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217-162
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS =L;LU 1etJ JUN 1 1 2019 1. Operations Abandon LJ Plug Perforations LJ Fracture Stimulate LJ Pull Tubing Li Operations(h;i o n Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Convert to WAG injection0 2. Operator ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑✓ Exploratory ❑ Stratigraphic ❑ Service [-]6. 217-162 3. Address: API Number: PO Box 100360, Anchorage, Al 99510 50-103-20765-60-00 7. Property Designation (Lease Number): 8. Well Name and Number: ASRC-NPR4, ASRC-AA092344, ASRC-NPR2 CRU CD5-251-1 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Colville River Unit / Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 20973 feet Plugs measured N/A feet true vertical 7599 feet Junk measured N/A feet Effective Depth measured 20973 feet Packer measured 7281 feet true vertical 7599 feet true vertical 7105 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 20" 115' 115' Surface 2156' 10.75" 2193' 2182' Intermediate 8426' 7.625" 8460' 7515' Liner 1016' 4.5" 9243' 7493' Liner 6560' 4.5" 19829' 7597' Perforation depth Measured depth 8560'-9238', 14067'-19824' feet True Vertical depth 7506'-7493', 7538'-7597' feet Tubing (size, grade, measured and true vertical depth) 4.5" L-80 8315' 7498' Packers and SSSV (type, measured and true vertical depth) Packer Baker 4.5" TC -ll x 7 5/8" 29# 7281' 7105' SSSV 3.81" MCX [NJ—VALVE 2081' 2072' 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 550 540 1 0 1050 370 Subsequent to operation: N/A N/A 12500 N/A 1800 14. Attachments (required per 20 AAC 25.070, 25.o71, a 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory ❑ Development❑ Service ❑� Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG Q GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 3A-18 Authorized Name: David Neville Contact Name: David Neville Authorized Title: Staff Production Engineer Contact Email: David.J.NevilleCrDcoo.com Authorized Signature: Owl— .[/ Date. Contact Phone: 265-6220 VTL �/zb/ty Form 10-404 Revised 4/2017 Submit Original Only RBDMS�JUN 121019 ConocoPhillips Well History CD5-25L1 Date Event 5/9/2019 (ISW) MIT -IA PASSED TO 2100 PSI (ADAM EARL) 5/2/2019 PRESSURE IA UP TO 250LBS JOB COMPLETE 4/16/2019 OPEN CMU @ 7349' RKB. SET 3.81" MCX INJ VLV @ 2081' RKB. COMPLETE. 4/15/2019 PULLED 3.81" XXN PLUG & GAUGES @ 7450' RKB. MAX PSI = 2503 @ 152 F. **UPLOAD TO "S" DRIVE/ ALP/ TEMP**. IN PROGRESS. 4/14/2019 **LRS CIRC'd OUT WELL w/ 290 BBL'S INHIBITED BRINE & 90 BBL'S DIESEL TBG X IA U -TUBE FOR FP** SET DV @ 7213' RKB. MITIA TO 3000 psi. **PASS**. PULLED 4.5" EVO TREVE PLUG @ 7250' RKB. EQUALIZED XXN PLUG @ 7450' RKB. RAN 10'X 2.5" PUMP BAILER TO SAME. **NO SAMPLE". IN PROGRESS. 4/13/2019 SET 4.5" EVO TRVE PLUG (CAL = 72") @ 7250' RKB. PRESSURE TBG TO 1500 psi TO VERIFY PLUG HOLDING. PULLED DV @ 7213' RKB. READY FOR CIRC OUT. 4/11/2019 RAN SHIFTING TOOL TO VERIFY SLEEVE @7349' RKB WAS CLOSED, PIN UNTOUCHED (SLEEVE CLOSED). TBG PT AGAINST PLUG FAILED. LAY DOWN DUE TO HIGH WINDS. IN PROGRESS 4/10/2019 SET DV @ 7213' RKB. UNABLE TO PRESSURE UP THE TBG AGAINST XXN PLUG. WITH HOLE FINDER BEGAN TESTING FROM XXN PLUG @ 7450', TOOL INDICATES LEAK IN THE TUBING BETWEEN —7320' RKB & —7239' RKB. RAN 42 BO SHIFTING TOOL TO 7349' RKB TO VERIFY SLEEVE CLOSED. IN PROGRESS. 