_7900ft_F - ast_ConCu_R01_Sta004_RST_PSTP.dlis ED C 28721 Digital Data 10/20/2017 Electronic File: CPAI_lH- 118_WFL_l6Octl7_Station_770BWPD_7900ft_ . Normal_ConCu_R01_Sta003_RST_PSTP.dlis ED C 28721 Digital Data 10/20/2017 Electronic File: CPAI_lH- 118_WFL_160ctl7_Station 770BWPD 7900ft_ - Slow_ConCu_Rol _Sta0D5_RST_PSTP.dl is ED C 28721 Digital Data 10/20/2017 Electronic File: CPAI 1H- 118_WFL 160ct17 FieldPrint.Pdf Log C 28721 Log Header Scans 0 0 2170840 KUPARUK RIV UNIT 1H-118 LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report oY Production Test Information Y /® Geologic Markers/Tops OY COMPLIANCE HISTORY Completion Date: 8/22/2017 Release Date: 7/7/2017 Description AOGCC Directional / Inclination Data D Mechanical Integrity Test Information �Y-/-1� Daily Operations Summary Date Comments Page 6 of 7 Mud Logs, Image Files, Digital Data Y Core Chips Y / Composite Logs, Image, Data Files Cy Core Photographs Y /6) Cuttings Samples Y/6 Laboratory Analyses Y /Q Wednesday, January 10, 2018 DATA SUBMITTAL COMPLIANCE REPORT 1/10/2018 Permit to Drill 2170840 Well Name/No. KUPARUK RIV UNIT 1H-118 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23578-00-00 MD 8131 TVD 4092 Completion Date 8/22/2017 Completion Status 1WINJ Current Status 1WINJ UIC No Comments: Compliance Reviewed By: V""��_ �— - - Date: AOGCC Page 7 of 7 Wednesday, January 10, 2018 RECEIVED Originated: Schlumberger OCT 2 0 2017 PTS - Sure CENTER AOGCC 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: Makana K Bender Natural Resources Tecluuclan 11 Alaska Oil & C -a9 Cnnaervaiion Gommaa�on • 217084 7TRANSMITTALDATEMITTAL# r• DATA LOGGED %0 /411/201'( M. K. BENDER WELL NAME 2G -OS 1G- 1H-0404 2H-09 2V-01 2W-12 1H-118 1H-102 API # 50-029.21125.00 50-029-20908.00 50.029-20770-00 50-103-20050-00 50-029-21034.00 50.029-21240-00 50-029-23578-00 50-029-23580-00 ORDERSERVICE # DSOS-00066 DM87-00131 DM87-00132 DM87.00133 6M87.00134 DM87-00135 DM87-00136 DM87-00137 FIELD NAME DESCRIPTION KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER DELIVERABLE WL WL WL WL WL WL WL WL DESCRIPTIONDATA Tubing IPROF IPROF PPROF Caliper PPROF RST,WFL USIT D. FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD TELOGGED 5.Oct-17 11 -Oct -17 12 -Oct -17 13 -Oct -17 14 -Oct -17 15.Oct-17 16 -Oct -17 18 -Oct -17 Prints 1 1 1 1 1 1 1 1 CD's 1 1 1 1 1 1 1 1 8 8 Receipt Print Name A Transmittal Receipt signature confirms that a package (box, �L _ envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. Signature Date specific content of the CDs and/or hardcopy prints may or ma Please return via courier or sign/scan and email a copy to Schlumberger. Y not have been verified for correctness or quality level at this point. RECEIVE® meerger AOGCOransmittal#: 21SEP17-SP01 Drilling & Measurements Product Delivery DATA LOGGED %0/7—/201-7 A K. BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well Name: 1H-118 Date Dispatched: 21 -Sep -17 Service Order #: 17AKA0010 Dispatched By: Stephanie Pacillo Product Description Hardcopy Digital Copy Logging Date Color Log Prints: 4 Contents on CD 16 -Aug -17 VISION Resistivit 2" MD x x 2" TVD x x 5" MD x x 5' TVD x x Digital Data N/A Contents on CD LAS/DLIS Data x Surveys 2 Contents on CD Directional Survey Nad27 x x Directional Survey Nad83 x x CD 1 Contents on CD Data: DLIS/ LAS x Graphics: PDF x Surveys: PDF/TXT x Please sign and email a copy to: Please sign and email a copy to: Tom Osterkamoaconocoohillios com AlaskaPTSPrintCenter(a)slb com Attn: Tom Osterkamp Attn: Stephanie Pacillo Received By: 21 7084 28632) LFINAL NADConversion Kuparuk River Unit Kuparuk 1H Pad 1H-118 IH -118 RECEIVED SEP 2 2 2017 AOGCC ConocoPhillips Definitive Survey Report 23 August, 2017 001 21 7084 28632 ConocoPhillips ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well TD: 1 H-118 Project: Kuparuk River Unit TVD Reference: 1 H-118 actual @ 92.85usft (Doyon 142) Site: Kupamk 1 H Pad MD Reference: 1 H-118 actual @ 92.85usft (Doyon 142) Well: TD: 1H-118 North Reference: True Wellbore: 1H-118 Survey Calculation Method: Minimum Curvature Design: 1H-118 Database: OAKEDMP2 Iroject Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level ;so Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor well TD: 1H-118 Audit Notes: From To Veil Position +N/ -S 0.00 usft Northing: 5,981,081.27 usft Latitude: 70" 21'32.750 1 834.00 1 H-118 Srvy 1 - SLB NSG+SSHOT (1 H- +E/ -W 0.00 usft Easting: 549,546.89 usft Longitude: 149° 35' 51.236 V -osition Uncertainty 1,749.06 0.00 usft Wellhead Elevation: usft Ground Level: 54.00 usf Wellbore 1H-118 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 1°I (I K) BGGM2017 8/20/2017 17.53 80.95 57,493 Design 1H-118 Date Audit Notes: From To Version: 1.0 Phase: ACTUAL Tie On Depth: 38.85 Vertical Section: Depth From (TVD) -NI-S +E/ -W Direction 834.00 1 H-118 Srvy 1 - SLB NSG+SSHOT (1 H- (usft) (usft) (usft) (°) 862.92 38.85 0.00 0.00 0.00 Survey Program Date From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 100.00 834.00 1 H-118 Srvy 1 - SLB NSG+SSHOT (1 H- GYD-GC-SS Gyrodata gyro single shots BIM017 8:41:0 862.92 1,655.471H-118 Srvy 2-SLBMWD+GMAG(1H- MWD+IFR-AK-SCC MWD+IFR AK SCC Sperry 8/8/2017 9:04:0 1,749.06 8,058.061H-118 Srvy 3-SLB_MWD+GMAG(11-1- MWD+IFR-AK-SCC MWD+IFR AK SCC Sperry 8/122017 8:53: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) C) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 38.85 coo 0.00 38.85 -54.00 0.00 0.00 5,981,08127 549,54689 0.00 0.00 UNDEFINED 100.00 0.34 33.06 100.00 7.15 0.15 0.10 5,981,081.42 549,546.99 0.56 0.15 GYD-GC-SS (1) 102.00 0.34 33.06 102.00 9.15 0.16 0.11 5,981,081.43 549.546.99 0.00 0.16 NOT en qday Survey 20" 200.00 0.37 28.25 200.00 107.15 0.69 041 5,981,06198 549,547.30 0.04 0.69 GYD-GC-SS(1) 300.00 0.65 27.72 299.99 207.14 1.47 0.83 5,981,08274 549,54731 0.28 1.47 GYD-GC-SS(1) 400.00 1.17 48.68 399.98 307.13 265 186 5,981,083.93 549.548.73 0.61 2.65 GYD-GC-SS(1) 500.00 1.74 62.79 499.95 407.10 402 3.98 5,981,085.31 549,550.84 0.67 4.02 GYD-GC-SS(1) 582.00 2.49 72.59 581.89 489.04 5.12 6.78 5,981,086.43 549,553.64 1.01 5,12 GYD-GC-SS(1) 675.00 3.03 89.80 674.79 581.94 5.73 11.17 5,981,08707 549,558.02 1.06 5.73 GYD-GC-SS (1) 771.00 3.94 WAS 770.61 677.76 5.20 16.96 5,981,086.58 549,563.81 1.13 5.20 GYD-GC-SS(1) 834.00 5.44 91,89 833.40 740.55 4.74 22.08 5,981,086.16 549,568.93 2.57 4.74 GYD-GC-SS(1) 8/232077 3:44 58P Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well TD: 1 H-118 Project: Kuparuk River Unit TVD Reference: 1HA18 actual @ 92.85usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1H-118 actual @ 92.85usft (Doyon 142) Well: TO: 11-1-118 North Reference: True Wellbore: 1H-118 Survey Calculation Method: Minimum Curvature Design: 111-118 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100-) (ft) Survey Tool Name 862.92 605 90.60 862.17 769.32 468 24.97 5,981,086.11 549,571.83 2.16 4.68 MWD+IFR-AK-SCC(2) 957.91 8.19 82.37 95643 863.58 5.53 36.69 5,981,08704 549,583.54 249 5.53 MWD+IFR-AK-SCC(2) 1,05326 8.00 72.22 1,050.83 957.98 8.46 49.74 5,981,090.05 549,598.56 1.51 8.46 MWD+IFR-AK-SGC(2) 1,147,84 8.61 68.66 1,144.39 1,051.54 13.10 62.75 5,98109478 549,609.55 1.02 13.10 MWD+IFR-AK-SCC(2) 1,242.04 11.51 69.46 1,237.11 1,144.26 1902. 78.28 5,981,10081 549,625.03 2.87 19.02 MWD+IFR-AK-SCC (2) 1,33643 13.65 71.28 1,329.23 1,236.38 25.90 9764 5.961,107.81 549,644.35 2.31 25.90 MWD+IFR-AK-SCC(2) 1,431.09 15.94 66.75 1,420.75 1,327.90 34.62 120.17 5,981,11868 549,66681 2.71 34.62 MWD -IFR -AK -SCC (2) 1,527.44 17.55 64.55 1.513.01 1420.16 46.09 14544 5,981,128.31 549,692.01 1.80 46.09 MWD+IFR-AK-SCC(2) 1,621.51 18.00 66.47 160259 1.509]4 57.98 171.58 5,981,140.38 549,718.06 0.79 57.98 MWDOFR-AK-SCC(2) 1,65547 19.11 6570 1,634]8 1,541.93 6237 181.45 5.981,144.83 549,727.91 3.35 62.37 MWD+IFR-AK-SCC(2) 1,719.00 20.54 65.78 1,694.55 1,601.70 7122 201.10 5,981,153.81 549,74749 224 71.22 10-3/4" z 13-1/2" . 1,749.06 21.21 65.82 1,722.63 1,629.78 75.61 210.85 5.981,158.26 549,757.23 2.24 75.61 MWD+IFR-AK-SCC (3) 1,810.71 23.37 64.75 1,779.67 1,686.82 85.39 232.10 5,981,168.18 549,77840 3.56 85.39 MWD+IFR-AK-SCC(3) 1,904.28 27.10 63.74 1,864.30 1,771.45 102.74 268.01 5.981,185.77 549,814.19 401 102.74 MW0+IFR-AK-SCC(3) 1,999.85 2980 62.25 1,948.32 1,85547 123.44 308.55 5,981206.73 549,85459 2.92 123.44 MWD+IFR-AK-SCC(3) 2,043.58 3174 61.59 1,985.89 1,893.04 133.97 328.29 5,981,217.39 549,874.26 4.50 133.97 MWD+IFR-AK-SCC(3) 2,094.55 34.56 60.37 2,028.56 1,935.71 147.50 352.66 5,961,23108 549,898.53 569 147.50 MWD+IFR-AK-SCC (3) 2.189.41 39.80 58.49 2,104.12 2,011.27 176.69 401.96 5,981,260.60 549,947.64 5.65 176.69 MWD+IFR-AK-SCC(3) 2,284.04 45.65 55.40 2,173.61 2,060.76 211.77 455.69 5,981,296.02 550,001.12 6.57 211.77 MWD+IFR-AK-SCC (3) 2,380.98 5038 53.68 2,238.19 2,145.34 253.72 514.51 5,981,338.36 550,05966 545 253.72 MWD+IFR-AK-SCC(3) 2,473.74 54.72 5309 2,294.33 2201.48 297.76 573.76 5,981,382.78 550,118.61 4.28 29776 MWD+IFR.AK-SCC(3) 2,568.39 59.32 51.96 2,345.84 2,252.99 346.07 836.74 5,981,431.50 550,181.27 4.96 348.07 MWD+IFR-AK-SCC(3) 2,65264 84.06 50.71 2,390.52 2,297.67 397.91 701.50 5,981,483.77 550,24567 5.18 397.91 MWD+IFR-AK-SCC (3) 2,75779 68.58 5049 2,428.73 2,335.88 453.20 76882 5,981,53950 550,312.61 4.76 45320 MWD+IFR-AK-SCC(3) 2,852.00 72.57 49.87 2,460.05 2,367.20 510.09 837.04 5,981,596.84 550,380.45 4.28 510.09 MWD+1FR-AK-SCC (3) 2,94691 74.95 4842 2,486.59 2,393.74 56970 905.95 5,981,656.89 550,448.96 291 569.70 MWD+IFR-AK-SCC(3) 3,039.87 7528 45.89 2,510.48 2,41763 630.79 971.81 5,981]1841 550,51441 2.65 630.79 MWD+IFR-AK-SCC(3) 3,13582 75.18 43.53 2,534.94 2,442.09 69672 1,037.08 5,981,78476 550,579.24 2.38 696]2 MWD+IFR-AK-SCC(3) 3,230.52 75.27 43.71 2,559.09 2,46624 763.01 1,100.25 5,981,851.46 550,641.96 0.21 763.01 MWD+IFR-AK-SCC(3) 3,326.05 75.33 43.23 2,583.33 2,490.48 830.07 1,163.82 5,981,918.94 550,705.08 0.49 830.07 MWD+IFR-AK-SCC (3) 341960 75.33 44.07 2,607.03 2,514.18 895.55 1,226.29 5,981,98482 550,767.11 0.87 895.55 MWD+IFR-AK-SCC(3) 3,515.01 7540 44.49 2,831.13 2538.28 961.64 1,290.74 5,982,051.33 550,831.11 0.43 96164 MWD+IFR-AK-SCC(3) 3,610.29 75.16 45.84 2,655.34 2.562.49 1,026.61 1,356.09 5,982,11613 550,896.02 1.39 1,02861 MWD+IFR-AK-SCC (3) 3,704.55 74.27 46.19 2,680.19 2,587.34 1,089.76 1,421.51 5,982,180.30 550,961.02 1.01 1,08976 MWD+IFR-AK-SCC(3) 3,798.88 74.35 4788 2,705.70 2,612.85 1,151.65 1,48796 5,982,242.62 551,027.05 1.73 1,151.65 MWD+IFR-AK-SCC(3) 3,893.50 74.42 48.46 2,731.17 2638.32 1,21243 1,555.86 5,982,30384 551,094.55 0.59 1,212.43 MWD+IFR-AK-SCC(3) 3,988.00 74.22 48.21 2.756.71 2,663.86 1,272.91 1,623.83 5,982,364.77 551,162.11 0.33 1.272.91 MWD+IFR-AK-SCC(3) 4,083.03 74.20 47.88 2,782.57 2,689.72 1,334.17 1,69172 5,982,426.47 551,229.58 0.56 1,334.17 MWD+IFR-AK-SCC(3) 4,17742 74.14 46.99 2,808.32 2,715.47 1,395.73 1,75848 5,982,488.46 551,295.93 0.69 1 395.73 MWD+IFR-AK-SCC (3) 823/2017 3:44:58PM Page 3 COMPASS 5000 14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well TD: 1 H-116 Project: Kuparuk River Unit TVD Reference: 1 H-118 actual Qa 92.85usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1H-118 actual @ 92.85usfl (Doyon 142) Well: TD: 1H-118 North Reference: True Wellbore: 11-1-118 Survey Calculation Method: Minimum Curvature Design: 1H-118 Database: OAKEDMP2 Survey Map Map Vertical MD Inc AN TVD TVDSS +N1S +EAW Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1108') (ft) Survey Tool Name 4,272.11 74.21 46.39 2,834.14 2,741.29 1,45822 1,82477 5,982,551.38 551,361.80 061 1,458.22 MWD+1FR-AK-SCC(3) 4,367.15 74.26 46.84 2.859.96 2,767.11 1,521.05 1,891.24 5,982,614.64 551,427.65 0.46 1521.05 MWD+1FR-AK-SCC(3) 4,461.07 74.26 47.59 2,885.44 2,792.59 1,58245 1,957.59 5,982,676.48 551,493.78 0.77 1,582.45 MWD+IFR-AK-SCC(3) 4,555.74 74.17 49.02 2.911.20 2,818.35 1.643.04 2.025.61 5,982,73751 551,56139 1.46 1643.04 MWD+IFR-AK-SCC(3) 4,651.15 74.30 50.34 2,937.12 2.844.27 1,702.45 2,095.62 5,982.797.38 551,630.99 1.34 1,702.45 MWD+IFR-AK-SCC(3) 4,745.40 74.20 48.99 296270 2,869.85 1,761.17 2,164.76 5,982,856.54 551,69934 1.38 1,761.17 MWD+IFR-AK-SCC(3) 4,84029 74.35 4797 2,968.42 2,895.57 1.821.71 2,233.15 5,982,917.53 551767.72 1.05 1,821.71 MWD+IFR-AK-SCC(3) 4,934.86 7432 46.23 3,013.96 2,921.11 1,883.69 2,299.85 5,982,979.95 551,83400 1.77 1,883.69 MWD+IFR-AK-SCC(3) 5029.00 74.32 45.53 3,039.40 2,946.55 1,946.79 2,364.91 5,983,043.47 551,898.64 0,72 1,946.79 MWD+IFR-AK-SCC(3) 5,124.91 74.32 44.72 3,065.32 2.972.47 2,011.94 2,430.35 5,983,109.05 551,96364 0.81 2,01194 MWD+IFR-AK-SCC(3) 5,219.45 74.32 44.34 3,090.87 2,998.02 2,076.83 2,494.18 5,993.174.35 552,027.04 0.39 2,076.83 MWD+IFR-AK-SCC (3) 5,313.93 74.23 43.43 3,116.48 3,023.63 2,142.38 2.557.23 5,983,240.30 552,08964 0.93 2,142.38 MWD+1FR-AK-SCC (3) 5,408.34 74.32 42.79 3,142.07 3,U9 22 2,208.72 2.619.33 5,983,307.05 552,151.30 0.66 2,208.72 MWD+IFR-AK-SCC(3) 5,50285 7441 42.77 3,167.54 3,074.69 2,275.52 2,681.14 5,983,37425 552,212.66 0.10 2,275.52 MWD+IFR-AK-SCC(3) 5,597.58 74.25 43.26 3,193.13 3,100.28 2,342.21 2,743.37 5,983,44135 552,274.43 0.53 2,342.21 MWD+IFR-AK-SCC (3l 5,691.24 74.34 41.98 3,21848 3,125.63 2,408.56 2,80442 5,983,508.09 552.335.04 1.32 2,408.56 MWD+IFR-AK-SCC(3) 5,786.63 7380 4063 3,244.66 3,151.81 2,477.46 2,864.96 5.983,57738 552,395.12 1.47 2,477.46 MWD+1FR-AK-SCC(3) 5,88102 72.69 37.94 3,271.88 3.179.03 2,547,40 2,922.19 5,983,64770 552,451.88 2.97 2,54140 MWD+IFR-AK-SCC(3) 5,975.43 71.59 36.01 3,30083 3,207.98 2,619.18 2,97624 5,983,719.83 552,505.45 2.27 2,619.18 MWD+IFR-AK-SCC(3) 6,070.43 71.21 34.57 3,331.14 3,238.29 2692.67 3,028.25 5,983.79365 552.556.97 1.49 2,692.67 MWD+IFR-AK-SCC(3) 6.164.93 71.09 31.88 3,361.67 3.268.82 2,767.48 3,077.25 5,983,86877 552,605.47 2.70 2,767.48 MWD+IFR-AK-SCC(3) 6,25940 69.54 3182 3,393.49 3,300.64 2,843.03 3,124.19 5,983,94463 552,651.90 1.64 2.84303 MWD+IFR-AK-SCC(3) 6354.10 68.75 29.24 3,427.21 3,334.36 2,919.25 3,169.14 5,964,021.13 552,696.34 2.68 2,919.25 MWD+IFR-AK-SCC(3) 6,401.98 66.35 27.32 3,444.72 3,351.87 2,958.49 3,190.25 5,984,060.51 552,717.19 3.82 2,958.49 MWD+IFR-AK-SCC(3) 6,448.31 67.96 2501 3,461.96 3,369.11 2,997.08 3,209.22 5,984,099.22 552735.90 4.70 2,997.08 MWD+IFR-AK-SCC(3) 6,510.17 67.08 21.61 3,485.62 3,392.77 3,049.56 3,231.83 5,984,15184 552,758.17 527 3,049.56 MWD+1FR-AK-SCC(3) 6,543.85 66.78 19.56 3,498.62 3,40597 3,078.57 3,242.73 5,W180 92 552,768.87 5.67 3,078.57 MWD+1FR-AK-SCC(3) 6,600.41 66.67 16.90 3,521.17 3,428.32 3,12791 3,258.98 5,984,230.36 552,784.79 4.32 3,127.91 MWD+IFR-AK-SCC(3) 6,637.74 66.26 1671 3,536.08 3,443.23 3,160.67 3,268.88 5,9U,263 19 552,794.47 1.19 3,16067 MWD+IFR-AK-SCC(3) 6,732.68 66.86 13.31 3,573.86 3,481,01 3,24479 3,291.43 5,984,347.45 552,816.46 3.35 3,244.79 MWD+1FR-AK-SCC (3) 6,62616 67.M 8.57 3,61069 3,517.84 3,329.76 3,307.85 5,984432.51 552,832.32 4.64 3,329.76 MWD+IFR-AK-SCC(3) 6,904.25 67.50 4.99 3,64063 3,54778 3,400.73 3,31628 5,984,503.52 552,840.28 4.30 3,400.73 MWD+IFR-AK-SCC(3) 6,921.67 67.59 4.08 3,64728 3,55443 3,416.77 3,31].55 5,984,519.58 552,841.45 4.86 3,416.77 MWD+IFR-AK-SCC(3) 7,016.17 67.96 0.58 3,683.04 3,590.19 3,504.16 3,321.11 5,9U.606 98 552,844.42 3.45 3,504.16 MWD+1FR-AK-8CC (3) 7,111.18 68.26 356.50 3,718.47 3,625.62 3,592.27 3,318.86 5,984,695.06 552.841.59 4.00 3,592.27 MWD+IFR-AK-SCC (3) 7,205.54 68.58 353.87 3,753.18 3,660.33 3,679.70 3,311.49 5.984,782.43 552,833.64 2.61 3,679.70 MWD+IFR-AK-SCC(3) 7,300.26 68.35 353.69 3,787.95 3,695.10 3,767.29 3,301.94 5,984,869.95 552,823.52 0.30 3,767.29 MWD -IFR -AK -SGC (3) 7,395.12 68.41 355.20 3,822.91 3,730.06 3,855.06 3,29341 5,984,957.65 552,814.40 148 3,855.06 MWD+IFR-AK-SCC(3) 7,489.30 68.64 355.84 3,857.38 3,764.53 3,942.43 3,286.56 5,985,044.97 552,806.98 0.68 3,942.43 MWD+IFR-AK-SCC (3) 7,584.71 68.50 356.30 3,892.24 3,799.39 4,031.03 3,280.47 5.985,133.52 552,800,31 0.47 4,031.03 MWD+1FR-AK-SCC(3) 8/23/2017 3:44:58PM Page 4 COMPASS 500014 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well TD: 1 H-118 Project: Kuparuk River Unit TVD Reference: 1H-118 actual @ 92.85usit (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1H-116 actual @ 92.85usft (Doyon 142) Well: TD: 1H-118 North Reference: True Wellbore: 1H-118 Survey Calculation Method: Minimum Curvature Design: 1 H-116 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7.679.25 68.57 357.88 3,926.84 3,833.99 4,118.90 3,276.01 5,985,22135 552,795.26 1.56 4,118.90 MWD+IFR-AK-SCC(3) 7,774.16 68.57 35744 3,961.52 3,868.67 4,207.17 3,272.40 5,985,309.59 552,791.07 043 4,207.17 MWD+IFR-AK-SCC(3) 7,868.62 6845 357.44 3,996.12 3,903.27 4,29498 3,268.48 5,985,397,36 552,786.57 0.13 4,294.98 MWD+IFR-AK-SCC(3) 7,98347 68.55 357.91 4,030.89 3,938.04 4,383.16 3,264.90 5,985,485.50 552,782.40 0.47 4,383.16 MWD+IFR-AK-SCC(3) 8,058.06 68.57 358.41 4,065.46 3,972.61 4,471.16 3,262.07 5,985,57347 552,77899 0.49 4,471.16 MWD+IFR-AK-SCC(3) 8,121.00 68.57 35841 4,088.46 3,995.61 4,529.72 3,260.44 5,985,632.02 552,776.98 0.00 4,529.72 (�T NAOhtal $MVey 7" z 8.1/2" 8.131.00 68.57 35841 4,092.11 3,999.26 4,539.03 3.280.18 5,985,641.32 552,776.66 DOD 4,539.03 PROJECTED to TO (Final Definitive Survey Verified and Signed -off All targets andlor well position objectives have been achieved. 2 Yes ❑ No I have checked to the best of my ability that the following data is correct: El Surface Coordinates 0 Declination & Convergence G GRS Survey Corrections [ Survey Tool Codes DgWIlligredby Banton SLB DE: Brandon Temple Nc°20170823 K54U4(rOD D9blysi9re,l b/ Ben TaNan Client Representatives Ea i64n� _060a 7e924099920 Date 8/23/2D17 8/232017 3: 44: 58PM Page 5 COMPASS 5000.14 Build 85 RECEIVED SEP 2 2 2017 FINAL AOGCC ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad 1H-118 1H-118 ConocoPhillips Definitive Survey Report 23 August, 2017 21 7084 28632 J ConocoPhillips Company: ConocoPhillips(Alaska) Inc.-Kupl Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: TD: 1H-118 Wellbore: 1H-118 Design: 1H-118 ConocoPhillips Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method; Database: Well TD: 1 H-118 - Slot 1H-118 1H-118 actual tQ 92.85usft (Doyon 142) 1H-118 actual @ 92.85usft (Doyon 142) True Minimum Curvature OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well TD: 1H -118 -Slot 1H-118 Audit Notes: From Well Position +NIS 0.00 usft Northing: 5,980,833.04 usft Latitude: 70" 21'31.703 N Vertical Section: +E/ -W 0.00 usft Easting; 1,689,578.57 usft Longitude: 149° 36'2.450 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 54.00 usft Wellbore 1H-118 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2017 8/20/2017 17.53 80.95 57,492.40 Design 1H-118 Date 8/23/2017 Audit Notes: From To Map Version: 1.0 Phase: ACTUAL Tie On Depth: 38.85 Vertical Section: Depth From (TVD) -NIS +E/ -W Direction 834.00 1 H-118 Srvy 1 - SLB_NSG+SSHOT (1 H- (usft) (usft) (usft) (°) 862.92 38.85 0.00 0.00 0.00 Survey Program Date 8/23/2017 From To Map Map (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 100.00 834.00 1 H-118 Srvy 1 - SLB_NSG+SSHOT (1 H- GYD-GC-SS Gyrodata gyro single shots 8/82017 8:414 862.92 1,655.471H-118 Srvy 2- BILE; _MWD+GMAG(1H- MWD+IFR-AK-SCC MWD+IFR AK SCC Sperry 8/8/2017 9:04:1' 1,749.06 8,058+061H-118 Srvy 3-S1-B_MWD+GMAG(1 H. MWD+IFR-AK-SCC MWD+IFR AK SCC Sperry 8/12/2017 8:53: Survey 8/2312017 2.50-22PM Page 2 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Av TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) (1 (') (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 38.85 0.00 0.00 38.85 -54.00 0.00 000 5,980,83304 1,689,578.57 0.00 0.00 UNDEFINED 10000 0.34 33.06 100.00 7.15 0.15 0.10 5,980,833.19 1,689,578.67 0.56 0.15 GYD-GC-SS(1) 102.00 0.34 33.06 102.00 9.15 0.16 0.11 5,980,833.20 1,689,57868 0.00 0.16 NOT an AcWal SUrvq 20" 200.00 0.37 28.25 200.00 107.15 0.69 0.41 5,980,833.72 1,689,57898 0.04 069 GYD-GC-SS(1) 300.00 0.65 27.72 299.99 207.14 1.47 0.83 5,980,834.51 1;689,579.39 0.28 1,47 GYD-GC-S$ (1) 400.00 1.17 4868 399.98 307.13 265 1.86 5,980,835.70 1,689,580.41 061 2.65 GYD-GC-SS(1) 500.00 174 62.79 49995 407.10 4.02 3.98 5.980,837,08 1,689,582.52 0.67 402 GYD-GC-SS(1) 58200 2.49 72.59 581.89 489.04 5.12 6.78 5,960,838.20 1,689,585.32 1.01 5.12 GYD-GC-SS (1) 675.00 3.03 89.60 674.79 581.94 573 11.17 5,980,838.84 1,689,589.70 1.06 573 GYD-GC-SS(1) 771.00 3.94 99.48 770.61 67776 5.20 16.98 5,980,838.34 1,689,595.50 1.13 5.20 GYD-GC-SS(1) 834.00 5.44 91.89 833.40 740.55 474 22.08 5,980,837.92 1,689,600.62 2.57 4.74 GYD-GC-SS(1) 8/2312017 2.50-22PM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 1H Pad MD Reference: Well: TD: 1H-118 North Reference: Wellbore: 1 H-118 Survey Calculation Method: Design: 1H-118 Database: Well TD: 11-1-118- Slot 1 H-118 11-1-118 actual @ 92.85us1t (Doyon 142) 1H-118 actual @ 92.85usft (Doyon 142) True Minimum Curvature OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +i +E/ -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) (°1100.) (ft) Survey Too] Name 86292 6.05 90.60 %2.17 769.32 4.68 24.97 5,98,837.86 1,689,60351 2.16 468 MWD+IFR-AK-SCC(2) 957.91 8.19 82.37 958.43 863.58 5.53 36.69 5,980,838.80 1,689,615.22 249 5.53 MWD+IFR-AK-SCC(2) 1,053.26 8.00 72.22 1050.83 957.98 6.46 49.74 5,980,841 82 1,689,628.25 1.51 8.46 MWD+IFR-AK-SCC (2) 1,147.84 8.81 68.66 1.144.39 1,051.54 13.10 6235 5,980 846 55 4,689,641.23 1.02 13.10 MWD+IFR-AK-SCC(2) 1,242.04 11.51 69.46 1,23].11 1,144.26 1902. 78.28 5,980,852.57 1,689,65871 2.87 1902. MWD+IFR-AK-SCC(2) 1,336.43 13.65 7128 1,329.23 1236.38 25.90 97.64 5,980,859.58 1,689,67603 2.31 25.90 MWD+IFR-AK-SCC(2) 1,431.09 15.94 66.75 1,42075 1,327.90 34.62 120.17 5,980,868.44 1,689,69850 2.71 34.82 MWD+IFR-AK-SCC(2) 1,527.44 17.55 6455 1,513.01 1,420.16 46.09 145.44 5,980,880.07 1689,723.70 1.80 46.09 MWD+IFR-AK-SCC (2) 1,621.51 18.00 66.47 1,602.59 1,509.74 57.96 171.58 5,980,89214 1.689,749 75 0.79 5798 MWD+IFR-AK-SCC(2) 1,655.47 19.11 6570 1,634.78 1,541.93 6237 181.45 5,980,896.59 1,689,759.59 3.35 62.37 MWD+IFR-AK-SCC(2) 1,719.00 20.54 6578 1,694.55 1,601.70 71.22 201.10 5,980,905.56 1,689,779.18 2.24 71.22 NOT dgpCga(ggly�r 103/4" x 13-1/2" 1,749.06 21.21 65.82 1722.63 1,629.78 75.61 210.86 5,980,91002 1,689,788.91 224 75.61 10WD+IFR-AK-SCC(3) 1,810.71 23.37 64.75 1,77967 1,686.82 85.39 232.10 5,980,919.94 1,689,810.08 3.% 8539 MWD+IFR-AK-SCC(3) 1,904.28 2710 63.74 1,864.30 1,771.45 102,74 268.01 5,980,937.53 1689,845.88 4.01 102.74 MWD+IFR-AK-KC(3) 1999.85 29.80 62.25 1,948.32 1,855.47 123.44 308.56 5,980,95848 1,689,88628 2.92 12344 MWD+IFR-AK-SCC(3) 2,043.58 31.74 61.59 1,985.69 1,893.04 133.97 328.29 5,980,969.14 1,689,905.95 4.50 133.97 MWD+IFR-AK-SCC(3) 2,09455 34.56 60.37 2,028.56 1,935.71 147.50 35266 5,980,982.83 1,689,930.22 5.69 147.50 MWD+IFR-AK-SCC(3) 2,189.41 39.80 58.49 2,104.12 2,011.27 176.69 401.96 5,981,012.34 1,6B9,979.33 5.65 176.69 MWD+IFR-AK-SCC(3) 2,284.04 45.65 55.40 2,173.61 2,080.76 211.77 455.69 5,981,047.77 1,690,03281 6.57 21177 MWD+IFR-AK-SCC(3) 2,380,98 50.78 5368 2,238.19 2,145.34 253.72 514.51 5,981,090.10 1,690,09136 545 253.72 MWD+IFR-AK-SCC(3) 2.47374 54.72 53.09 2,294.33 2,201.48 297.76 573.76 5,981,134.52 1,690,150.31 4.28 297.76 MWD+IFR-AK-SCC (3) 2,568.39 59.32 51.96 2,345.84 2,252.99 346.07 636.74 5,981,18324 1,69,212.97 4.96 346.07 MWD+IFR-AK-SCC(3) 2,662.64 64. D6 50.71 2,390.52 2,297.67 39.91 701.50 5,981,235.50 1,690.27738 5.18 39291 MWD+IFR-AK-SCC(3) 2,757.79 68.58 5049 2,428.73 2,335.88 453.20 768.82 5,981,291.23 1,690,344.32 4.76 453.20 MWD+IFR-AK-SCC(3) 2,852.00 7257 49.87 2,460.05 2,36720 510.09 $37.04 5,981,348.56 1,690,412.16 4.28 510.09 MWD+IFR-AK-SCC(3) 2,946.91 74.95 4842 2,486.59 2,393.74 569.70 905.95 5.981,40861 1690,480.67 2.91 569.70 MWD+IFR-AWSGC(3) 3,039.87 75.28 45.89 2,510.48 2.417.63 630.79 971.81 5,981470.13 1,690,546.13 2.65 630.79 MWD+1FR-AK-SCC(3) 3,135.82 75.18 43.53 2,534.94 2,442.09 696.72 1,037.08 5,981,536.48 1,690,610.96 2.36 696.72 MWD+IFR-AK-SCC(3) 3,230.52 75.27 43.71 2,55909 2,466.24 763.01 1,100.25 5,981603.17 1,60,67368 0.21 76301 MWD+IFR-AK-SCC(3) 3,326.05 75.33 43.23 2,583.33 2,490.48 830.07 1,163.62 5,981,670.64 1,690,736.81 0.49 830.07 MWD+IFR-AK-SCC (3) 3,419,60 75.33 44.07 2,69.03 2,514.18 895.55 1,226.29 5,981,736.53 1,690,798.84 0.87 895.55 MWD+IFR-AK-SCC(3) 3,515.01 75.40 44.49 2,631.13 2,538.28 961.64 1,290.74 5,981,803.04 1,690,86285 0.43 961.64 MWD+IFR-AK-SCC 13) 3,610.29 75.16 45.84 2,655.34 2,562.49 1,026.61 1,35609 5,981,858.43 1,690,927.76 1.39 1,026.61 MWD+IFR-AK-SCC(3) 3,704.55 74.27 46.19 2,680.19 2,587.34 1,089.76 1,421.51 5,981,93200 1,690,992.76 1.01 1,08976 MWD -IFR -AK -SCC (3) 3.798.88 74.35 47.88 2,705.70 2,612.85 1,151.65 1,487.96 5,981,994.32 L691,058.80 173 1,151.65 MWD+IFR-AK-SCC(3) 3,893.50 74.42 48.46 2.731.17 2,638.32 1,21243 1,555.86 5,982,05553 1,691,126.29 0.59 1,212.43 MWD+IFR-AK-$CC (3) 3,988.00 7422 48.21 2,756.71 2,663.86 1,272.91 1,623.83 5,982,116.45 1,691,19386 0.33 1,272.91 MWD+IFR-AK-SCC(3) 4,083.03 74.20 47.86 2,782.57 2,689.72 1,334.17 1,691.72 5,982,178.16 1,691,26133 0.56 1,334.17 MWD+IFR-AK-SCC(3) 4,177.42 74.14 46.99 2,808.32 2,71547 1,395.73 1,75848 5,982,240.14 1,691,327.68 0.69 1,395.73 MWD+IFR-AK-SCC(3) 8/232017 2:50 22PM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupi Local Coon inate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 1H Pad MD Reference: Well: To 111-118 North Reference: Wellbore: 1 H-118 Survey Calculation Method: Design: 1H-118 Database: Well TD: IH -118 -Slot IH -118 111-118 actual @ 92.85usft (Doyon 142) 11-1-118 actual @ 92.85usft (Doyon 142) True Minimum Curvature OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS -NIS +EAW Northing Easting DLS Section (usft) (I (I (usft) (usR) (usR) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,272.11 74.21 46.39 2834.14 2,741.29 1,458.22 1,824.77 5.982,303.06 1,691,393.56 061 1,458.22 MW1)+1FR-AK-SCC (3) 4,367.15 74.26 46.84 2,859.96 2,767.11 1,521.05 1,891.24 5,982,366.31 1691,45961 0.46 1,521.05 MWD+IFR-AK-SCC(3) 4461.07 74.26 47.59 2.885.44 2,792.59 1,582.45 1,95].59 5,982,428.14 1.691,525.54 0.77 1,58245 MWD+IFR-AK-SCC(3) 4555.74 74.17 49.02 2,911.20 2,818.35 1.643.04 2,025.61 5,982489.18 1,691593.16 146 1643.04 MWD+1FR-AK-5CC(3) 4.651.15 74.30 50.34 2,93712 2,844.27 1,70245 2,095.62 5,982,54904 1,691,662.76 1.34 1,702.45 MWD+IFR-AK-SCC(3) 4,74540 7420 48.99 2,96270 2,869.85 1,761.17 2,16476 5,982.608.20 1,691,731.52 1.38 1,761.17 MWD+IFR-AWSCC(3) 4,84029 74.35 47.97 2,988.42 2,895.57 1,821.71 2,233.15 5,982,669.19 1,691,799.50 1.05 1,821.71 MWD+IFR-AK-SCC 13) 4,934.86 74.32 46.23 3,013.96 2.921.11 1,883.69 2,299.85 5,982,73160 1,691,865.78 1.77 1,883.69 MWD+1FR-AK.SCC (3) 5,029.00 74.32 45.53 3,03940 2,946.55 1,946]9 2,364.91 5,982,795.12 1691,930.43 0.72 1,94639 MWD+IFR-AK-SGC(3) 5,12491 74.32 4472 3,065.32 2,972.47 2,011.94 2,430.35 5,982,860.69 1,691,99543 0.81 2.011.94 MWD+IFR-AK-SCC(3) 5.219.45 74.32 44.34 3,090.87 2,998.02 2,076.83 2,494.18 5,982,925.99 1,692,058.83 0.39 2,07683 MWD+IFR-AK-SCC(3) 5,31393 74.23 4343 3,116.48 3,023.63 2,142.38 2,557.23 5,982,99194 1,692,12143 0.93 2,142.38 MWD+IFR-AK-SCC(3) 5,408.34 74.32 42.79 3,142.07 3,049.22 2,208.72 2,619.33 5,983,058.69 1,692,183.09 0.66 2,208.72 MWD+IFR-AK-SCC (3) 5,502.85 74.41 42.77 3,167.54 3,074.69 2,275.52 2,681.14 5,983,12588 1,692,24446 0.10 2,275.52 MWD+IFR-AK-SCC(3) 5,597.58 74.25 43.26 3,193.13 3,100.28 2,342.21 2,743.37 5,983,19297 1,692,306.24 0.53 2,342.21 MWD+IFR-AK-SCC(3) 5,691.24 74.34 41.98 3,218.48 3,125.63 2,408.56 2,81NIA2 5,983,259.71 1,692,36685 1.32 2,408.55 14 D+IFR-AK-SCC(3) 5,78663 73.80 40.63 3,24466 3,151.81 2,477.46 2.864.% 5,983,329.00 1,692,426.93 1.47 2,477.46 MWD+IFR-AK-SCC(3) 5.88102 72.69 37.94 3,271.88 3,179.03 2,54].40 2,922.19 5,983,399.32 1,692,483.69 2.97 2,547.40 MWD+IFR-AK-SCC(3) 5,975.43 71.59 36.01 3,300.83 3.207.98 2,619.18 2,976.24 5,983,471.44 1.692,537 26 2.27 2.619.18 MWD+1FR-AK-$CC (3) 6,070.43 71.21 34.57 3,331.14 3,238.29 2,692.67 3,028.25 5,983,545.27 1,692,588.79 149 2,692.67 MWD+1FR-AK-SCC (3) 6,164.93 71.09 31.88 3,361.67 $,268.82 2,]6]48 3,077.25 5,983,620.38 1,692,63729 2.70 2,767.48 MWD+IFR-AK-SCC(3) 6,259.40 69.54 31.82 3,393.49 3,300.64 2,84303 3,124.19 5,983,696.23 1,692,683.73 1.64 2,843.03 MW0+1FR-AK-SCC(3) 6,354.10 68.75 29.24 3,427.21 3,334.36 2,919.25 3,169.14 5,983,772.74 1,692,728.18 268 2,919.25 MWD+1FR-AK-SCC(3) 6,401.98 6835 27.32 3444.72 3,351.87 2,95849 3,190.25 5,983,812.11 1,692,749.03 382 2.958.49 MWD+IFR-AK-SCC(3) 6,448.31 67.96 25.01 3,461.% 3,369.11 2,99708 3,209.22 5.983,850.82 1,692,76773 4.70 2,99708 MWD+IFR-AK-SCC(3) 6,510.17 67.08 21.61 3,485.62 3,392.77 3,049.56 3,231.83 5983,903.45 1,692,790.01 527 3,049.