4/10/2019 CIRC -OUT, PUMPED 290 BBLS INHIBITED BRINE DOWN TBG, TAKING RETURNS UP THE IA TO PROD, FOLLOWED BY 90 BBLS OF DSL, GAS / CRUDE RETURNS AT SURFACE, PUMPED ADDITIONAL 20 BBLS OF DIESEL DOWN THE TBG STILL GAS / CRUDE RETURNS AT SURFACE. ATTEMPT TO COMBO TEST TXIA, UNABLE TO BUILD PRESSURE. FREEZE PROTECT FL WITH 5 BBLS DSL, RIG DOWN AND TURN WELL OVER TO HALLIBURTON SIL. **JOB IN PROGRESS" 4/9/2019 GAUAGE TBG TO 3.78" TO 7450' RKB. SET 3.81" XX PLUG ASSY w/ SPARTEK GAUGES @ 7450' RKB. PULL GLV'S @ 5762'& 3507' RKB's & REPLACE WITH DV's. PULLED OV @7213' RKB. **READY FOR CIRC OUT**. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY David Neville Staff Production Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CRU CD5-25L1 Permit to Drill Number: 217-162 Sundry Number: 3 19-18 9 Dear Mr. Neville: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a og c c. a l a s k a. g o v Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner Q( yt DATED this Z ay of April, 2019. f{BDN�SAPR 231019 PECEIVED STATE OF ALASKA APR 1 1 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS®GCC 20 AAC 25.260 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Convert to WAG injection Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development Q • Stratigraphic ❑ Service ❑ 217-162' 3. Address: 6. API Number: PO Box 100360, Anchorage, AK 99510 50-103-20765-60-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A CRU CD5-2511 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field/Pool(s): ASRC-NPR4, ASRC-AA092344, ASRC-NPR2 I Colville River UniVAlpine Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 20973' 7599' 20973' 7599' Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 20" 115' 115' Surface 2156' 10.75" 2193' 2182' Intermediate 8426' 7.625" 8460' 7515' Liner 1016' 4.5" 9243' 7493' Liner 6560' 4.5" 19829' 7597' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Pert Pups 14067'- 19824' 7538'- 7597' 4.5" L-80 8315' Perf Pups 8560' - 9238' 7506'- 7493' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker Premiere Production Packer 4.5" TC -ll x 7 5/8" 29/t, No SSSV Packer: 7281' MD, 7105' TVD, No SSSV 12. Attachments: Proposal Summary r7 Wellbore schematic r 13. Well Class after proposed work: q. rz Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hic g p ❑ DevelopmenService ❑v 14. Estimated Date for 4/18/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: David Neville Contact Name: David Neville Authorized Title: Staff Production Engineer Contact Email: 29vid.J.Nevillena cop.com C Contact Phone: 265-6220 Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity TestLA Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes [t/ No ❑ RMS-' APR 2 3 2019 Spacing Exception Required? Yes ❑ No r� Subsequent Form Required: 64�r2� APPROVED BY J / -1 / Approved by: COMMISSIONER THE COMMISSION Date: L/!