% MWD+IFR-AK-SCC(3) 6,543.85 66.78 19.56 3,498.82 3,405.97 3,078.57 3,242.73 5,983,932.52 1,692,800.71 5.67 3,07857 MWD+IFR-AK-SCC(3) 6,60041 66.67 16.90 3,521.17 3,428.32 3,12].91 3,258.98 5.983,981.97 1,692,81664 4.32 3,127.91 MWD+IFR-AK-SCC(3) 6,637.74 65.26 16.71 3,53608 3,443.23 3,160.67 3,26868 5,984,014.79 1,692,826.31 1.19 3,160.67 MWD+IFR-AK-SCC(3) 6.732.68 66.86 13.31 3.573.86 3,48101 3,24419 3,291.43 5,984,099.05 1,692,848.31 3,35 3,244]9 MWD+IFR-AK-SCC(3) 6,826.76 67.06 8.57 3,610.69 3,517.84 3,329.76 3,307.85 5,984,184.11 1,692,864.17 4.84 3,329.76 MWD+1FR-AK-5CC(3) 6,904.25 6750 4.99 3,640.63 3,547 78 3,400,73 3,316.28 5,984,255.12 1,692.872.14 4.30 3,40033 MWD+1FR-AK-SCC (3) 6,921.67 67.59 4.08 3,647.28 3,554.43 3,416.77 3,317.55 5,984,271.18 1,692,873.30 4.86 3,416.77 MWD+IFR-AW$CC(3) 7,016.17 67.98 0.58 3,683.04 3,590.19 3,504.16 3,321.11 5,984,358.58 1,692,87628 3.45 3,504.16 MWD+IFR-AK-SCC(3) 7,111.18 68.26 355.50 3,718.47 3,625.62 3,592.27 3,318.86 5,984,446.66 1,692,873.46 4.00 3,592.27 MWD+IFR-AK-SCC (3) 7,205.54 68.58 353.87 3,753.18 3,660.33 3.679.70 3,311.49 5,984,534.03 1,692,865.52 261 3,679.70 MWD+lFR-AK.$CC(3) 7,300.26 68.35 35369 3,787.95 3,695.10 3,767.29 3,301.94 5.984,621.55 1,692,855.40 0.30 3,767.29 MWD+IFR-AK-SCC(3) 7,395.12 68.41 35520 3,822.91 3,730.06 3,855.06 3,293.41 5,984,709.25 1,692,846.29 1.48 3,855.06 MWD+IFR-AK-SCC(3) 7,489.30 6864 355.84 3,857,38 3,764.53 3,942.43 3,286.56 5,984,796.57 1,692.838.87 068 3,94243 MWD+IFR-AK-SCC(3) 7,584.71 68.50 356.30 3,892.24 3,799.39 4,031.03 3,28047 5,984885.12 1,692,83220 047 4031.03 MWD+IFR-AK-SCC(3) 8/23/2017 2:50.22PM Page 4 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: TD: 1H-118 Wellbore: 1H-118 Design: 1H-118 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well TD: 1H-118 - Slot 1H-118 1H-118 actual @ 92.85usft (Doyon 142) 11-1-118 actual @ 92.85usft (Doyon 142) True Minimum Curvature OAKEDMP2 Survey Map Map Vertical MD Inc AN TVD TVDSS +N/ -s +E/ -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) ('1100') (ft) Survey Tool Name 7,679.25 68.57 357.88 3,926.84 3,833.99 4,11890 3276.01 5.984,972 95 1692,827.16 1,56 4,118.90 MWD+1FR-AK-SCC(3) 7,774.16 68.57 357.44 3,961.52 3.86867 4,207.17 3,272.40 5.985,061.19 1,692,822.97 0.43 4.207.17 MWD+IFR-AK-SCC(3) 7,86862 68.45 357.44 3,996.12 3,903.27 4,294.98 3,266.48 5,985,148.96 1,692,81847 0.13 4,294.98 MWD+IFR-AK-SCC(3) 7,96347 68.55 357.91 4,030.89 3,938.04 4,383.16 3,264.90 5,985,237.10 1,692,814.31 847 4,383.16 MWD+IFR-AW$CC(3) 8,058.06 68.57 35841 4,05546 3,972.61 4,471.16 3,262.07 5,985.32507 1,692,81091 0.49 4,471.16 MWD+IFR-AK-SCC 13) 8,121.00 68.57 35841 6,088.46 3.995.61 4,52932 3,260.44 5,985,38362 1,692,808.90 0.00 4,52972 NOT an Aelual Survey 7 x 8.1/2" 8,131.00 68.57 358.41 4,092.11 3,99926 4539.03 3,260.18 5,985.39292 1,692,808.58 0.00 4,539.03 PRCJECTEDtOTD (Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. Q Yes ❑ No I have checked to the best of my ability that the folloWng data is correct., p Surface Coordinates 0 Declination & Convergence O GRS Survey Corrections Fal Survey Tool Codes Brandon Temple ." SLB DE. tac20v102315545441em INjhtysig al by bm Tohan Client Representative: Date. 8/23/2017 8/23/2017 2:50.22PM Page 5 COMPASS 5000.14 Build 85 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED SEP 2 12017 WELL COMPLETION OR RECOMPLETION REPORT A la. Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ R] , WAGE] WDSPL ❑ No. of Completions: 1b. Well Class: Development E] Exploratory E] Service R] • Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 8/22/2017 14. Permit to Drill Number/ Sundry: 217-084 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 8/8/2019 15. API Number 235,78'po 4<7 50-028-00 . 4a. Location of Well (Governmental Section): Surface: 378' FSL, 791' FEL, Sec 28, T12N, R10E, UM Top of Productive Interval: 1187' FNL, 2755' FEL, Sec 27, T12N,R103, UM Total Depth: 364' FNL, 2801' FEL, Sec 27, T12N, R10E, UM 8. Date TD Reached: 8/15/2017 16. Well Name and Number: KRU IH -118, 9. Ref Elevations: KB:92.85 GL: 54 BF: 17. Field / Pool(s): Kuparuk RiverFieldNVest Sak Oil Pool , 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 25639 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 549547 y- 5981081 Zone- 4 TPI: x- 552830 y- 5984818 Zone- 4 Total Depth: x- 552777 y- 5985641 Zone- 4 11. Total Depth MD/TVD: 8131/4092 , 19. DNR Approval Number: 80-261 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MDfTVD: 1654/1633 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: 1 (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: N/a 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of 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/CBL Log 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20 78.7 B 39 119 39 42 Existing 103/4 45.5 L-80 40 1719 40 131/2 683 sx 11.0ppg LiteCrete 291 sx 15.8opa Class G 7 26 L-80 38 8121 38 81/2 215 sx 14.Oppg Extended G 24. Open to production or injection? Yes ❑� No ❑ If Yes, list each interval open (MD/rVD of Top and Bottom; Perforation Size and Number; Date Perfd): PERFORATIONS @ 7246-7348 MID, 3768-3806TVD PL F. T'ON 7424-7504 MD, 3834-3863 TVD no (r 7554-7587 MD, 3881-3893 TVD �� 7( --��- 7693-7737 MD, 3932-3948 TVD �-cq�c�;_-h 7815-7861 MD, 3977-3993 TVD - - 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 31/2 1 7950 7146/3731, 7399/3824, 17521/3869, 7937/4021 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes EJ No ❑� Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: NIA Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing P Casino Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Form 10-407 Revised 5/2017 k7L 121.2q11 -7 2/Z i //-7 CONTINUED ON PAGE 2 2 201%Submit ORIGINIAL o PJ<a 1/1//? r1 8 RB�f s �, SEP 2 _ 6 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No ] If Yes, list formations and intervals cored (MDf VD, Fromrro), 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 ❑� Permafrost - Top Surface Surface Permafrost - Base Top of Productive Interval 7244 3767 Formation @ TPI - West Sak UGNU 5260 3102 West Sak Sand 7244 3767 TD 8131 4093 Formation at total depth: West Sak 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematics Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontoloaical report, production or well test results. per 20AA 7. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. 3� Authorized Name: G. L. Alvord Contact Name: Ben Tolman Authorized Title: Alaska Drilling Manager Contact Email: ben.v.tolman 0 co .00m Authorized Contact Phone: 265-6828 �� ��. "((Z a' Signature: Date: INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 512017 Submit ORIGINAL Only Wellhead/Tubing Banger/Tree, NEWS 1H-118 Injector r 13-3/8" x ¢Y:" HYD563, 5M _ t( (ACTUALS) at Crossoverbelow i = Insuled Conductor: ¢I2"x3-1/2" Tububing 20" Casing 1OJ14", 45.5N, 480, BYD563DL @ 1,719' MD / 1,656' MD @ 20.54° ine @ TD (13.5" bole) 3-12", 93 N, L-80. E11E-AB @ 7,95(V MD 13,98V TVD 3-1a" MMG with SOV @ 2,539 MD PIP tae: 6,988'311) Pecker @ 7,146' MD _A "D" Sand Perforations: 7,246'- 7,348' MD Gauge @ 7,160' MD 2.813" Nipple @ 7,176 MD MMWG Mandrel @ 7,18 & 7,22 MD Packer@7,399'MD �P "D" Sand Perforations: 7,424'-7,504'MD Gauge Mandrel @ 7,412' MD MMWG Mandrels @ 7,429'& 7,469 MD Packs @ 7,521' MD A4 perfs: 7,554' — 7,587' MD A3 perfs: 7,693' — 7,737' MD Gauge Mandrel @ 7,535' MD A2 perfs: 7,815' — 7,861'MD 2 813' Nipple @ 7,551' MD MMGW Mandrel @ 7.557'& 7 597' MD 7", 260, L-80, BVD50/1'XP Baker VVTV @ 7,937 MD @ &121' MD / 4,050' TVD a� @ 6857° @ TD (8.5" hole) Scraper/Magnet Assy @ 7,940 MD TD @ %131' MD Durab von rnuleahoe @ 7,946' MD r KUP SVC _�-�-�_�k4yyr� • FGI - Cf1UCVr't 1ll��'iS - Well Altdb' Awa IOC No; AWUWI 7 AST W0: 1H-118 .x MIwGWn Ilepth 11X(81nE Dah Mndatlon IxtMW BY End Cape LAST TAG'. REVREASON: NEW WELL jenn.11 91182017 MANGEfl, 31.) same nngs _............................. .......- CONDUCTOpUon oG Ohl Io On) ]op lnxel set Oepm lnxal set Deem O119i W#Len0..67 C,nde Top rnreea CONDUCTOR 20 19.2110 391 119.1 119.1 ]B.6J B Caing BeecnllUnn OGpn) Ip(Io) Top 111X61 Sel Oepm I- Stl CeNo(16pI... WtlLen IL.. Grafi Top TLreaE SURFACE ION4 9.950 40.4 1,)193 1,894.8 45501-80 Hydri1563 Calnp Oaecngbn 00(In) 10(In) rap0-8, gel Oept111nKBl SH OepM DVGj._ W...... Grade Top ThreaO . .......... ........_.. ._.. ......_....PRODUCTION 7 6276 377 8,121.0 4,068.5 26.00 L-80 ITXP BTC 1 Tubing SMngs Tubing co -Se" Sinn"Me-_lo lin) Top Bane) set Uepm m.. sN cepin lT/DII,..W19WIn Glaee Tupcunn Ho. Upper Complelign 3112 2992 34) ).9502 40260 9.30 L-80 EUE Completion Details rvominallo ]rap lnKsl Top RVD1ILMB) Top lMl r) IOlrn Des d- (in) 343 34.7 012 MANGER Ve=4-1Z TUNIg Hanger 3958 CONDUCTOR: 391-1191 7,146.2 3.731 0 68.38 PACKER Halliburton Feed Through Packer #3 VAM connenion 2.920 ( Any #10) SN# SG3542445-01 7,159.9 3,7364 68.43 PRESSURH TLB ORD #3 EUE ORD-Mod(Any#10)SN#C15GM- 2.898 SURFACeb4i.]1G3 EMPERATUR E SENSOR 0736 7,1763 3,7425 MAS NIPPLE Camc02.812DSnipple EUEBRD-Mod (Msy#9)SN# 2813 36514 73983 3,8242 6842 PACKER Hellibunon Feed Through Pecker 0 VAM connec4lon 2.920 GAS UPr; Z.1 ( Any #7) SN# SG3542445 7,4124 3,829.3 68.45 PRESSURErt SLB DHG#2 CUE BRD-Mod SN#C15G"739 2.01M EMPERATUR ESENSOR 7,521.1 3.8690 SO 69 PACKER Hallihunon Feed Through Packer#1 VAM connection 2920 ( Any #4) SAO SG3532048-02 7,534.8 3,8740 68.57 PRESSUREiT SWDHG#1EUEBRDJAod SN#C15GM-0728 2.898 RAORER:].MS.2 EMPERATUR E SENSOR PRESSUAWEMPERATURE7,550.fi sENSON.7.193.s 3,8)98 68.55 NIPPLE Camco 2813Xnipple EUE8RD-Mod (Ass #3 SN# C15GM-0728 y ) 2813 NIPPLE, 7.1763 7,937.2 4,0213 MR WIV 3112"Baker WIV EUE-MOD 1000 7,940.4 4,0225 6853 CASING Baker Trailblazer CSG scrapper! brush/Mag combo 3.833 GAs LIFT. 1.1.5 BRUSH IAny #1) 7,946.1 4024.5 6853 MULE THOE I 312" Mule shoe tubing tail 2,992 Perforations & Slots GAs un; 7,223.$ shin roP(rdua) BW Mel Tap [TAD) "Noel an RVp) MINOR Zana Data (epbpl m TYw C. IPERC7,SNO-7amO_ 7,246.0 7,3480 3,7680 3,8050 WS D. 111- &191201] 60 IPERF 118 7,424.0 7,504.0 3,833.5 3,862.7 WS8,1H- &191201] 6.0 (PERF vacKER: ],3W] 118 PRESSUNISTEMPERATURE ,55 740 7,587.0 3,681.0 3.893.1 WSA4,1H- 8119no1) 60 (PERF SE-80-3,a12a 118 7,6930 7,737.0 3,931.9 3,947.9 WSA3,111- 8/192017 60 IPERF 118 Gras LIFT, ],Q8 7,8150 7,861.0 3,976.5 3,993.3WSA2, 1H- 811&201] 601PERF 18 IPERF;],eze.a]5D+.o- Mandrel Inserts al ou GAS LIFT: ].M9,9 N Tep OVD) VaM LatrL PonSW TRO Run 'Top lnxa) WB) Make Motel Mon) Se(In) , Type Type (Po6 Porous Cbm 1 $529.7 2,3255 Camco MUG 1112 GAS LIFT SOV RKP 0.313 0.0 MlQO17 2 ],182.5 3)44.8 CAMCO MMG 112 GAS LIFT DMY RK 0.000 0.0 812112017 PACKER.7s21.1 3 ],222.8 3,759.5 CAMCO MMG 112 GAS LIFT JDMY RK 0000 0.0 82112017 PRESSURETEMPERATURE 4 7.428.8 3,835.3 GAMCO MMG 112 GAS LIFT DMY RK 0.000 00 821201) ssxsoR; ].zee 5 7,468.9 3,6499 CAMCO MM 112 GAS LIFT OMV RK 0000 00 6212017 6 ).55]4 3,682.2 CAMCO MUG 1112 GAS LIFT JDMY RK 0000 00 8212017 xIPPLE;7,5XS ) 73597.5 3,8969 CAMCO MMG 1112 GAS LIFT JDMY RK 0000 00 8212017 Notes: General & Safety End Dare Arrpcu n GAS LIR;1RRO (PERF; ],SSa.675S].p� NOTE. GAS LIFT;],She IPERF ; 7.61S C0.7,]9I.0- (PERF:7 ISS -7.N10- WN:],Wi3 CASINO MUSH, T9w.4 MULE MOE:]Spa .I PRODUCTION: 3].]$1210 Operations Summary (with Timelog Depths) 1 H-118 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depm Start Time End Time Dur (hr) Phew Op Code Acbvlty Code Time P -T -X operation (ftKB) End Depth (ttKB) 7/24/2017 7/24/2017 4.75 MIRU MOVE RURD P Lay mats on 2K access road. Prep rig 0.0 0.0 00:00 04:45 for move.Prepare to skid rig floor. Raise cellar door. Lay down beaver slide.Remove cuttings tank and berm. Raise stairwells. Blow down water system. Disconnect air and water lines at interconnects. Sim-ops/Con9 w/drag chain mod. Prep handling equip f/MPI and send off rig floor. 7/24/2017 7/24/2017 0.75 MIRU MOVE MOB P Load rockwasher and stage at pad 0.0 0.0 04:45 05:30 lentrance. 7/24/2017 7/24/2017 2.75 MIRU MOVE MOB P Pull pump, motor, pit and pipeshed 0.0 0.0 05:30 08:15 modules away from well and stage at pad entrance. 7/24/2017 7/24/2017 1.50 MIRU MOVE MOB P Skid rig floor, raise stompers and 0.0 0.0 08:15 09:45 install towing tongue. 7/24/2017 7/24/2017 1.00 MIRU MOVE MOB P Move motor module from 2K pad to 0.0 0.0 09:45 10:45 1 2H pad. 7/24/2017 724/2017 2.25 MIRU MOVE MOB P Crib up beneath tires on substructure 0.0 0.0 10:45 13:00 due to soft ground and pull sub off of 2K30. Stage for transport to 2H pad. 7/24/2017 7/24/2017 2.00 MIRU MOVE WAIT P Load out substructure mafting boards 0.0 0.0 13:00 15:00 and transport to 2H pad. 7/24/2017 7/24/2017 1.50 MIRU MOVE MOB P Move pipeshed, pump and pit 0.0 0.0 15:00 16:30 modules to 2H pad. 7/24/2017 724/2017 0.50 MIRU MOVE WAIT P Lay plywood and matting boards on 0.0 0.0 16:30 17:00 1 soft location at entrance to 2H pad. 7/242017 724/2017 0.75 MIRU MOVE MOB P Move substructure from 2K pad to 2H 0.0 0.0 17:00 17:45 pad. Sub contacted mats due to soft road causing mats to stack kup. 7/24/2017 7/24/2017 0.75 MIRU MOVE WAIT P Pull matting boards and reset. 0.0 0.0 17:45 18:30 724/2017 7/24/2017 0.50 MIRU MOVE MOB P Con't to move substructure to 2H pad. 0.0 0.0 18:30 19:00 Sink into soft location at entrance to 2H pad. 7/24/2017 7/24/2017 1.50 MIRU MOVE MOB P Crib up tires on sub and move to 0.0 0.0 19:00 20:30 1 staging area on 2H pad. 7/24/2017 7/252017 3.50 MIRU MOVE WAIT P Pick up matting boards on road from 0.0 0.0 20:30 00:00 2H to 2K pads. Sim-ops/Work on annual maintenance. Install idler sprockets on drag chain. Assemble drag chain. Stage skate rail for modification. Sandblast handling equipment. Perform housekeeping in PUMP room. 7/25/2017 7/2512017 6.00 MIRU MOVE WAIT P Continue to wait on rig mat shuffle. 0.0 0.0 00:00 06:00 Move sub clear of entrance to 2H pad. Perform prep work for rotary table inspection during maintenance shut down. Paint pump room addition. 7/25/2017 7/25/2017 6.00 MIRU MOVE WAIT P Continue rig mat shuffle. Pull hatches 0.0 0.0 06:00 12:00 and inspect gas buster. Prepare mud pumps for annuals. Begin work on pipe skate modifications. Prepare handling equipment for MPI. Istall rig floor steam line isolation valves. Prep hatches to be pulled on pumps. Page 1121 Report Printed: 8/23/2017 Operations Summary (with Timelog Depths) 11-1-118 I& Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depth Steil 7th End Time our Phase OP Code Activity Code Time P-T-X Operahm (WS) EM Depm(ftKB) 7/25/2017 7/25/2017 4.75 MIRU MOVE WAIT P Continue to shuffle mats. Install 0.0 0.0 12:00 16:45 snubbing pad eye on rig floor. Continue hot well modifications. Sand blast all handling equipment for MPI., Load out equip for transport to 1H and unload same. 7/25/2017 7/25/2017 0.50 MIRU MOVE MOB P Move power complex form 2H - 4 0.0 0.0 16:45 17:15 1 1 comers. 7/25/2017 7/25/2017 0.50 MIRU MOVE MOB P Move Pits, Pump, and pipe shed to 4 0.0 0.0 17:15 17:45 corners. from 21-1-pad. 7/25/2017 7/25/2017 0.75 MIRU MOVE MOB P Move Pits, pump, pipe shed, and 0.0 0.0 17:45 18:30 motor comples from 4 comers to 28 pad and stage. 7/25/2017 7/26/2017 5.50 MIRU MOVE WAIT P Wait on additional mats to be laid out 0.0 0.0 18:30 00:00 for sub from 21-1-4 comers. Also some additional mats from 4 comers to 2B pad for staging. Crews continuing to prep for summer maintenance,. 7/26/2017 7/26/2017 6.00 MIRU MOVE WAIT P Continue to shuffle mats and prep • 0.0 0.0 00:00 06:00 handling equipment for MPI. Pull rolla road and prep to restage / deploy for sub move. 7/26/2017 7/26/2017 3.50 MIRU MOVE WAIT P Deploy rolla road and plywood from 0.0 0.0 06:00 09:30 2H - rig mats towards 4 corners. Continue hot well modifications. 7/26/2017 7/26/2017 1.75 MIRU MOVE MOB P Move sub from 2H - 2B pad. 0.0 0.0 09:30 11:15 7/26/2017 7/26/2017 0.75 MIRU MOVE MOB P Move motor, pump, pits, pipe shed 0.0 0.0 11:15 12:00 modules from 2B pad to CPF-2. 7/26/2017 7/26/2017 0.50 MIRU MOVE MOB P Raise sub on suspension for move to 0.0 0.0 12:00 12:30 CPF-2. 7/26/2017 7/26/2017 1.50 MIRU MOVE MOB P Move sub from 2B - CPF 2. 0.0 0.0 12:30 14:00 7/26/2017 7/26/2017 1.00 MIRU MOVE MOB P Unhook Sows from pump / pits / motor 0.0 0.0 14:00 15:00 complex and return to 2K to pick up shop / parts houses etc and prep to move to 1 H- pad. 7/26/2017 7/26/2017 3.00 MIRU MOVE MOB P Move parts houses / shop from 2K - 0.0 0.0 15:00 18:00 1H and spot same according to PFSR. 7/26/2017 7/26/2017 2.00 MIRU MOVE MOB P Return trucks to CPF - 2 and load up 0.0 0.0 18:00 20:00 Pump I pits / motor/ pipe shed modules for transport to KOC pad. 7126/2017 7/26/2017 2.50 MIRU MOVE MOB P Move Pump / pits / motor / pipe shed 0.0 0.0 20:00 22:30 modules to KOC / KCC pad. 7/26/2017 7/27/2017 1.50 MIRU MOVE WAIT P Wait for mat placement around airport 0.0 0.0 22:30 00:00 and road from KIC to 1 H - pad. Mats being transported via truck from behind rig move. Rig crews working on maintenance list. Drag chain installed,and second coat of paint in pump house. 7/2712017 7/27/2017 11.50 MIRU MOVE WAIT P Continue to waif on rig mat shuffle for 0.0 0.0 00:00 11:30 1 H-road access. Hauling mats from 2H - 1 H. Perform rig maintneance and PM's. Prep rig floor for inspect. Lay rig mats in from of 1 H-118 for rig squat. Page 2121 Report Printed: 8/23/2017 Operations Summary (with Timelog Depths) 1H-118 Rig: DOYON 142 Job: DRILLING ORIGINAL Time log Stan DepN SM Torre End Time Dur (hr) Phase Op Code AcWity Cade Torre P -T -X Opmmon (MB) End Depth (ttKB) 7/27/2017 7/27/2017 0.50 MIRU MOVE MOB P Begin to move pits, pump, motor, and 0.0 11:30 12:00 pipeshed + Sub to 1H -pad from KCC. 7/27/2017 7/27/2017 1.00 MIRU MOVE MOB P Stage sub at KIC rear entrance while 12:00 13:00 confine to move Pipe shed, Motor, pits, pump modules to 1 H -pad. 7/27/2017 7/27/2017 0.50 MIRU MOVE MOB P Stage Pipe shed, pits, motor, and 13:00 13:30 pump modules on 1H -pad and prepare for sub arrival. 7/27/2017 7/27/2017 8.50 MIRU MOVE WAIT P Extend mat layout to 1H -pad from KIC 13:30 22:00 pad due to narrow road way. Call up an additional 285 mats from 2H -pad. Rig crew continuing to prepare for annual inspections etc. etc. 7/27/2017 7/27/2017 1.00 MIRU MOVE MOB P Move sub to 1 H pad form rear 22:00 23:00 entrance of KIC pad. 7/27/2017 7/28/2017 1.00 MIRU MOVE MOB P Spot sub on dg mat layout for summer 23:00 00:00 maintenance. Crews continueing with summer maintenance list prep and complete. 7/28/2017 7/28/2017 1.50 MIRU MOVE MOB P Set stompers and skid dg floor. 0.0 0.0 00:00 01:30 7/28/2017 7/28/2017 0.75 MIRU MOVE MOB P Spot pits and install sub handrails / 0.0 0.0 01:30 02:15 stairs. MIN service lines. 7/28/2017 7/28/2017 0.75 MIRU MOVE MOB P Spot pump module and mu service 0.0 0.0 02:15 03:00 lines 7/28/2017 7/28/2017 0.75 MIRU MOVE MOB P Spot motor mod. RU / Service lines. 0.0 0.0 03:00 03:45 7/28/2017 7/28/2017 0.75 MIRU MOVE MOB P Set rock washer. m/u lines 0.0 0.0 03:45 04:30 7/28/2017 7/28/2017 0.50 MIRU MOVE MOB P spot pipe shed and m/u lines, stairs, 0.0 0.0 04:30 05:00 etc. 7/28/2017 7/28/2017 0.75 MIRU MOVE RURD P install Beaver slide. continue to lower 0.0 0.0 05:00 05:45 and oonenct all stairs /walkways. 7/28/2017 7/28/2017 6.25 MIRU MOVE RURD P Plug in all interconnects. Swap power 0.0 0.0 05:45 12:00 from cold starts. remove grating from mud pumps. remove pit hatches, Install Beaver slide guide roller assym. 7/28/2017 7/28/2017 0.00 MIRU MOVE OTHR P Switch billing over to Maintenance 0.0 0.0 12:00 12:00 AFE. 8/7/2017 8/7/2017 2.00 MIRU MOVE MOB P Release from summer maintenance at 0.0 0.0 00:00 02:00 00:00 hrs on 8/7/17. Pull riser from rotary table. Unplug from motor complex and swap to cold starts on each module. Go through pre -rig move checklist. Blow down water and disconnect lines. Raise landings and disconnect interconnect lines. 8/7/2017 8/7/2017 0.50 MIRU MOVE MOB P Pull rockwasher away and stage on 0.0 0.0 02:00 02:30 1 pad. 8/7/2017 8/7/2017 0.75 MIRU MOVE MOB P Pull motor complex away and stage 0.0 0.0 02:30 03:15 on pad 8/7/2017 8/7/2017 0.75 MIRU MOVE MOB P Pull pipe shed module away and stage 0.0 0.0 03:15 04:00 on pad. 8/7/2017 8/7/2017 0.75 MIRU MOVE MOB P Pull pump room and pit module away 0.0 0.0 04:00 04:45 and stage on pad. Page 3121 Report Printed: 8/23/2017 Operations Summary (with Timelog Depths) 1 H-118 I& Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depth Start Time End Time Owthh) Phase Op Code Ad" Code Time NTA Oparahon (110) End Depth tftl(S) 8/7/2017 8/7/2017 0.75 MIRU MOVE MOB P Skid rig floor and raise stompers. 0.0 0.0 04:45 05:30 Attach towing hitch. 8/7/2017 8/7/2017 1.00 MIRU MOVE MOB P Pull sub forward back to give access 0.0 0.0 05:30 06:30 to the well and to the rig mats. 8/7/2017 8!7/2017 1.00 MIRU MOVE RURD P Install surface annular on lop of 0.0 0.0 06:30 07:30 diverter tee. 8/7/2017 8/7/2017 1.00 MIRU MOVE RURD P Re -shuffle mats for spotting rig over 0.0 0.0 07:30 08:30 1 H-118. 8/7/2017 8/7/2017 1.00 MIRU MOVE MOB P Move pump room and pit module over 0.0 0.0 08:30 09:30 mats and stage. 8/7/2017 8/7/2017 1.25 MIRU MOVE MOB P Pull sub over 1 H-118. 0.0 0.0 09:30 10:45 8/7/2017 8/7/2017 1.25 MIRU MOVE MOB P Lower stompers and start removing 0.0 0.0 10:45 12:00 towing hitch from sub. 8/7/2017 8/7/2017 1.00 MIRU MOVE MOB P Finish removing lowing hitch from sub 0.0 0.0 12:00 13:00 and skid rig floor into drilling position. 8/7/2017 8/7/2017 1.00 MIRU MOVE MOB P Spot pit and pump modules. 0.0 0.0 13:00 14:00 8/7/2017 8/7/2017 1.00 MIRU MOVE MOB P Spot motor comples and pipe shed 0.0 0.0 14:00 15:00 module. Begin connecting interconnects. SIMOPS - Continue seam welding on pump module. 8/712017 8/7/2017 1.50 MIRU MOVE MOB P Spot rockwasher in place. 0.0 0.0 15:00 16:30 8/7/2017 8/7/2017 2.00 MIRU MOVE RURD P Continue connecting interconnects. 0.0 0.0 16:30 18:30 Spot cuttings tank and install berming around it. 8/7/2017 8/7/2017 1.50 MIRU MOVE RURD P Raise pipe skate rail to rig floor. 0.0 0.0 18:30 20:00 Function test skate and install chain guards. Continue connecting interconnects. Prepare pits for taking on water. Finish installing all handrails and landings. Rig accepted at 20:00 hrs. 8/7/2017 8/7/2017 1.25 MIRU MOVE NUND P Torque surface annular and diverter 0.0 0.0 20:00 21:15 tee flange bolts. Attach koomey hydraulic lines to annular. Obtain RKB measurements and diverter length. Perform pre -spud derrick inspection. Note: RKB to MSL = 92.85 ft 8/7/2017 8/7/2017 1.00 MIRU MOVE RURD P Install 4-12" IF saver sub. Torque and 0.0 0.0 21:15 22:15 secure saver sub and lower IBOP. 8/7/2017 8/8/2017 1.75 MIRU MOVE RURD P Nipple up surface bell nipple and riser. 0.0 0.0 22:15 00:00 Take on cold water to pits for mixing spud mud. Load 5' HWDP and BHA in shed. 8/8/2017 8/8/2017 3.75 MIRU MOVE RURD P Center surface annular and riser and 0.0 0.0 00:00 03:45 secure. Function test annular and knife valve. Make up torque ring on top drive quill. Install bell guide on top drive. Pick up and install mousehole. Take on water for building spud mud. Troubleshoot pit hatch #1 gasket. Page 4121 Report Printed: 812 312 01 7 Operations Summary (with Timelog Depths) 1 H-118 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time bur(hr) Phase op Code Activity Code Tune P -T -X Operation stun cepth (WS) End oeptl kWS) 8/8/2017 8/8/2017 1.25 MIRU MOVE SHAH P Mobilize BHA tools to rig floor. 0.0 0.0 03:45 05:00 8/8/2017 8/8/2017 2.00 MIRU MOVE PULD P Pick up and rack back 7" NMDC 0.0 0.0 05:00 07:00 stand, jar stand, and 5 x stands of 5" HWDP. Tag up at 102.54' MD. 8/8/2017 8/8/2017 1.50 MIRU MOVE BOPE P Perform diverter lest, witnessed by 0.0 0.0 07:00 08:30 AOGCC rep Matt Herrera and Lou Labenstein. Annular dosing time = 24 seconds. Knife opening time = 4 seconds. Conduct koomey drawdown test. Accumulator starting pressure = 2800 psi. After closure = 1750 psi. Buildup 200 psi in 6 x seconds with 2 x electric pumps. Full pressure attained after 48 seconds with 2 x electric pumps and 2 x air pumps. 6 x nitrogen backup bottle average = 2040 psi. Test PVT system for gainlloss, flow paddle, and trip tank gain/loss. Test all gas alarms. Function rig evacuation alarm - all good tests. Confirm end of diverter line further than 75' from nearest ignition source and all warning signs posted. SIMOPS - Load 5" DP in shed, and wireline crew/Gyro hand start mobilizing tools to beaver slide and rig floor. 8/8/2017 818/2017 0.50 MIRU MOVE PULD P Finish racking back 5" HWDP, totaf of 0.0 0.0 08:30 09:00 5 x stands racked back. 8/8/2017 8/8/2017 1.00 MIRU MOVE RURD P Rig up slickline and mobilize Scientific 0.0 0.0 09:00 10:00 Drilling gyro tools to floor. 8/8/2017 8/8/2017 0.75 MIRU MOVE SEOP P Fill surface lines and pressure test 0.0 0.0 10:00 10:45 with both mud pumps to 3500 psi and confirm no leaks. Blow down top drive. 8/8/2017 8/8/2017 0.25 MIRU MOVE SFTY P PJSM for picking up BHA. 0.0 0.0 10:45 11:00 8/8/2017 818/2017 1.50 MIRU MOVE BHAH P Pick up 13-1/2" Baker VM -3 bit w/ 4 x 0.0 93.0 11:00 12:30 18's and 8-1/4" power pak motor w/ 1.83` bend, 13-3/8" straight stabilizer, and ported float. Motor has 4/5 5.3 power section, 0.25 rev/gal. Pick up 8- 1/4" arcVISION, 8-1/4" MWD, 8-1/4" NM UBHO, and NM XO. Scribe per MWD/DD and RIH to 93' MD. 8/8/2017 8/812017 1.50 MIRU MOVE RURD P Finish rigging up for running gyro and 93.0 93.0 12:30 14:00 1 1 continue building spud mud. 8/8/2017 8/8/2017 0.25 MIRU MOVE CIRC P Fill conductor and riser and check for 93.0 102.0 14:00 14:15 leaks - all good. RIH to 102' 8/8/2017 8/8/2017 3.75 SURFAC DRILL DDRL P Spud 13-1/2" surface hole, drilling 102.0 390.0 14:15 18:00 from 102'to 390' MD, 390' TVD. Pumps at 466 gpm, 725 psi, 34% F/O. Rotary at 60 rpm, 3k Tq. WOB 20k. PUW 65k, SOW 65k, ROT 65k. AST = 0, ADT = 1.91 hrs, Bit = 1.91 hrs, Jars = 81.59 hrs Page 5121 Report Printed: 8/23/2017 Anil W, Operations Summary (with Timelog Depths) 1 H-118 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Steri Time Er Time Mr (hi-) Phase Op Cotle Ac6vay Cada Time P -T -X Operation (ftKB) FMDBpM(ftKB) 8/8/2017 8/8/2017 5.50 SURFAC DRILL DDRL P Directionally drill 13-1/2" surface hole 390.0 937.0 18:00 23:30 from 390'- 937' MD, 936' TVD. Pumps at 500 gpm, 1120 psi on bottom, 840 psi off bottom, 35% F/O. Rotary at 60 rpm, 4k Tq. WOB 29k. PUW 91k, SOW 93k, ROT 92k w/ 2.5k Tq. MW in/out 9.3 ppg, 250 vis. AST = 1.24 hrs. ADT = 3.51 hrs. Bit = 5.42 hrs. Jars = 85.10 hrs. 8/8/2017 8/8/2017 0.25 SURFAC DRILL CIRC P Circulate with reciprocation from 937' - 937.0 937.0 23:30 23:45 878' MD with 500 gpm, 835 psi, 36% F/O, 8/8/2017 8/912017 0.25 SURFAC DRILL SLKL P Rig up and run Scientific Drilling gyro 937.0 937.0 23:45 00:00 tool on slickline. 8/9/2017 8/912017 1.00 SURFAC DRILL SLKL P RIH wl Gyro tool on slick line to UBHO 937.0 937.0 00:00 01:00 @ 848' MD. POOH taking gyro surveys every 100'. 8/92017 8/9/2017 5.00 SURFAC DRILL DDRL P Directionally drill 13-1/2" surface hole 937.0 1,506.0 01:00 06:00 from 937' MD' to 1506' MD, 1492' TVD. Pumps at 550 gpm, 1370 psi on bottom, 1039 psi off bottom, 37% FIO. Rotary at 60 rpm, 5k Tq on, 3K Tq off . WOB 28-30k. P/U= 100k, S/0= 101k, ROT=92k. Observed gas hydrates @ 1360' MD, 5229 units. AST = 1.56 hrs, ART= 2.06 hrs, ADT = 3.62 hrs. Bit hrs= 9.04, Total Jar hrs= 88.72. 8/9/2017 8/9/2017 3.00 SURFAC DRILL DDRL P Directionally drill 13-1/2" surface hole 1,506.0 1,729.0 06:00 09:00 from 1506' MD' to TD @ 1729' MD, 1704' TVD. Pumps at 550 gpm, 1371 psi on bottom, 1094 psi off bottom, 36% F/0. Rotary at 60 rpm, 5k Tq on, 3K Tq off . WOB -30k. P/U= 104k, SIO= 1051k, ROT=102k. Max gas= 365 units. AST = 1.16 hrs, ART= .44 ITS, ADT = 1.60 hrs. Bit hrs= 10.64, Total Jar hrs= 90.32 8/9/2017 8/9/2017 0.75 SURFAC CASING CIRC P Circulate bottoms up, pump @ 750 1,729.0 1,599.0 09:00 09:45 gpm= 1870 psi. P/U= 104K, S/O= 105K, ROT= 105K. 8/92017 8/9/2017 0.50 SURFAC CASING OWFF P Monitor well for flow for 30 minutes- 1,599.0 1,599.0 09:45 10:15 well static. 8/92017 8/9/2017 3.25 SURFAC CASING BKRM P Backream OOH from 1599'- 752' MD 1,599.0 752.0 10:15 13:30 with 550 gpm, 950 psi, 34% FIO, 60 rpm, 1-5k Tq, PUW 86k, SOW 89k, monitoring displacement via pits 1-5. Observed gas hydrates at 1220' MD of 915 units while backreaming out. 8/9/2017 8/9/2017 0.25 SURFAC CASING OWFF P Blowdown topddve and monitor well 752.0 752.0 13:30 13:45 for flow - well static ' 8/912017 8/9/2017 3.50 SURFAC CASING BHAH P Pull OOH on elevators and lay down 752.0 0.0 13:45 17:15 BHA per SLB, monitoring displacement via trip tank. Bit was in good shape and appeared to be ok to run on next well, graded 1 -1 -WT -A -E- 0 -NO -TD 8/9/2017 8/9/2017 1.00 SURFAC CASING BHAH P Clean and clear rig floor of BHA 0.0 0.0 17:15 18:15 equipment. 8/9/2017 8/9/2017 1.25 SURFAC CASING RURD P Rig up to run 10-3/4" rasing. Drain 0.0 0.0 18:15 19:30 stack for dummy hanger ran. Page 6121 Report Printed: 8123/2017 Operations Summary (with Timelog Depths) 1H-118 DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Stan Tim End Time Our (M) Phase Op Code Ac ty Cade Tim P -T -X Operation MKS) EM Depth MKB) 8/9/2017 8/9/2017 1.25 SURFAC CASING OTHR P Make up casing hanger to landing joint 0.0 0.0 19:30 20:45 in pipe shed and mobilize to rig floor. Perform dummy run and confirm 40.4' MD from rig floor to load shoulder. Mark pipe and lay down same. 8/9/2017 8/9/2017 0.25 SURFAC CASING SFTY P Hold PJSM for running casing. 0.0 0.0 2045 21:00 8/9/2017 8/9/2017 1.00 SURFAC CASING PUTS P Make up shoetrack and RIH to 168', 0.0 168.0 21:00 22:00 bakedocking connections and torquing to 21 k to make-up mads. Fill pipe and circulate additional 15 bbis. Check floats - floats holding. 8/9/2017 8/10/2017 2.00 SURFAC CASING PUTB P RIH on 10-314" 45.5# L-80 Hydril 563 168.0 737.0 22:00 00:00 dopeless rasing from 168'- 737' MD, filling on the fly and topping off every 10 joints, monitoring displacement via pit#5. PUW 71 k, SOW 66k. Torque connections to 23k to make-up mark, no remakes/no rejects. 8/10/2017 8/10/2017 3.50 SURFAC CASING PUTB P Cont RIH on 10-3/4" 45.5# L-80 Hydril 737.0 1,675.0 00:00 03:30 563 dopeless rasing from 737'- 1675' MD, filling on the fly and topping off every 10 joints, monitoring displacement via pit#5. PUW 112k, SOW 101 k. Torque connections to 23k to make-up mark. For overall casing trip, calculated displacement = 27.8 bbls, Actual displacement = -7.9 bbls. Total losses during trip = 35.7 bbls. 8/10/2017 8/10/2017 0.50 SURFAC CASING HOSO P Remove spiders and R/U power 1,675.0 1,719.3 03:30 04:00 tongs. M/U GE casing hanger and landing joint, wash down @ 1 bpm=75 psi. Landing casing hanger on depth @ 1719.31' MD. 8/10/2017 8/10/2017 1.75 SURFAC CEMENT CIRC P Circulate and condtion mud for 1,719.3 1,719.3 04:00 05:45 cement job. Stage pumps up to 7 bpm= 110 psi. Once at 7 bpm pumped 70 bola of weight spud mud 10.5 ppg marker pill with 2 gallons of red dye and 5 ppb NutPlug. Observed pill return to surface @ 3476 stokes, 60 bbls late. P/U= 115K, S/O= 111 K. Note: Discuss results with town and reduce planned lead cement volume to 230 bbls. 8/1012017 8/10/2017 0.25 SURFAC CEMENT RURD P Shut down, blow down top drive and 1,719.3 1,719.3 05:45 06:00 I I R/U cement hose. 8110/2017 8/10/2017 1.50 SURFAC CEMENT CIRC P Cont to circulate and condition mud as 1,719.3 1,719.3 06:00 07:30 per MI @ 7 bpm=230 psi. I Page 7/21 Report Printed: 8/2312017 Operations Summary (with Timelog Depths) IH-118 Rig: DOYON 142 Job: DRILLING ORIGINAL Tlme Log smoepm Stan Torre End Too DW(hr) Phase Op Code Activity Coda Tana RT-X Operabm MKB) End oepm (ftK6) 8/10/2017 8/10/2017 3.50 SURFAC CEMENT CMNT P Hold PJSM. Pumped 5 bola of CW- 1,719.3 1,719.3 07:30 11:00 100, shut down and PT lines to 725/3500 psi. Pumped 35 bbls of CW- 100, 76.2 bbls of 10.5 ppg MP II and dropped bottom plug. Batched up lead cement ( cement wet @ 8:40 hours) Pumped 232.6 bbls of 11.0 ppg LiteCRETE lead cement followed by 60.1 bbls of 15.8 ppg G blend tail cement, kicked top plug out with 10 bbls of fresh water. Displaced cemgnt with 9.5 ppg spud mud, rig pumped @ 6.5 bpm=150 psi ICP, 3.0 bpm=330 psi FCP. Bumped plug @ 1448 strokes, pressure up to 1022 psi for 5 min, bleed off and check floats, good. Observed 24.8 bbls of good 11.0 ppg cement returned to surface. 8/10/2017 8/10/2017 2.25 SURFAC CEMENT RURD P Blow down and rig down cement lines. 1,719.3 0.0 11:00 13:15 Lay down landing joint and drain riser. Wash out lines, remove/clean/re- install cement valves. Rig down GBR volant tool and clean/clear rig floor. 8/10/2017 8/10/2017 0.50 SURFAC WHDBOP WWWH P Make up stack washer, RIH, and flush 0.0 0.0 13:15 13:45 stack and annular with blackwater pill. 8/10/2017 8110/2017 5.75 SURFAC WHDBOP NUND P Pull and laydown mousehole and 0.0 0.0 13:45 19:30 riser. Nipple down and skid diverter line back from cellar. Nipple down surface annular and diverter tee, lift out of cellar, and remove from mezzanine deck. 8/10/2017 8/10/2017 2.25 SURFAC WHDBOP NUND P Remove Vetco starting head. Observe 0.0 0.0 19.30 21:45 it trying to bind up on conductor while lifting with cellar bridge cranes. Rig up long sling with topdrive to starting head and remove successfully. Remove from cellar/mezzanine deck. Clean off casing hanger and install starting flange. SIMOPS - Mobilize wellhead to off- driller side cellar door. Remove off- driller side sliding cellar door frame. 8/1012017 8/11/2017 2.25 SURFAC WHDBOP NUND P Tail wellhead into cellar. Nipple up 0.0 0.0 21:45 00:00 Vetco MB-222A wellhead system and test seal sub to 2000 psi 110 min, witnessed by CPAI - good lest. SIMOPS - Clean pits for taking on LSND. Page 8/21 Report Printed: 8123/2017 Operations Summary (with Timelog Depths) 1 H-118 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Tme End Time Our (hr) Phase Op Code AChvity Code Time P -T -X Operahon Staft Depth (RKB) End Depth(iWB) 8/11/2017 8/11/2017 5.50 SURFAC WHDBOP NUND P Break apart spacer spool to achieve 0.0 0.0 00:00 05:30 needed length for nippling up choke/kill lines to BOPE. M/U spacer spool to wellhead. Nipple up BOPE. to spacer spool. Make up choke and kill hoses. Install riser. Secure stack and air up boots. RKB to center of bag = 19.46'. RKB to upper rams = 22.93'. RKB to blinds = 25.17'. RKB to lower rams = 29.0'. RKB to ULDS = 32.99'. RKB to LLDS = 36.83'. 8/11/2017 8/11/2017 2.50 SURFAC WHDBOP RURD P Mobilize wellhead equipment to rig 0.0 0.0 05:30 08:00 floor. RIH and install test plug. Rig up to test BOPS. Make up floor valves, line up manifold and test hoses. Fill stack and perform shell test on BOPE, 250/3500 psi 5/5 min. Wait for AOGCC rep to arrive to continue. Page 9121 Report Printed: 8/23/2017 AMPIL Operations Summary (with Timelog Depths) 1 H-118 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sam Time End Time Dur (hr)Phase Op Code Activity Code Time P-T-X Operation Sean Depm (ftKB) Erb DepM (WS) 8/11/2017 8/11/2017 6.00 SURFAC WHDBOP BOPE P Test BOPE w/ 7", 5", and 3-1/2" test 0.0 0.0 08:00 14:00 joints to 250/3500 psi, 5/5 min, charted. Witnessed by AOGCC rep Matt Herrera. Test Sequence as follows: With 7" Test joint 1) Annular, Mud Manifold valves 1,12,13, 14, 4" Kill line, and 4-1/2" IF dart valve 2) Upper 7" Casing Rams, Mud Manifold valves 9, 11, Mezz Kill line, and 4-1/2" IF FOSV 3) Mud Manifold valves 8,10, HCR Kill line, and 4" XT39 Dart valve 4) Mud Manifold valves 6, 7 5) Manually Operated Choke and Super Choke tested to 2000 psi 6) Mud Manifold valves 2 and 5, Manual kill, and 4" XT39 FOSV 7) HCR choke 8) Manual choke Perform koomey drawdown test: System Pressure = 2,925 psi PSI after closure = 1,800 psi 200 psi Attained with 2 x electric pumps = 7 seconds Full Pressure attained with 2 x electric and 2 x air pumps = 47 seconds N2 = 6 each @ 2,000 psi Remove 7" test joint 9) Blind Rams, Mud Manifold valves 3 and 4 With 3-1/2" Test Joint 10) Annular, and upper [BOP 11) Lower 3-1/2" x 6" Rams and lower IBOP With 5" test joint: 12) Lower 3-1/2" x 6" Rams Tested all gas and H2S sensors, PVT and Flow alarms both audio and visual, and functioned primary and remote BOP controls - all good. 8/11/2017 8/11/2017 1.50 SURFAC WHDBOP RURD P Pull test plug and install long 0.0 0.0 14:00 15:30 wearbushing with ID = 12.31". Run in lock down screws per Vetco. Blow down test equipment. 8/11/2017 8/11/2017 1.50 SURFAC CEMENT BHAH P PJSM. Mobilize BHA tools to dg Floor. 0.0 0.0 15:30 17:00 8/11/2017 8/11/2017 1.50 SURFAC CEMENT BHAH P PJSM. M/U 8-1/2" production ddllin� 0.0 360.0 17:00 18:30 BHA #2 w/ Smith SDi513 PDC bit nozzled with 3 x 13's and 5 x 14's per SLB. RIH to 360' MD, PUW 75k, SOW 70k. 8/11/2017 8/11/2017 0.75 SURFAC CEMENT TRIP w/ BHA #2 on 5" DP stands from 360.0 1,400.0 18:30 19:15 rrick to 1400'MD, PUW 89k, SOWk, 7PReIH monitoring dis. Page 10121 ReportPrinted: 812312017 Operations Summary (with Timelog Depths) 1 H-118 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stag Time End Time Dr (hr) Phase 4 code Atlrv,ty Coda T,. P -T -X Opeietion a oeDw (flKa) End Deptlt {Itl(a) 8/11/2017 8/11/2017 1.75 SURFAC CEMENT SLPC P PJSM. Slip/cut 73'of drilling line. 1,400.0 1,400.0 19:15 21:00 SIMOPS: Circulate/condition mud at 4 bpm, 112 psi, 14% F/O. 8/11/2017 8/11/2017 1.25 SURFAC TEMENT P Rig up and pressure test 10-3/4" 1,400.0 1,400.0 21:00 22:15 casing and OA valve on wellhead to 3000 psi / 30 min - good test. 3 bbls pumped / 3 bbls returned. 8/11/2017 8/11/2017 0.50 SURFAC CEMENT PULD P RIH from 1400'- 1592' MD on 5" DP 1,400.0 1,592.0 22:15 22:45 singles, monitodng displacement via pit #1 8/1112017 8/11/2017 0.25 SURFAC CEMENT COCF P Ream down from 1592'to 1632' MD 1,592.0 1,632.0 22:45 23:00 with 450 gpm, 695 psi, 30% F/O, 60 rpm, 2k Tq, tagging top of plugs on depth. Observe cement stringer at 1602' and consistent 1k WOB from 1613' onwards. 8/11/2017 8112/2017 1.00 SURFAC CEMENT DRLG P Drillout plugs from 1632'- 1634' MD 1,632.0 1,634.0 23:00 00:00 and transition to float collar from at 1634' MD with 450 gpm, 665 psi, 30% F/O, 50-80 rpm, 2-5k Tq, 5-12k WOB, PUW 95k, SOW 97k, ROT 97k. 8/12/2017 8/12/2017 3.25 SURFAC CEMENT DRLG P Drillout shoetrack f/ 1634'- 1719' MD 1,634.0 1,729.0 00:00 03:15 with 550 gpm, 945 psi, 34% F/O, 70 rpm, 4-5k Tq, 12-17k WOB, 930 psi Off btm, PUW 95k, SOW 93k, ROT 97k. 8/12/2017 8/12/2017 0.25 SURFAC TEMENT P Drill 20' of new 8-1/2" hole from 1729' 1,729.0 1,749.0 03:15 03:30 - 1749' MD, 1722' TVD, with 550 gpm, 945 psi, 34% VO, 10.3 ppg ECD, 9.6ppg Spud mud, 70 rpm, 4-5k Tq, 6k WOB, PUW 95k, SOW 93k, ROT 97k w/ 2k Tq. ADT = 0.26 hrs, Bit = 0.26 hrs, Jars = 0.26 hrs. 8/12/2017 8112/2017 0.50 SURFAC CEMENT CIRC P Rack back stand and circulate I 1,749.0 1,685.0 03:30 04:00 condition mud with 750 gpm, 1590 psi, 45 rpm, 2k Tq, 10.15ppg ECD, 38% F/O, until even 9.5+ in/out observed. 8/1212017 8/12/2017 0.75 SURFAC CEMENT FIT P Line up to pump down drill pipe and 1,685.0 1,685.0 04:00 04:45 annulus, Gose bag, and use mud pump #1. Perform FIT w/ 9.55 ppg Spud mud at 1695' TVD. Applied 310 psi surface pressure, observing slight bobble in pressure at 250 psi. Shut in and monitored for 10 minutes, observing pressure drop down to 170 psi after 3 minutes and 140 psi after 10 minutes. FIT chart picked it at a 12 ppg EMW FIT. Pumped 2 bbls / retumed 1 bbl. Rig down and blow down test lines. 8/12/2017 8/12/2077 0.50 PROD1 DRILL CIRC P Pump 30 bbl hi -vis spacer at 166 gpm, 1,685.0 1,749.0 04:45 05:15 160 psi and wash down to bottom while starting displacement to 9.2ppg LSND. Stage up rate to 550 gpm, 950 psi, 34% F/O, 55 rpm, 2.5k Tq. Page 11121 Report Printed: 8-123-120-171 Operations Summary (with Timelog Depths) 1 H-118 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Tuna Our(hr) Phase Op Code Activity Code Time PJA Operation De pah nt Start Eh End Depth (ttKB) 8/12/2017 8/12/2017 0.75 PROD1 DRILL DDRL P Directionally drill 8-1/2" production 1,749.0 1,795.0 05:15 06:00 hole from 1749'- 1795' MD with 550 gpm, 760 psi, 34% F/O, 9.95ppg ECD, 80 rpm, 4-5k Tq, 4k WOB, 740 psi off- btm, PUW 97k, SOW 95k, ROT 97k w/ 2K Tq. ADT = 0.53 hrs, Bit = 0.79 his, Jar = 0.79 hrs. Finish displacing well to 9.2ppg LSND and take new SPR's. SPRs @ 1778' MD 1748' TVD, MW=9.20 ppg, 05:30 hours MP#1: 30 spm=100 psi, 40 spm=120 psi. MP #2: 30 spm=100 psi, 40 spm=120 psi. 8/12/2017 8/12/2017 6.00 PROD? DRILL DDRL P Directionally drill 8-1/2" production 1,795.0 2,447.0 06:00 12:00 hole from 1795'- 2447' MD with 650 gpm, 1040 psi, 35% F/O, 10.5 ppg ECD, 110 rpm, 4-5k Tq, 5-8k WOB, 1020 psi off-btm, PUW 107k, SOW 102k, ROT 104k w/ 2k Tq. ADT = 4.43 hrs, Bit = 5.22 hrs, Jar = 5.22 hrs. Pump 30 bbl hi-vis sweep with 5 ppb NutPlug Medium every-400'. Observe sharp gas peak of 5925 units at 2026' MD and 4000 units at 2157' MD and then tapered off back to zero. 8/12/2017 8/12/2017 6.00 PROD1 DRILL DDRL P Directionally drill 8-1/2" production 2,447.0 3,484.0 12:00 18:00 hole from 2447'- 3484' MD, 2623' TVD with 700 gpm, 1376 psi, 37% VO, 10.99 ppg ECD, 120-170 rpm, 4-6k Tq, 10-15k WOB, PUW 106k, SOW 94k ROT 101 k w/ 5k Tq, 1364 psi off- btm, Max gas 30 units, ADT = 4.16 hrs, Bit = 9.38 hrs, Jar = 9.38 hrs. Pump 30 bbl hi-vis sweep with 5 ppb NutPlug Medium every -400'. SPRs @ 2630' MD 2384' TVD, MW=9.20 ppg, 13:00 hours MP#1: 30 spm=150 psi, 40 spm=180 psi. MP #2: 30 spm=140 psi, 40 spm=180 psi. Page 12/21 ReportPrinted: 8/23/2017 Operations Summary (with Timelog Depths) IH -118 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sout Lme End Tima Dur (hr) Phase Op Code Ac" Code Time P -T -X Operation Start Depth (ftKe) End Depth (111<8)8/12/212 017 8/13/2017 6.00 PROD1 DRILL DDRL P Directionally drill 8-1/2" production 3,484.0 4,507.0 18:00 00:00 hole from 3484'- 4507' MD, 2899' TVD with 700 gpm, 1565 psi, 39% f/O, 11.43 ppg ECD, 140-170 rpm, 7k To, 10-15k WOB, PUW 115k, SOW 86k, ROT 99k w/ 5k Tq, 1497 psi off-btm, Max gas 17 units, ADT = 3.91 hrs, Bit = 13.29 hrs, Jar = 13.29 hrs. Pump 30 bbl hi -vis sweep with 5 ppb NutPlug Medium every -400'. SPRs @ 3670' MD 2670' TVD, MW=9.25 ppg, 19:15 hours MP#1: 30 spm=200 psi, 40 spm=250 psi. MP #2: 30 spm=200 psi, 40 spm=250 psi. No downhole losses for past 24 hours. 8/13/2017 8/13/2017 6.00 PROW DRILL DDRL P Directionally drill 8-1/2" hole from 4,507.0 5,408.0 00:00 06:00 4507'- 5408' MD, 3142' TVD with 750 gpm, 1900 psi, 39% F/O, ECD 11.86 ppg, 1890 psi off-btm, 125-140 rpm, 7- 10k Tq, 10-15k WOB, PUW 123k, SOW 82k, ROT 103k w/ 7k Tq. Max gas 17 units. ADT 4.42 hrs, Bit 17.71 hrs, Jar 17.71 hrs. Pump 30 bbl hi -vis sweep with 5 ppb NutPlug Medium every —400'. 8/13/2017 8/13/2017 6.00 PROD1 DRILL DDRL P Directionally drill 8-1/2'holefrom 5,408.0 6,061.0 06:00 12:00 5408'- 6061' MD, 3328' TVD with 750 gpm, 1950 psi, 39% F/O, ECD 11.55 ppg, 1900 psi off-btm, 130-160 rpm, 9- 11k Tq, 10-15k WOB, PUW 144k, SOW 99k, ROT 109k w/ 7k Tq. Max gas 109 units, ADT 4.29 hrs, Bit 22. hrs, Jar 22 hrs. Pump 30 bbl hi -vis sweep with 5 ppb NutPlug Medium every —400'. Note: Increase lubes to 1.25% from 5700' onwards due to increased torque / stick -slip. SPRs @ 5849' MD 3261' TVD, MW=9.20 ppg, 10:00 hours MP#1: 30 spm=260 psi, 40 spm=340 psi. MP #2: 30 spm=260 psi, 40 spm=340 psi. Page 13/21 Report Printed: 8/23/2017 Operations Summary (with Timelog Depths) 1 H-118 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Tone End Time Dur (hr) Phase Op Cmtle Activity Cmee Time P -T -X Cpeahmn Steri DepN. (ftK6) End CepN (itKa) 8/13/2017 8/13/2017 6.00 PROD1 DRILL DDRL P Directionally drill 8-1/2" hole from 6,061.0 6,612.0 12:00 18:00 6061'- 6612' MD, 3535' TVD with 550 gpm, 1274 psi, 33% F/O, ECD 10.86 ppg, 1270 psi Off-btm, 100 rpm, 12k Tq, 13k WOB, PUW 154k, SOW 107k, ROT 124k w/ 10k Tq, Max gas 88 units, ADT 4.04 hrs, Bit 26.04 hrs, Jar 26.04 his. Pump 30 bbl hi -vis sweep with 5 ppb NutPlug Medium every —500'. Note: Vary parameters per DD to try and maximize dogleg for making left - tum due to dead spots - encounter hard spot at 6612' MD / 3533' TVD SPRs @ 6508' MD 3485' TVD, MW=9.30 ppg, 16:00 hours MP#1: 30 spm=260 psi, 40 spm=320 psi. MP #2: 30 spm=260 psi, 40 spm=320 psi. 8/13/2017 8/14/2017 6.00 PROD1 DRILL DDRL P Directionally drill 8-1/2" hole from 6,612.0 6,852.0 18:00 00:00 6612'- 6852' MD, 3620' TVD with 460 gpm, 984 psi, 32% F/O, ECD 10.5 ppg, 940 psi off-btm, 130 rpm, 10k Tq, 1 O WOB, PLAN 158k, SOW 109k, ROT 125k w/ t Ok Tq, Max gas 23 units, ADT 3.7 hrs, Bit 29.74 hrs, Jar 29.74 hrs. Pump 30 bbl hi -vis sweep with 5 ppb NutPlug Medium every , —500'. Note: Vary parameters per DO to try and maximize dogleg for making left - turn due to dead spots - encounter concretion at transition into top of N - sand at 6781' MD - 6784'/ 3593' TVD No downhole losses observed over past 24 hours 8/14/2017 8/14/2017 6.00 PROD1 DRILL DDRL P Directionally drill 8-1/2" hole from 6,852.0 7,190.0 00:00 06:00 6852' - 7190' MD, 3735' TVD with 475 gpm, 1080 psi, 32% IF/O, 110-130 rpm, 11k Tq, 11-13k WOB, PUW 160k, SOW 109k ROT 121k w/ 10k Tq, 10.5ppg ECD, 1080 psi Off-btm, Max gas 9 units, ADT 4.76 hrs, Bit 34.5 hrs, Jar 34.5 hrs. Encounter hard spot at 6968'- 6969' MD. Page 14/21 Report Printed: 8123/2017 . Operations Summary (with Timelog Depths) w 1 H-118 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Torre Our (iv) Phase Op codeArAvlty Code Time P-T-X Ope2tion Start Depth (Ih(B) EM DOM (ftKB) 8/14/2017 8/14/2017 6.00 PROD1 DRILL DDRL P Directionally drill 8-1/2" hole from 7,190.0 7,368.0 06:00 12:00 7190'- 7368' MD, 3810' TVD with 593 gpm, 1500 psi, 32% F/O, 130-150 rpm, 14k Tq, 13-15k WOB, PUW 162k, SOW 111 k, ROT 123k w/ 1 Ok Tq, 10.91ppg ECD, 1460 psi off-btm, Max gas 229 units, ADT 4.28 hrs, Bit 38.78 hrs, Jar 38.78 hrs. Encounter hard spot at 7281' - 7288', and 7327' - 7330' MD. SPRs @ 7368' MD 2810' TVD, MW=9.30 ppg, 12:00 hours MP#1: 30 spm=300 psi, 40 spm=340 psi. MP #2: 30 spm=280 psi, 40 spm=360 psi. 8/14/2017 8/14/2017 6.00 PRODt DRILL DDRL P Directionally drill 8-1/2" hole from 7,368.0 7,703.0 12:00 18:00 7368'- 7703' MD, 3936' TVD with 655 gpm, 1860 psi, 36% F/O, 130 rpm, 10- 13k Tq, 17k WOB, PUW 168k, SOW 108k, ROT 132k w/ 11k Tq, 11.3ppg ECD, 1850 psi off-btm, Max gas 33 units, ADT 4.74 hrs, Bit 43.52 hrs, Jar 43.52 hrs. Encounter hard spot at ' 7441'- 7444' and 7529'- 7532' MD. 8/14/2017 8/15/2017 6.00 PROD1 DRILL DDRL P Directionally drill 8-1/2" hole from 7,703.0 8,011.0 18:00 00:00 7702'- 801 VMD, 4049' TVD with 655 gpm, 1920 psi, 35% VO, 140 rpm, 7- 14k Tq, 171k WOB, PUW 167k, SOW 110k, ROT 125k w/ 12k Tq, 11.25 ppg ECD, 1885 psi off-btm, Max gas 36 units, ADT 4.38 hrs, Bit 47.9 hrs, Jar 47.9 hrs. Encounter hard spot at 7775' - 7779' MD. SPRs @ 7929' MD 4018' TVD, MW=9.35 ppg, 22:15 hours MP#1: 30 spm=320 psi, 40 spm=380 psi. MP #2: 30 spm=320 psi, 40 spm=360 psi. No downhole losses for past 24 hours. 8/15/2017 8/15/2017 3.00 PROD1 DRILL DDRL P DDRIL from 8,011'to 8,131' MD 4,092' 8,011.0 8,131.0 00:00 03:00 TVD. 650 GPM @ 1,930 PSI DPP on BTM. 140 RPM with with 16K TQ on BTM. 12K OFBM. 17K WOB. F/O 36%,178K UP WT -- 135K WT ROT. ECD = 11.21 PPG with 9.3 PPG MW. 120 Gas units. TD Called. 8115/2017 8/15/2017 0.50 PRODi CASING CIRC P Pump sweep and spot at TD. 8,131.0 8,131.0 03:00 03:30 Circulate sweep to surface at 700 GPM 2,167 PSI DPP. Recip / rotate pipe 150 RPM. 8/15/2017 8/15/2017 0.50 PROD1 CASING OWFF P Observe well for static conditions. 8,131.0 8,131.0 03:30 04:00 8115/2017 8115/2017 7.00 PROD1 CASING BKRM P Back ream from 8131'- 5,100' MD. 8,131.0 5,100.0 04:00 11:00 150 RPM at 700 GPM. 1,736-2000 PSI DPP. Page 15121 ReportPrinted: 8/2312017 Operations Summary (with Timelog Depths) 1H-118 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Siert Time End Time Dur (hr) Phase Op Cptle Az"Cotle Time P -T -X 0'.h.n 5lart Depth MKS) Ertl Depih(WB) 8/15/2017 8/15/2017 2.75 PROD1 CASING RGRP T Elevators came in contact with 5,100.0 5,100.0 11:00 13:45 monkey board, CBU @ 700 gpm=1800 psi, slow pumps to 2 bpm=300 psi. Assess damage to monkey board and develop plan forward. Installed another secondary retention to monkey board and decision made to BROOH L/D DP using 90' mouse hole. 8/1512017 8/16/2017 10.25 PRODt CASING BKRM P Back Ream from 5.100'- 1,689' MD, 5,100.0 1,689.0 13:45 00:00 laying down stands in 90' mousehole. 700-750 GPM at 1,792 - 1,600 PSI DPP. 36-38% F/O. No overpulls. Some indication of packoffs but no events. Did try to POOH on elevators three attempts but swabbing prevented this procedure. 8/16/2017 8/16/2017 0.50 PROD1 CASING CIRC P Rotate and circ at 1689'- 1590' MD at 1,689.0 1,689.0 00:00 00:30 750 GPM. 1,350 PSI DPP. 37% F/O, with 80 RPM. 2K TQ up wt = 94K. ROT WT = 96K. Complete 3 BU and observe well for flow. 8/16/2017 8/16/2017 1.50 PROD1 CASING PULD P POOH on elevators laying down drill 1,689.0 364.0 00:30 02:00 pipe. to 364' MD. LD 14 stands of HWDP. (42)jts. 8/162017 8/16/2017 2.00 PRODt CASING BHAH P LD 8 112" BHA and HWDP. Clear pipe 364.0 0.0 02:00 04:00 shed. and rig floor of BHA componets. 8/16/2017 8/16/2017 1.00 COMPZN CASING WWWH P MU NZLATOR for washing stack. MU 0.0 0.0 04:00 05:00 pulling tool - back out LD bolts and pull wear bushing. 8/16/2017 8116/2017 2.50 COMPZN CASINO RURD P Pick up GBR equip for casing run. 0.0 0.0 05:00 07:30 Make up Volant & handling equipment for effect. 8/16/2017 8/16/2017 5.50 COMPZN CASING PUTB P Make up Shoe track and Baker lock 0.0 1,254.0 07:30 13:00 same. RIH / check floats. Continue to RIH with 7" casing torquing up TXP connections to 17,500 FT?LBS Filling pipe every ten joints. RIH to 1,254' MD. Bad threads on joint 31 and 32. LD Joints and swap out with backup 12. after installing centralizers. 8/16/2017 8/16/2017 1.00 COMPZN CASING PUTB P RIH with 7" 26# casing from 1254'to 1,254.0 1,700.0 13:00 14:00 1700' MD monitor displacement via pHs. Fill on the fly and top off every len joints. TW TXP connections to 17,500 FT/LBS 8/16/2017 8/16/2017 0.50 COMPZN CASING CIRC P Condition mud at 1,700' MD. Stage 1,700.0 1,700.0 14:00 14:30 pumps up to 7 BPM, ICP = 78, FCP = 95 PSI. 23% F/O. Total strokes pumped = 1,729. UP WT = 82K. OWN WT = 86K. 8/16/2017 8/16/2017 6.25 COMPZN CASING PUTB P RIH with 7"26#casing from 1,700'- 1,700.0 4,500.0 14:30 20:45 4,500' MD Monitor displacement via pits. FU on the fly. also every 10 jts. TQ TXP connections to 17,500 FT/LBS. Observe steady decline in V%17. Page 16121 Report Printed: 8/23/2017 Operations Summary (with Timelog Depths) 1 H-118 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code AMVity Code Time P-T-XStart Operetlon DepN (flKa) End Depth (rtK6) 8/16/2017 8/16/2017 1.25 COMPZN CASING CIRC P Recipricale pipe from 4,500'-4,475' 4,500.0 4,575.0 20:45 22:00 MD. Stage pumps up to 7 BPM @ 318 PSI.. FCP = 470 PSI. UP WT 112K. DWN WT=78K. Total stks pumped = 3,402. Sand in returns. 8/16/2017 8/17/2017 2.00 COMPZN CASING PUTB P Continue to RIHI with 7" 26# casing. 4,575.0 5,533.0 22:00 00:00 from 4,575'- 5,533' MD. UP WT = 160K, DWN WT=80K. Monitor disp via active pits. Fill on the fly every ten joints. TW TXP to 17,500#. 16 BELS loss for the day. 8/17/2017 8/17/2017 6.00 COMPZN CASING PUTB P Cont to RIH w/ 7", 26# TXP/H563 f/ 5,533.0 8,079.0 00:00 06:00 5533' MD to 8079' MD. P/U= 200K, S/0= 80K. Make up 7" TXP to 17,500 It/lbs w/ run n seal w/ 1.2 FF, 7" Hyd 563 to 9,500 ItAbs. Wash the last joint down @ 2.5 bpm= 560 psi. 2 remakes and 2 rejects. 8/17/2017 8/17/2017 0.50 COMPZN CASING HOSO P Make up Vetco 7" casing hanger and 8,079.0 8,121.0 06:00 06:30 landing joint. Land hanger on load shoulder @ 8120.95' MD 8/17/2017 8/17/2017 2.00 COMPZN CEMENT CIRC P Circulate and condition mud for 8,121.0 8,110.0 06:30 08:30 cement job, stage pumps up f/ 2 bpm= 400 psi to 7 bpm= 700 psi. P/U= 177K, S/O= 66K. 8/17/2017 8/17/2017 3.00 COMPZN CEMENT CMNT P PJSM. Cement 7" casing as follows. 8,110.0 8,121.0 08:30 11:30 SLB pump 5 bbls of water, PT lines to 350 psi low, 4500 psi high. Batch up and pump 28.7 bbls of 12.5 ppg MPII, shot down and drop bottom plug. Batch up lead cement ( cement wet @ 9:19 hrs) Pump 59.4 bbls of 14.0 ppg lead cement followed by 68 bbls of 15.8 ppg tail cement, shut down and drop lop plug. SLB washed up cement lines to rock washer before kicking top plug out. SLB pumped displacement with 9.0 ppg brine @ 7 bpm= 590 psi. Al 280 bbls into the displacement flow out dropped from 21°% to 11%, slowed pump rate to 3 bpm= 1200 psi. Bumped plugs @ 308 bbls, pressure up to 2200 psi ( 500 psi over FCP) hold for 5 min, bleed off and check floats, good. Observed good lift pressure while displacing cement and lost 10 bbls of fluid to the formation. 8/17/2017 8/17/2017 1.00 COMPZN CEMENT RURD P OWFF, static. RID cement hose, 8,121.0 0.0 11:30 12:30 landing joint, Volant CRT and elevators. 8/17/2017 8/17/2017 2.00 COMPZN CEMENT W WSP P PU 5" test joint and install 10.75" X 7" 0.0 0.0 12:30 14:30 packoff. Test packoff to 5000 PSI as per Velco Rep. Test witnessed by DC. Sim OPs with clearing of rig floor and cleaning of mud manifold / pits. Install 9" ID wear bushing and RILDS. Page 17121 Report Printed: 8123/2017 Operations Summary (with Timelog Depths) 1 H-118 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time EM Time our hr ( ) Phase Op L'oCe ANvity Cotla Tmie P -T -X Operation Start Depth (ttKe) EM Depen (flKB) 8/17/2017 8/18/2017 9.50 COMPZN CEMENT WOC P Wait on cement to cure while 0.0 0.0 14:30 00:00 perfomdng pipe management in shed. L:oad up 3 1/2" completion, and 4" drill pipe stap all. Load HES guns in shed. Change out Saver Sub to XT 39. CO dies of 4". Service top drive. 8/18/2017 8/18/2017 1.00 COMPZN CEMENT WOC P Wail on cement. Tally 4" DP in shed./ 0.0 0.0 00:00 01:00 Prep for CBL run. 8/18/2017 8/18/2017 4.50 COMPZN CEMENT ELOG P MIRU SLB for CBL. Pre -job with rig 0.0 0.0 01:00 05:30 crew. RIH 8/18/2017 8/18/2017 4.50 COMPZN CEMENT ELOG P Logging up from 8,024' MD. 0.0 0.0 05:30 10:00 Corrected 2' for depth control. 8/1812017 8/18/2017 0.75 COMPZN CEMENT ELOG P RD aline and stand back. 0.0 0.0 10:00 10:45 8/18/2017 8/18/2017 1.25 COMPZN CEMENT PRTS P Rig up to pressure test casing to a 0.0 0.0 10:45 12:00 charted 3,500 PSI. (GOOD) 60 STKS to pressure. 4.6 BBLS bleed back. SIMOPS LRS injecting ISOTHERM in to 10 3/4" X 7" ann. 8/18/2017 8/18,"2017 1.00 COMPZN PERF SHAH P Pick up TCP handling exuipment to rig 0.0 0.0 12:00 13:00 floor and dg up. 8/18/2017 8/18/2017 3.25 COMPZN PERF SHAH P PJSM. PU 3.125" TCP pert gun BHA 0.0 765.0 13:00 16:15 785.67' UP wt 52K. DWN wt = 52K. Monitor disp via pit one. SIMOPS ISOTHERM freeze protect in 10 3/4" X 7" ann. Pump 100 BBLS of water staging up to 4 112 BPM. ICP = 500 PSI. FCP = 375 PSI. Chase water with 93 BBLS of isotherm at 3 BPM. ICP 350 PSI / Final = 700 PSI. Log sent to town and verbal recieved from AOGCC Victoria to proceed with , perforation as program is written. 8/18/2017 8/19/2017 7.75 COMPZN PERF PULD P PU 4" XT -39 DP in singles. from 785' 765.0 7,039.0 16:15 00:00 to 7,039' MS. up WT = 107K. DWN WT = 70K. moniotor displacemet via pit one. 8/19/2017 8/19/2017 1.75 COMPZN PERF PULD P Cont RIH picking up 4" DP from pipe 7,039.0 8,028.0 00:00 01:45 shed fl 7039' MD to 8026' MD. P/U= 122K, BID= 73K. Set down 5K on float collar @ 8028' MD. Tally depth for FC 8030, add 1.5' for plugs, tag on depth. 8/19/2017 8/19/2017 0.50 COMPZN PERF TRIP P POOH f/ 8028' MD to 7886.65' MD, 8,028.0 7,886.9 01:45 02:15 21' below perp depth. P/U= 122K, S/O= 73K. 8119/2017 8/1912017 7.25 COMPZN PERF ELOG P RN SLB E -line and RIH to attempt to 7,886.9 7,886.9 02:15 09:30 correlate marker joint and PIP tag. Unable to get past 3800' MD, POOH w/ a -line and remove rollers and add 2 weight bars. RIH w/ E -line and unable to get past 3900; MD. POOH w/ E - line, RIH w/ 4 weight bars and 3 rollers, unable to get past 4170' MD. E -line observed fluid level @ 3600' MD, added additional fluid to raise fluid level to 2300' MD to achieve desired 1000 psi under balance. decision made to perf based on pipe tally , depths. Page 18121 Report Printed: 8/23/2017 Operations Summary (with Timelog Depths) 1 H-118 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Star) Time End Time Dur (hr) Phase Op Cotla Agivity Code Time P -T-% Operation Start Depth (ftKB) End Deptlt (fIKB) 8/19/2017 8/19/2017 0.50 COMPZN PERF MPSP P M/U 10'4" XT -39 pup joint, set Champ 7,886.9 7,865.3 09:30 10:00 packer as per HES rep and set down 20K to ensure packer set. PIU= 128K, S/O= 74K. 8/19/2017 8/19/2017 1.00 COMPZN PERF RURD P LID single and R/U floor valve, head 7,865.3 7,865.3 10:00 11:00 pin, plug valve and high pressure hose from DP and choke manifold. Install bail extensions and close annular. 8/19/2017 8/19/2017 0.50 COMPZN PERF PERF P Pressure IA to 3200 psi to fire guns, 7,865.3 7,865.3 11:00 11:30 bleed pressure off to 250 psi on IA. Observed guns fire after 6: 25 min's. Allow pressure to equalize, pressure on IA increased from 250 psi to 300. No increase observed on OF. Perforations: 7246' to 7348', 7424' to 7504', 7554' to 7587', 7693' to 7737' and 7815'to 7861'. 8/19/2017 8/19/2017 1.00 COMPZN PERF CIRC P Open bypass on champ packer, P/U 7,865.3 7,865.0 11:30 12:30 and observed 300 psi drop off the IA. Reverse circulate out oil/gas from under balanced perforating. Bring pumps online @ 2 bpm= 150 psi until DP side reacted. Maintain pump pressure @ 150 psi while CBU adjusting chokes as needed. Circulated out — 10 bbls of crude oil to cuttings tank. Still seeing crude and shakers after 1-1/2 drill pipe volumes. Shut and pumps and close chokes to monitor pressures. 8/19/2017 8/19/2017 0.50 COMPZN PERF OWFF P Close annular and monitor pressure. 7,865.0 7,865.0 12:30 13:00 Observe 20 PSI on DP. 8/19/2017 8/19/2017 1.00 COMPZN PERF CIRC P Open chokes and circulate at 4BPM. 7,865.0 7,865.0 13:00 14:00 424 PSI total stks 894. W/ANN closed and 500 PSI on string PU on string to release packer. Observed 150 UP WT. STBY 10 MIN for PKR relax. Slack off to confirm release. 72K OWN WT. 8/19/2017 8/19/2017 1.00 COMPZN PERF CIRC P RU to circulate down drill string taking 7,865.0 7,865.0 14:00 15:00 returns through gas buster. Circ S/S volume @ 5 BPM -- 475 PSI. 2,410 stks. 8/19/2017 8/19/2017 0.75 COMPZN PERF OWFF P Pumps off. open ann and OWFF. 7,865.0 7,865.0 15:00 15:45 Static. BID lines and manifold. 