—( Gl� /� gU l) V rL- -f//,?11 q Submit Form and Form 0 Rev bbbddd 4& 7 Approved application �a1�11o0 � 5 the date of approval. /�/ Attachments in Duplicate / UR V /'` �� CDS -25L1 Description Summary Of Proposal ConocoPhillips Alaska Inc. requests approval to convert Colville River Unit (CRU) well CD5-25L1(PTD# 217-162) from Oil Production service to Water Alternating Gas Injection service as the pre -production period has been completed. Area of review V Colville River Unit well CD5-251_1 was completed in March 2018 to provide enhanced recovery injection into the reservoir to increase the ultimate recovery of oil. This well will support existing production well CD5-20. The top of the Alpine A sand was found at 8924' MD / 7496' TVD. Area map with % mile radius around target injection zone (see attached): This map shows locations of wells and a % mile radius around the CD5-25L1 penetrations of the Alpine interval. CD5-25 is a lateral to be converted to injection and connects to the same parent -bore as CD5- i 251-1. The nearest existing wells are CD5-20 and CD5-20L1, both are production laterals in the Alpine interval intended to receive injection support from CD5-25 and C135-251-1. Mechanical condition of well to be converted The mechanical condition of CRU well CD5-25L1 is "Normal," with no annular communication noted. The tubing -by -casing annulus is isolated by a production packer at 7281' MD / 7105' TVD. Approval was granted to set the production packer as high as 6900' MD due to casing wear concerns near the heel of the intermediate casing. A state -witnessed MITIA will be performed once well CD5-25L1 is converted to injection, online, and stabilized. CBL and interpretation of cement quality During the production casing cement job, full returns were achieved, plugs bumped, and floats held. A sonic log indicates the top of cement is at 6655' MD. I Proposed conversion steps CD5-25L1 will be shut-in. The tubing by casing annulus will be loaded with corrosion -inhibited brine and dummied off. A subsurface safety valve will be set. Surface facilities will be installed to tie-in to the injection system. WNS PROD WELLNAME CD5-25 WELLBORE CD5-25L1 %te" .11011111111w Conci.aJPhillip$ Well Attributes Max Angle 8l MD 7D AlasJol Inc. Field Name ALPINE WNIMre APIhRM 501032076560 Wellbore"A" ncl I'l MO(M1KB) PR00 3.02 $508.40 gc191m (M1KB1 20,WJ.0 Lanment XS (grml Oah Mnzhlion ed Oat, K...(MR IB Release "N"LUST WO: 36.58 311 J/2018 XORRONipL-COS35LI, 4110/A188E8.31 MI Last Tag NTnI Aematb (actuary MrMMbn 0.MMKBl End Dale I MIIWe Last MM By .ER: Re— w LAST TAO: CD1351-1 1jennalt Last Rev Reason ._...... ................_............._._........... ....... Mnalalun End Dale William- 1.111 km 13YREV REASON: NEW IATERAI 4/11/2018 COS25L1 jennalt Casing $fringe ... ............ ._.......... _.._........... �.. cssing pescripNon CD(inl Open Hole 63/4 to (^I To 19,819 3 2g9i30 (xKBI set Depth RyGL.. Ween (1_. Grade roprnread Cazing Description 00hm' LINER2 41/2 IG(ial rap(RKB) 3.96 8.22],it Set Deplr'IK. 9.243.5 Sel pepin jN0... WLten (I,,, Gratle J493.4 12.60 L-80 Top Thread TXP coNODCTOR:333.11b.0 Liner Details TapmKB) rellic"SmKBI Tpp Mclry Ihm Dea Cam wall nnlo gn) 8842.6 "Cee.9 t,d.