8/19/2017 8/19/2017 0.25 COMPZN PERF RURD P LD 10' XT39 pup. RD bail 7,865.0 7,865.0 15:45 16:00 extensions. Install pipe wipe and power slips. 8/19/2017 8/19/2017 6.00 COMPZN PERF PULD P POOH with 4" sideways from 7,865'- 7,865.0 786.0 16:00 22:00 1,609' MD. UP WT 150K. DWN WT= 77K. Monitor well via TT. 8/19/2017 8/20/2017 2.00 COMPZN PERF BHAH P PJSM, LD pert guns from 786' MD - 0' 786.0 0.0 22:00 00:00 All shots fired. 8/20/2017 8/20/2017 1.50 COMPZN PERF SHAH P Finish laying down HES TCP guns' 0.0 0.0 00:00 01:30 and clean rig floor. Pull wear bushing. 8/20/2017 8/20/2017 3.50 COMPZN RPCOMP PULD P Lay down stands out of derrick prior to 0.0 0.0 01:30 05:00 RIH iwth new completion. Page 19121 Report Printed: 8123/2017 Operations Summary (with Timelog Depths) 1 H-118 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stat Tina End Tsne Our (hr) Phase Op Code Activity Code Time P-T-X Operation start Depth (flKB) End Depth (WS) 8120/2017 8/20/2017 3.00 COMPZN RPCOMP RURD P RU all equipment needed for 0.0 0.0 05:00 08:00 completion run.. GBR / Load pipe shed with completion equipment. Send 240 clamps to rig floor. Verify pipe running order. 8/20/2017 8/20/2017 1.25 COMPZN RPCOMP PUTS P Hold PJSM. RIH with 3 1/2" 9.3# L-80 0.0 466.0 08:00 09:15 8RND EUE upper completion as per program. to 466' 8/20/2017 8/20/2017 2.75 COMPZN RPCOMP PUTB P Terminate tech wire into DHG #1 and 466.0 429.0 09:15 12:00 test same as per proceedure. 8/20/2017 8/20/2017 1.50 COMPZN RPCOMP PUTS P Terminate tech wire into Halliburton 429.0 429.0 12:00 13:30 packer and test same. 8/20/2017 8/20/2017 0.50 COMPZN RPCOMP PUTB P Pick up DHG / and Halliburton packer 429.0 557.0 13:30 14:00 number two as per program and !stall / test same. 8/20/2017 8/2012017 3.75 COMPZN RPCOMP PUTS P Terminate tech wire into Halliburton 557.0 557.0 14:00 17:45 packer and test same. 8/20/2017 8/20/2017 0.75 COMPZN RPCOMP PUTB P RIH from 557'-810 MD with 3 112" 9.3# 557.0 810.0 17:45 18:30 L-80 tubing pick up DHG and Halliburton packer Q. , 8/20/2017 8/20/2017 3.75 COMPZN RPCOMP PUTB P Terminate tech wire into Halliburton 810.0 810.0 18:30 22:15 packer and test same. 8/20/2017 8/21/2017 1.75 COMPZN RPCOMP PUTB P RIH forth 810'-1,909' MD with 3 1/2" 810.0 1,909.0 22:15 00:00 9.3# L-80 production tubing as per tally. UP WT=61K OWN WT=62K. Monitor disp via TT. Installing Cannon clamps every jconnection. 8/21/2017 8/21/2017 8.50 COMPZN RPCOMP PUTB P Continue to RIH with 31/2" 9.3# L-80 1,909.0 7,570.0 00:00 08:30 Production tubing strapping every connection with Cannon clamp. 8/21/2017 8/21/2017 0.75 COMPZN RPCOMP PUTS P Begin seeing WT at 7,570' MD. Wash 7,570.0 7,602.0 08:30 09:15 down with 3 BPM 245 PSI DPP. WOB = 2-4K. 7,570'- 7,602' MD. DWN WT =61K. Up WT=101K. 8/21/2017 8/21/2017 0.50 COMPZN RPCOMP PUTB P Continue to RIH with 3 1/2" completion 7,602.0 7,697.0 09:15 09:45 from 7,602'-7,697' MD. DWN WT = 61 K. 8/21/2017 8/21/2017 3.25 COMPZN RPCOMP PUTS P Continue to wash down from 7,697'- 7,697.0 8,034.0 09:45 13:00 8,034' MD UP WT = 108K, DWN WT = 60K. Utilizing 3 1/2" 9.3# L-80 completion. Pump 85 BBLS of Cl brine at 3 BPM 235 PSI DPP. Monitor disp via TT. 8/21/2017 8/21/2017 0.50 COMPZN RPCOMP HOSO P POOH on elevators from 8,034 - 8,034.0 7,923.0 13:00 13:30 7,923' MD UP WT = 108K. DWN WT = 60K. Monitor disp via TT. 8/21/2017 8/21/2017 1.50 COMPZN RPCOMP ELOG P PJSM with SLB MIRU 7,923.0 7,923.0 13:30 15:00 8/21/2017 8/21/2017 2.75 COMPZN RPCOMP ELOG P RIH with Gamma / CCL / SLMD on 7,923.0 7,923.0 15:00 17:45 SLB wline. LOG and POOH. Eline logged PIP tag at 6,986' MD. Logged correlation pass accross completion equipment to tie pkrs on depth. Page 20/21 Report Printed: 8/23/2017 . Operations Summary (with Timelog Depths) 1 H-118 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time EM Time Our (hr) Phase Op codeActivity Code Time P-T-% OPerztion Start Capth (WS) End DBPtlt (Wa) 8/21/2017 8/21/2017 1.25 COMPZN RPCOMP HOSO P Space out. LAY down joints 240-241. 7,923.0 7,923.0 17:45 19:00 PU and make up joints 10.21' and 6.16' pup joints EUE X 4 1/2" 563 X/O (1.55') , C/O elevators, PU and TO 4 112" 563 (40.37') MU landing joint to TBG hanger and POOH to orient hanger. 8/21/2017 8/21/2017 1.00 COMPZN RPCOMP THGR P Terminate tech wire from DHG. Test 7,923.0 7,923.0 19:00 20:00 connections to 5000 PSI. 8/21/2017 8/21/2017 0.50 COMPZN RPCOMP THGR P RIH and land tubing hanger. RILDS. 7,923.0 7,946.0 20:00 20:30 8/21/2017 8/21/2017 1.00 COMPZN RPCOMP THGR P Pressure test seals to 5,000 PSI 7,946.0 7,946.0 20:30 21:30 upper/ lower. (PASSED) 8121/2017 8/21/2017 0.75 COMPZN RPCOMP CIRC P Pump 150 BBLS of Cl brine at 3 BPM. 7,946.0 7,946.0 21:30 22:15 290 PSI with 12% F/O. 1,426 STKS. 8/21/2017 8121/2017 0.50 COMPZN RPCOMP PACK P Pump 1.25" ball (confimed) at 3 BPM 7,946.0 7,946.0 22:15 22:45 264 PSI DPP. 12% F/O. Ball on seal at 624 STKS. Increase PSI to 3,500 PSI to close WIV and fully set Halliburton PKRS. Hold for 30 Min. 8/21/2017 6122/2017 1.25 COMPZN RPCOMP PRTS P Pressure test tubing then casing to 7,946.0 7,946.0 22:45 00:00 3,500 PSI for 30 min apiece and charted. (PASSED). 8/22/2017 8/22/2017 1.00 PRODt RPCOMP PRTS P Continue pressure testing tubing to 00:00 01:00 - 3,500 PSI charted (PASSES) Pressure up on IA to 2,600 PSI and shear out SO valve. confirmed with 2 BPM @ 225 PSI. 8/22/2017 8/2212017 0.50 PROD1 RPCOMP OWFF P Monitor well for flow (10) min. BD all 01:00 01:30 1lines. 8/22/2017 8/22/2017 0.75 PROD1 RPCOMP THGR P Set BPV and test same to 2,500 PSI. 01:30 02:15 8/22/2017 8/2212017 4.75 PRODt RPCOMP NUND P NO BOPS EQUIP. Clean out hanger 02:15 07:00 area and install production tree. 8/22/2017 8/22/2017 0.75 PROOI RPCOMP THGR P Test hanger void both seals to 5,000 07:00 07:45 PSI. (PASSED) 8/22/2017 8/22/2017 1.25 PRODt RPCOMP OTHR P Terminate Tech line and test. 07:45 09:00 8122/2017 1.00 PROD1 RPCOMP PRTS P RU and pressure test production tree 18122/2017 09:00 10:00 to 5,000 PSI charted (PASSED). RD test lines and drain tree, remove cap. 8/22/2017 8/22/2017 8.00 PROW RPCOMP FRZP P Remove test dart and RU freeze 10:00 18:00 protect lines. Spot LRS and prep cellar area for rig move / wait on returns truck for freeze protect as preping rig for move. PT all lines to 2,500 PSI. pumped 53.3 BBLS of ISOTHERM followed by 11 BBLS of diesel at 1 BPM. ICP 150 PSI. FCP = 500 PSI DWN IA taking returns up TBG. Pump 16 BBLS diesel dwn tubing taking returns out the IA.@ 1 BPM 500 PSI. Lubricate BPV and test same. clean out pit 5. RD all freeze protect equipment and prepare for rig move. RD all innerconnects / choke /kill lines etc. 8/22/2017 8/23/2017 6.00 PROD? MOVE MOB P Move rig to 1H-102 18:00 00:00 Page 21/21 Report Printed: 8/2312017 Nage 1/i ReportPrinted: 9/19/20171 Cement Detail Report IH -118 String: Conductor Cement Job: DRILLING ORIGINAL, 7/24/2017 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Conductor Cement 10/30/2016 0000 10/31 /2016 00:00 1 H-118 Comment Cement Stages Stage # 7 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Conductor Cement 43.6 119.1 No No No Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) No No I Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (kK8) Amount (sacks) Class Volume Pumped (bbl) 43.6 119.1 6 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa•s) Thickening Time (hr) CmprStr t (psi) Additives Additive Type Concentration Conc Unit label Nage 1/i ReportPrinted: 9/19/20171 AL Cement Detail Report 1H-118 String: Surface Casing Cement Job: DRILLING ORIGINAL, 7/24/2017 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 8/10/2017 07:30 8/10/2017 10:00 11H-118 Comment Pumped 40.3 bbls of CW -100, 76.2 bbis of 10.5 ppg MPII, 232.6 bbls of 11.0 ppg ALC lead and 60.1 bbls of 15.8 ppg G tail cement. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement 40.4 1,729.0 Yes 24.8 Yes Yes Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbU... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 5 7 7 330.0 1,022.0 Yes 10.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pumped 5 bbls of CW -100, shut down and PT lines to 725/3500 psi. Pumped 35 bbls of CW -100, 76.2 bbls of 10.5 ppg MP II and dropped bottom plug. Batched up lead cement ( cement wet @ 8:40 hours) Pumped 232.6 We of 11.0 ppg ALC lead cement followed by 60.1 bbls of 15.8 ppg G blend tail cement, kicked top plug out with 10 bbls of fresh water. Displaced cement with 9.5 ppg spud mud, rig pumped @ 6.5 bpm=150 psi ICP, 3.0 bpm=330 psi FCP. Bumped plug 1448 strokes, pressure up to 1022 psi for 5 min, bleed off and check floats, good. Observed 24.8 bbls of good 11.0 ppg cement retuned to surface. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Bim (ftKB) Amount (sacks)Class Volume Pumpetl (bbl) CW -100 Chem Wash 40.0 Yield (felsack) Mix H2O Ratio (gallas.,. Free water (%) Density (lorgal) Plastic Viscosity (Pa -s) Thickening Time (hr) Cmprbtr 1 (psi) 8.34 Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Bum (ftKB) Amount (sacks)Class Volume Pumped (bbl) Pre Flush MudPushl1 762 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pan) Thickening Time (hr) CmprStr 1 (psi) 10.50 Atlditives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluitl Description Estimated Top (ftKB)Est Bum (ftKB) Amount (sacks) class Volume Pumped (bbl) Lead Cement 40.4 1,229.0 683 LiteCrete 232.6 Yield (ft/sack) Mix H2O Ratio (gal/sa... Free Water (%) Densityphlgal) Plastic Viscosity (Pais) Thickening Time (hr) CmprStr 1 (psi) 1.91 6.83 11.00 47.0 0.00 Additives Additive Antifoam Type Concentration Cone Unit label D046 0.2 %BWOC Additive Retarder Type Concentration Cone Unit label D177 0.02 gal/sx Additive Dispersant Type Concentration Cone Unit label D185 0.08 gagsx Fluid Fluid Type Fluid Description Estimated Top (ftKB) I Est Bon (ftKB) Amount (sacks)Class Volume Pumped (bbl) Tail Cement 1,229.0 1,729.0 291 G 1 60.1 Yield imisack)Miz H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity(Pais) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.12 15.80 130.0 0. 00 Additives A Anotiasm Type Concentration Cone Unit label D047 0.05 gal/sx Additive Atltlitivive Dispersant Type Concentration Cone Unit label D065 0.3 %BWOC Additive Fluid Loss Control Type D255 Concentretion Cone Unit label 0.35 %BWOC Page 7/t ReportPrinted: 9/19/2017 Cement Detail Report h-v�r 1 H-118 String: Production Casing Cement Job: DRILLING ORIGINAL, 7/24/2017 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Production Casing Cement 1 8/17/2017 08:30 8/17/2017 11:00 II H-118 Comment Pumped 28.7 bbls MPII, 59.4 bbis of 14.0 ppg lead and 68 We of 15.8 ppg tail cement. Lost 10 bbis to formation. Cementstages Stage # 1 Description Production Casing Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? atm Plug? Cement 4,300.0 8,131.0 No Yes Yes Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Related? Pipe RPM (rpm) 5 3 7 1,700.0 2,200.0 Yes 10.00 NTaggedo Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Comma PJSM. Cement 7" casing as follows. SLB pump 5 bbls of water, PT lines to 350 psi low, 4500 psi high. Batch up and pump 28.7 bbls of 12.5 ppg MPII, shot down and drop bottom plug. Batch up lead cement ( cement wet @ 9:19 hrs) Pump 59.4 bbls of 14.0 ppg lead cement followed by 68 bbis of 15.8 ppg tail cement, shut down and drop top plug. SLB washed up cement lines to rock washer before kicking top plug out. SLB pumped displacement with 9.0 ppg brine @ 7 bpm= 590 psi. At 280 bbis into the displacement flow out dropped from 21 % to 11%, slowed pump rate to 3 bpm= 1200 psi. Bumped plugs @ 308 bbls, pressure up to 2200 psi ( 500 psi over FCP) hold for 5 min, bleed off and check floats, good. Observed good lift pressure while displacing cement and lost 10 bbls of fluid to the formation. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) ClassVolume Pumped (bbl) MudPush II Yield (ft /sack) Mix H2o Ratio (gal/sa... Free Water (%) Density porgal) Plastic Viscosity (Pa-s) 1 Thickening Time (hr) 28.7 CmprStr 1 (psi) 2.50 1 Additives Additive Type Concemretlon Conc UnK label Fluid Fluid Type Fluid Description E8tlmat8d Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 4,300.0 6,100.0 215 Extended G 59.4 Yreld Msack) Mix H2o Ratio (gal/sa... Free water (%) Density paigal) Plastic Viscosity (Pa•s) Thickening Tlme (hr) CmprStr 1 (psi) 1.56 7.97 14.00 68.0 0.00 Adtlitives Additive Antifoam Type ConcentrationCone Unit label D047 0.05 gagsx Additive Dispersant Type Concentration Conc Unit label D065 0.8 %BWOC Additive Extender Type Concentmuon Cone Unit label D079 2.0 %BWOC Additive Retarder Type Concentration Zone Unit label D110 0 .08 gal/sx Additive Liqu Liquid Fluid Loss Type Concentration Cone Unit label D255 0.7 %BWOC Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Bbn (ftl(B) Amoum (sacks) Class Volume Pumped (bbl) Tail Cement 6,100.0 8,131.0 330 G 68.0 Mix H2o Ratio (gausa... Free water (%) Density (Ib/gal) Plastic viscosity (Pa•s) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.12 15.80 163.0 0.00 ivesack) Additives Atlditives Adtlitive Type Concentration Core Unit label I '^s= ." Report Printed: 9/19/20171 NADConversion Kuparuk River Unit Kuparuk 1H Pad 1H-118 IH -118 ConocoPhillips Definitive Survey Report 23 August, 2017 ConocoPhillips I 1 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordmate Reference: Well TD: 1H-118 Project: Kuparuk River Unit TVD Reference: 1H-118 actual @ 92.85usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1H-118 actual @ 92.85usft (Doyon 142) Well: TD: 1H-118 North Reference: True Wellbore: 11-4-118 Survey Calculation Method: Minimum Curvature Design: 1H-118 Database: OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well TD: 11-1-118 Audit Notes: Survey Program Well Position +NI -S 0.00 usft Northing: 5,981,081.27 usft Latitude: 70" 21'32.750 N Vertical Section: +EI -W 0.00 usft Easting: 549,546.89 usft Longitude: 149° 35'51.236 W Position Uncertainty (usft) (°) 0.00 usft Wellhead Elevation: usft Ground Level: 54.00usft Wellbore 11-1-1118 Magpetics Model Name Semple Date Declination Dip Angle Field Strength (°I (°) (nT) BGGM2017 8/20/2017 17.53 80.95 57,493 Design 1H-118 Audit Notes: Survey Program Data Map Version: 1.0 Phase: ACTUAL Tie On Depth: 38.85 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) Survey (Wellbore) (usft) (usft) (usft) (°) 100.00 38.85 0.00 0.00 0.00 Survey Survey Program Data Map Nap From To Inc Azi TVD (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 100.00 834.00 1 H-118 Srvy 1 - SLB_NSG+SSHOT (1 H- GYD-GC-SS Gyrodata gyro single shots 818/2017 8:41:0 862.92 1,655.471H-118Srvy2-SLB_MWD+GMAG(1H- MWD+IFR-AKSCC MWD+IFR AK SCC Sperry 8/8/2017 9:04:0• 1,749.06 8,058.061H-118Srvy3-SLB_MWD+GMAG(1H- MWD+IFR-AK-SCC MWD+IFRAKSCCSpeny 8/12/2017 8:53:• Survey 823!2017 3:44'58PM Page 2 COMPASS SOW.. 14 Build 85 Map Nap Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section Welt) (1) C) (usft) (usft) (usft) (usft) (ft) (ft) r11007 (ft) Survey Tool Name 3885 0.00 0.00 38.85 -54.00 0.00 0.00 5,981,081.27 549,546.89 0.00 0.00 UNDEFINED 10000 0.34 33.06 100.00 7.15 0.15 0.10 5,981,081.42 549,546.99 0.56 0.15 GYD-GC-SS(1) 102.00 0.34 33.06 102.00 9.15 0.16 0.11 5,981,081.43 549,546.99 0.00 0.18 NOT Bn Actual SBNBy 20" 200.00 0.37 28.25 200.00 107.15 0.69 0.41 5,981,081.96 549,547.30 0.04 0.69 GYD-GC-SS(1) 300.00 0.65 27.72 299.99 207.14 1.47 0.83 5,981,082.74 549,547.71 0.28 1.47 GYD-GCSS(1) 40000 1.17 48.68 399.98 307.13 2.65 186 5,981,083.93 549,54813 061 2,65 GYD-GC-SS(1) 500.00 1.74 62.79 499.95 407.10 4.02 3.98 5,981,085.31 549,550.84 0.67 4.02 GYD-GC-SS(1) 582.00 249 72.59 581.89 489.04 5.12 6.78 5,981,088.43 549,553.64 1.01 5.12 GYD-GC-SS(1) 675.00 303 89.80 674.79 581.94 5.73 11.17 5,981,087.07 549,558.02 1.06 5.73 GYD-GC-SS(1) 771.00 3.94 99.48 770.61 677.76 5.20 16.96 5,981,08658 549,563.81 1.13 5.20 GYD-GC-SS(1) 834.00 5.44 91.89 833.40 740.55 4.74 22.08 5,981,086.16 549,568.93 2.57 4.74 GYD-GC-SS(1) 823!2017 3:44'58PM Page 2 COMPASS SOW.. 14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion local Coordinate Reference: Well TD: 1H-118 Project: Kuparuk River Unit TVD Reference: 1 H-118 actual @ 92.85usf[ (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1 H-118 actual @ 92.85usft (Doyon 142) Well: TO 1H-118 North Reference: True Wellbore: IH -118 Survey Calculation Method: Minimum Curvature Design: 1H-118 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +EFIN Northing Easgng DLS Section (usft) P) (1) ("It) (usR) (usm Wit) (R) (ft) (°/low) (R) Survey Tool Name 86292 6.05 90.60 852.17 769.32 4.68 24.97 5,981,086.11 549,571.83 2.16 4.68 MWD+IFR-AK-SCC(2) 957,91 8.19 82.37 9%A3 863.58 5.53 36.69 5,981,087.04 549,583.54 2.49 5.53 MWD+IFR-AKSCC(2) 1,053.26 8.00 72.22 1,05083 957.98 8.46 49.74 5,981,090.05 549,596.56 1.51 8.46 MWD -IFR -AK -SCC (2) 1,147.84 8.81 68.65 1,144.39 1,051.54 13.10 62.75 5,981,094.78 549,609.55 1.02 13.10 MWD+IFR-AKSCC(2) 1,24204 1151 69.46 1,237.11 1,144.26 19.02 78.28 5,981,100.81 549,625.03 2.87 19.02 MWD+IFR-AKSCC(2) 1,336.43 13.65 71.28 1,32923 1,236.38 25.90 97.64 5,981,107.81 549,644.35 2.31 25.90 MWD+IFR-AKSCC(2) 1,431,09 15.94 66.75 1,429.75 1,327.90 34.62 120.17 5,981,116.68 549,666.81 2.71 34.62 MWD+IFR-AKSCC(2) 1,527.44 17.55 64.55 1,51301 1,420.16 46.09 14544 5,981,12831 549,69201 1.80 46.09 MWD+IFR-AK-SCC(2) 1,621.51 1800 66.47 1,602.59 1,509.74 57.98 171.58 5,981,140.38 549,718.06 0.79 57.98 MWD+IFR-AK-SCC(2) 1,655.47 19.11 65.70 1,634.78 1,541.93 62.37 18145 5,981,144.83 549,727.91 3.35 62.37 MWD+IFR-AKSCC(2) 1,719.00 20.54 65.78 1,694.55 1,60170 7122 201.10 5,981,153.81 549,747.49 2.24 71.22 NOT an Actual Survey 103/4" z 13412" 1,749.06 21.21 65.82 1,722.63 1,629.78 75.61 210.86 5,981,15826 549,757.23 2.24 7561 MWD+IFR-AK-SCC(3) 1,810.71 23.37 64.75 1,779.67 1,686.82 85.39 232.10 5,981,168.18 549,778.40 3.56 85.39 MWTI+IFR-AK-SCC(3) 1,904.28 27.10 63.74 1,864.30 1,771.45 102.74 268.01 5,981,18577 549,814.19 4.01 10274 MWD+IFR-AK-SCC(3) 1,999.85 29.80 62.25 1,948.32 1,855.47 123.44 308.55 5,981,206.73 549,854.59 2.92 123.44 MWD+IFR-AK-SCG(3) 2,043.58 31.74 61.59 1,985.89 1,893.04 133.97 328.29 5,981,217.39 549,874.26 4.50 133.97 MWD+IFR-AK-SCC(3) 2,094.55 34.55 60.37 2,028.56 1,935.71 147.50 352.66 5,981,231.08 549,896.53 5.89 147.50 MWD+IFR-AK-SCC (3) 2,189.41 3980 58.49 2,10.1.12 2,011.27 176.69 401.96 5,981,260.60 549,94764 5.65 176.69 MWD+IFR-AK-SCC(3) 2,284.04 45.65 55.40 2,173.61 2,080.76 211.77 455.69 5,981,296.02 550,001.12 6.57 211.77 MWD+IFR-AK-SCC(3) 2,380.98 50.78 5368 2,238.19 2,145.34 253.72 514.51 5,981,338.36 550,059.66 5.45 253.72 MWD+IFR-AK-SCC(3) 2,473.74 54.72 53.09 2,294.33 2,201.48 297.76 573.76 5,981,382.78 550,118.61 4.28 297.76 MWD+IFR-AK-SCC (3) 2,568.39 59.32 51.95 2,345.84 2,252.99 346.07 636.74 5,981,43150 550,181.27 4.96 346.07 MWD+IFR-AK-SCC(3) 2,66264 64.06 50.71 2,390.52 2,297.67 397.91 701.W 5,981,483.77 550,245.87 5.16 397.91 MWD+IFR-AK-SCC(3) 2,757.79 68.58 50.49 2,428.73 2,335.88 453.20 768.82 5,981,53950 550,31261 4.76 453.20 MWD+IFR-AK-SCC(3) 2,85200 7257 49.87 2,46005 2,367.20 510.09 83204 5,981,596.84 550,380.45 4.28 510.09 MWD+IFR-AK-SCC(3) 2,946.91 74.95 48.42 2,486.59 2,393.74 569.70 905.95 5,981,656.89 55,448.96 2.91 569.70 MWD+IFR-AK-SCC (3) 3,039.87 75.28 45.89 2,510.48 2,417.63 630.79 971.81 5,981,718.41 550,51441 2.65 630.79 MWD+IFR-AK-SCC(3) 3,135.82 75.18 43.53 2,534.94 2,442.09 696.72 1,037,08 5,981,78476 550,579.24 2.38 698.72 MWD+IFR-AK-SCC(3) 3,230.52 75.27 43.71 2,559.09 2,466.24 763.01 1,100.25 5,981,851.46 550,64196 021 76301 MWD+IFR-AKSCC(3) 3,326.05 7533 43.23 2,583.33 2,490.48 830.07 1,163.82 5,981,918.94 550,705.08 0.49 830.07 MWD+IFR-AKSCC(3) 3,419.60 75.33 44.07 2,607.03 2,514.18 895.55 1,226.29 5,981,984.82 550,767.11 0.87 895.55 MWD+IFR-AKSCC(3) 3,515.01 7540 44.49 2,631.13 2,538.28 961.64 1,290.74 5,982,051.33 55Q831.11 043 96164 MWD+IFR-AKSCC(3) 3,610.29 75.16 45.84 2,655.30 2,562.49 1,026.61 1,356.09 5,982,11673 55,896.02 1.39 1,028.61 MWD+IFR-AKSCC(3) 3,700.55 74.27 46.19 2,680.19 2,587.34 1,089.76 1,421.51 5,982,180.30 55,961.02 1.01 1,089.76 MWD+IFR-AKSCC(3) 3,798.88 74.35 47.88 2,705.70 2,612.85 1,151.65 1,487.96 5,982,242.62 551,027.05 1.73 1,15165 MWD+IFR-AKSCC(3) 3,893.50 74.42 4846 2,731.17 2,638.32 1,212.43 1,555.86 5,982,303.84 551,094.55 0.59 1,212.43 MWD+IFR-AKSCC(3) 3,968.00 74.22 48.21 2,756.71 2,663.86 1,272.91 1,623.83 5,982,364.77 551,162.11 0.33 1,272.91 MWD+IFR-AKSCC(3) 4,08303 74.20 47.66 2,782.57 2,68972 1,334.17 1,891.72 5,982,42647 551,229.58 0.56 1,334.17 MWD+IFR-AK-SCC(3) 4,1T/.42 74.14 46.99 2,808.32 2,715.47 1,395.73 1,758.48 5,982,488.46 551,295.93 0.69 1,395.73 MWD+IFR-AKSCC(3) 8232017 3:44:58PM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Corrlparry. NADConversion Local Coordinate Reference: Well TD: 11-1-116 Protech Kuparuk River Unit TVD Reference: IH -118 actual @ 92.85usft (Doyon 142) Sieg: Kuparuk 1H Pad MD Reference: 11-1-118 actual @ 92.85usft (Doyon 142) Wall: TD: 11-1-118 North Reference: True Wellbore: IH -118 Survey Calculation Method: Minimum Curvature Design: 11-1-118 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Aid TVD TVDSS +WS +E/ -W Northing Easgng DLS Section (usN) (1) P) (usR) (usR) (usm (usft) (ft) (11) (111001 (1t) Survey Tool Name 4,272.11 74.21 46.39 2,834.14 2,74129 1,458.22 1,824.77 5,982,551.38 551,361.80 061 1,458.22 MWDHFR-A-$CC(3) 4,367.15 74.26 46.84 2,859.96 2,767.11 1,521.05 1,891.24 5,982,614.64 551,427.85 0.46 1,521,05 MWD+IFR-AK-SCC(3) 4,461.07 7426 47.59 2,885.44 2,792.59 1,582.45 1,957.59 5,982,676.48 551,49378 0.77 1,582.45 MWD+IFR-AKSCC(3) 4,555.74 74.17 49.02 2,911.20 2,818.35 1,643.04 2,025.61 5,982,737.51 551,561.39 1.46 1,643.04 MWD+IFR-AKSCC(3) 4,651.15 74.30 50.34 2,937.12 2,84427 1,702.45 2,095.62 5,982,797.38 551,630.99 1.34 1,702.45 MWD+IFR-AKSCC(3) 4,745.40 7420 48.99 2,962.70 2,869.85 1,761.17 2,164.76 5,982,855.54 551,699.74 1.38 1,761.17 MWD+IFR-AKSCC(3) 4,840.29 7435 4297 2,988.42 2,895.57 1,821.71 2,233.15 5,982,917.53 551,767.72 1.05 1,821.71 MWD -IFR -AK -SCC (3) 4,934.86 7432 46.23 3,013.96 2,921.11 1,883.69 2,299.65 5,982,979.95 551,834.00 1.77 1,883.69 MWD+1FR-AKSCC(3) 5,029.00 74.32 45.53 3,039.40 2,94655 1,946.79 2,354.91 5,983,043.47 551,898.64 072 1,946.79 MWD+IFR-AKSCC(3) 5,124.91 74.32 44.72 3,065.32 2,972.47 2,011.94 2,430.35 5983,109.05 551,963.64 0.81 2,011.94 MWD+IFR-AKSCC(3) 5,219.45 7432 44.34 3,090.87 2,998.02 2,076.83 2,494.18 5,983,174.35 552,027.04 0.39 2,076.83 MWD+IFR-AKSCC(3) 5,313.93 74.23 43.43 3,116.48 3,023.63 2,142.38 2,557.23 5,983,240.30 552,089.64 0.93 2,142.38 MWD+IFR-AKSCC(3) 5,408.34 74.32 42.79 3,142.07 3,049.22 2,20872 2,619.33 5,983,307.05 552,151,30 0.66 2,208.72 MWD+IFR-AKSCC(3) 5,502.85 74.41 42.77 3,167.54 3,074.69 2,275.52 2,681.14 5,983,37425 552,212.66 0.10 2,275.52 MWD+IFR-AKSCC(3) 5,597.58 7425 43.26 3,193.13 3,100.28 2,342.21 2,743.37 5,983,441.35 552,274.43 0.53 2,342.21 MWD+IFR-AKSCC(3) 5,691.24 74.34 41.98 3,218.48 3,12563 2,408.56 2,804.42 5,983,508.09 552,335.04 1.32 2,408.56 MWD+IFR-AKSCC(3) 5,786.63 7380 40.63 3,244.66 3151.81 2,477.46 2,864.96 5,983,577.38 552,395.12 1.47 2,477.46 MWD+IFR-AKSCC(3) 5,881.02 72.69 37.94 3,271.88 3,179.03 2,547.40 2922.19 5,983,647.70 552,451.88 2.97 2,547.40 MWD+IFR-AKSCC(3) 5,975.43 71.59 35.01 3,30083 3,20298 2,619.18 2,97624 5,983,719.83 552,505.45 227 2,619.18 MVD+IFR-AKSCC(3) 6,070.43 71.21 34.57 3,331.14 3,238.29 2,692.67 3,028.25 5,983,793.65 562,556.97 1.49 2,692.67 MWD+IFR-AKSCC(3) 6,164.93 7109 31.88 3,361.67 3,268.82 2,767.48 3,077.25 5,983,868.77 552,605.47 2.70 2,767.48 MWD+IFR-AKSCC(3) 6,259.40 69.54 31.82 3,39349 3,300.64 2,843.03 3,124.19 5,983,944.63 552,651.90 1.64 2,643.03 MWD -IFR -AK -SCC (3) 6,354.10 68.75 29.24 3,427.21 3,334.36 2,919.25 3,169.14 5,984,021.13 552,696.34 2.68 2,919.25 MWD+IFR-AKSCC(3) 6,401.98 68.35 27.32 3,444.72 3,351.87 2,958.49 3,190.25 5,984,060.51 552,717.19 3.82 2,958.49 MWD+1FR-AKSCC(3) 6,448.31 67.96 25.01 3,461.96 3,369.11 2,997.08 3,209.22 5,984,099.22 552,735.90 470 2,997.08 MWD+IFR-AKSCC(3) 6,510.17 67.08 21.61 3,485.62 3,392.77 3,049.56 3,231.83 5,984151 84 552,758.17 5.27 3,049.55 MWD+IFR-AK-SCC (3) 6,543.85 66.78 19.56 3,498.82 3,405.97 3,078.57 3,242.73 5,984,180.92 552,768.87 587 3,078.57 MWD+IFR-AK-SCC (3) 6,600.41 66.67 16.90 3,521.17 3,428.32 3,127.91 3,258.98 5,984,230.36 552,784.79 4.32 3,127.91 MWD+IFR-AK-SCC(3) 6,637.74 66.26 16.71 3,53608 3,443.23 3,160.67 3,268.88 5,984,263.19 552794.47 1.19 3,160.67 MWD+IFR-AKSCC(3) 6,732.68 Was 13.31 3,573.86 3,481.01 3,244.79 3,291.43 5,984,347.45 552,816.46 3.35 3,244.79 MWD+IFR-AKSCC(3) 6,826.76 67.06 8.57 3,610.69 3,517.84 3,329.76 3,307.85 5,984,432.51 552,832.32 4.64 3,329.76 MWD+IFR-AK-SCC (3) 6,904.25 67.50 4.99 3,640.63 3,547.78 3,400.73 3,316.28 5,984,503.52 552,840.28 4.30 3,400.73 MWD+IFR-AK-SCC (3) 6,921.67 67.59 4.08 3,647.28 3,554.43 3,416.77 3,31255 5,984,519.58 552,841 45 4.86 3,416.77 MWD+IFR-AK-SCC (3) 7,016.17 67.96 0.58 3,683.04 3,590.19 3,504.16 3,321.11 5,984,606.98 552,844.42 3.45 3,504.16 MWDAFR-AK-SCC (3) 7,111.18 68.26 356.50 3,718.47 3,625.62 3,592.27 3,318.86 5,984,695.06 552,841.59 4.00 3,59227 MWD+IFR-AK-SCC(3) 7,205.54 68.58 353.87 3,753.18 3,660.33 3,679.70 3,3W49 5,984,782.43 552,833.64 2.61 3,679.70 MWD+IFR-AK-SCC(3) 7,300.26 68.35 353.69 3,787.95 3,695.10 3,767.29 3,301.94 5,984,869.95 552,823.52 0.30 3,767.29 MWD+IFR-AK-SCC(3) 7,395.12 68.41 355.20 3,822.91 3,730.06 3,855.06 3,293.41 5,984,957.65 552,814.40 1.48 3,855.06 MV4D+IFR-AK-SCC (3) 7,489.30 68.64 355.84 3,857.38 3,764.53 3,94243 3,28656 5,985,044.97 552,806.98 0.68 3,942.43 MWD+IFR-AK-SCC(3) 7,584.71 68.50 356.30 3,892.24 3,799.39 4,031.03 3,280.47 5,985,133.52 552,800.31 0.47 4,031.03 MVD+IFR-AKSCC(3) 8232017 3,44'58PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well TD: 1H-118 Project: Kuparuk River Unit TVD Reference: 1 H-118 actual @ 92.85usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1H-118 actual @ 92.85usft (Doyon 142) Well: TD: 1H-118 North Reference: True Wellbore: 1H-118 Survey Calculation Method: Minimum Curvature Design: 1H-118 Database: OAKEDMP2 Survey Surface Coordinates O Declination & Convergence GRS Survey Corrections [� Survey Tool Codes Brandon Temple..;k p9 °ygo don SLB DE: NwWVD823BS4544 00 Map Map Vertical MD Inc Axi TVD TVDSS +W_$ +E1 -W Northing Eastlng OLS Section (usft) r) (9 (uaft) Wit) (usft) (usft) (ft) (ft) (°nool (ft) Survey Tool Name 7,679.25 68.57 357.88 3,926.84 3,833% 4,118,90 3,276.01 5,985,221,35 552,795.26 1.56 4,118.90 MWDHFR-AK-SCC(3) 7,774,16 68.57 357.44 3,951.52 3,86867 4,207.17 3,27240 5,985,309.59 552,791.07 0.43 4,207.17 MWD+IFR-AK-SCC(3) 7,86862 68.45 35744 3,996.12 3,903.27 4,294.98 3,266.48 5,985,397.36 552,786.57 0.13 4,294.98 MWD+IFR-AK-SCC(3) 7,963.47 68.55 35291 4,030.89 3,938.04 4,383.16 3,264.90 5,985,485.50 552,782.40 0.47 4,383.16 MWD+IFR-AK-SCC (3) 8,058.06 68.57 35841 4,065.46 3,972.61 4,471.16 3,262.07 5,985,573.47 552,778.99 0.49 4,471.16 MWD+IFR-AK-SCC(3) 8,121.00 68.57 358.41 4,088.46 3,995.61 4,529.72 3,260.44 5,985,632.02 552,776.98 0.00 4,529.72 NOT en AOWil Survay 7• x 5-irr 8,131.00 68.57 358.41 4,092.11 3,999.26 4,539.03 3,260.18 5,985,641.32 552,77666 0.00 4,539.03 PROJECTEDto TD (Final Definitive Survey Verified and Signed -off AM targets andlor well position objectives have been achieved. Q Yes ❑ No I have checked to the best of my ability that the following data is correct M Surface Coordinates O Declination & Convergence GRS Survey Corrections [� Survey Tool Codes Brandon Temple..;k p9 °ygo don SLB DE: NwWVD823BS4544 00 Dghll"Igr bBen Tnlrmn Client Representative: toy 4wP0 7 624084990 Date: 8/23121317 8232017 3:44: 58PM Page 5 COMPASS 5000.14 Build 85 Loepp, Victoria T (DOA) From: Sent: To: Subject: Follow Up Flag: Flag Status: Great. Thanks Victoria. John Peirce PTD a 1-7-0ff¢ Peirce, John W <John.W.Peirce@conocophillips.com> Monday, September 18, 2017 11:29 AM Loepp, Victoria T (DOA) RE: [EXTERNAL]RE: 11-1-118 Leak Off Test - Do we need any Sundries Follow up Flagged From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday, September 18, 2017 11:26 AM To: Peirce, John W <John.W.Peirce@conocophillips.com> Subject: [EXTERNAL]RE: 11-1-118 Leak Off Test - Do we need any Sundries John, No sundry is required. Thanx, Victoria From: Peirce, John W [ma ilto:John.W.Peirce @conocophillips.com] Sent: Monday, September 18, 2017 11:25 AM To: Loepp, Victoria T (DOA) <victoria.loepp(@alaska.gov> Subject: 11-1-118 Leak Off Test - Do we need any Sundries Victoria, Per the Sundry Matrix, I don't believe I need to file a 10-403 or 10-404 to perform an LOT, but I thought I better ask to double check. Do I need to provide any sundries to do the LOT in the procedure described below? Procedure Objective: 11-1-118 is a newly drilled injector completed 8/22/17, so I am writing a well work procedure to pull the BPV, and then have SL swap a sheared SOV to DV, and then MITT, and then swap the lower DV in B selective to a WFRV to set the well up for a B Sand Leak Off Test (LOT). A LOT will then be performed pumping Diesel to determine B Sand Frac Gradient, B Sand Frac Pressure, and to verify that the WFRV can take 500 BPD rate, and to verify that the Packers are properly set. Post - LOT, SL will swap the DV's to WFRV's in lower stations of the A and D selectives to leave 11-1-118 ready to start Seawater injection. We would not be doing a Stimulation or a Frac job here. Note, the LOT max rate would be —0.34 bpm through the WFRV, since that is the max allowable rate capacity through the valve. As soon as we attain an initial pressure response indicating that we have reached Frac pressure, we would shut down pumping to end the LOT. Regards, John Peirce Loepp, Victoria T (DOA) From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Friday, August 18, 2017 4:44 PM To: Loepp, Victoria T (DOA) Cc: Tolman, Ben V; Buck, Brian R; Bearden, J Daniel; Doyon 142 Company Man Subject: RE: 11-1-118 CBL interpretation Follow Up Flag: Follow up Flag Status: Flagged 0 I received a call from Victoria today at 16:31. She informed me she may be having email issues, as she had not received my email with the CBL, and was not able to send me an email either. She informed me that based on our interpretation of the CBL that I gave her over the phone, that we are granted permission to proceed with operations and perforate the wellbore. Give me a shout if you have any questions. Adam Klem From: Klem, Adam Sent: Friday, August 18, 2017 2:11 PM To-.'Loepp, Victoria T (DOA)' <victoria.loepp@alaska.gov> Cc: Tolman, Ben V <Ben.V.Tolman@conocophillips.com>; Buck, Brian R <Brian.R.Buck@conocophiIIips.com>; Bearden, J Daniel <1.Daniel.Bearden@conocophillips.com> Subject: 1H-118 CBL interpretation Victoria, Attached is the CBL and interpretation for 1H-118 7" intermediate casing. Based on the CBL, we have the TOC at 3,160'MD, with good cement across the reservoir. Based on these results, can we receive approval to proceed with perforations as per the PTD? Thanks, Adam oft Cement Evaluation Company: ConocoPhillips Alaska, Inc. Field: Kuparuk River Well Name: 1 H-118 Log Date: 18 -Aug -2017 Service: Slim Cement Mapping Tool Analyst: Chew Yeong Leong Reviewed by: Matt Roorda toVr.MM16 ScM1Wnbrpr aix. Nl� nrrvW 1200 00&:t Software Integrated Solutions Schlumberger Schlumberger ConocoPhillips Alaska, Inc. Cement Evaluation 1H-118 1. Schlumberger Legal Disclaimer................................................................................. 