>3 XO Casing G.,Sub 5 1& M63 8x4117 TXPP NIPPLE. I canny lxsn.iwion LINER 1 40(ml 112 3,96' ro3269.1 S19N.8M29w.3h 17.598,9 ),595,9 12.60 N._LGAr0de TTopPmread X 'Liner Details iw (nnB roplrvol ptl<Bl rap Incl rl Dem Des Lwn ISO. rvommauD (in)) Illlpp SURFACE: 31.0.3,1834 13.285.0 ],5260 88 fit XO 5- H521 x AY TXP pinxpin 3.958 Notes: General 6 Safety Entl oah m A aderm GPS I1Ff:3.Yfi.i NOTE: OASuFr:5MU oPs un', 1.3m.3 .KM 72006 SaDING GLEEW 7.M.3 HIPPIE: 7,4Gi.6 MWLE'. i.a•A.0 I WERINROLATE. ] A-sA &i LINER 2:8=(F%3435 LINEN 1:1).388.1-18.8183 O, WY:I8a29d.A.y)30� + ASRC-NPR2 �O I 7.0 t 2u I Q Well Pad i — Well Path F ASRC-AA092344 LU r> v I Z 'Z I O CD5-25L1 Open Interval 1/4 Mile Buffer �O I 7.0 t 2u I Q Well Pad ? — Well Path CD5-25, Open Interval CD5-25L1, Open Interval Q CD5-25 Open Interval 1/4 Mile Buffer O CD5-25L1 Open Interval 1/4 Mile Buffer — Wells in radiii j — Nearby Producer i¢ a rirr_ _: : r : National Petroleum Reserve -Alaska id j Q Alpine PA i ¢ I T11 NR4E Unit Boundary _ 0 CPAI Lease i T10NR4E mocoPhillips X Alaska CDS-25 10-403 Sundry 4/9/2019 ADL387208 ADL387207 ADL380075 ADL387209 1 N 0 0.2 0.4 0.6 0.8 1 1.2 Miles DATA SUBMITTAL COMPLIANCE REPORT 1/11/2019 Permit to Drill 2171620 Well Name/No. COLVILLE RIV UNIT CD5-25L1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20765-60.00 MD 20973 TVD 7599 Completion Date 3/17/2018 Completion Status 1-0IL Current Status 1-0IL UIC No -- — - REQUIRED INFORMATION Mud Log N Samples No _ ✓ Directional Survey Yes ✓ DATA INFORMATION List of Logs Obtained: GR/RES/ Sonic Scope Well Log Information: (from Master Well Data/Logs) - Log/ Electr Data Type Digital Dataset Med/Frmt Number Name Lo Lo Interval 9 g Run OH/ ED _ C 29424 Digital Data Scale Media No Start Stop CH Received _ Comments__ 54 2202 6/26/2018 Electronic Data Set, Filename: CPAI CD5- ED C 29424 Digital Data 25L1_Scope Gamma Ray_RM_LAS_LWD001.las 2163 8470 6/26/2018 Electronic Data Set, Filename: CPAI CD5- ED C 29424 Digital Data 251.1–Scope Resistivity_RM_LAS _LW D002.1as 8469 15238 6/26/2018 Electronic Data Set, Filename: CPAI CD5- ED C 29424 Digital Data 250–Scope Resistivity_RM_LAS _LWD006.1as 15198 20974 6/26/2018 Electronic Data Set, Filename: CPAI CD5- ED C 29424 Digital Data 251_1–Scope Resistivity_RM_LAS _LW D007.1as 8168 8578 6/26/2018 Electronic Data Set, Filename: CPAI_CD5- 251.1 Scope Resistivity_RM_LAS Motor Kickoff ED C 29424 Digital Data t.las – 8377 8571 6/26/2018 Electronic Data Set, Filename: CPAI_CD5- 251_1 Scope Resistivity_RM_LAS Kickoff ED C 29424 Digital Data _Motor 2.las 54 20974 6/26/2018 Electronic Data Set, Filename: CPAI_CD5- ED C 29424 Digital Data 25L1 Scope Resistivity_RM_LAS.las 6/26/2018 Electronic File: CPAI CD5-25L1 Scope ED C 29424 Digital Data Resistivity_RM_DLIS_LW D001.61is 6/26/2018 Electronic File: CPAI_CD5-25L7_Scope ED C 29424 Digital Data Resistivity_RM_DLIS_L W 0002.d1is 6/26/2018 Electronic File: CPAICD5-251.1 Scope ED C 29424 Digital Data Resistivity_RM_DLIS__LW D006.dlis 6/26/2018 Electronic File: CPAI CD5-25L1 Scope ED C 29424 Digital Data Resistivity_RM_DLIS_L W D007.d1is 6/26/2018 Electronic File: CPAI_CD5-25L1 Scope Resistivity_RM_DLIS_Motor Kickoff 2.dlis AOGCC Pagel of3 Friday, January 11, 2019 DATA SUBMITTAL COMPLIANCE REPORT 1/11/2019 Permit to Drill 2171620 Well Name/No. COLVILLE RIV UNIT CD5-251-1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103.20765.60.00 MD 20973 TVD 7599 Completion Date 3/17/2018 Completion Status 1-0I1 Current Status 1-0I1- UIC No ED C 29424 Digital Data 6/26/2018 Electronic File: CPAI_CD5-25L1_Scope Resistivity_RM_DLIS_Motor Kickoff.dlis ED C 29424 Digital Data 6/26/2018 Electronic File: CPAI_CD5-25L1_Scope Resistivity_RM_DLIS.dlis ED C 29424 Digital Data 6/26/2018 Electronic File: CPAI CD5- 25L1 _Scope_Resistivity_2MD_RM.pdf ED C 29424 Digital Data 6/26/2018 Electronic File: CPA1CD5- 25 L 1 _S oope_Resisti vity_2T V D_R M. pdf ED C 29424 Digital Data 6/26/2018 Electronic File: CPAI CD5- 25L 7 _Scope_Resistivdy_5MD_RM. pdf ED C 29424 Digital Data 6/26/2018 Electronic File: CPAI CD5- 25L 1 _Soope_Resistivity_5TVD_RM. pdf ED C 29424 Digital Data 6/26/2018 Electronic File: CPAI_C05-251-1_Final Surveys.csv ED C 29424 Digital Data 6/26/2018 Electronic File: CD5-25 GYROCOMPASS- revised.pdf ED C 29424 Digital Data 6/26/2018 Electronic File: CD5-25 GYROCOMPASS- revised.txt ED C 29424 Digital Data 6/26/2018 Electronic File: CD5-25 GYROCOMPASS- revised.xlsb ED C 29424 Digital Data 6/26/2018 Electronic File: C05-251-1 NAD27 EOW Compass Surveys [Canvas].txt ED C 29424 Digital Data 6/26/2018 Electronic File: CD5-251-1 NAD27 EOW Compass Surveys [Macro].txt ED C 29424 Digital Data 6/26/2018 Electronic File: CD5-251-1 NAD27 EOW Compass Surveys [Petrel].txt ED C 29424 Digital Data 6/26/2018 Electronic File: CD5-251-1 NAD27 EOW Compass Surveys [Surveys].txt ED C 29424 Digital Data 6/26/2018 Electronic File: CD5-251-1 NAD27 EOW Compass Surveys.pdf ED C 29424 Digital Data 6/26/2018 Electronic File: CD5-251-1 NAD83 EOW Compass Surveys [Canvas].txt ED C 29424 Digital Data 6/26/2018 Electronic File: CD5-251-1 NAD83 EOW Compass Surveys [Macro].txt ED C 29424 Digital Data 6/26/2018 Electronic File: CD5-251-1 NAD83 EOW Compass Surveys [Petrel].txt AOGCC' Page 2 of 3 Friday, January 11, 2019 DATA SUBMITTAL COMPLIANCE REPORT 1/11/2019 Permit to Orill 2171620 Well Name/No. COLVILLE RIV UNIT C135-251-1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50.103-20765-60-00 MD 20973 TVD 7599 ED C - - - Completion Date 3/17/2018 Completion Status 1 -OIL Current Status 1 -OIL 29424 Digital Data - - _ UIC No 6/26/2018 Electronic File: CD5-251-1 NAD83 EOW ED C 29424 Digital Data Compass Surveys [Surveys].txt 6/26/2018 Electronic File: CD5-251-1 NAD83 EOW Log C 29424 Log Header Scans Compass Surveys.pdf 0 0 2171620 COLVILLE RIV UNIT C05-251-1 LOG Well Cores/Samples-information: - HEADERS Interval Sample Name Start StopSent Received Number Comments INFORMATION RECEIVED/ Completion Report I YI �,�-/'�� �i, Directional / Inclination Data /Y / Mud Logs, Image Production Test Informationo NA l/ Mechanical Files, Digital Data Y / g�j Core Chips y C% Geologic MarkersR � Integrity Test