2 2. Executive Summary ..................................................................................................... 3 Recordeddata and comments.....................................................................................................................3 Objectives......................................................................................................................................................... 3 Resultsand Observations..............................................................................................................................3 3. Summary Log................................................................................................................ 4 4. Observations................................................................................................................ 5 5. Theory of Operation..................................................................................................... 7 6. Log Quality Control...................................................................................................... 8 Transit Time (Ti), CBL Amplitude (CBL) & Variable Density Log(VDL)................................................ 8 7. Contextual Information................................................................................................9 FieldLog Header..............................................................................................................................................9 WellSketch....................................................................................................................................................10 ToolSketch.....................................................................................................................................................11 CementInformation......................................................................................................................................12 8. Appendix......................................................................................................................14 Schlumberger NAM 1 18 August 2017 Schlumberger -Private Schlumberger ConocoPhillips Alaska, Inc. Cement Evaluation 1H-118 1. Schlumberger Legal Disclaimer ANY INTERPRETATION, RESEARCH, ANALYSIS, DATA, RESULTS, ESTIMATES, OR RECOMMENDATION FURNISHED WITH THE SERVICES OR OTHERWISE COMMUNICATED BY SCHLUMBERGER TO CUSTOMER AT ANY TIME IN CONNECTION WITH THE SERVICES ARE OPINIONS BASED ON INFERENCES FROM MEASUREMENTS, EMPIRICAL RELATIONSHIPS AND/OR ASSUMPTIONS, WHICH INFERENCES, EMPIRICAL RELATIONSHIPS AND/OR ASSUMPTIONS ARE NOT INFALLIBLE, AND WITH RESPECT TO WHICH PROFESSIONALS IN THE INDUSTRY MAY DIFFER. ACCORDINGLY, SCHLUMBERGER CANNOT AND DOES NOT WARRANT THE ACCURACY, CORRECTNESS OR COMPLETENESS OF ANY SUCH INTERPRETATION, RESEARCH, ANALYSIS, DATA, RESULTS, ESTIMATES OR RECOMMENDATION. CUSTOMER ACKNOWLEDGES THAT IT IS ACCEPTING THE SERVICES "AS IS', THAT SCHLUMBERGER MAKES NO REPRESENTATION OR WARRANTY, EXPRESS OR IMPLIED, OF ANY KIND OR DESCRIPTION IN RESPECT THERETO. SPECIFICALLY, CUSTOMER ACKNOWLEDGES THAT SCHLUMBERGER DOES NOT WARRANT THAT ANY INTERPRETATION, RESEARCH, ANALYSIS, DATA, RESULTS, ESTIMATES, OR RECOMMENDATION IS FIT FOR A PARTICULAR PURPOSE, INCLUDING BUT NOT LIMITED TO COMPLIANCE WITH ANY GOVERNMENT REQUEST OR REGULATORY REQUIREMENT. CUSTOMER FURTHER ACKNOWLEDGES THAT SUCH SERVICES ARE DELIVERED WITH THE EXPLICIT UNDERSTANDING AND AGREEMENT THAT ANY ACTION TAKEN BASED ON THE SERVICES RECEIVED SHALL BE AT ITS OWN RISK AND RESPONSIBILITY AND NO CLAIM SHALL BE MADE AGAINST SCHLUMBERGER AS A CONSEQUENCE THEREOF. Schlumberger NAM 2 18 August 2017 Schlumberger -Private Schlumberger ConocoPhillips Alaska, Inc. Cement Evaluation IH -118 2. Executive Summary Recorded data and comments A Slim Cement Mapping Logging Tool (SCMT) log was logged in the 1 H-118 well on the 18 August 2017. The data were recorded over the 7 26ppf L-80 production casing from 8,015ft-1,967ft. The data quality is generally good overthe entire logged interval. The expected top of cement as perthe completion program is 4,260ftwith 15.8ppg class G tail slurry pumped from 8,294ft MD to 6,100ft MD and 14 ppg class G lead slurry pumped from 6,100ft MD to 4,260ft MD. Objectives The objectives of the logging areto evaluate the top of cement and cement quality overthe logged interval. Results and Observations 1. Top of cement (TOC) appears to be at approximately 3,160ft. 2. The gradual increment of CBL amplitude near TOC indicates possible slurry/spacer contamination. 3. Below TOC, the log shows overall low CBL amplitude, suggesting good cement bond throughout the rest of the logged interval. Detailed interpretation comments and snapshots are provided in the Section 4 below. Schlumberger NAM Schlumberger -Private 18 August 2017 Schlumberger ConocoPhillips Alaska, Inc. Cement Evaluation iH-118 3. Summary Log figure Z- summary tog Schlumberger NAM 4 18 August 2017 Schlumberger -Private cv...a w.r+sa CYW IOfiW at eea.w-mew. IM,fiI.1Tl MlOPW mXeaara.-cea �� muaca>vv-m M0NC6 51[IYWMtl-VOL Y01tl NWx XxXP 0 mV 1W RefQhince 1t COL -v v s LVni a my LOp �axn .vm.ao -- m wu wwv oL VM_Ri e. 1:5000 pnr, ax a my NO o.as a»oz o - - i2M _nice 2000 - 2200 2400 i 2600 I 2800 3000 3200 3400 3600 i , 3800 i I -:� I I €•> a.. _ _ 4000:- 4200 4400 4600 4800 i I y c+y 5000 , 5200 5400 5600 i i liarZit. 5800 ` 6000 IcF'sr. '" 6200 4� it j �Aid 6400 ¢ .tt.. 6600 6800 7000 7200 - 7400 600 �. , a L7800 %nnn _i )c figure Z- summary tog Schlumberger NAM 4 18 August 2017 Schlumberger -Private Schlumberger ConocoPhillips Alaska, Inc. Cement Evaluation IH -118 4. Observations Top of Cement Figure 2 below show the log section from-2,100ft --3850ft. The 2ft receiver for the mapping from SCMT shows a shift starting around 3,160ft. Similarly, the 3ft receiver shows increment in CBL amplitude starting from 3,160ft. VOL also shows stronger formation arrival below this depth. Above 3,160ft, the CBL amplitude reads close to the free pipe value of 62.77mV. These observations suggest that the top of cement is at approximately 3,160ft. The gradual increment of CBL amplitudes near TOC indicates possible slurry/spacer contamination as shown in Figure 2 below. Figure 2- Top of Cement Schlumberger NAM 5 18 August 2017 Schlumberger -Private Schlumberger ConocoPhillips Alaska, Inc. Cement Evaluation iH-118 Cement Quality Figure 3 below shows the log section below TOC (3,160ft) to the bottom of the logged interval. Overall, the log shows low CBL amplitude. The azimuthal mapping from the 2ft receivers also show low amplitude. VOL shows little to no casing arrival and strong formation arrival. These observations are the typical scenario for a good cement bond, suggesting presence of good cement below this interval. ]fl Rec m cRL Ga.C.I RL.Casrq ]fl Racafva�-Xaa"Fvy 3R R¢eiva-CSL Corrlocaty MIn SCM MapOM AXOYURde9 apOnv AmOtupe SR Recaue�-va BaM NG¢ M%MP 0 mV 100 CCLC AVMA V Refy�nce -1s V s a my 100103.47 -3]767.00 ll GR MIMA M"r CBL V . K l BI 1:10000 0 aAli 1aB 0 my IN 0.41 ]aw] o my 1C0 ]ao 1200 B unaiass 1 3200 3600 4000 4400 4500 ,tt 5200 5600 1$J$ 6000 6400 ! 4l# 6800 k 1 � { 7200 7600 Figure 3 - Cement Quality Schlumberger NAM 6 18 August 2017 Schlumberger -Private Schlumberger ConocoPhillips Alaska, Inc. Cement Evaluation 1H-118 5. Theory of Operation Sonic logging is a measurement of the sound energy that travels across media allow the evaluation of various formation characteristics. Sonic waves emitted by the transmitter of the sonic tool travel in different paths on their way to the receivers. Sound travels the fastest through solid materials. The first arrival is usually the result of a sonic wave traveling outward from the transmitter through the borehole fluid, then up the casing and out into the borehole and back to the receiver. The next arrivals will usually be the result of sound traveling through the formation rock and back outto the receiver. In this case, the first arrival will have an amplitude indicative of the losses obtained while traveling through the formation rock, casing, and borehole fluid. The amount of fluid or gas behind the pipe plays a role in whether or not any formation arrivals will be seen at all in the detection gate allowed. In fast formations, sound travels faster through the formation than it does through the casing wall. The travel time and the amplitude of the sound energy reflected by the casing are measured in cement bond logging (CBL). The eight cement map receivers cover radially equal segments around the circumference of the casing. Each receiver detects sonic signals resulting in a digitized waveform sent uphole. The first arrival of the waveform indicates the quality of cement in that 45° section of pipe. It should be noted thatthe map outputs should only be used for qualitative analyses and is not recommended to be used for azimuthal bond values and feature description/size estimation as sonic frequencies are not optimal for azimuthal maps. The amplitude equalization computation has a known limitation in compensating MAP image biasing resulting from tool eccentralization, where direction may not necessarily be constant relative to a receiver (1-8). Schlumberger NAM 7 18 August 2017 Sch I u m b erge r -Private Schlumberger ConocoPhillips Alaska, Inc. Cement Evaluation 1H-118 6. Log Quality Control Transit Time (TT), CBL Amplitude (CBL) & Variable Density Log (VDL) Average transit time on the 2ft receiver shows consistent detections, suggesting fairly good centralization in most of the logged interval. The 3ft receiver average TT shows occasional spikes in the reading, possibly attributed to the cycle skipping due to the good cement bond in the log. Overall, the interpretations are not affected. The 2ft MAP data reads in agreement 3ft CBL data, suggesting strong confidence in data quality. VOL also shows good contrasts in cemented section, casing arrivals and formation arrivals are visible, indicating good data quality as shown below. Figure 11- LQC Log Schlumberger NAM Schlumberger -Private 18 August 2017 cac svw Refe/ence 11 v s o my soo .o -svmm lRl Ga niw wrxs <vrt cax n wx-a, a� 1:100011 — MV 4 042 n.oz xw aso aw xm uNwa Figure 11- LQC Log Schlumberger NAM Schlumberger -Private 18 August 2017 Schlumberger Conocol"hillips Alaska, Inc. Cement Evaluation 1H-118 7. Contextual Information Field Log Header From 0.00 ft To 8294.00 ft Casing/Tubing Size 7 in Weight 26 IbnVft Grade L80 From 0.00 fl To 8294.00 R Max Recorded Temperatures Logger on Bottom Time 18 -Aug -2017 05:30:00 Unit Number Location 2316 Kupamk Recorded By Miles Witnessed By Tolman Schlumberger NAM 9 18 August 2017 Schlumberger -Private Schlumberger ConocoPhillips Alaska, Inc. Cement Evaluation 1H-118 Well Sketch W.®1 TOMHW. Tm %0.wX - L-xID -W-m NEWS 1H-118 Injector Well Design Slick Line Accessible 10.11-, 4< 1-.1 -.V, MD!63D1 H ' I - L -K ILT-AB -0- UW PMa~w T19T T33TUD -W Saw 1173 7a55' w A4,.+1.: M2 75A5W AS w,t. 7ffi Y71MD ,,— 7op d fmt oLw 31� NO Iti ":N.1 90 IUD5633, TV if -'*f* D61iY DPffTi V94 MD Schlumberger NAM 10 18 August 2017 Schlumberger -Private Schlumberger Conoco Phillips Alaska, Inc. Cement Evaluation 1H-118 Tool Sketch Equip name length MM -22 57.18 AM -3 B SSb1 ERS -E 5533 ERS£ H pfg ERS -E wle SAM -G 5397 ANpW_M 52 6 ea6(3) EQF1612 51.66 ) ApaptP I_H 45.66 ea6(2) EQr-46(i 44.66 i A6aptaf H 38.66 ea0(Ij PSTP-EA1 37.66 5 PSC, PSTC-"17 PB 21 5 Sapaafe 17 5 29.39 NP name Offset AH -97(2) 29.39 1L82 AH -97(1) I 28.06 S01CCA TTG -C 26.72 Um, SCMT-CA: 23.11 11.32 8155 1L82 SEOItA IL82 S01CCA 11.82 8198 11.32 SUHH 10.32 SetS{A8 155 t SOU -M8 127 AH -2n T3GC Bean$ To —DT 11.32 �CBL5 1L82 OT5C IL82 —CBL3 11.82 —MAP 11.32 —ADx f 10.32 Rdk I 1 11 —SCMT 6.00 GR 33.95 PSTC 33.66 PBTC T9 0.00 a strhr9 Bottom Tetnpra 30.83 time Bean$ To 36.75 IOOL.7ERO anwalu Lergft are M R ne Maaknum Outer 01amater - 2125 In Sapp Nae 30.75 LBie: $e0©r Laptbn, Yage: GaDg Offset PressW a N measeaement5 are relatNe M TOU_AMO Schlumberger NAM 11 18 August 2017 Schlumberger -Private Schlumberger Conocol"hillips Alaska, Inc. Cement Evaluation 1H-118 Cement Information 7" Production Casing Cement lob (PHASE: PRODl OPCODE: CEMENT) Lead slurry from 6,100' MD to 4,260 with Extended Class G Lead @ 14 ppg Bottom of Lead to Top of Cement 1 (6,100'- 4,260') x 0.1268 ft3/ft x 1.40 (40% excess) = 327 ft3 Total Volume = 327 ft3 = 58 bbls => 230 sx of 14 ppg Class G @ 1.42 ft3 /sk FlNICa,prttiM SRrgI NrAal Tail slurry from 8,294' MD to 6,100' MD with UniSLURRY Class G Tail @ 15.8 ppg Shoe to Top of Tail (8,294'- 6,100') x 0.1268 ft3/ft x 1.40 (40% excess) = 389 ft3 Shoe Joint (80') x 0.3171 ft3/ft x 1.0 (0% excess) = 25 ft3 Total Volume = 389 + 25 = 414 ft3 = 74 bbls => 360 sx of 15.8 ppg Class G @ 1.16 ft3/sk FMtYIk'.11016511ll1 Displacement (8,294'- 80') x.03826 bbl/ft = 314.3 bbls Lead Cement LICA .. at Ua 11 dmn[Cupnuly 5l,Igl. lam,, SW lum be rger SapkgRNdA1e[wW FlNICa,prttiM SRrgI NrAal RLJn Bay YeISI N'et uLcrabry �a.orttlw 1ny! bR 6 Hurt !an L e9a9 n epaR. • 11mmr elss FMtYIk'.11016511ll1 IB 1001 6— 1200 Ili lb l is 1z +e qp G W u y 16 ! C € $ 3 p 600- 006 8- a- 6 2- , n 20 ¢ 2W- ''. 2- 0 0 0 0 0 is z0 +5 W Torre (NN7 wl:a rt11 Ill 5ap1'. IYNW Nk Nm, 01100031UW W, Nnlr OHI SWRI 2101.51 S.,M- b n NmM1M 1lW pl 1] RW T1f 150r1R M2011 Ia1155W 61.111'. 710 WAlin YW pi NA MIS4Rva G1A600».OB%00u.61Y6EY0 WgR0011.0WgR011a IIIA BICE 1 12 1, ssR1 Rhea: anllAnsn n W 61ST 0& 211r AFRI h.gF aOF� EN!I[tl6hM 1 RgNse a'. Ogon 113 la�Twg'. Schlumberger NAM 12 18 August 2017 Schlumberger -Private Schlumberger ConocoPhillips Alaska, Inc. Cement Evaluation 1H-118 Tail Cement UCA "antnt PM SGSA 3a1P1 Sch lum be rge r SspRgR000: 10511'nMl flnalCaprtsfly 5Rng1:11111pIa11a05:W RuOa 8a1Wpk M'71IaW1% Cos DrtffH 1Ry!MPt e(swe aanla hgag TtlsaAF '11016511MI FSBd:.19a 6A f Y!I 4007 50W- 8 — ... –_ t8 oSIoI-- 3N7 167 40W j 2 6c 11 g]SW{ 54 u 34 y 127 3ppp:ij �u 320! € t 1500 • 3 w 5g F E e 9 1 W Y ------------ 2- 4- 4 q sga� 0 0 0 0 V.w 15:00 30M 45:00 Time MN:MM) lacaton: 11118 SOpL 10 50 R!Nast'.,a11h00II%SA Oww". I SW @I: 1&A M sup Mort nldaIh. IWpl 244M Ttst50rta' M2MV 1011VIN O'mlt: 150 b.9e1 100041: 311 W TtttS"* 8A4M111:M40M Spe• GaTi0a5'asi0n5.0Mgpsoal a, U. 13&9F 1111: In0i RMea: M4M)1111)11 M W ST 10hgF 21r Mai A T, hire'OW! TANkInM Pd91 RN Nae':0O 111 SBek a ISRgnt(IN I'Do a) lwA SBR Q is" No (500 MM) 41" Schlumberger NAM 13 18 August 2017 Schlumberger -Private Schlumberger ConocoPhillips Alaska, Inc. Cement Evaluation 1H-118 8. Appendix GLment bond toots measure the bund between the casing and the cement placed in the amwlus between the casing and the wellbore. The mea- surement is mask by using acoustic smile and ultrasonic tools, In the case of some tools, the measurement is usually displayed on a cement bond log (CBL) in millivolt units, decibel attenuation, or both. Reduction of the reading in millivolts or increase of the decibel attenuation is an indication of better -quality bonding of the cement. behind the casing to the casing wall. Factors that affect the quality of the cement bonding are ■ cement job design and execution as well as effective mud renmral ■ compressive strength of the cement in place ■ temperature and pressure changes applied to the casing after cement- ing • epoxy resin applied to the outer wall of the casing Slim Array Sonic Tool The Slim Array Sonic Tool (SSLT) is a digital some tool that provides conventional openhole some measure- ments, standard CBL amplitude and Variable Density log (VDL), and atten- uation measurements, which are less affected by borehole environmental conditions. The SSLT can also make a short -spacing (1 -ft 10.30-mt) CBL measurements for cement evaluation in fast formations The two transmit- ters and six receivers of the SSLT sonde have transmitter—receiver spacings of 1, 3, 3.5, 4, 4.5, and 5 It 10.30, 0.01,1.07, 1)0,1.37, and 1.52 in to compute the following: SchWmherger Cement Bond Logging Tools • standard 3 -ft CBL and 541 VDL measurements ■ borehole -compensated (BHC) attenuation from the 3.5- and 4.5 -fl spacing receivers ■ near-pseudoattenuation from the 3-[L spacing receivers ■ short -spacing attenuation from the 1 -ft spacing receiver for cement bone) measurement in fast fomta- tiom that may affect the standard 'ift spacing Slimxtreme Sonic Logging Tool The SlimXtrente Sonic Logging Tool (QSLT) provides the same measure- ments as the SSLT of the cement bond amplitude, attenuation, and Variable Density display for cwaluation of the cement bond quality of a cemented casing in high-pressure mid high-tem- perature environments. Cement bond log from Digital Sonic Logging Tool The Digital Sonic Lugging Tool (DSLT) uses the Sonde dogging Sonde (SIS) to measure the cement bond ampli- tude and provide a Variable Density display for evaluation of the cement bond quality of a cemented casing string Variable Density or x -,v wave- form display of the some signal is prc- senttd in coryurwtimt with the bond hdex and amplitude signal. The DSLT is also used in the open borehole environment for conventional some measurements of BHC (3- to 5.11) transit Lime and long -spacing depth-derhed BHC (DDBHC) (0- to 11 -ft 12.74 to 3.35-m1) transit time. I OS:T J� II nemury 54m SsLT OSLT CSLTo SCAT eSLT Schlumberger NAM 14 18 August 2017 Schl um berger-Private Schlumberger ConocoPhillips Alaska, Inc. Cement Evaluation 1H-118 Schlumberger Cement bond log from Hostile Environment Sonic Logging Tool The Hostile Emimmnent Sonic Logging Tool (HSLT) provides the sane mca- surements of the cement bond ampli- tude and Variable Density display for evaluation of the cement bond quality of a cemented casing string as the SSLT in high-pressure and high-temperature environments. Slim Cement Mapping Tool The Slim Cement Mapping Tool (SCMT) is a through -tubing cement evaluation tool combinable with the PS Platform production logging sor- vice for a variety of web diagnostics. The two sizes are Pit. in 14.29 cm] for the standard (302 degF [I,% degC]) temperature rating mid 24k in 159A cral with a 392 degF 1200 degC1 tempera- ture rating. The SCMT is suitable for running workover operations and in new wells. SCMT operations provide a char advantage in workover wells because there is no need to pull tubing above the zone of interest for cement evaluation. The SCMT is capable of running through most tubings to evalu- ate the casing below. in new welts the SCMT is an excellent tool for evaluating casing that is 71A in 119.36 cm] or less The SCMT features a single tray& mitter, two receivers spaced at 3 and 5 It from the transmitter, and eight segmented receivers 2 ft 10.61 ml from the transmitter. The output of the near (3-A) receiver is used for CBL and transit -time measurement. The out- put of the far (54) receiver is used for the VDL measurement. The eight segmented receivers generate a radial image of the cement bond variation. Memory Slim Cement Bond Logging Tool The Memory Slim Cement Bond Logging Tool provides through -tubing 3 -ft CBL and 5 -ft VDL measurements with the same accuracy and quality as ssrrfaa-readout logs. Because of its slim size, the PXin tool can be run into the zone of interest without hav- ing to remove the tubing from the well. The tool simultaneously records gamma ray, casing collar location, pressure, temperature, and waveforns in a single pass, with the waveforms fully digitized downhole. More than 40 h of combim+l tool running time is possible, including 16 h of continuous waveform record- ing time, Depth -recording systems are available for both hazardous and non- hazardous environments. The Memory Slits CBL Tool can be nun with other PS Platform production logging tools for complete well and reservoir evaluation in one descent. The tools and sensors can be conveyed in the borehole by drillptpe, coiled tub- ing, slickline, or unintelligent tractor. PS Platform software is used to perform onsite data processing or any necessary postprocessing and prepare the log pre- sentation. Applications ■ Evaluation of cement quality ■ Determination of zone isolation ■ Location of cement top Schlumberger NAM 15 18 August 2017 Schlumberger -Private Schlumhuger Cement Evaluation ConocclPhillips Alaska, Inc. 1H-118 Kuparuk River Date Recorded: 18 -Aug -2017 Project: CPAI_1H-118_SCM7 Date Analyzed: 8/18/2017 Intzpreter: Chew Yeong Leong Gamma Ray, Casing 2R Reciever-Max, Avg, M Reciever- CBL AMplitude Mapping 3R Receiver- CBL SR Receiver -VDL Bond Inde. Collar Locator Min SCMT Mapping Lnage AmplRude MXMA 0 mV CCLC AVMA Reference -15 V s o mV loo 203.47 -32767.00 GR MIMA MPWF CBL VDL-111 8I 1:1200 0 gAPI 100 10 mV 100 0.42 2e+02 0 mV 100 200 us 1200 0 Unrtless 1 2200 2400 2600 !4 Il Loepp, Victoria T (DOA) From: Klem, Adam <Adam.Kiem@conocophillips.com> Sent: Friday, August 18, 2017 4:44 PM To: Loepp, Victoria T (DOA) Cc: Tolman, Ben V; Buck, Brian R; Bearden, 1 Daniel; Doyon 142 Company Man Subject: RE: 1H-118 CBL interpretation Follow Up Flag: Follow up Flag Status: Flagged All, I received a call from Victoria today at 16:31. She informed me she may be having email issues, as she had not received my email with the CBL, and was not able to send me an email either. She informed me that based on our interpretation of the CBL that I gave her over the phone, that we are granted permission to proceed with operations and perforate the wellbore. Give me a shout if you have any questions. Adam Klem From: Klem, Adam Sent: Friday, August 18, 2017 2:11 PM To: 'Loepp, Victoria T (DOA)' <victoria.loepp@alaska.gov> Cc: Tolman, Ben V <Ben.V.Tolman@conocophillips.com>; Buck, Brian R <Brian.R.Buck@conocophiIlips.com>; Bearden, J Daniel <1.Daniel.Bearden@conocophillips.com> Subject: 1H-118 CBL interpretation Victoria, Attached is the CBL and interpretation for 1H-118 7" intermediate casing. Based on the CBL, we have the TOC at 3,160'MD, with good cement across the reservoir. Based on these results, can we receive approval to proceed with perforations as per the PTD? Thanks, Adam Loepp, Victoria T (DOA) From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Thursday, August 17, 2017 1:50 PM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]RE: KRU 11-1-118 PTD 217-084 CBL question Sounds good, thanks! From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Thursday, August 17, 2017 1:49 PM To: Klem, Adam <Adam.Klem@conocophillips.com>; Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Subject: [EXTERNAL]RE: KRU 1H-118 PTD 217-084 CBL question Adam, Please email TOC/cementing section to me as well as interpretation as soon as they are available. You may call me at 242-9156 as soon as you have the CBL results. I will be able to respond immediately. This will not cause any rig downtime. Thanx, Victoria From: Klem, Adam [mailto:Adam.Klem conocophillips.com] Sent: Thursday, August 17, 2017 1:19 PM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov>; Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: KRU 11-1-118 PTD 217-084 CBL question All, The PTD specifies to review the CBL with the AOGCC (as shown below). We just finished cementing and plan to run the CBL sometime tonight. Immediately following we plan to proceed with shooting perfs on rig with TCP. Our question is, do we have to review the CBL and get approval before perforating? Or, assuming the CBL shows adequate cement isolation, can we proceed with perforating prior to reviewing the CBL? We are trying to minimize rig down time, as the CBL will probably be ran late tonight. Thanks, I M.,ic it + rq up IA.3up Rat 137, Inf1a11 M1aneur wish I O" diatnee Ise and raxlira: tpv. ?. Spod erddncpauadly doll l3�'hdcbtasinR pouNx•fI,TM'h1U(:,TOT"]'YUa: par rhettieuaal plan Rua MI I) b31s ew1 nVuiraf fiv d+rcctiwa vtunia-mat I Wuwe my, faksfiviti'), ;t. flan and rasnN :0.33", 45 50F. 1.90.11Y11350.1.9 W-JX(-t. Dlylex cemcm with m W and chock fk u - Upon butnpies prixraffwm alp tub ifnquked A'P bf, AOfr C C- 4 Rdemt d�verta rygsm Imrol' rd la; 1 i•SR" a 3.000 pri nOP'i b 2$0 pti kaw epd ]500 pu hlRp (epmllr ryawemte W 3$00 pit). Nwly AOL T 24 Yn bcfurc trq. 5. 10.7 R.S"bil and 0.7i dri!iinq nixtptbly, with MWlYL1k'D (ram+wt fay, roaigivgy). Rln,ek,=—a a"a W fup . Mm a aripmcm wd IW Mot b 3.000 poi for 10 min. ti. I/till pia moans and Fxtwtam 20'. W'-efnro holt rrrtetfn ltai Mfmq :oam�nimum Ml2 oppt F.MW L.O7!rrr, re .rdmg rmalls, 7 Displ:ux k+ 1 ill) ." based dr Ihng fluid. R U1rc4it+itufly dri11 W T <nNit {o:n: q 6,74,3• M11 f d,10i' IVII. 4. Ilreukz Mlc crew. Moll, 10 Rxn T.?61.IdtP, /fVI75Gaf1'%Y cxaint fu wr[atc. (Tupaf ccmcnfW he 0.1ZO. MD 13,360' TVn which mnutpeadi b 250"R'U abort qp of the Wes Salt Yttd ) II Irota'-I wellhead a 7' ptcaotT end ate m 3.500 psi 12f lush 10.75' a r' amulna acib wxa, 61J—WW b2 tmmtrm, 13. Aans,rt fall prod"60r, taint% m 5,500 psi Wt 30 min. w/ .4p n e 1:. Run CPI. mal wOAir. Re,ie W I s. RIH xNh 7l `Pe and rtd+na4 nems. 7Aake clean wt alp Y[ nn-0asl IG. Iter. 7.3" upper tump4etwus xitl+ Prken ead team. 17. IAM hangce• run ®1cA w,ewi, ed I'A mA, a. 5,040 pri. is 41 RrV. i4, Ntppk duxes Rl N'L•. nrppk s:p See wdtcu Ns RPV 70 rrtese pn t wail wuk dicval h$ pumps, mW 33` a T" emtuia tAint mrams fmm t-biag and alluwinN m OR.hec. 41f the aehedu:t utd Naipmem av f.l bilig dlewa, the Weill Group ill fvicenu routes the weft pw fit). 21. Sa RPV and mwe air rot Discussion of Mud and Gutlinp Disposal and Annular Disposal AAC 21L00S 11)(I ra qe y.uw.dv r a...« t, :. uY.ww- N a;..t...rrtrwW.jW,sa..roa tu... i,R+Fa u-iwxaht•M r nu .xl w,..w..y., 2 Loepp Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Thursday, July 06, 2017 11:00 AM To: ben.v.tolman@cop.com Subject: KRU 1H-118(PTD 217-084) Ben, Could you please include the packer depths as well as perforation depths on your wellbore schematic? Are there any plans to run a cement evaluation log on the production casing? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(Walaska goy 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 Loeoo@alaska.aov Originated: RECEIVED Schlumberger PTS- PRINTCENTER AUG 2 3 2017 6411 A Street Anchorage, AK 99518 A�(�('��'+ (907)273-1700 main (907)273-4760f3x' UVC Delivered to: MakanaK Bender Natural Resources Technician It Alaska Oil & Gas Conservation Commission 333 W T Ave, Suite 1OO Anchoraae, AK 99501 21 7084 28541 2854MON2 r 22 -Aug -17 22Aug17.1W02 DATA LOGGED SI+L201-1 M. K. 9ENDER Receipt m Name A Transmittal Receipt signature confirms that a package (box, X D n envelope, etc.) has been received and the contents of the A /�Q��p•►yK� �/ package have been verified to match the media noted above. The Signature Date specific content of the CDs and/or hardcopy prints may or may Please send signed transmittal to CPAI via email or post. not have been verified for correctness or quality level at this Tom Osterkami2Eco ocophillips com point. ORDERSERVICE 2A-22 50-103-20221.00 87-0 DM01 00 FIELD NAME DESCRIPTION KUPARUK RIVER WL DELIVERABLE r • LDL r. FINAL FIELD D. • r 25 -Jul -17 1 r 1 1F-07 50-029-20830-00 DSOS-00049 KUPARUK RIVER WE PPROF FINAL FIELD 10 -Aug -17 1 1 2W-17 50.029-23370-00 DSOS-00050 KUPARUK RIVER WL PPROF FINAL FIELD 12 -Aug -17 1 1 1J-160 50-029-23344-00 DSOS-00052 KUPARUK RIVER WL IPROF FINAL FIELD 15 -Aug -17 1 1 2Z -13A 50-029-21360-01 DM87-00119 KUPARUK RIVER WE Tubing FINAL FIELD 17 -Aug -17 1 1 11-1-118 50-029-23578.00 DM87-00120 KUPARUK RIVER WL SCMT FINAL FIELD 18 -Aug -17 1 1 1H-118 50-029-23578-00 DM87-00121 KUPARUK RIVER WL Packer FINAL FIELD 21 -Aug -17 1 1 7 7 Receipt m Name A Transmittal Receipt signature confirms that a package (box, X D n envelope, etc.) has been received and the contents of the A /�Q��p•►yK� �/ package have been verified to match the media noted above. The Signature Date specific content of the CDs and/or hardcopy prints may or may Please send signed transmittal to CPAI via email or post. not have been verified for correctness or quality level at this Tom Osterkami2Eco ocophillips com point. THE STATE °fALASKA GOVERNOR BILL WALKER Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.cogcc.alaska.gov Re: Kuparik River Field, West Sak Oil Pool, KRU 1H-118 ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-084 Surface Location: 378' FSL, 791' FEL, SEC. 28, T12N, R10E, UM Bottomhole Location: 109' FNL, 2493' FWL, SEC. 27, T12N, R10E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Hollis S. French Chair �J DATED this -'� day of July, 2017. STATE OF ALASKA Ab,,A OIL AND GAS CONSERVATION COMMI _iON PERMIT TO DRILL RECEIVED JUN 06 2017 AAV :r%n_ 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp4,Kuparak a NI M VV Specify if well is proposed for: Drill Q Lateral ❑ Slratigraphic Test ❑ Development -Oil ❑ Service - Winj ❑✓ Single Zone lbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone thermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Single Well Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 ' 1 H-118 3. Address: 6. Proposed Depth: ield/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 8,2941 . TVD: 4,16 River Field . 4a. Location of Well (Governmental Section): 7. Property Designation: - West Sak Oil Pool . Surface: 378' FSL & 791' FEL, Sec 28, T12N, R10E, UM ADI -066-39- ,i Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 1207' FNL & 2488' FWL, Sec 27, T12N, R10E, UM 80-261 7/19/2017 Total Depth: 109' FNL & 2493' FWL, Sec 27, T12N, R1011, UM 9. Acres in Property: 14. Distance to Nearest Property: 2560 acres • 201'to ADL025636 4b. 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- 549,546.95' y- 5,981,081.22' Zone- 4 • GL / BF Elevation above MSL (ft): 54'.0 - to Same Pool: 8,001' to 1 B-102 16. Deviated wells: Kickoff depth: 700 feet - 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 74.06 degrees , Downhole: 1,780 psi Surface: 1,382 psi 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" 94# H-40 Welded 80' Surf Sort 80' 80' Existing 13-1/2" 10-3/4" 45.5# L-80 HYD563&T 1701' Surf Surt 1740' 170 7' 600 sx 11.0 ppg, 275 sx 15.8 ppg 6# 8-1/2" 7" 26#L-80 TXP 8255' Surt Surt 8294' 4163' 355 sx 15.8 ppg Class G 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (11): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes ❑ No ❑� 20. Attachments: Property Plat BOP Sketch B Diverter Sketch Drilling Program B Time v. Depth Plot Seabed Report Drilling Fluid Program B Shallow Hazard Analysis 20 AAC 25.050 requirementse 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Ben Tolman C.T. Authorized Name: Chip Alvord W. Contact Email: ben.v.toInnanrcDcon.coM Authorized Title Alaska Drilling Manager Contact Phone: 907-265-6828 i Authorized Signature: TIJ Date: 4-Jr -Z0/1 Commission Use Only Permit to Drill C, Number: �O API Number: Q Permit Approval -7 See cover letter for other - 50- Q JS -QQ -Q� Date: - -7- 1-7 requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: fp -'75-220 /ps7 / fJ vz n u!c r pr -t VY h 7G � S � Samples req'd: Yes ❑ No Mud log req'd: Yes❑ NoZ Z IZJ�-!526 n asures: Yes No❑ Directional svy req'd: Yes Lo"No❑ Spacing exception req'd: Yes ❑ Nog Inclination -only svy req'd: Yes Post initial injection ,.❑_/No2r MIT regal Yes V✓J No❑ Approved by: APPROVED BY :1111, ^ Jl COMMISSIONER THE COMMISSION Date: T N) 10-401 Revis 5/217 �!� Submit Form and ^ /\/ I47J� 1 �� s 5/2 T�Ya pefilit,jsyalid fpr $4 mo� from the date of approval per 20 AAC 25.005(8) Attachments in Duplicate '\ KA KI(G NAL W17 Application for Permit to Drill, Well 1H-118 Saved: 5 -Jun -17 June 05, 2017 Alaska Oil and Gas Conservation Commission 333 West 7" Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill Well 1H-118, a West Sak Sand Injector Dear Commissioner: 011'C) ?A8 ConocoPhillips Alaska, Inc. hereby applies for a permit to drill an onshore grassroots pre- ed injector well from the 1H pad. The expected spud date for this well is July19'", 2017. It is planned to use rig Doyon 142.E IH -1 18 is planned to be a slant thru the West Sak sands. The surface section will be drilled with 13-1/2" bit and run 10- 3/4" casing to ±1,740' MD / 1,707' TVD. The production section will be drilled with 8-1/2" bit and run 7" casing to +/- f8,294'MD / 4,163' TVD. The upper completion will be run with 3-1/2" tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Ben Tolman at 265-6828 (ben.v.tolman@cop.com) or Chip Alvord at 265-6120. Sinly, ymmJ y(,/�, / Chip Alvord far Drilling Manager K Application for Permit to Drill Document Kuparuk Well 1 H-118 Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as 1H-118 Location Summary Requirements of 20 AAC 25.005(c)(2) An application far a permit to Drill must be accompanied by each of the follmving items, except for an item already on file with the commission and identified in the application: (2) a plat idem f ,ing the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration: (C) the proposed depth of the well at the tap of each objective formation and at total depth: Location at Surface 378' FSL, 791' FEL, Sec 28, T12N, R010E, UM NGSCoordmates Northings: 5,981,081.22' Eastings: 549,546.95' IRKB Elevation 93' AMSL 1Pad Elevation I 54'AMSL Location at Top of Productive Interval FNL, 2488 FWL, Sec 27, T12N, Northings: 5,984,797.54' Eastings: 552,793.18' Total 17f 13 Location at Total De th 109' FNL, 2493' FWL, Sec 27, T12N, R010E, UM NGS Coordinates Northings. 5,985,823.92' Eastings: 552,789.59' I Measured Depth, RKB: 8,294' Total Vertical De th, RKB: 4,163' Total Vertical De th, SS: 4,070' and (D) other information required by 10 AAC 25.050(b); Requirements of 20 AAC 25.050(b) /f a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale. sharing the path of the proposed wellbore, including all adjacent we/lbores within 200 feet of any portion of the proposed it ell: Please see Attachment: Directional Plan And (2) far all it within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail: or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Pernin to Drill must be accompanied by each of the follmving items, except for an item already on file with the commission and identified in the application: (3) a diagrams and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 142. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(41 An application for a Permit to Drill must be accompanied by each of the following items, except for an item alreadq on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient: The maximum potential surface pressure (MPSP) while drilling 1H-118 is calculated using an estimated maximum reservoir pressure of 1,590 psi (based on 1H-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 3,981' TVD (WP22): A Sand Estimated. BHP = 1,780 psi A Sand estimated depth (WP22) = 3,981' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 398 psi (3,981' TVD * 0.10 psi/ft) MPSP = BHP — gas column =1,382 psi I (1,780 psi — 398 psi) (B) data on potential gas cones; The well bore is not expected to penetrate any shallow gas zones. And (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation cones, and cones that have a propensity far differential sticking; See attached 1H-118 Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(1): A procedure is on file with the commission for performing LOT'S. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file vith the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of airy slotted liner, pre -perforated liner, or screen to be inledled Casing and Cement Program Casing and Cementing Program Csg/Tbg OD Hole Size Weight Grade Conn. Length Top MD?VD Btm MD7TVD (in) Ob//tl (B) (h) (ft) Cement Program in 20 42 94 H-40 Welded 80 Surf 119/119 Existing Cement to Surface with 10-3/4 13-1/2 45.5 L-80 HYD563 1,701 Surf 1,740 / 1,707 600 sx LIteCRETE Lead 11.0 ppg, 275 sx UniSLURRY Tail 15.8 ppg 7 8-1/2 26 L-80 HYD5663 / 8,255 Surf 8,294 / 4,163 355 sx Class G at 15.8ppg w/ TOC at 6,120' MD 10-3/4" Surface casing run to 1,740' MD / 1.707' TVD Cement from 1,740' MD to 1,240'(500' of tail) with 15.8 ppg UniSLURRY, and from 1,240' to surface with l l ppg LiteCRETE. Assume 150% excess annular volume for lead and 50% excess for tail, and 0% excess in 20" conductor. Lead slurry from 1,240' MD to surface with Arctic LiteCRETE @ 11 ppg Conductor (119'— 0') x 1.339 Oft x 1.0 (0% excess) = 159 11:3 Bottom of Lead to Conductor (1,240'— 119') x 0.3638 ft3 /ft x 2.5 (150% excess) = 1,020 ft3 Total Volume = 119 + 1,020 = 1,139 ft3 => 600 sx of 11 ppg LiteCRETE @ 1.91 ft3/sk Tail slurry from 1,740' MD to 1,240' MD with 15.8 ppg UniSLURRYe Shoe to Top of Tail (1,740'— 1,240') x 0.3638 ft3/ft x 1.50 (50% excess) = 273 ft3 Shoe Joint (80') x 0.5400 Will x 1.0 (0% excess) = 43 ft3 Total Volume = 273 + 43 = 316 ft3 => 275 sx of 15.8 ppg UniSLURRY @ 1.16 Wifsk 7" Production casing run to 8.294' MD / 4.163' TVD Single stage slurry is designed to be placed from TD to 6,120' MD, which is 250' TVD above top of West Sak Pool (base of Ugnu); 40% excess annular volume. Slurry from 8,294' MD to 6,120' MD with 15.8ppg Class G + additives Shoe to Top of Cement (8,294'— 6,120') X 0.1268 Olt X 1.40 (40% excess) = 386 ft3 Shoe Joint (80') X 0.3171 ft3/ft X 1.0 (0% excess) = 21 ft3 Total Volume = 386 + 21 = 407 ft3 => 355 sx of 15.8 ppg Class G @ 1.16 ft3lsk Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application far a Permit to Drill must be accompanied by each of the follotring items, except for an item already on file a nh the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25 035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); Please reference diverter schematic on file for Doyon 142. I Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25033, Mud Program Summary Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, excep( for an item alreadv on file with the commission and identified in the application The proposed drilling program is included below. Please refer to attachment for proposed well schematic. Surface Production 13-1/2" Hole 8-1/2" Hole 10-3/4" Casing 7" Casing Mud System Spud (WBM) LSND (WBM Density 8.8-9.5 9.0-10.0 PV ALAP ALAP YP 30-80 20-30 Funnel Viscosity 250-300 Permafrost Base 100-150 to TD N/A Initial Gel 30-50 9-11 10 minute Gel 30-50 < 20 API Filtrate NC <6 HTHP Fluid Loss at 160° F N/A < 10 H 10.8-11.2 9.5-10.0 Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, excep( for an item alreadv on file with the commission and identified in the application The proposed drilling program is included below. Please refer to attachment for proposed well schematic. 1. Move in / rig up Doyon Rig 142. Install Annular with 16" diverter line and function test. 2. Spud and directionally drill 13.5" hole to casing point at +/- 1,740' MD / 1,707' TVD as per directional plan. Run MWD tools and required for directional monitoring (gamma ray, resistivity). 1 3. Run and cement 10.75", 45.5#, L80, HYD563 casing to surface. Displace cement with mud and check floats upon bumping plug. Perform top job if required. /V' ' f i ¢q ff Oh C L 4. Remove diverter system. Install and test 13-5/8" x 5,000 psi BOP'S to 250 psi low and 3500 psi high (annular preventer to 3500 psi). Notify AOGCC 24 hrs before test. 5. PU 8.5" bit and 6.75" drilling assembly, with MWD/LWD (gamma ray, resistivity). RIH, clean out cement to top of float equipment and test casing to 3,000 psi for 30 min. 6. Drill out cement and between 20' - 50' of new hole. Perform leak off test to a minimum of 12.Oppg EMW LOT/FIT, recording results. 7. Displace to LSND water based drilling fluid. 8. Directionally drill to 7" casing point at 8,294' MD / 4,163' TVD. 9. Circulate hole clean. POOH. 10. Run 7, 26#, L80, HYD563/TXP casing to surface. (Top of cement to be 6,120' MD / 3,360' TVD which 4 -- corresponds to 250' TVD above top of the West Sak Pool.) 11. Install wellhead x 7" packoff and test to 3,500 psi. 12. Flush 10.75" x 7" annulus with water, followed by isotherm. 13. Pressure test production casing to 3,500 psi for 30 min. 4 14. Run CBL on wireline. v1 Re Vic hi [� i i 1 Q C? Lr C 15. RIH with TCPs and perforate zones. Make clean out run if needed. 16. Run 3.5" upper completions with packers and gauges. 17. Land hanger, run in lock screws, and test seals to 5,000 psi. 18. Set BPV. 19. Nipple down BOPE, nipple up tree and test. Pull BPV. 20. Freeze protect well with diesel by pumping into 3.5" x 7" annulus, taking returns from tubing and allowing to equalize. (If the schedule and equipment availability allows, the Wells Group will freeze protect the well post rig). 21. Set BPV and move off rig. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill music be accompanied by each of the following items. except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and datings and a statement of whether the operator intends to request authori-otion under 20 AAC 25.080for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class Il disposal well (DS I B 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. Loepp, Victoria T (DOA) From: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Sent: Thursday, July 06, 2017 1:32 PM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL] KRU 1H-118(PTD 217-084) Attachments: 1H-118_AK_PTD_Revl.pdf Victoria, Good afternoon. To answer your questions, please see my responses below: Could you please include the packer depths as well as perforation depths on your wellbore schematic? Please reference the depths below or the updated schematic attached. Please note that the depth listed are best estimates based on planned wellbore trajectory and offset logs. Actual depths will depend on the actual wellbore trajectory, depths, and LWD logs. • Packer #3: 7155' MD • Packer #2: 7355' MID • Packer #1: 7487' MD • D Sand Perforations: 7193'— 7332' MD • B Sand Perforations: 7373' — 7465' MD • A4 Perforations: 7502' — 7546' MD • A3 Perforations: 7660'— 7718' MD • A2 Perforations: 7796'-7846' MD Are there any plans to run a cement evaluation log on the production casing? Yes, we plan to run a cement bond log (CBL) on the production casing (as described in Step 14 of the Proposed Drilling Program). I hope that answers your questions. Please let me know if you have any further follow-up questions/items. Hope you have a great sunny afternoon! Thanks, Ben Tolman Drilling Engineer I ConocoPhillips, Alaska (907)265-6828(o)1(307) 231-3550(m) From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Thursday, July 06, 2017 11:00 AM To: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Subject: [EXTERNAL] KRU 1H-118(PTD 217-084) Ben, Could you please include the packer depths as well as perforation depths on your wellbore schematic? Are there any plans to run a cement evaluation log on the production casing? Thanx, Insulated Conductor: 20" Casing Wellhead / Tubing Hanger / Tree, 13-3/8" x 4-1/? HYD563, 5,000 ksi Crossover below TH: 4-1/2" x 3-1/2" Tubing 10-3/4',45.5#, L-80, HYD563 .� Q 1740' MD 3-12", 9.2 #, L-80, EUF AB 3-12" MMG with SOV Feed Through Packer #3: 7155' MD 2.812" Camco DS Nipple Upper MMG Gauge Mandrel — Lower MMG Feed Through Packer #2: 7355' MD Upper MMG Gauge Mandrel Lower MMG Feed Through Packer #1: 7487 MD 2.75" Canto D Nipple Upper MMG G Gauge Mandrel — Lower MMG Baker WIV 1 H-118 Injector Well Design PTD Schematic (Rev 1) "D" Sand Perforations: 7193' - 7332' MD Scraper/Magnet Assy — Dumb iron muleshoe "B" Sand Perforation: 7373'- 7465' MD A4 Perforations: 7502' - 7546' MD A3 Perforations: 7660' - 7718' MD A2 Perforations: 7796'- 7846' MD Top of float collar *-� 7',26#, L-80, HYD563/TXP (6.276" ID, 6.151" DRIFT) ® 8294' MD Wellhead/l'ubing Hanger/Tree, 11-1-118 Injector Well Design / 13-3/8" x 4-'L" HYD563, 5,000 ksi Crossover below TH: PTD Schematic Insulated Conductor 4-1/2" x 3-1/2" Tubing _--= 20" Casing 10-3/4", 45.5#, L-80, HYD56 - @ 1740' MD 3-1/2",9.2 #, L-80, EUE-AB 3-12" MMG with SOV ro e 6 r Feed Through Packer #3 ae 2.512" Camco DS Nipple "D" Sand Perforations V Upper MMG ee Gauge Mandrel LowerMMG Feed Through Packer #2 "B" Sand Perforations Upper MMG Gauge Mandrel Lower MMG Feed Through Packer #I A4 Perforations 2.75" Camco D Nipple A3 Perforations Upper MMG A2 Perforations Gauge Mandrel Lower MMG Baker WIV Top of float collar 2 Scraper/Magnet Assy r� 7", 26#, L-80, HYD563/TXP (6.276" ID, 6.151" DRIFT) z Dumb iron muleshoe @ 8294' MD Attachments: Attachment 1 AOR Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 Well Schematic Attachment 5 Diverter Layout Diagram Attachment 1 AOR / An Area of Review plot is shown below of the I H-118 planned wellpath and offset wells. The included table identifies any of the offset wellbores within the''/. -mile review. 1H•118wp21 Quarter Mile View n ay°�a I 7500 TOC Determined By Reservoir Status Zonal Isolation Cement Operations Summary Proposed 6,120'/ i I C Column of cement to be 250' 1H-118 Injector 7.193' / 3,737' 3,358' CBL I $ Well does not exist yet 3,358' TVD N Kuparuk and West Cement plugs placed in OH: I Z.!So0 Sak P&A'd. Original • Plug #1:9,825'-10,890' • Plug #1: 225 sxs, "G"@ wellbore was (Kuparuk) 15.8 ppg sidetracked outside • Plug#2: 5,100'MD - 5,700' • Plug #2: 290 sxs, "G" @ surface casing (11-1- MD (West Sak D -A2) 15.8 ppg 1H-05 P&A'd 5,242'/3,715' OH through OH through 305). Cement plugs • Plug #3:3,979'-4,590'(Ugnu • Plug #3: 260 sxs, "G"@ reservoir. reservoir. 1500 11 � / 15.8 ppg (tagged) wellbore isolating • Plug#4: 2,550'- 2,715' / hydrocarbon zones (below surf shoe & K -markers) II" @ 15.7 ppg (tagged) V-1 (both Kuparuk and • Plug Its: 2,200-2,545(into • Plug #5: 250 sxs,"Antic Set West Sak surface casing, but drilled out I" @ 15.7 ppg (tagged) �fp0 1500 3000 4500 6000 7500 9000 10500 12000 Well Name Status Top of West Sak D Sand (MD/TVD) TOC (MD/TVD) TOC Determined By Reservoir Status Zonal Isolation Cement Operations Summary Proposed 6,120'/ Column of cement to be 250' 1H-118 Injector 7.193' / 3,737' 3,358' CBL Not Yet Drilled above pool top @ 6'120 MD/ Well does not exist yet 3,358' TVD Kuparuk and West Cement plugs placed in OH: Cement plugs as follows: Sak P&A'd. Original • Plug #1:9,825'-10,890' • Plug #1: 225 sxs, "G"@ wellbore was (Kuparuk) 15.8 ppg sidetracked outside • Plug#2: 5,100'MD - 5,700' • Plug #2: 290 sxs, "G" @ surface casing (11-1- MD (West Sak D -A2) 15.8 ppg 1H-05 P&A'd 5,242'/3,715' OH through OH through 305). Cement plugs • Plug #3:3,979'-4,590'(Ugnu • Plug #3: 260 sxs, "G"@ reservoir. reservoir. In OH abandoned C) 15.8 ppg (tagged) wellbore isolating • Plug#4: 2,550'- 2,715' • Plug #4: 240 sxs, "Antic Set hydrocarbon zones (below surf shoe & K -markers) II" @ 15.7 ppg (tagged) (both Kuparuk and • Plug Its: 2,200-2,545(into • Plug #5: 250 sxs,"Antic Set West Sak surface casing, but drilled out I" @ 15.7 ppg (tagged) formations). with sidetrack operations). - 20'x42" �. 10314" x 1312' 4� o 0 650 1300 1 m 60- 0 30- 30 0 0 Depth Rate rise Plan: 54+39 93.00usfl (Doyon 142) Rig Doyon 142 0 P n 0 m yt m 2600 3250 3900 4550 5200 Horizontal Departure 1H -116.p21 1 H-118wp21 o" 6DD65 Plan Summary 330 T-3 K-15 1500 3000 fI'01~ 1H 22 -119wp 6000 1070 1260 5 {.ii. ;!4'1+120wP21 1H-11]wp22 UG_A No WSD 1t 5 I 'v J \�440 so :630 63 810 UG_B ' WS 700.00 1700,0 1810 - 200 u 103/4" x 13-12 MWD -C I 1 6720 7240 700.00 or z±ROST MWDHFR-AKLAZ-SC I WS 180 `' 7240 Mo1740.00 t P a 3240.00 1H-118wp21 (Plan: 1H-118) I rr WS MWD CASING DETAILS 0 1740.00 8294.07 - UG_C A A3 MWD+IFR-AK-CAZSC T/70 - 8294 1i_A2 / 0 ND MD Name 0 0 20"x42^ 2000 4000 6000 8000 WS At T - 20'x42" �. 10314" x 1312' 4� o 0 650 1300 1 m 60- 0 30- 30 0 0 Depth Rate rise Plan: 54+39 93.00usfl (Doyon 142) Rig Doyon 142 0 P n 0 m yt m 2600 3250 3900 4550 5200 Horizontal Departure 0 1H -116.p21 39 700 o" 700 890 330 - 1500 3000 fI'01~ 1H 22 -119wp 6000 1070 1260 {.ii. ;!4'1+120wP21 1H-11]wp22 39.00 i I i% GYD-GC-SS \�440 so 0 2280 253n 2570 - 2790 3050 - 3310 3310 - 3570 U70 - 3640 3840 - 4100 39 700 o" 700 890 330 0 1500 3000 fI'01~ IYFlr 6000 1070 1260 {.ii. u1.. 1260 1440 39.00 i 1H -118.p21 (Plan: 1H-118) i% GYD-GC-SS \�440 so :630 63 810 6200 - 6720 700.00 1700,0 1810 - 200 MWD 2280 253n 2570 - 2790 3050 - 3310 3310 - 3570 U70 - 3640 3840 - 4100 6 1]40.00 27.86 66.14 1]06.81 ]6.]t 212.01 L50 -25.85 76.71 7 1760do 23.05 fi6.14 1]25.13 ]9.98 220.21 0.00 0.00 79.98 8 2911.64 74.06 46.1`9 2480.72 5889] 88243 4.50 -23.91 588.37 95659.05 74.06 46.79 3215.70 2397.71 2808.43 0.00 0.00 2397.71 10 8239"4 6920 28.00 3400.28 2836.69 313791 150 -106.99 283689 11-118 WTI 090816 KU 11 6986.91 66.8] 35].8] 368161 3505.67 32]6.]4 3.50 400.35 3505.87 12 7120.53 88.0] 357.87 3]3].09 3628.46 32]2.18 0.00 0.00 3528.46 13 7202.42 68.79 0.10 3768.00 3]04.29 3270.90 3.50 48.48 370620 1K11803.T3000816 KU 14 8294.07 65.78 0.18 4163A0 4721.95 3274.04 0,00 0.00 4721.95 1H -11804.T4 W0816 KU Start 4.5-A 00 DI -S. -25.86 TF, for 43.43' Hold for 211' San 4.5°/100' MS. -23.91° T5 for 1151.54' Hold for 274&31' San 3.5/10' OLS,-108.99°TF. for 57999' Aau51 IF to A00.35-, for ]OAT Had for 133.62 San 10100DLS, 4040° TF, for Way Hod for 1091.64' TO: 8294AT MD, 4163' TN K-15 3083.1 UG_C 3342.8 UG a 3471.4 UG A 3610.3 Na By signing this I acknowledge that I have been informed of all risks, the etl that the dela is coned, ensured it's completeness, and all surrounding wells are assigned to the proper position and I approve Ne scion and Prepared by: Checked by: Accepted by: i Approved by. is Bnl Potnis Nate Beck Enk Steric ;Tolman, Phelps , 0 1500 3000 4500 6000 7500 240 '. 120 4100 - 4620 820 - 5150 1' --' 5150 - 5870 - ID0 _ from SURVEY PROGRAM epth From Depth To Sul y/Plan Tool 39.00 700.00 1H -118.p21 (Plan: 1H-118) GYD-GC-SS Pao Elevation: 54.00 210 fla' _ 6200 - 6720 700.00 1700,0 IH -118.p21 (Plan: 111-118) MWD 6720 7240 700.00 1740.00 1H -116w1121 (Plan: 111-118) MWDHFR-AKLAZ-SC 180 `' 7240 Mo1740.00 3240.00 1H-118wp21 (Plan: 1H-118) MWD CASING DETAILS 1740.00 8294.07 1H-118wP21 (Plan' 11-118) MWD+IFR-AK-CAZSC T/70 - 8294 ND MD Name 118.00 116.00 20"x 42" Magnetic Woke: BGGM2016 T 1706.84 1740.00 103/4" x 13-12" Magnetic Madel Date: IWW47 1 4163.00 8294.07 T' x 8-12" Magnetic DeclinMan: 17.57° 1 To converta Magni Dintlion 10 a True Direction, Add 17.57' Pact SECTION DETAILS 1629.4 Sec MD Inc A6 WO +NAS +E/ -W Oleg TFece Vasa Target Annotation PFROST 1 39.00 0,00 0.00 39.00 0.00 0.00 0,00 0.00 0.00 1793.2 2 700.00 0.00 0.00 ]00,00 0.00 0.00 0.00 0,00 0.00 KOP: Shot 2.5°/100' MS. so- TF, for 26335' 12024.3 3 900.25 5A1 80.00 900.00 1.52 8.61 2.50 80.00 1.52 Adfuel TF lc -15•, for 608.4' i-3 4 I5B8.66 5 1696.5] 22.08 60.25 1566.86 2208 6825 166686 55.09 7013 159.51 19719 2.50 -15.00 000 000 55,09 7013 Had for 10].92' 6 1]40.00 27.86 66.14 1]06.81 ]6.]t 212.01 L50 -25.85 76.71 7 1760do 23.05 fi6.14 1]25.13 ]9.98 220.21 0.00 0.00 79.98 8 2911.64 74.06 46.1`9 2480.72 5889] 88243 4.50 -23.91 588.37 95659.05 74.06 46.79 3215.70 2397.71 2808.43 0.00 0.00 2397.71 10 8239"4 6920 28.00 3400.28 2836.69 313791 150 -106.99 283689 11-118 WTI 090816 KU 11 6986.91 66.8] 35].8] 368161 3505.67 32]6.]4 3.50 400.35 3505.87 12 7120.53 88.0] 357.87 3]3].09 3628.46 32]2.18 0.00 0.00 3528.46 13 7202.42 68.79 0.10 3768.00 3]04.29 3270.90 3.50 48.48 370620 1K11803.T3000816 KU 14 8294.07 65.78 0.18 4163A0 4721.95 3274.04 0,00 0.00 4721.95 1H -11804.T4 W0816 KU Start 4.5-A 00 DI -S. -25.86 TF, for 43.43' Hold for 211' San 4.5°/100' MS. -23.91° T5 for 1151.54' Hold for 274&31' San 3.5/10' OLS,-108.99°TF. for 57999' Aau51 IF to A00.35-, for ]OAT Had for 133.62 San 10100DLS, 4040° TF, for Way Hod for 1091.64' TO: 8294AT MD, 4163' TN K-15 3083.1 UG_C 3342.8 UG a 3471.4 UG A 3610.3 Na By signing this I acknowledge that I have been informed of all risks, the etl that the dela is coned, ensured it's completeness, and all surrounding wells are assigned to the proper position and I approve Ne scion and Prepared by: Checked by: Accepted by: i Approved by. is Bnl Potnis Nate Beck Enk Steric ;Tolman, Phelps , �`e`adnass-mad FrEdo Ver A..lyais pmt Rrocn Tnol1 Wind- Hap Cnh:IM1U65uttY Fret1- Oa6m:�%an:54H9TNsb Systen Lwal.yot1-- J '' ®Plan Pddm Plan: IH -118 flamatyAg119)/Plam1H-IIFAH-I18wpA o]1 Cr aJ �Leglnd 1 rte. y{ 5ttfon Yov Plan: 11-118,,,21(Plan.3H a 3 :3 f9 b� �� Q - 118 dp1merN 300.119UFIm.iH llBa _- $1H Ile Pn FY 4S a°r + 5C @1 4 4!.' K act 4 Dogleg iF eIH-0O11UGNtH1Hb13H_�- no a Irc nz nv Twss rs e2/ j (usR) Osn) (% (% (uffi1 (mh) (usry fusR) (°IINusR p1 9n TaRt -0f Pan IH 101 for MYIC3 3 3900 000 OC4' 39W 51.ry pp3 o.W OW OOO M. $p1 .1H 102 (fr 1y31) r- LT --- 'M { -..T- --j- E MISM. f6L00 OW 000 T)O.pO LOLW 111 2.2 pw OOOStre.(or 1y 311,.. � i 3 9W8 3V1.25; 501 BO.pp' 9CO.00 OJ).W 1.53' 8.61 2W e0 p00tE: dFpl .1H 110 (!cm ITlll, ... -' =- -� ._.J.._. 9 iS89 t6 �.tl-. H. 60 E5 155 8e 197)86 5509 959.51 $'A IS BO fIrE epl 'IH 111 lfm Iy10'3J ~ 5 Ifi%5] IOJ.93 2E� 6835 96660'6 15]J,85 Nl3 19].19 0M 1. Sae 1 6 1]9pW 13.13 3386 F619 17)681 1613.89 ]6]I 213,81 5'7) 3506 0!] iEPI .SH 112 (Imm Iy 10].. ] 1]e0W 7) 00 2386 fi6H 1]]513 mzl 7)96 SEp.21 OW ON.56a: $PI '.1H 12ff 11112,. 8 2911.59 I]SLN - 157) 3960]$ 3%].]3- SS911 8821] 95p '3." W! �PI '.1H31<(f IyWB 9 5659.85 2".51 NO6 %A 33157) 3@,A 119]], 3008,93 OW OW - - - API ,1H 1151! Iy 115. 10 fi33989 57)99 692 ISM aIW28 330),26 ]H36m 3133.91 350 MOON 1H 11901.T109218N11 �PI ,1H ss ' 11 698691 71707 6681 .'N 368161 3591.61 JScs6) 32)6.)9 ]50 IW 35 �1 Plan:1H31)Ilar 15118. 5 L 1 1 12 )]2053 La363 6607 3518) "17.093o. N... YM9A9 36R i6 3ER.10 OW 000 4PI 1H 119R Iy Ma 13 ]2293 8369. E6A O.IH 3J63N $JSW 37)9 ]B 3$7),90 Sin M96 IW� 119p1T3p'tla.. 19 Plan SH 1M 1!<1035,1 :mC, 19 83910] IC91.fi1'. 68.7)' 0.18 I. an tlN.N, 4$21.95 3E]909 OW 000 pF6 p-119 M.i9pip91fig1 '" TT -. 8PI 'SH IIl IP1p3C fcem[r. API n:1H-321(7)1033 fcrmer. MD 3vD ramyya Haas APIam1H123 (m9v ta�T h) ("sh) Nm (1 Cl ro TMfM TOs.s To paM �- EP" -IH 12a(A1031.mrmer, tlePo P E 30 92C ( ft) (.ft) 0¢h) ( fl) $PIen.1Hl]5 (2030 loaner. { 1?b Bi 1p 3/1 3 112 W 9/i ]J 13'C 1655.15 6H 9J 16331) PFROST Narc wr o m m f ,nc n3as tlx MIN T-3 9 63.GO T 8 12 M3.% 06 A 'Y ral &q21 R1}: 1& J 8 IIYC -11.14 in 1 3042 B _� l II Ne enne p a ons o u Paj $11092 EON 26 313136 NIS r i na" NU rr.e f s., ,„Iy,. µyd 3%306 VL C rudH }dl) S^'e/'TIT IWemde) SWaI'iml 69351) 3iJl iJ _ 3900 ..... '.INII&g21 ORT iWllgl3¢8294 G'RIGC 55 6A]Si 361033 0000 1100M 11+11 1188358291 MN/0 )19295 3]6955 3)6155 u+5 Po09 1JapW'1H11&g211}Ya: IH -018)398291 IAIWD-IFR axG625C ]319.19 3810.% 302%I, WSC usklft T ua[ Survey/Plan Pro m T 1 c0pp 32<0CC I1&12&g21(�,iH 1188 3 9 83 91 "MWD )371.2 .23981 WiF.61 :'A5� 3H-138 P211P1 1]1000 8254 O,1N118rg310111N-1181398291 h11VD-ILRAKCQSC ]960.15.3eb1 .9%126 �v;5_Ai 3H-ItB PIlIP1 TrevNln9 Cylndn'new 7)68.99 J900.6a EOp 69 W'SJ1J SH-118wPIl (11 ®... FTy ®Q '�:e '+w �' �. a0 ]TTJ W 3900,62 .3980 62 'NS A3 1H-I18w iPl 0121,93 11016E 1301@-P5 AI PIl .. -r.° ..-._ p-,.- �. ,r,.. _ 400.83 BASE 1H -118"M 4Pl to Plan ® Planned Welip - - - 100 0 _ - - 3J0 30 Y` •1 WOII PIe[C mpaur C. Users pM bplC Cr¢ Ce oPFiILp::hN... ^i .II �planVem-Pmrt 1H 118,,21 (Plan IH918tlenad,30+- a []^ A ! 30Virv- 18wpIl (PIe21Hd1H llermetl3 ./ P - a" 'I:]ra'- 1+Y�p._7 4Plan.tH1 -,�.-®�,.�... ®:1�®mid B:OHP QRS B.+:e Ib(Fk1n Y ® im�l�8ab�t�9h ti RSu_ Jpo sp = `l1 e0 I � 0 270 90� 2e0 - 120 50 1 �� `11 t 210 ' .'4' 150 ---- + oa lin Tinder Azimut TFO+AZIIBD o Is00 3900 .500 6000 ]So0 _ Travel g Cylinder ( ) [°] vs Centre 10 Centre Separation [usft] $'Ccmmpn Wdl Name UnM1&y-API-U55unn Faal Angles' IDeptFs: ush Meo: udt 12:17, June 02 2017 Easting (2000 usft/in) 1H-19AL2 1H-16AU PB1' j 1H-11 21 I iH-115wp21 1 H-108wp21 1 H-iYOwp21 �- 1H-15 Easting (2000 usftlin) 1H-125wp20 1 H-124wp20 1H-123wp20 1H-122wp20 _ g 1H-121wp20 1H-120wp21 1R-27 _�Ijy 3) 1R -29L1 R -29L1-01 1 H-20 -102L8wp 3fE-�1 B7 IR - R- y ggppL H-� QRP IH 1 H 4i H- 01 wp2 o H-19AL1 1 H-118wp w 10 5 1 HH199A it - 6A r H-119 p22 H-103wp2 Z1 -17_1 nc 1H-19AL2 1H-16AU PB1' j 1H-11 21 I iH-115wp21 1 H-108wp21 1 H-iYOwp21 �- 1H-15 Easting (2000 usftlin) 1 H-118wp21 Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 4800 7" x 8-1/2"----- 94 1-118wp21 8000 1H-118 04.74 090816 U 4000 11H-118 03.T3 090816 U 7000 3200 1H-118 01.T1 090816 U_ + 1 H-118 02.T2 090816 U L 1400-19000r 0 0 00 1600 90,00 800- 10-3/4" x 13-1/2" �O O° 20" x 42" 0 -1600 -800 CP 800 1600 2400 3200 4000 4800 West( -)/East(+) 0� 700 J 1400 CL a) 2100 2800-1 1 H-118wp21 20" x 42" 0° 1000 PFROST 10-3/4" x 13-1/2" T-3 p . K-15 COQ, 00 \ Mo 00 a ° o0 �o UG C Section View UG_B U G_A Na 0 0 , o 3500 --------- BASE ---- ----- o ---------------------- — ------------------ ____________________________ ____ ___________ _...___ _ _ ,� o ------------ ---------------------------------------- 4200 0 550 1100 16150 2200 2750 3300 3850 4410 Vertical Section at 0.000 ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1H Pad Plan: 1H-118 (formerly 30A, 119) - Slot IH -118 Plan: 11-1-118 Plan: 1 H-118wp21 Standard Proposal Report 02 June, 2017 Database: EDM Production Local Co-ordinate Reference: Company: ConomPhillips(Alaska) Inc.-Kup1 TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1H Pad North Reference: Well: Plan: lH-118 (formerly 30A, 119) Survey Calculation Method: Wellbore: Plan: 114-118 +E/ -W 0.00 usft Design: 1H-118wp21 Position Uncertainty Project Kuparuk River Unit, North Slope Alaska, United States System Datum SLB Standard Proposal Report Well Plan: 1H-118 (formerly 30A, 119) - Slot 1H-1 Plan: 54+39 r@ 93.00usft(Doyon 142) Plan: 54+39 Qa 93.00usft (Doyon 142) True Minimum Curvature Mean Sea Level Using Well Reference Point Using geodetic scale factor Site Site Position: From: Position Uncertainty: Kuparuk I Pad Map 0.00 usft Slot Radius: 0" Well Plan: 1 H-118 (formerly 30A, 119) - Slot 1 H-118 Measured Well Position +N/ -S 0.00 usft Vertical TVD +E/ -W 0.00 usft Dogleg Build Position Uncertainty 0.00 usft Depth Ground Level: 54.0].it Wellbore Plan: iH-118 System _ - -- - - Magnetics Model Name Sample Date Declination Dip Angle Field Strength Tool Face (usft) (9 V) Inn (usft) BGGM2016 7/11/2017 (usft) 17.57 80.97 57,543 Design 1H-118wp21 ("1100usft) - - Audit Notes: 0.00 0.00 39.00 Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 0.00 (usft) (usft) (usft) (°) 0.00 39.00 0.00 0.00 0.00 Plan Sections Measured Vertical TVD Dogleg Build Tum Depth Inclination Azimuth Depth System +N/ -S +E/ -W Rate Rate Rate Tool Face (usft) (') V) (usft) usft (usft) (usft) ('1100usft) ('1100usft) ("1100usft) 39.00 0.00 0.00 39.00 -54.00 0.00 0.00 0.00 0.00 0.00 0.00 700.00 0.00 0.00 700.00 607.00 0.00 0.00 0.00 0.00 0.00 0.00 900.25 5.01 80.00 900.00 807.00 1.52 8.61 2.50 2.50 0.00 80.00 1,588.66 22.08 68.25 1,566.86 1,473.86 55.09 159.51 2.50 2.48 -1.71 -15.00 1,696.57 22.08 68.25 1,668.86 1,573.86 70.13 197.19 0.00 0.00 0.00 0.00 1,740.00 23.86 66.14 1,706.84 1,613.84 76.71 212.81 4.50 4.08 -4.85 -25.86 1,760.00 23.86 66.14 1,725.13 1,632.13 79.98 220.21 0.00 0.00 0.00 0.00 2,911.54 74.06 46.79 2,460.72 2,367.72 588.37 882.43 4.50 4.36 -1.68 -23.91 5,659.85 74.06 46.79 3,215.70 3,122.70 2,397.71 2,808.43 0.00 0.00 0.00 0.00 6,239.84 69.20 26.00 3,400.28 3,307.28 2,836.89 3,133.91 3.50 -0.84 -3.58 -106.99 6,986.91 68.87 357.87 3,684.61 3,591.61 3,505.67 3,276.74 3.50 -0.31 -3.76 -100.35 7,120.53 66.87 357.87 3,737.09 3,644.09 3,628.46 3,272.18 0.00 0.00 0.00 0.00 7,202.42 68.79 0.18 3,768.00 3,675.00 3,704.28 3,270.90 3.50 2.34 2.81 48.48 8,294.07 68.79 0.18 4,163.00 4,070.00 4,721.95 3,274.04 0.00 0.00 0.00 0.00 62/2017 1104.'45AM Page 2 COMPASS 5000.1 Build 74 Database: EDM Production Company: ConomPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Plan: 1H-118 (formerly 30A, 119) Wellbore: Plan: 1H-118 Design: 1H-118wp21 SLB Standard Proposal Report Local Co-ordinate Reference: Well Pian: 1H-118 (formerly 30A, 119) - Slot 1 H-1 TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) MD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +NI -S +E/.W OLS Vert Section (usR) (°) (°) (nsft) usft (usft) (usR) -54.00 39.00 0.00 0.00 39.00 -54.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 7.00 0.00 0.00 0.00 0.00 118.00 0.00 0.00 118.00 25.00 0.00 0.00 0.00 0.00 20" x 42" 200.00 0.00 0.00 200.00 107.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 207.00 0.00 0.00 0.00 0.00 400.00 0.00 0.00 400,00 307.00 0.00 0.00 0.00 0.00 500.00 0.00 0.00 500.00 407.00 0.00 0.00 0.00 0.00 600.00 0.00 0.00 600.00 507.00 0.00 0.00 0.00 0.00 700.00 0.00 0.00 700.00 607.00 0.00 0.00 0.00 0.00 KOP: Start 2.6°1100' DLS, 80° TF, for 200.26' 800.00 2.50 80.00 799.97 706.97 0.38 2.15 2.50 0.38 900.00 5.00 80.00 899.75 806.75 1.51 8.59 2.50 1.51 900.25 5.01 80.00 900.00 807.00 1.52 8.61 2.50 1.52 Adjust TF to -16°, for 688.4' 1,000.00 7.44 75.01 999.15 906.15 3.95 19.14 2.50 3.95 1,100.00 9.91 72.48 1,098.00 1,005.00 8.21 33.61 2.50 8.21 1,200.00 12.40 70.95 1,196.10 1,103.10 14.31 51.97 2.50 14.31 1,300.00 14.89 69.93 1,293.27 1,200.27 22.22 74.18 2.50 22.22 1,400.00 17.38 69.19 1,389.33 1,298.33 31.93 100.21 2.50 31.93 1,500.00 19.87 68.64 1,484.08 1,391.08 43.43 130.00 2.50 43.43 1,588.66 22.08 68.25 1,566+86 1,473.86 55.09 159.51 2.50 55.09 Hold for 107.92' 1,600.00 22.08 6825 1,577.37 1,464.37 56.67 163.47 0.00 56.67 1,656.15 22.08 68.25 1,629.40 1,536.40 64.50 183.08 0.00 64.50 PFROST 1,696.57 22.08 68.25 1,666.86 1,573.86 70.13 197.19 0.00 70.13 Start 4.6°1100' DLS, -25.86' TF, for 43.43' 1,700.00 22.22 68.07 1,670.03 1,577.03 70.61 198.39 4.50 70.61 1,740.00 23.86 66.14 1,706.84 1,613.84 76.71 212.81 4.50 76.71 Hold for 20' -103/4" x 13-1/2" 1,760.00 23.86 66.14 1,725.13 1,632.13 79.98 220.21 0.00 79.98 Start 4.6°/100' DI -S, -23.91° TF, for 1151.64' 1,800.00 25.51 64.45 1,761.48 1,668.48 86.97 235.38 4.50 86.97 1,835.41 26.99 63.11 1,793.24 1,700.24 93.89 249.43 4.50 93.89 T3 1,900.00 29.72 60.99 1,850.07 1,757.07 108.29 276.50 4.50 108.29 2,000.00 33.99 58.33 1,934.99 1,841.99 135.00 322.00 4.50 135.00 2,100.00 38.32 56.21 2,015.72 1,922.72 166.94 371.58 4.50 166.94 2,110.92 38.79 56.00 2,024.26 1,931.26 170.73 377.23 4.50 170.73 K-16 2,200.00 42.67 54.45 2,091.75 1,998.75 203.90 424.94 4.50 203.90 2,300.00 47.05 52.97 2,162.62 2,069.62 245.66 481.76 4.50 245.66 2,400.00 51.44 51.68 2,227.89 2,134.89 291.97 541.68 4.50 291.97 2,500.00 55.85 50.54 2,287.16 2,194.16 342.54 604.33 4.50 342.54 61212017 11:04:45AM Page 3 COMPASS 5000.1 Build 74 SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan: 1 H-118 (formerly 30A, 119) - Slot 1H-1 Company: ConocoPhillips (Alaska) Inc. -Kupt TVD Reference: Plan: 54+39 @ 93.00us11 (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 54+39 (d1 93.00usft (Doyon 142) Site: Kuparuk 1H Pad North Reference: True Well: Plan: 1H-118 (formerly 30A, 119) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 11-1-118 TVDss +Nl-S Design: 1H-118wp21 Vert Sec0on (usft) Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +Nl-S +El -W DLS Vert Sec0on (usft) (I (I (usft) usft (usft) (usft) 2,247.06 2,600.00 60.26 49.51 2,340.06 2,247.06 397.05 669.33 4.50 397.05 2,700.00 64.68 48.58 2,386.26 2,293.26 455.17 736,28 4.50 455.17 2,800.00 69.11 47.70 2,425.49 2,332.49 516.54 804.76 4.50 516.54 2,900.00 73.54 46.88 2,457.50 2,364.50 580.79 874.35 4.50 580.79 2,911.54 74.06 46.79 2,460.72 2,367.72 588.37 882.43 4.50 588.37 Hold for 2748.31' 3,000.00 74.06 46.79 2,485.02 2,392.02 646.61 944.42 0.00 646.61 3,100.00 74.06 46.79 2,512.49 2,419.49 712.44 1,014.50 0.00 712.44 3,200.00 74.06 46.79 2,539.96 2,446.96 778.28 1,084.58 0.00 778.28 3,300.00 74.06 46.79 2,567.43 2,474.43 844.11 1,154.66 0.00 844.11 3,400.00 74.06 46.79 2,594.90 2,501.90 909.95 1,224.74 0.00 909.95 3,500.00 74.06 46.79 2,622.37 2,529.37 975.78 1,294.82 0.00 975.78 3,600.00 74.06 46.79 2,649.84 2,556.84 1,041.62 1,364.90 0.00 1,041.62 3,700.00 74.06 46.79 2,677.32 2,584.32 1,107.45 1,434.98 0.00 1,107.45 3,800.00 74.06 46.79 2,704.79 2,611.79 1,173.29 1,505.06 0.00 1,173.29 3,900.00 74.06 46.79 2,732.26 2,639.26 1,239.12 1,575.14 0.00 1,239.12 4,000.00 74.06 46.79 2,759.73 2,666.73 1,304.96 1,645.22 0.00 1,304.96 4,100.00 74.06 46.79 2,787.20 2,694.20 1,370.79 1,715.30 0.00 1,370.79 4,200.00 74.06 46.79 2,814.67 2,721.67 1,436.62 1,785.38 0.00 1,436.62 4,300.00 74.06 46.79 2,842.14 2,749.14 1,502.46 1,855.46 0.00 1,502.46 4,400.00 74.06 46.79 2,869.61 2,776.61 1,566.29 1,925.54 0.00 1,568.29 4,500.00 74.06 46.79 2,897.08 2,804.08 1,634.13 1,995.62 0.00 1,634.13 4,600.00 74.06 46.79 2,924.55 2,831.55 1,699.96 2,065.69 0.00 1,699.96 4,700.00 74.06 46.79 2,952.02 2,859.02 1,765.80 2,135.77 0.00 1,765.80 4,800.00 74.06 48.79 2,979.49 2,886.49 1,831.63 2,205.85 0.00 1,831.63 4,900.00 74.06 46.79 3,006.97 2,913.97 1,897.47 2,275.93 0.00 1,897.47 5,000.00 74.06 46.79 3,034.44 2,941.44 1,963.30 2,346.01 0.00 1,963.30 5,100.00 74.06 46.79 3,061.91 2,968.91 2,029.14 2,416.09 0.00 2,029.14 5,177.00 74.06 46.79 3,083.06 2,990.06 2,079.83 2,470.06 0.00 2,079.83 UG -C 5,200.00 74.06 46.79 3,089.38 2,996.38 2,094.97 2,486.17 0.00 2,094.97 5,300.00 74.06 46.79 3,116.85 3,023.85 2,160.81 2,556.25 0.00 2,160.81 5,400.00 74.06 46.79 3,144.32 3,051.32 2,226.64 2,626.33 0.00 2,226.64 5,500.00 74.06 46.79 3,171.79 3,078.79 2,292.48 2,696.41 0.00 2,292.48 5,600.00 74.06 46.79 3,199.26 3,106.26 2,358.31 2,766.49 0.00 2,358.31 5,659.85 74.06 46.79 3,215.70 3,122.70 2,397.71 2,808.43 0.00 2,397.71 Start 3.5°1100' DLS, -106.99° TF, for 579.99' 5,700.00 73.65 45.39 3,226.87 3,133.87 2,424.46 2,836.22 3.50 2,424.46 5,800.00 72.68 41.87 3,255.84 3,162.84 2,493.72 2,902.25 3.50 2,493.72 5,900.00 71.77 38.33 3,286.38 3,193.38 2,566.54 2,963.58 3.50 2,566.54 6,000.00 70.93 34.74 3,318.37 3,225.37 2,642.65 3,019.96 3.50 2,642.65 6,073.84 70.35 32.07 3,342.85 3,249.85 2,700.80 3,058.33 3.50 2,700.80 UG_B 6,100.00 70.16 31.12 3,351.69 3,256.69 2,721.77 3,071.23 3.50 2,721.77 6,200.00 69.46 27.46 3,386.22 3,293.22 2,803.60 3,117.14 3.50 2,803.60 622017 11:04:45AM Page 4 COMPASS 5000.1 Build 74 Database: EDM Production Company: ConomPhillips (Alaska) Inc. -Kup1 Project: Kupamk River Unit Site: Kuparuk 1H Pad Well: Plan: 11-1-118 (formerly 30A, 119) Wellbore: Plan: 1H-118 Design: 1H-118wp21 SLB Standard Proposal Report Local Co-ordinate Reference: Well Plan: 1 H-118 (formerly 30A, 119) - Slot IH -1 TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) MD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss -N/-S +E/ -W DLS Vert Section (usft) 0 (') (usft) usft (usft) (usft) 3,307.28 6,239.84 69.20 26.00 3,400.28 3,307.28 2,836.89 3,133.91 3.50 2,836.89 Adjust TF to -100.35°, for 747.07' 6,300.00 68.84 23.78 3,421.82 3,328.82 2,887.84 3,157.55 3.50 2,887.84 6,400.00 68.30 20.06 3,458.38 3,365.38 2,974.17 3,192.30 3.50 2,974.17 6,435.17 68.12 18.75 3,471.43 3,378.43 3,004.97 3,203.15 3.50 3,004.97 UG_A 6,500.00 67.84 16.32 3,495.74 3,402.74 3,062.28 3,221.26 3.50 3,062.28 6,600.00 67.47 12.56 3,533.78 3,440.78 3,151.82 3,244.32 3.50 3,151.82 6,700.00 67.18 8.78 3,572.34 3,479.34 3,242.48 3,261.41 3.50 3,242.48 6,797.54 66.99 5.08 3,610.32 3,517.32 3,331.64 3,272.24 3.50 3,331.64 Na 6,800.00 66.99 4.98 3,611.28 3,518.28 3,333.90 3,272.44 3.50 3,333.90 6,900.00 66.89 1.18 3,650.47 3,557.47 3,425.75 3,277.39 3.50 3,425.75 6,986.91 66.87 357.87 3,684.61 3,591.61 3,505.67 3,276.74 3.50 3,505.67 Hold for 133.62' 7,000.00 66.87 357.87 3,689.75 3,596.75 3,517.69 3,276.29 0.00 3,517.69 7,100.00 66.87 357.87 3,729.03 3,636.03 3,609.59 3,272.88 0.00 3,609.59 7,120.53 66.87 357.87 3,737.09 3,644.09 3,628.46 3,272.18 0.00 3,628.46 Start 3.5'/100' DLS, 41l TF, for 81.89' 7,192.95 68.56 359.91 3,764.55 3,671.55 3,695.45 3,270.89 3.50 3,695.45 WS_D 7,200.00 68.73 0.11 3,767.12 3,674.12 3,702.02 3,270.89 3.50 3,702.02 7,202.42 68.79 0.18 3,768.00 3,675.00 3,704.28 3,270.90 3.50 3,704.28 Hold for 1091.64' 7,300.00 68.79 0.18 3,803.31 3,710.31 3,795.24 3;271.18 0.00 3,795.24 7,319.49 68.79 0.18 3,810.36 3,717.36 3,813.41 3,271.24 0.00 3,613.41 WS_C 7,373.25 68.79 0.18 3,829.81 3,736.81 3,863.52 3,271.39 0.00 3,863.52 WS_e 7,400.00 68.79 0.18 3,839.49 3,746.49 3,888.46 3,271.47 0.00 3,888.46 7,460.15 68.79 0.18 3,861.26 3,768.26 3,944.54 3,271.64 0.00 3,944.54 INS -A4 7,500.00 68.79 0.18 3,875.68 3,782.68 3,981.69 3,271.76 0.00 3,981.69 7,568.99 68.79 0.18 3,900.64 3,807.64 4,046.00 3,271.95 0.00 4,046.00 WS -A3 7,600.00 68.79 0.18 3,911.86 3,818.86 4,074.91 3,272.04 0.00 4,074.91 7,700.00 68.79 0.18 3,948.04 3,855.04 4,168.14 3,272.33 0.00 4,168.14 7,790.04 68.79 0.18 3,980.62 3,887.62 4,252.08 3,272.59 0.00 4,252.08 WS -A2 7,800.00 68.79 0.18 3,984.23 3,891.23 4,261.36 3,272.62 0.00 4,261.36 7,900.00 68.79 0.18 4,020.41 3,927.41 4,354.58 3,272.91 0.00 4,354.58 8,000.00 68.79 0.18 4,056.59 3,963.59 4,447.81 3,273.19 0.00 4,447.81 8,100.00 68.79 0.18 4,092.78 3,999.78 4,541.03 3,273.48 0.00 4,541.03 8,124.43 68.79 0.18 4,101.62 4,008.62 4,563.81 3,273.55 0.00 4,563.81 WS -Al 8,200.00 68.79 0.18 4,128.96 4,035.96 4,634.25 3,273.77 0.00 4,634.25 62,2017 11:04:45AM Page 5 COMPASS 5000.1 Build 74 Database: EDM Production Company: ConocoPhillips (Alaska) Inc. -Kupi Project: Kuparuk River Unit Site: Kupawk 1 H Pad Well: Plan: 1 H-118 (formerly 30A, 119) Wellbore: Plan: 1H-118 Design: 1H-118wp21 SLB Standard Proposal Report Local Co-ordinate Reference: Well Plan: 1H-118 (formerly 30A, 119) -Slot 1H-1 TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) MD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey 3,133.91 Target Name Measured Vertical -Shape M (') (usft) (usft. (usft) Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W OLS Vert Section (usft) (1) (1 (usft) usft (usft) (waft) 4,070.00 8,294.07 68.79 0.18 4,163.00 4,070.00 4,721.95 3,274.04 0.00 4,721.95 TD: 8294.07' MD, 4163' TVD 3,270.90 - plan hits target center Targets 3,133.91 Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/.S +E/ -W -Shape M (') (usft) (usft. (usft) 1 W119 D 01 Octl4 RW 0.00 0.00 3,769.50 3,593.36 3,661.45 - plan misses target center by 390.82usft at 7087.73usft MD (3724.21 TVD, 3598.32 N, 3273.30 E) - Circle (radius 100.00) 3,661.45 1H -30A MW d 27Jan14 0.00 0.00 3,779.00 3,461.35 3,660.58 - plan misses target center by 397.55usft at 6980.34usft MD (3682.02 TVD, 3499.62 N, 3276.95 E) - Point 3,427.12 1 H-119 03.T3 090816 KU 0.00 0.00 3,768.00 3,704.28 3,270.90 - plan hits target center - Circle (radius 100.00) 3,663.17 1H-11901. D 052115 RW 0.00 0.00 3,769.16 3,586.90 3,426.38 - plan misses target center by 159.94usft at 7089.68usft MD (3724.97 TVD, 3600.11 N, 3273.23 E) - Circle (radius 100.00) 1H-119 02. T2 090816 KU 0.00 0.00 3,423.00 2,872.53 3.168.55 - plan misses target center by 16.89usft at 6291.77usft MD (3418.86 TVD, 2880.83 N, 3154.44 E) - Circle (radius 100.00) 1 HA 19 A3072914 DL 0.00 0.00 3,913.00 3,855.38 3,663.17 - plan misses target center by 399.90usft at 7396.88usft MD (3838.36 TVD, 3885.56 N, 3271.46 E) - Circle (radius 100.00) 1H -30A MW a327Jan14 0.00 0.00 3,923.00 3,605.36 3,661.53 - plan misses target center by 430.16usft at 7162.75usft MD (3753.35 TVD, 3667.41 N, 3271.14 E) - Point 1H-11901.71090816 KU 0.00 0.00 3,400.28 2,836.89 3,133.91 - plan hits target center - Circle (radius 100.00) 1H-11904.74090816 KU 0.00 0.00 4,163.00 4,721.95 3,274.04 - plan hits target center - Circle (radius 100.00) 11-1-119 D 072914 DL 0.00 0.00 3,779.00 3,593.36 3,661.45 - plan misses target center by 392.01usft at 7091.46usft MD (3725.67 TVD, 3601.75 N, 3273.17 E) - Circle (radius 100.00) 1H -11901.D 081215 RW 0.00 0.00 3,769.16 3,699.91 3,427.12 - plan misses target center by 156.25usft at 7198.81 usft MD (3766.69 TVD, 3700.91 N, 3270.89 E) - Circle (radius 100.00) 1H-119 A201 Oct14 RW 0.00 0.00 3,984.00 3,855.38 3,663.17 - plan misses target center by 418.21 usft at 7422.57usft MD (3847.66 TVD, 3909.51 N. 3271.53 E) - Circle (radius 100.00) 6/212017 11:04:45AM Page 6 COMPASS $000.1 Build 74 Database: EDM Production Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Plan: 1 H-118 (formerly 30A, 119) Wellbore: Plan: 1H-118 Design: 1H-118wp21 Casing Points Vertical Vertical Local Coordinates Measured Vertical +N/ -S Depth Depth (usft) (usft) (usft) UG_B 118.00 118.00 20"x42" 1,740.00 1,706.84 10-3/4" x 13-1/2" 8,294.07 4,163.00 7"x8-1/2" Formations Measured Vertical Vertical Local Coordinates Depth Depth Depth SS +N/ -S (usft) (usft) (usft) 6,073.84 3,342.85 UG_B 7,460.15 3,861.26 WS A4 6,435.17 3,471.43 UG_A 7,373.25 3,829.81 WS B 2,110.92 2,024.26 K-15 7,790.04 3,980.62 W$_A2 5,177.00 3,083.06 UG—C 7,319.49 3,810.36 WS C 7,568.99 3,900.64 WS A3 6,797.54 3,610.32 Na 7,192.95 3,764.55 WS_D 8,124.43 4,101.62 WS Al 1,835.41 1,793.24 T-3 1,656.15 1,629.40 PFROST Plan Annotations SLB Standard Proposal Report Local Co-ordinate Reference: Well Plan: 1 H-118 (formerly 30A, 119) - Slot 1 H-1 TVD Reference: Plan: 54+39 Q 93.00usft (Doyon 142) MD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) 700.00 700.00 0.00 0.00 900.25 900.00 1.52 8.61 1,588.66 1,566.86 55.09 159.51 1,696.57 1,666.86 70.13 197.19 1,740.00 1,706.84 76.71 212.81 1,760.00 1,725.13 79.98 220.21 2,911.54 2,460.72 588.37 882.43 5,659.85 3,215.70 2,397.71 2,808.43 6,239.84 3,400.28 2,836.89 3,133.91 6,986.91 3,684.61 3,505.67 3,276.74 7,120.53 3,737.09 3,628.46 3,272.18 7,202.42 3,768.00 3,704.28 3,270.90 8,294.07 4,163.00 4,721.95 3,274.04 Casing Hole Diameter Diameter Name 20 42 10-314 13-112 7 B-112 Dip Dip Direction Name Lithology (1) (1) Comment KOP: Start 2.5'/100' DLS, 80° TF, for 200.25' Adjust TF to -15', for 688.4' Hold for 107.92' Start 4.5'/100' DLS, -25.86" TF, for 43.43' Hold for 20' Start 4.5°/100' DLS, -23.91" TF, for 1151.54' Hold for 2748.31' Start 3.5°/100' OILS, -106.99° TF, for 579.99' Adjust TF to -100.35°, for 747.07' Hold for 133.62' Start 3.5°/100' DI -S, 48.48° TF, for 81.89' Hold for 1091.64' TD: 8294.07' MD, 4163' TVD 622017 11:04:45AM Page 7 COMPASS 5000.1 Build 74 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 1H-118 (formerly 30A, 119) Plan: 11-1-118 1 H-118wp21 Clearance Summary Anticollision Report 02 June, 2017 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuporuk 1H Pad - Plan: 1 H-1 18 (formerly 30A,119) -Plan: 1H-118-1H-118wp21 Datum Height: Plan: 54+39 @ 93.00usft (Doyon 142) Scan Range: 0.00 to 8,294.07 usft. Measured Depth. Scan Radius is 1,025.51 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED'. All wellpaths within 2004100/1000 of reference Scan Type: 25.00 ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for Plan: 11-1-118 (formerly 3OA, 119)-1H-118wp21 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kupamk 1H Pad -Plan: 1H-118 (formerly 30A, 119) -Plan: IH -118- 1H-118wp21 Scan Range: 0.00 to 8,294.07 usfL Measured Depth. Scan Radius is 1,026.51 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Site Name Comparison Well Name - Wellbore Name - Design Measured Depth (usft) Minimum Distance (usft) @Measured Depth (usft) Ellipse Separation (usft) @Measured Depth usft Clearance Factor Summary Based on Minimum Separation Warning Kuparuk 1H Pad 1H-401(UGNU)-11-1-401-1H-401 1H-401(UGNU) - 1 H401 - 1 H401 Plan : 1 H-1 01 (formerly 103, 29) -Plan: 1H -101-1H-10 Plan: 1 H-1 01 (formerly 103, 29) -Plan: 1H -101-1H-10 Plan: 1 H-1 02 (formerly 31) -Plan: 1H-1021-3-iH-102L Plan : IH -102 (formerly 31) -Plan: 1H -10213 -1H -102L 1,821.00 1,839.91 200.00 275.00 300.00 375.00 161.93 162.11 479.89 480.49 419.82 420.38 1,821.00 1,839.91 200.00 275.00 300.00 375.00 117.37 115.87 476.30 475.68 414.48 413.83 2,125.00 2,150.00 200.00 275.00 300.00 375.00 3.634 3.506 133.472 99.963 78.580 64.178 Centre Distance Clearance Factor Centre Distance Clearance Factor Centre Distance Clearance Factor Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Plan: I H-1 02 (formerly 31) -Plan: 1H-10214-iH-102L Plan: 1H-102(formerly 31) -Plan: IH -10214 -1H -102L Plan: 11-1-110 (formerly 111, 113,34D) -Plan 1H-110- Plan* 1H-110(formerly 111, 113, 34D) -Plan: 1H-110- Plan: 1H-111 (formerly 109, 32D) - Plan: 1H-111 - IH -1 Plan: 1H-111 (formerly 109, 32D) - Plan: iH-111 - 1 H-1 300.00 375.00 375.00 499.98 400.00 574.96 419.82 420.38 239.67 240.65 209.75 211.04 300.00 375.00 375.00 499.98 400.00 574.96 414.48 413.83 233.02 232.04 202.66 201.11 300.00 375.00 375.00 500.00 400.00 575.00 78.580 64.178 36.025 27.953 29.584 21.257 Centre Distance Clearance Factor Centre Distance Clearance Factor Centre Distance Clearance Factor Pass - Major Risk Pass - Major Risk Pass- Major Risk Pass - Major Risk Pass - Major Risk Pass- Major Risk Plan: 1 H-112 (formerly 107, 28D, 106) - Plan: 1H-112 - Plan: 1H-112 (formerly 107, 28D, 106) - Plan: 1 H-112 - Plan: IH -113 (formerly 112, 34B) -Plan: 1H -113-1H-1 Plan: 1H-113(formerly 112, 34B) -Plan: 1H-113-iH-1 Plan: 1 H-114 (formerly 30B,116) -Plan: 1H -114-1H-1 Plan: 1H-114 (formerly 30B, 116) IH -114-1H-1 700.00 774.34 375.00 474.99 449.90 599.87 179.63 179.65 149.63 150.29 119.68 120.73 700.00 774.34 375.00 474.99 449.90 599.87 167.30 166.40 142.98 142.07 111.72 110.39 700.00 775.00 375.00 475.00 450.00 600.00 14.567 13.367 22.491 18.290 15.031 11.668 Centre Distance Clearance Factor Centre Distance Clearance Factor Centre Distance Clearance Factor Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Plan :1H-115(formerly 115, 34A, 114)- Plan: 11-1-115- Plan: 1H-115(formerly 115, 34A, 114) -Plan : 1H-115- Plan : 11-1-116 (formerly 114, 32B, 115) - Plan: 1H-116 - Plan: 1H-116 (formerly 114, 32B, 115) - Plan* 1H-116 - Plan: IH -117 (formerly 118, 28B) -Plan: 1H -117-1H-1 Plan: I H-11 7 (formerly 118, 28B) -Plan: 1H -117-1H-1 299.90 474.84 399.90 624.80 700.00 849.59 89.78 91.15 59.80 61.37 29.55 30.47 299.90 474.84 399.90 624.80 700.00 849.59 84.44 82.95 52.71 50.60 17.22 15.90 300.00 475.00 400.00 625.00 700.00 850.00 16.810 11.119 8.436 5.700 2.396 2.092 Centre Distance Clearance Factor Centre Distance Clearance Factor Centre Distance Clearance Factor Pass - Major Risk Pass - Major Risk Pass- Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Plan: 1 H-119 (formerly 28A, 120) - Plan: 1H-119 - 1 H-1 Plan: 1 H-119 (formerly 28A, 120) - Plan: 1 H-119 - 1 H-1 Plan: 1H -120(A1035, formerly 117) -Plan: 1H -120-1H Plan: 1H-120(At 035, formerly 117) -Plan: 1H-120-iH 699.80 824.96 649.71 774.90 30.30 31.16 59.62 60.75 699.80 824.96 649.71 774.90 17.97 16.98 48.31 47.47 700.00 825.00 650.00 775.00 2.458 2.197 5.274 4.574 Centre Distance Clearance Factor Centre Distance Clearance Factor Pass- Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk 02 June, 2017 - 11:06 Page 2 of 5 COMPASS ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for Plan: 1H-118 (formerly 3OA, 119) -1 H-118wp21 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 1H Pad -PIan:1H-118(formerly 30A, 119) -Plan: 1H-118-iH-118wp21 Scan Range: 0.00 to 6,294.07 usft. Measured Depth. Scan Radius is 1,026.51 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Ellipse error terms are correlated across survey tool fie -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. 02 June, 2017 - 11:06 Page 3 of 5 COMPASS Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft Plan :1H-121(At 034, formerly 119) -Plan: 1H -121-1H 574.87 90.20 574.87 80.16 575.00 8.991 Centre Distance Pass - Major Risk Plan : 1H-121(At 034, formerly 119) -Plan: 1H -121-1H 699.43 91.13 699.43 78.98 700.00 7.498 Clearance Factor Pass - Major Risk Plan; iH-122(At 033, formerly At 040) -Plan: 1H-122 350.00 120.41 350.00 114.08 350.00 19.035 Centre Distance Pass - Major Risk Plan: 1H-122(At 033, formerly Al 040) -Plan: 1H-122 3,111.72 158.63 3,111.72 93.52 2,925.00 2.437 Clearance Factor Pass - Major Risk Plan, 1H-123(At 032, formerly A1033) -Plan: 1H-123 300.00 150.41 300.00 144.96 300.00 27.589 Centre Distance Pass - Major Risk Plan: 1H-123(At 032, formerly Al 033) -Plan: 1H-123 3,181.19 197.12 3,181.19 127.56 2,925.00 2.834 Clearance Factor Pass - Major Risk Plan, 1H -124(A1031, formerly A1036)-PIan: 1H-124 300.00 180.42 300.00 174.96 300.00 33.092 Centre Distance Pass - Major Risk Plan: 1H -124(A1031, formerly A1036) -Plan: 1H-124 499.91 181.94 499.91 173.11 500.00 20.608 Clearance Factor Pass - Major Risk Plan: 1H-125(At 030, formerly At 039) -Plan: IH -125 250.00 210.42 250.00 205.84 250.00 45.959 Centre Distance Pass - Major Risk Plan :1H-125(At 030, formerly At 039) -Plan: 1H-125 399.97 211.56 399.97 204.43 400.00 29.673 Clearance Factor Pass - Major Risk Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 39.00 700.00 1H-118wp21 GYD-GC-SS 700.00 1,700.00 1 H-118wp21 MWD 700.00 1,740.00 1 H-118wp21 MWD+IFR-AK-CAZ-SC 1,740.00 3,240.00 1H-118wp21 MWD 1,740.00 8,294.07 1H-118wp21 MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool fie -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. 02 June, 2017 - 11:06 Page 3 of 5 COMPASS Ladder View 1 H-118wp21 The Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. 300-- A 11111111117—__ C O I, EU N Co N 150 U 0 I d U ®EQwvdam May�rc 0 0 0 1500 3000 4500 6000 7500 Displayed interval could be less than entire well:Measured Depth 39.00 To 8294.07 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.00 700.00 1 H-118wp21 (Plan: 11-1-118) GYD-GC-SS 118.00 118.00 20" x 42" 700.00 1700.00 1H-118wp21 (Plan: 11-1-118) MWD 1706.84 1740.00 10-3/4"x13-1/2" 700.00 1740.00 1H-118wp21 (Plan: 1H-118) MWD+IFR-AK-CAZ-SC 4163.00 8294.07 7"x8-1/2" 1740.00 3240.00 1H-118wp21 (Plan: 11-1-118) MWD 1740.00 8294.07 1H-118wp21 (Plan: 1H-118) MWD+IFR-AK-CAZ-SC 3 i i ss a O m _ n , v 30 .... __-_. _ _...... --_-. _. .— I � eymveiam n+,yn.c 0.:mice ;14 C U 0 0 500 1000 1500 2000 2500 3000 3500 Partial Measured Depth 1H-118wp21 ND Inc Azi TO Dle9 TFace Tai yet 39.00 0.00 0.00 39.00 6.00 0.00 39.00 To 8294.07 700.00 0.00 0.00 700.00 0.00 0.00 900.25 5.01 80.00 900.00 2.50 80.00 1588.66 1696.57 22.08 22.08 68.25 68.25 1566.86 1666.86 2.50 0.00 -15.00 0.00 11:16, Jun® 02 2017 1740.00 1760.00 23.86 23.86 66.14 66.14 1706.84 1725.13 4.50 0.00 -25.86 0.00 CASING DETAILS 2911.54 5659.85 74.06 74.06 46.79 46.79 2460.72 3215.70 4.50 0.00 -23.91 0.00 TVDND Name 118.00 118.00 20" x 42- 6239.84 69.20 26.00 3400.28 3.50 -106.99 1H-119 01.T1 090816 KU 1766.84 1740.00 10-314^ x 13-112- 6986.91 66.87 357.87 3684.61 3.50 -100.35 4163.00 8294.07 7- x 6-112• 7120.53 66.87 357.87 3737.09 0.00 0.00 7202.42 68.79 0.18 3768.00 3.50 48.48 1H-119 03.T3 090816 KU 8294.07 68.79 0.18 4163.00 0.00 0.00 IH -119 04.T4 090816 KU IH -401 -90 H-401 -90 12 1 H-125wp20 1H-124wp20 700 - 890 890 - 1070 1070 - 1260 1260 - 1440 1440 - 1630 1630 - 1810 1810 i 2000 2000 - 2260 2260 2530 2530 - 2790 2790 - 3050 3050 3310 3310 - 3570 3570 3840 3840 - 4100 4100 - 4620 5150 5670 6200 6720 7240 7770 8294 - -1801180 1 H.112wp21 1 H-117wp22 1 H-111 wp21 1 H-113wp27 H-122wp20 H-12lwp20 120wp21 1 11:17, June 02 2017 Kuparuk 1 Easting (2000 usft/in) Easting (2000 usftlin) ,p20 1 H-120wp21 AC Flipbook Casing Details 1 H _118 W P 21 n YYN urvey Program 39 700 ID MD Name 78.00 48.00 o^ x qr pgo.00 o-3lq"xg-ilx" Depth from oevxn To 100 39.00 ]norm an IH vB) 6YbGC-55 4163-nq 963.40 8x990) ]"x8-ih" Joo.00 1740.00 an IF 7118w, MWD 39.00 TO 500.00 ]00.00 179000 an Ma�B) m,g) 179n oo 3x94.07 an, IH nB) Bx990) am M-118) MWDHiP AK CH2dC700090 MWD MWDNLR HK-CHLSC J090.00 890 1070 M D Azi 0/360 1070 1260 39.00 0.00 90 700.00 0.00 -30/33 0 1260 1440 900.25 80.00 80 1440 1630 1588.66 68.25 1630-1810 1696.57 68.25 1F-170"INp21 1740.00 66.14 - - 1810 2000 1760.00 66.14 -6o/300 50 60 2000 2260 2911.54 46.79 - 5659.85 46.79 41.119WP22 2260 2530 6239.84 26.00 - 2530 2790 6986.91 357.87 zo 2790 3050 7120.53 357.87 10 7202.42 0.18 -90/270 90 3050 3310 8294.07 0.18 1 3310 3570 20 3570 ---. __ 3840 lfaf:w1''WP22 3840 ._ __ 4100 -u 4100 4620 -120/240 50 120 4620 5150 - IH-115)WP21 5150 5670 5670 6200 go 6200 -6720 -150/210 150 1HW115'Wp21 6720 7240 02 2017 7240 7770 7770 8294 11:58, June Cams Dr+au: 1H_�18VV„�� n VYYP survey Program 39 700 ND MD Name a... „s o.In" x4r• +Io6B4 +790.00 +0314"x+3 -+I2" Depth From Depth To su eylPlan o0 3900 700.00 +Hwawpz+(Plan:+H n8) CYD-0C-SS 4163 o0 8x94.W 7"x8 -1I1" 7...00 1700.00 IS uawpz,(PlannHa,B) MWD 5oo.00 To woo.00 7`0 00174D.00 »90.00 M-nBWP21(PlannH-n8) 329000 +HnawPz+(PlannS118) MWD+IFR AK mVSC MWD 700 890 1740.00 8x94..7 1--118wpx,(PlannH-118) MWD�IFR-AR{A23C 8go 1070 MD Azi 0�;0 1070 126o 39.00 0.00 1260 700.00 0.00 -30/33 0 ,440 900.25 80.00 8o�\. 