Information Y / NAv Composite Logs, Image, Data Files U Core Photographs Y /69 ops Daily Operations Slei Summary Cuttings Samples --- Y / p /3 Laboratory Analyses Y /b l/ COMPLIANCE HISTORY Completion Date: 3/17/2018 Release Date: 1/12/2018 Description Date Comments Comments Compliance Reviewed IS AOGCC Page 3 of 3 Date: Friday, January 11, 2019 berger Transmittal #: 26JUN18-SP02 Drilling & Measurements Product Delivery Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Natural Resource Tech Well Name: CD5-25L1 Date Dispatched: 26 -Jun -18 Service Order #: 17AKA0032 Dispatched B p Y Stephanie Pacillo TVD MD TVD )nal Survey Nad83 Survey Graphics: PDF Surveys: PDF/TXT Please sign and email a copy to: Tom Osterkamp eived Rv '- x x x R C^EI V `' x UN 26201 1OGC( x is on X x x 1 Please sign and email a copy to: Stephanie Pacillo 21 71 62 29424 STATE OF ALASKA ALASKA nil ANn rAR CnM521=RVATlnkl rnkes COMPLETION RECOMPLETIONREPORTIAND LOG CO❑MPLETIOSPLUG❑ ta.WellStatusWEoL ElOther ❑ Abandoned ❑ Suspended ❑ l Class: 20aac25.105 20AAC25,110 GINJ ❑ WINJ ❑ WAGE) WDSPL ❑ No. of Completions: 2. Operator Name: 6. Date Comp., Susp., or ConocoPhillips Alaska, Inc. Aband.: .3/17/2018 Development❑ Exploratory ❑ Service C-] Stratigraphic Test ❑ 14. Permit to Drill Number / Sundry: 217-162 ' 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 •2/26/2018 50-103.20765-60-00 - 4a. Location of Well (Governmental Section): Surface: 432' FNL, 2900' FEL, Sec 18, T11 N. R4E, UM ' Top of Productive Interval: 2862' FNL, 1701' FEL, Sec 18, T1IN, R4E, UM Total Depth: 2930' FNL, 1385' FEL, Sec 29, Tl IN, R4E, UM 8. Date TD Reached: •3/6/2018 16. Well Name and Number: CRU CD5-25L1 - 9. Ref Elevations: 'KB:70.28 • GL:33.70 ' BF: 17. Field / Pool(s): Coleville River Unit/Alpine Pool ' 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ASRC-NPR4,ASRC-AA092344, ASRC-NPR2- 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 349077 y- 5965786 Zone- 4 TPI: x- 350236 y- 5963332 Zone- 4 Total Depth: x- 355659 y- 5952597 Zone- 4 11. Total Depth MD/TVD: .2097317699 - 19. DNR Approval Number: 932669, 932128, 340757 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1321/120 5. Directional or Inclination Survey: Yes ❑+ (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: 21. NIA (ft MSL) Re-drill/Lateral Top Window MD/TVD: .8184/7483 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 evarion, casing collar to welry, and perforation record. Acronyms may be used. Attach a separate page N necessary GR/Res/Sonic Scope APR > > 2010 AOGCO 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER SETTING DEPTH MD SETTING DEPTH TVD FTGRADE HOLE SIZE CEMENTING RECORD TOP BOTTOM TOP BOTTOM AMOUNT PULLED 20 10 3/4 7 5/8 94 H-40 33 115 133 115 42 10 yds y)ct 45.5 L-80 37 2193 37 2182 13.4 1 sx 11.0 ppg, 299 sx 15.8ppg 29.7 L-80 34 8460 34 7515 9.875 x 11 61 sx 12.2 ppg, Class G, 41/2 Sin sx 15.8ppg, Class G 12.6 L-80 13269 19829 7526 7597 6.75 Liner 4112 12.6 L-80 8227 9243 7487 7493 16.75 Liner 24. Open to production or injection? Yes ❑� No ❑ 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perf l): Perforated