1440 1630 1588.66 68.25 �a�%� 1630-1810 1696.57 68.25 l0 1810 2000 1740.00 66.14 _` 21 176o.00 66.14 -6o/300 '6o 2000 2260 2911.54 46.79 1.1t9`W 2 5659.85 46.79 226o 2530 6239.84 26.00 30 0 2530 2790 6986.91 357.87 0 2790 3050 7120.53 357.87 10 7202.42 0.18 -90/27 0 90 3050 3310 8294.07 o.18 1 3310 3570 3570 3840 nj li 3840 4100 ,p , ( 4100 4620 -120/240 0 120 4620 5150 Jho : 5150 5670 + -70 21 5670 6200 -150 / 210 80 150 6200 6720 cry _ ------ - 6720 7240 o2 2017 -18o/18o 7240 7770 7770 8294 11.59, June MD Azi 700 Casing Details _ 890 700.00 0.00 1070 900.25 80.00 1260 1588.66 68.25 1440 1696.57 68.25 Survey Program 1H_il8WP21 ND „s pp MD a.00 TP xo••. qz^ Depen From Depth 7D 1 �J YY �,/ +]06.89 040.00 10 3/4'. 00 IH 118WP21 ]oOAo (Plan: H�+ffi) 7120.53 357.87 q+63oo Bx94.oy ]•xe-+Ix" on ]oo-oo poo.00 +H-»8wpx+(Plan: it 118) 3840- -- 4100 4100 4620 Joo.00 +Hm Bwpv (PIart,H-n8) 1000 Oo TO 2000 00 5670 5670 6200 ggo.po ;70oo 3x90."-7 ,H-»Bwpx+(Plan:+H-n8) • • 7240 7240 7770 ,79o.00 8x99.0] +H-n8wpx+(Pla,nH-nB) MD Azi 700 39.00 0.00 _ 890 700.00 0.00 1070 900.25 80.00 1260 1588.66 68.25 1440 1696.57 68.25 1630 1740.00 66.14 1810 1760.00 66.14 -60 2911.54 46.79 2260 5659.85 46.79 2530 6239.84 26.00 2790 6986.91 357.87 3050 7120.53 357.87 3310 7202.42 0.18 -90 / 270 8294.07 0.18 ___ 3840 -120/ 1159, .lune 02 2017 o /X60 Tool GYD GC SS MWD MWD.IFR AK CA SC M\VD MW D.IFR-AK CI -SC -18o/18o 39 700 700_ _ 890 8go 1070 1070 1260 1260 1440 1440 1630 1630 1810 1810 2000 2000 2260 z26o 2530 2530 2790 2790 3050 3050 _ 3310 3310 3570 3570 - ___ 3840 3840- -- 4100 4100 4620 4620 5150 5150 5670 5670 6200 6200 6720 6720 7240 7240 7770 7770 8294 1H-118wp21 z000.00 To 3000.00 MD Azi 700 39.00 0.00 Np 700.00 0.00 Depth from 900.25 80.00 7p69 4166.84 1588.66 68.25 3406 1696.57 68.25 8294,67 174o.00 66.14 1H-118) t]oo.00 1H 118Wpv(Plana&n8) 176o.00 66.14 -6o 2911.54 46.79 3310 5659.85 46.79 D4o.po 6239.84 26.00 4100 6986.91 357.87 &94-o2 IH 118WP21(Plann&118) 7120.53 357.87 5670 7202.42 0.18 -90 / 270 8294.07 o.18 7240 -120/ 12:01, June 02 2017 0/36o Tool GYD-CC-SS MWD MW D.IFR AK CAZ SC MWD MWD.IPR AK CA2-SC -180/180 39 Ca9ng Detaas 700 _ 890 Survey Program Np MD ame Depth from Depth To Su :IPII to 4.,ao xo"x qx" 7p69 4166.84 040.op m -314"x 3406 118woan Joo.00 m-n8wpr(Plan 4i63�oo 8294,67 81)6" J°x8 111" 7retrtt 1H-118) t]oo.00 1H 118Wpv(Plana&n8) 2790 2790 3050 760 00 pq p.o6 tll-n Bwpx1(Plann&n8) 3310 3570 3570 -- D4o.po 3290.00 H 118Wpxf(Plan: 1H S) 4100 4100 4620 174e.60 &94-o2 IH 118WP21(Plann&118) 0/36o Tool GYD-CC-SS MWD MW D.IFR AK CAZ SC MWD MWD.IPR AK CA2-SC -180/180 39 700 700 _ 890 890 1070 1070 r26o 1260 1440 1440 1630 1630 1810 1810 2000 2000 226o 226o 2530 2530 2790 2790 3050 3050 - 3310 3310 3570 3570 -- 3840 3840 - 4100 4100 4620 4620 5150 5150 5670 5670 6200 6200 6720 6720 7240 7240 7770 7770 8294 iH-ii8wp21 3000.00 To 5000.00 MD Azi 700 39.00 0.00 Np 700.00 0.00 Depth 900.25 80.00 7.684pgo.po 1588.66 68.25 9,00 3400 1696.57 68.25 8x94.0] 1740.00 66.14 1740.00 Hq�Bwpzl(Plan: IN118) 176o.00 66.14 -6o) 2911.54 46.79 3310 5659.85 46.79 +]40.04 6239.84 26.00 4100 6986.91 357.87 8194.o7 iH-n8wpm (Plana: IH 118) 7120.53 357.87 5670 7202.42 0.18 -90 / 270 8294.07 o.18 7240 -120/ 12:02, June 02 2017 01360 Tool GYD GC SS MWD MWD.IFR AN CAZ.SC MWD MWDNFR AK CIbSC -18o/180 39 Casing DPcails 700 890 Saway Program Np MD me Depth Depmrn aO ns.00 41.00 zo^xgra 7.684pgo.po 1630 io-317r 8�lx" 9,00 3400 IN118j 700.00 i&vBwpn(Plan: M -n8) 963.4. 8x94.0] ]°x8lix" 70o.00 1740.00 Hq�Bwpzl(Plan: IN118) 2790 2790 3050 ]00.44 1740.00 m -u8wpn (Plan: IN118) 3310 3570 3570---- +]40.04 3x9.,07 tHniewpa(Plan : Mg18) _ _ 4100 4100 4620 pgo..o 8194.o7 iH-n8wpm (Plana: IH 118) 01360 Tool GYD GC SS MWD MWD.IFR AN CAZ.SC MWD MWDNFR AK CIbSC -18o/180 39 700 700 890 890 1070 1070 1260 1260 1440 1440 1630 1630 1810 1810 2000 2000 2260 226o 2530 2530 2790 2790 3050 3050 3310 3310 3570 3570---- _. 3840 3840 -- _ _ 4100 4100 4620 4620 5150 5150 5670 5670 6200 6200 6720 6720 7240 7240 7770 7770 8294 Casing Details 1H-118WP21 sti Program 39 700 TCD MD ueme 1800 11a.,5,5 "x 13ne^ 990.00 log;9"x8V2" Depm6om Depth 7o InnZ,",n Ti Ioo.4p +H-u8wpzl(Plan: 'DS)GYP a 41,5689 gf63 oo 8294,0) "281/x" ]00.00 ea,ea 17,5,5.00 InIPPCI 1H 119) epast, MWD 5000.00 To 8294.07 ]Opo 1740. an 1790.00 1H-»8wpx1(Plan: IN 118) 3294.00 M-n8wpxl(PlannX-n8) MWDr1f0. AK{q$SC MWD 700 --- Bgo 990.04 8299-p7 IN n Bwpv (PIan:1H-fit) MWDrIFR AK CAZdC 8go 1070 MD Azi 0/36o 1070 1z6o 39.00 0.00 180 700.00 0.00 -30/33 0 126,5 1440 900.25 80.00 160 0 1440 1630 1588.66 68.25 140 1630 18lo 1696.57 68.25 1740.00 66.14 120 1810 2000 176o.00 66.14-6o/300 100 60 z000 226,5 2911.54 46.79 8o 5659.85 46.79 226o 2530 60 6239.84 26.00 2530 2790 6986.91 357.87 rr 40 2790 3050 7120.53 357.87 zo __ 7202.42 0.18 -90/270 go 3°5° 3310 8294.07 0.18 2 3310 357° 3570 --- 3840 6o 3840 -- -- 4100 So 4100 4620 -120/240 100 120 4620 5150 120 5150 5670 1 0 5670 62oo -150/210 160 150 6200 - 6720 18o 6720 7240 -18o / 180 7240 7770 7770 8294 12:02, lune 02 2017 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 1 H-118 (formerly 30A, 119) Plan: IH -118 Plan: 1 H-118wp21 Error Ellipse Survey Report 02 June, 2017 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: Plan: 1 H-118 (formerly 30A, 119) Wellbore: Plan: 11-1-118 Design: 1H-118wp21 SLB Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 1 H-118 (formerly 30A, 119) - Slot 1H-118 Plan: 54+39 @ 93.00usft (Doyon 142) Plan: 54+39 ® 93.00usft(Doyon 142) True Minimum Curvature 1.00 sigma EDM Production Survey Tool Program Date 6/2/2017 Aalmulh Veniwl From To Vesical (usft) (usft) Survey (Wellbore) Tool Name Descriptlon 39.00 700.00 1 H-118wp21 (Plan: 11-1-118) GYD-GC-SS Gymdata gyro single shots 700.00 1,700.001H-118wp21(Plan: 1H-118) MWD MWD - Standard 700.00 1,740.001H-118wp21(Plan: 111-118) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 1,740.00 3,240.00 1H-118wp21 (Plan: 1H-118) MWD MWD -Standard 1,740.00 8,294.07 1H-118wp21 (Plan: 1H-118) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC Position uncertainty and bias at survey station Measured 1.1hofbn Aalmulh Veniwl Hi9hslee lepnl Vesical Ma9nputle Semi+najar semimiaor Dorm UepM Error Bias E., Bks Error Bias IXBias Error E., AzimNh Tool loss) IN (1) lues) lush) (oan) loan) lush) loan) (.G) lush) lose) (usft) (1) 39.00 000 OOo 3900 0.00 000 0.00 000 0.00 000 000 0.00 0.00 0.00 UNDEFINED 118.00 000 0.00 11800 0.19 coo 0.19 0.00 1.15 000 000 0.19 0.19 000 GYD- GC -SS N 1) 700.00 0.00 0.00 700.00 091 000 0.91 000 1.16 0.05 0.05 091 0.91 0.00 GYD-GC-SS(1, 1) 900.25 501 sew 900.00 1.00 -0.01 1.01 0.00 1.16 0.09 0.09 t01 1.00 91.47 MM (1, 2) 1.58866 22.06 66.25 11500.66 1.44 -D.07 285 020 1.15 0.30 036 2.85 152 72.20 MM (1, 2) 1,656.15 22.08 68.25 1.62940 1.50 -007 3.44 027 1.17 0.34 044 3.45 1.65 71.52 MM (1, 2) 1,696.57 22.08 68.25 1,668.86 1.58 -0ff/ 344 0.27 117 0.34 0.44 3.45 1.65 71.52 MWD(1, 2) 1,74000 23.86 88.14 1]06.84 147 -0.07 192 0.00 1A6 0.36 ow 194 1.55 79.20 MWD+IFR-AK-CAZSC(2,2) 1,76000 23.86 66.14 1,725.13 1A8 4,07 1.96 0.01 1.15 030 0.37 1.98 1.58 78.96 MM (2, 3) 1,835.41 2899 63.11 1,79324 1.48 4.12 2.44 0.14 1.13 OA2 0.45 246 1.63 71.18 FAM (2, 3) 2,110.92 30.79 woo 2,024.26 1.88 -0.25 4.72 054 1.16 ow 0.77 4.75 1.91 62.02 MWD(2,3) 2,911.54 74M 46]9 2./80]2 3.02 -0.61 13.72 2,12 2.54 0.71 225 13.81 2.76 63.60 MV0D(2,3) 5177.00 74.06 46]9 3,08306 560 -0.55 1863 0.07 521 1.03 190 18.65 3,33 4947 MWD+1FR-AK-CAZ-SC(3.3) 5,85985 74.06 4879 3,215.70 840 -0.55 2125 007 5.90 1.11 2.17 2127 3.22 49.18 MWD+IFR-AK-CAZ-SC (3,3) 6.073.84 7035 3207 3,34285 7.61 -043 2134 061 6.70 1.20 248 22.38 3.43 48.72 MM+IFR-AH-CAZ-SC(3,3) 8,239.84 69.20 26.00 3,400.28 8.11 -041 2099 079 893 1.24 2.55 2267 3.52 4843 MWD+IFR-AK-CAZ-SC(3,3) 6,435.17 68.12 1875 3,471.43 9.18 -0.42 19.89 1.15 734 131 2.74 23.18 379 47.71 M=+IFR-AK-CAZ-SC(3,3) 6]97.54 uses 5.0 3,61032 10.43 -048 17.91 1.56 7.81 1.40 2.95 23,68 4.29 46.67 MWD+IFR-AK-CPZ-W(3,3) 8,988.81 6a87 35187 3,68461 11.15 -0.56 18.30 1.02 8.10 1.46 3.07 23.94 4.72 4594 MWD+IFR-AK-CP2-SC(3,3) 7,120.53 66.87 357.87 3.737.09 11.33 -056 16.89 182 831 1.51 3.16 24.28 4.84 45.01 MWD+IFR-AKCAZ-SC(3, 3) 7,192.95 68.56 359.91 3,764.55 1099 -0.62 1788 173 8.44 1.54 3.22 2450 4.89 4450 MWWIFR-AH-CAZ-SC(3,3) 7,20242 68.79 0.18 3,768.00 1099 -D.62 17,88 1.73 044 154 3.22 24.50 4.09 44.50 MWD+1FR-AK-0AZ-SC(3,3) 7.319A9 68.79 0.18 3,810.36 11.27 -0.62 1866 1.73 0.75 1.60 3.36 25.07 5.06 43.18 MWD+IFR-AK-CAZ-6C 13,3) 7.373.25 6879 0.18 3,82981 11.27 -062 1866 1.73 875 1.60 335 25.07 5.08 43.16 MWD+IFR-AK-CAZ-SC(3,3) 7,460.15 68.79 0.18 3,051.26 1142 -O.62 19.09 1.73 891 163 343 25.38 5.18 4249 MWD+IFR-AK-CAZ-SC(3, 3) 7,568.99 08.79 0.18 3,900,64 11.56 -062 1953 1.73 9.07 IN 3.51 25.70 Sb 41.80 MM+IFR-AK-CAZ-50(3.3) 7,79004 6879 0.18 3,980.62 11.85 -0.62 20.43 1.73 9.39 172 3.66 2635 5.56 4045 MWD+IFR-AK-CAZ-SC(3,3) 8.12443 68.79 0.18 4,10162 12.45 -0.62 22.27 173 10.03 1.86 398 27.73 6.13 3783 MWD+IFR-AK-CAZ-W(3, 3) 6,284.07 8879 0.18 4,16300 12.59 -082 22.72 1.73 10.18 1.89 4.08 28.07 626 3123 MWD+IFR-AR4AZ-sc(3, 3) 81212017 11:19:17AM Page 2 COMPASS 5000.1 Build 74 Pool Report r I,1H-118wp21 Surface Location fM CPAI Coordinate Converter o e1 From: Datum: NAD83 Region: alaska + C Latitude/Longitude IDecimalDegrees, + f UTM Zone: I r South r" State Plane Zone: 14 _j Units: jus.ft C' Legal Description (NAD27 only) To: Datum: NAD27 Region: alaska + C Latitude/Longitude IDecimaiDegrees + C UTM Zone: True r South 6 State Plane Zone: q + Units: us -ft C Legal Description (NAD27 only) Starling Coordinates:----- --- -- - --- —Ending Coordinates: X: 11689578.57 Y: 15900833.04 549546.948756498 Y: 5981081.22423732 ..................... Transform ................................. Quit Help J1H-118wp21 Surface Location � IZ- CPAI Coordinate Converter o_ CE i From: - — ---- - Datum: NAD83 Region: alaska C' LatitudelLongitude IDecimalDegreas r UTM Zone: r— r South R State Plane Zone: F--:-] Units: us -ft + i C L_aal Gescriptinn jhlt+.D27 Drily) Starting Coordinates: ---- -- X: 11689578.57 Y: 15980833.04 To: -- Datum: NAD27 Region: alaska + f' Latitude/Longitude jDacimalDegrees + C UTM Zone: True r South • State Plane Zone: Units: us ft C Legal Description (NAD27 only) Legal Description----------- - -- ------- Township: 012 ry + Range: 010 E + Meridian: U Section:28 FNL + 4901.5929 FEL 791.46172 Transform Quit Help 1.1H-118wp21 Surface Casing I M CPAs Coordinate Converter o O From: - ---- -- ---.-.. _ Datum: NAD83 Region: alaska + C Latitude/Longitude Decimal Degrees + C UTM Zone: F— r South C State Plane Zone: 4Units: us -ft + Legal Description (NAD27 only) Starting Coordinates: - X: 11689790.85 Y: 15980911.13 To Datum: NAD27 Region: alaska + C- Latitude/Longitude IDecimalDegrees * UTM Zone: True F South G State Plane Zone: F--+] Units: us -ft + r Legal Description (NAD27 only) EndingCoordinates: - --- --------------- X: 549759.226056394 Y: 5981159.3083802 ..................... .... .-. ... ........................-r Transform Quit Help 11H-118wp21 Surface Casing I S. CPAI Coordinate Converter o I wl From:--_. Datum: INAD83 Region: alaska + Latitude/Longitude pecimal Degrees 7D- UTM UTM Zone: F— South C: State Plane Zone: 4 + Units: us -ft + C Lea_! DF ription INAD-27 onlyl To.-------. .. _- -_ - Datum: NAD27 Region: alaska C Latitude/Longitude IDecimalDegrees—� r UTM Zone: True r South C State Plane Zone: F7:-] Units: FTE (-- Legal Description (NAD27 only) Starting Coordinates: Legal Description--- ------------------ X: 11689790.85 Township: 012 N + Range: 010 [F7, Y: 15980911.13 Meridian: I" Section:2B FNL 4824.9162 FEL 578.48368 — - I .................................. € Transform ; Quit Help 11H-118wp21 TD ®. CPAI Coordinate Converter o � rara�5'nl From: - - -- --_-- ITo: - --- Datum: NAD83 Region: alaska r Latitude/Longitude IDecimalDegfees r UTM Zone: r— r South f. State Plane Zone: F-':-:1 Units: us -ft r Legal Description (NAD27 only) Starting Coordinates: X 1692821.23 i Y: 15985575.91 I Datum: INAD27 Region: alaska r Latitude/Longitude IDecimalDegfees f UTM Zone: True r South f• State Plane Zone: F__:-:1 Units: us -ft C Legal Description (NAD27 only) Ending Coordinates:— — ------ - X: r552789.592500425 Y: 5985823.9205799 r._._....._...................._.._...._...........s Quit Help Transform 1 H -118w 21 TD M CPAI Coordinate Converter o Q ews From:. --__.....- Datum: fNAD83 � Region: jalaska r Latitude/Longitude IDecimalDegtees * UTM Zone:1 — r South G State Plane Zone: F47-7,1 Units: u -s -ft i LF�alDescriptkn lFlA027 nrilvl Starting Coordinates: - - - - ----- X: 11692821.23 Y: 15985575.91 To: Datum: NAD27 Region: alaska (" Latitude/Longitude IDecimalDegrees r UTM Zone: True r South C State Plane Zone: F-----3 Units: us -ft {- Legal Description (NAD27 only) -Legal Description--- ..._.------------------ Township: 012 FN --,l Range: 010 E Meridian: U Section:27 FNL 18D.72247 FEL 2786.7124 Transform Quit Help .................. ..... _................ ... .... _... ... .....r 16:03, June 022017 1 H-118wp21 Quarter Mile View 17:13, June 052017 1 H-118wp21 Quarter Mile View --- ---- ---- -- .v,WV IGUv 1 H-118wp21 Section View - o - 2 x 42" PFROST 0° T-3 K-15 1000 1500- --- ------ --------- --- 1 -3/4" 13-1/2", - oo U G_C �o 0o gg q UG_ U G_ N a W� w D(CL3000 �o o �" o -' o ,;, - S Al BASE - ----- Q _ .. _ CO n ____-_ r _ _ _, ,' ~45007" x 8-1/2" �' I iy i s 2 i o 6000 D v CO 2 -850 0 850 1700 2550 3400 4250 5100 5950 Vertical Section at 0.000 I I T-3 " Tollerable Collision Risk Worksheet As -built 1 12/05/01 MRT I CC I IRev. Per K05014ACS 12 02/01/11 JAH I LGM I Rev. Per K170005ACS 1. BASIS OF LOCATION AND ELEV. IS DS1H N25 30 29 28 27 I 7 2: 1C COORDINATES SHOWN ARE ALASKA STATE _ PLANE, ZONE 4, N.A.D. 27, AND GEODETIC 36 31 IH 1112111mmI 1 COORDINATES ARE NAD 27. 3. KCS 32 33 34 35 36 ALL CONDUCTORS ARE LOCATED WITHIN *14 T1 N 1 E 1 05 IOE TOWNSHIP 12 NORTH, RANGE 10 EAST, 920 n1NF LI—T6 UMIAT MERIDIAN, ALASKA. *19 922 5 4 3 2 917 010 0120 >a 06 L17-02 & L17-03. �'�FtO *21 1 ASP GRID NORTH 0119CPFl 2 e *15 013 0118 ALL DISTANCES SHOWN ARE GROUND. 0 09 92 0117 qo 03 12 0116 GRAPHIC SCALE 0115 D 6 5 14j 08 0114 ,K 04 LEGEND 01 2 F 24 0 AS—BUILT CONDUCTOR ID 0111 24 19 20 2t 2 23 MAP & 3 FOR COORDINATE TABLE 0110 VICINITY • EXISTING CONDUCTOR 0109 SCALE: 1" = 2 MILES 0104 0108 0103 28 27 0102 33 34 0106 0101 & A330L4AT6S, 1NC. EW YORS ENGINEERS FL NMS y/ AREA: IH MODULE: XXXX UNIT: 01 ConocoPhillips DS1H WELL CONDUCTOR Alaska, Inc. WELL LOCATIONS CADD FILE NO. DRAWING NO. PART: REV: LK6108d31 2/05/05 CEA—D1HX-6108D31 1 of 3 2 NOTES: 1. BASIS OF LOCATION AND ELEV. IS DS1H MONUMENTATION PER LOUNSBURY & ASSC DS1 H 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES ARE NAD 27. 3. ELEVATIONS ARE B.P.M.S.L. *UGNU 01 4. ALL CONDUCTORS ARE LOCATED WITHIN *14 PROTRACTED SECTIONS 28 AND 33, 05 TOWNSHIP 12 NORTH, RANGE 10 EAST, 920 *12 UMIAT MERIDIAN, ALASKA. *19 922 011 5. DATES OF SURVEY: 12-26-16 THRU 917 010 1-31-17 FIELD BOOKS 1_16-35, L16-40, 016 06 L17-02 & L17-03. *21 *15 013 6. ALL DISTANCES SHOWN ARE GROUND. *1 09 92 07 03 018 GRAPHIC SCALE 0 100 200 400 08 04 1 inch = 200 ft. SEE SHEET 2 & 3 FOR COORDINATE TABLE LOUNSBURY & A330L4AT6S, 1NC. EW YORS ENGINEERS FL NMS y/ AREA: IH MODULE: XXXX UNIT: 01 ConocoPhillips DS1H WELL CONDUCTOR Alaska, Inc. WELL LOCATIONS CADD FILE NO. DRAWING NO. PART: REV: LK6108d31 2/05/05 CEA—D1HX-6108D31 1 of 3 2 1 102/01/11 JAH I LGM I lCreate Per K170005ACS I CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 28, T. 12 N__ R_ 1n F. 111MIAT ►IF@InIAAI Well No. NAD 27 ASP Coordinates NAD 27 Geo ra hic Coordinates Section Offset. Elev. Y X Lat. 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' 768' 48.0' 54.1' *104 5,980,782.43' 549,568.74' N 70' 21' 29.809" W 149' 35' 50.655" 79' 772' 48.0' 54.1' *108 5,9809752.52' 549,570.98' N 70' 21' 29.515" W 149' 35' 50.595" 49' 770' 48.0' 54.0' *109 5,980,812.20' 549,566.50' N 70' 21' 30.102" W 149' 35' 50.714" 109' 774' 48.0' 54.0' *110 5,980,842.21' 549,564.40' N 70' 21' 30.398" W 149' 35' 50.770" 139' 776' 48.0' 54.0' *111 5,980,872.05' 549,562.21' N 70' 21' 30.691" W 149' 35' 50.828" 169' 778' 48.0' 54.1' *112 5,980,902.08' 549,559.94' N 70' 21' 30.987" W 149' 35' 50.889" 199' 780' 48.0' 54.0' *113 5,980,932.00' 549,557.76' N 70' 21' 31.281" W 149' 35' 50.947" 229' 782' 48.0' 54.0' *114 61.86' 549,555.50' N 70' 21' 31.575" W 149' 35' 51.006" 259' 784' 48.0' 54.1' *115 91.68' L5,981,051.73' 549,553.43' N 70' 21' 31.868" W 149' 35' 51.062" 289' 786' 48.0' 54.1' *116 1.61' 549,551.58' N 70' 21' 32.163" W 149' 35' 51.110" 319' 787' 48.0' 54.1' *117 549,548.80' N 70' 21' 32.459" W 149' 35' 51.185" 349'790 48.0' 54.0' 5,981,081.22' 549,546.95' N 70' 21' 32.750" W 149' 35' 51.234" 378' 791' 48.0' 54.0'5,981,111.42' t 549,544.52' N 70' 21' 33.047" W 149' 35' 51.299" 408' 794' 48.0' 54.2' 5,981,141.33' 549,542.48' N 70' 21' 33.341" W 149' 35' 51.353" 438' 795' 48.0' 54.1' * CONDUCTOR ASBUILT THIS SURVEY ' 49th �•'JEREMIAH •F. CORNELL b1 LS-12663AV i ♦�..................... uuuu '� SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT 1 AM PROPERLY REGISTERED AND LICENSED TO PRAC77CE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION ARE CORRECT AS OF JANUARY 37, 2017. LOUNSBURY & AMOCUTES, INC. MYORS ENGINEERS 11L4YNERS `� AREA: 1H MODULE: XXXX UNIT: D1 ConocoPhilli S DS1H WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CADD FILE N0.DRAVANG NO. PART: REV: LK6108d31 12/27/16 CEA-DIHX-6108D31 3 OF 3 1 Hmag e n Dazs Necessary Plan Request (NPR) Initiated by: Hen Tolman Dale: 08/28/17 Contact Information: mn."n engea Nein b : OA25H) poem y TMu,war 12aN for Event: Penn&Pack Well Name: IH-118 Placeholder Well Name: Bottom Hole Location Name Last Plan Number (prior to this change request): ap 20 As4bui8 available? Yea As-built attached? Yes Slat l Surface Wasson: 18 Y/N: e9s.et23 XIE: eusu.es Z: ..so NAD 27 Rig: Other Dayan 142 Air Gap: 39 RKB: 93 Inclination Front. Pilot Hole?: No Laterals?. None New Hde from: Surface MD used anywhere in this request forth. then Reference Well: Name JNumber L of Hole Sections: 2 Strings D Formation¢ De hs M -Motor 20 x 42 ex.. TVD PFROST -1536.40 WKS Max Dogleg: T3 -170024 truss K-15 -1931.28 SO TVDSS Limit Steering in this Hale Section?: No UG_C -2990.06 TWss S S UG B -3249.85 TWSS u u UG A 3378.43 7%cSS r r Na 3517.32 f f Twos a WS_D -3671.55 a rvnss c WS_C 3717'38 c TVDSS B a 10314 x 13112 11..00 Mn WS_B -3738.81 Twss WS A4 -3768.26 TVLI55 WS A3 3807.64 nwss WS—A2 3887.62 w Tss WS—Al 4008.62 TwsS BASE 4087.83 T S I Pump Tanga.: No Limit Steering in this Hole Section?: No Top of Pool / Protludion Inteal: ry Noma M10 V0 cenT Bottom of POol / Production Interval: Name MDRVD Depth Tn, Ta ees Wlm Y/East n .I-Radlua Ina' M -Motor D rest. 3672. adTYDW 100 ft Max Dogleg: TD (see commeni I As I l I i 1 7 8112 x Approved by: Dale: Contact Information: Geology / Reservoir Contacts: Ryan Phelps Dr96ng / Completion Contacts: Ben Tolman Wet Planning Contacts: Fired 8 Last Name(s) Prima im rice is hhtirg the d to et Maintain inclination thm reser- interval at 50 de roes Well TO should be constructed as 459 MD below the top of the a2 sand which should be roughly 3909 [Was. (Ent, is It possible to Increase the Indination an Is t:hrough the reservoir interval to W degrees to better mainloaminda spacingfor downhole ui ent? Well trajectory shads mimic previous reg plan as owiery as possIble in regard to sail angle UPDATED SURFACE COORDINATES based on new information pmiftd by facilities. Primary importance is hening me d target Maintain iodination thru reservoir interval at 50 d teas Well TO Shodtl be constructed as 459 MD helowthe top of the a2 santl which should be nought -39091vdss. B 4. is it ossible to increase the indinatlon an le thro h the reservoir interval to 80 tl tees to better meinwinin a ad for downhole enta .---'-dory snouts nPhidupreviouses,I ps, as cosely as absinthe d to san angle. UPDATED SURFACE COORDINATES based on new irdornation provided reclines. 05/25/17 06:59 AM tdmabv Need lounojal. surface cosi setting depth. Plan to have 100' MD below base of Pedmafrost —109 MD above T31. 05/25/17 09:10 AM 10lmabv Add tangent section thru Surface cesin seltin de m. Cweml tra act thru West Sas is ok. Appendix M ■ Tier 1: Standard ■ Intervals without issues noted for Tier 2 or 3 ■ Tier 2: Challenging Orientation ■ Drilling within 300 of horizontal inclination AND drilling within 30° of magnetic East/West azimuth in extreme northern or southern locations ■ Tier 3: Critical Steering ■ Driller's Target of 50' Radius or Less ■ Lease line constraint ■ Small Geologic Target ■ Failure of Major Risk Rule (Close Approach) ■ Defined during directional planning, based on the positional uncertainty ■ Theoretical intersection of the path of the well being planned with an offset well • If HSE risks are eliminated, the Tolerable Collision Risk assessment can be implemented ■ Tier 4: Single section containing both Tier 2 and Tier 3 challenges ■ Tier 1 (Standard): ■ Directional interval across which no special mitigations are needed ■ Tier 2 (Challenging Orientation): ■ Increase non-magnetic insulation of MWD tool in the BHA ■ Take rotational check shots and/or increase survey frequency at the start of a BHA run ■ Alter well directional plan, if feasible ■ Consider gyro surveys where feasible ■ Tier 3 (Critical Steering): ■ Increase survey frequency across critical interval ■ Increase correction frequency across critical interval ■ Take rotational check shots and/or increase survey frequency if the critical interval is at the start of a BHA run ■ Define escalation based on deviation from plan ■ Minor Risked close approach intervals with a high financial or scope risk should strongly consider the use of relevant mitigations ■ Tier 4 (Critical Steering & Challenging Orientation): ■ Consider all Tier 2 & 3 mitigations IH -118 Jrillint! Hazards S.�mmary 13-1/2" Open Hole / 10-3/4" Casing Interval Hazard Risk Level Mitigation Strategy Broach of conductor Low Monitor cellar continuously during interval. Gas hydrates Moderate Control drill, reduced pump rates, reduced drilling fluid Abnormal reservoir pressure Low temperatures, additions of Lecithin. Running sands and gravels Low Maintain planned mud parameters, increase mud weight, Differential sticking Moderate use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), Hole swabbing on trips Moderate pumping out Washouts / hole sloughing Low Cool mud temperatures, minimize circulating times when Fault crossings and concretions Moderate possible. 8-1/2" 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. 1H-118 Drilling Hazards Summary.doc 5/3 1/2 0 1 78:43:20 AM Bettis, Patricia K (DOA) From: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Sent: Wednesday, June 7, 2017 10:24 PM To: Bettis, Patricia K (DOA) Subject: RE: [EXTERNAL)KRU 1 H-118 (PTD 217-084): Permit to Drill Application Good evening Patricia, Due to the completions, we not have plans to pre -produce the KRU 11-1-118 injector. Please let me know if you have any more questions. Thanks, Ben Tolman Drilling Engineer I ConocoPhillips, Alaska (907)265-6828(o)1(307) 231-3550(m) From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday, June 07, 2017 4:51 PM To: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Subject: [EXTERNAL]KRU 11-1-118 (PTD 217-084): Permit to Drill Application Good afternoon Ben, How long does ConocoPhillips plan to pre -produce KRU 1H-118? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at (907) 793-1238 or patricia.bettisOalaska.eov. Well 11-1-118 I <== Data Name: I CPAI I — Data Input Mud Weight (ppg) 10.00 <_= Data input Weak point or LOT - Measured depth (ft)1,740' <_= Data Input Weak point or LOT True vertical depth (ft) 1,707' <==Data Input Weak point or LOT - Hole angle (deg) 34.00 <== Data Input Weak point or LOT - Hole size (in) 8.500" <== Data Input Weak point pressure or LOT - EMW (ppg) 12.00 <== Data Input V1 m.mcm - ivneasureu unpin tn) Weak point pressure (psi): Data Input of interest - True vertical depth (ft) 4,163' <== Data Input of interest - Hole angle (deg) 69.00 <== Data Input of interest - Hole size (in)1 6.750" <== Data Input of interest -Pore pressure EMW (ppg) 8.60 Data Input Gas gradient (psi/ft) 0.10 <_= Data Input Bottom hole assembly OD (in) Weak point pressure (psi): 8.0" — Data Input Bottom hole assembly length (ft) Weak point pressure -Safety margin: 151 <_= Data Input )rill pipe OD (in) Max anticipated formation pressure(psi): 5.000" — Data Input A annular vol. @ zone of interest (bbl/ft) -0.0175 annular vol. @ zone of interest (bbllft) 0.0200 annular vol. 0 weak nnini I n nnso <== Data Kick Tolerance: V2 31, V Weak point pressure (psi): P10 1,065 psi Weak point pressure -Safety margin: Pmax Prnax EMW 1,065 psi 12.00 ppg Max anticipated formation pressure(psi): Pf 1,862 psi Weak Pt to Zone of Interest distance (TVD ft): OH (TVD) 2,456' Weak Pt to Zone of Interest distance (MD ft): OH (MD) 6,554' Maximum influx height at the bit (TVD ft): H (TVD) 1,144' Maximum influx height at the bit (MD ft): H {MD) 3,193' Calc. volume of {H) around BHA: Calc. volume of (H) around drill pipe: Calc. volume that H equals @ initial shut in: V1 bha Vtdp V1 -2.7 bbl 60.8 bbl 58.1 bbl Calc. vol. that H equals @ weak point (MD ft): VWp 63.4 bbl Calc. volume of Vwp @ initial shut in: V2 36.2 bbl Kick Tolerance: V2 31, V TRANSMITTAL LETTER CHECKLIST WELL NAME: /Q u , /14-#T PTD: 21? - oty Development VIService _ Exploratory Stratigraphic Test _ Non -Conventional FIELD: �( �t�/E,f POOL: 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 sam les 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 & Pool KUPARUK RIVER, WEST SAK OIL - 490150 _ Well Name: KUPARUK RIV UNIT 1HJ1.8— Program SERWell bore seg ❑ PTD#:2170840 Company CONOCOPHILLIPS ALASKA, INC. _ Initial Class/Type SER / PEND GeoArea 890_ Unit 11160 On/Off Shore _O_ Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31.05,030(j.1.A),(j.2.A-D) .. NA _ 1 Permit fee attached _ _ _ _ _ _ _ _ NA 2 Lease number appropriate_ _ _ _ Yes ADL0025639, entire wellbore, 3 Unique well. name and number Yes KRU 11-1-118 _ 4 Well located in. a. defined_ pool. _ Yes KUPARUK RIVER,. WEST SAK OIL. -490150,_ governed by Conservation. Order No. 406C.. 5 Well located proper distance. from drilling unit boundary Yes CO 4060 contains no spacing restrictions with. respect to drilling unit boundaries. 6 Well located proper distance from other wells _ _ _ Yes _ CO 406C has no intenvell spacing restrictions. 7 Sufficient acreage. available in. drilling unit Yes 8 If deviated, is wellbore plat included _ _ _ _ Yes 9 Operator only affected party Yes Wellbore. will be more than 500' from an external property line where ownership or landownership changes. I10 Operator has. appropriate bond in force _ _ Yes Appr Date 11 Permit. can be issued without conservation order. _ _ _ Yes 12 Permit can be issued without administrative. approval Yes PKB 6/8/2017 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by. Injection Order # (put 10# in comments) (For Yes AIO 2C 15 All wells within 1/4. mile .area _of review identified (For service well only). Yes _ KRU 111-1-05 16 Pre -produced injector: duration of pre production less than 3 months (For service well only) No Ben. Tolman (email 6/7/17) 18 Conductor string. provided Yes 80' conductor set_ _ Engineering 19 Surface casing protects all known USOWs Yes 1740'.MD 20 CMT vol adequate to circulate on conductor & surf csg Yes 132% excess _ 21 CMT. vol adequate to tie-in long string to. surf csg No 22 CMT will cover all known productive horizons Yes 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 NA 26 Adequate wellbore separation proposed Yes Anti -collision analysis complete; no major risk failures 27 If diverter required, does it meet regulations Yes Diverter route meets regulation Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure is 1780 psig(8.6 ppg EMW ); will drill w/ 8.8-10.0 ppg EMW VTL 7/6/2017 29 BOPEs, do they meet regulation _ Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 1382 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 1-12S gas probable Yes H2S measures required. 34 Mechanical. condition of wells within AOR yerified (For service well only) Yes KRU 1H-05 within AOR and is P&A'd _ 35 Permit can be issued w/o hydrogen sulfide measures No Wells _on.1 H -Pad are. H2S-bearing. 1-12S measures required. Geology 36 Data. presented on potential overpressure zones Yes _ Expected reservoir pressure is 8.6 ppg EMW; will be drilled using 8.8 to 10.0 ppg mud. Appr Date 37 Seismic analysis of shallow gas. zones NA PKB 6/8/2017 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Onshore service well to be drilled. Geologic Date C Engineering Public Date Commissioner: Date: Co ssione r