Pups @ SIZE DEPTH SET (MD) PACKER SET (MD/rVD) 4 112 8315 728017104 14067 - 19824 MD and 7538 - 7597 TVD 5110 COMPLETION 8560 - 9238 MD and 7506 - 7493 TVD 3��t DAT �i_�(6 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes No Per 20 AAC 25.283 (i)(2) attach electronic and printed information 2] VERIIF�IED M&_ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 3123/2018 GASLIFT a Hours Tested: 4hrs Production for Test Period Oil -Bbl: 97 Gas -MCF: 83 Water -Bbl: 22 Choke Size: 42 Gas -Oil Ratio: 860 Casino Press: 1174 Calculated 24 -Hour Rate Oil -Bbl: 581 Gas-MCF g Water-Bbl: 12 Oil Gravitv - API (corr): orm iu-vur Kewseci 5/2017 CONTINUED ON PAGE 2 ,C,o>,�� ATL �a�/� ��I RRn1�s �� Apq C 2L+,18SubmitORIGINIALon� 28. CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MD/TVD, Fromlfo), 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 I] If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1321 1320 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 8924 7496 information, including reports, per 20 AAC 25.071. Formation @ TPI - Alpine C C30 2328 2314 K3 3795 3765 K2 4105 4072 Albian 97 4392 4356 Albian 96 5451 5404 HRZ 7432 7204 Kalubik 7491 7239 Kuparuk C 7630 7316 Alpine C 8924 7496 TO 20973 7599 Formation at total depth Alpine C - 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontoloaicalr well test results. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: G.L. Alvord Contact Name: Weifeng Dai W Authorized Title: Alaska Drilling Manager Contact Email: Weifeng.DaiCcDcup.collIl Authorized // Contact Phone: 263-4324 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 10404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 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 tb: 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 5/2017 Submit ORIGINAL Only CD5 - 25 Alpine A & C Multi-Lat Injector Updated 3/14/2018 20" 94# H-40 Welded Conductorto 114' Landing Nipple, 3.813"X Gas Lift Mandrel 3,510' MD 10-3/4" 60# L-80 H563 Surface Casing cemented to surface Gas Lift Mandrel 5,765' MD 4-1/2" 12.6# L-80 HYD563 7 5/8" 29# L-80 Hyd 563/BTCM Intermediate Csg 8,459' Top of Cement 6,655' Gas Lift Mandrel, KBMG 7,216' �J Upper Completion: 1) 4-Y2" 12.6#/ft HYD563 2) Shallow nipple profile, 3.813" X 3) (3) 4-%" x 1" Camoo KBMG GLM (xx°) w/DCK2 pinned for 2500 psi casing to tbg shear 4) Baker Premier Packer 5) CMU sliding sleeve 6) 3.813" X 7) 3.813" XN 8) Seals A Sand Lower Completion: 8) Two 4.5" 12.6# L80 TXP Liners with Perf Pups 9) ZXP liner top packer & Flexlock Liner Hanger X0 5" HYdril 521 Box X 4-%° TXP pin C Sand Lower Completion: 10) Two plop and drop liners, 4.5" 12.6# L80 TXP with Perf Pups 4-1/2" 12.6# L-80 TXP Liners with Perf Pups A sand Liner #1: 19,108' — 20,028' A sand Liner #2: 8,269'— 9,388' C Sand Liner#1: 13,269' -19,824- C 3,269' -19,824'C sand Liner #2- 8,227' —9,238' Baker Premier Production Packer" - - -- -- - 7,284' CMU Sliding Sleeve�`y::::.. 7,352' .:ci::::.. o Landing Nipple, 3.813"X-:,s,,<EfiEEEifEEEiE;%sl:E<:>.:::;:;- --------- 7,409' Landing Nipple, 3.813"XN 7,453' ZXP liner top packer 8,269' C aerld 6 8,1 A sand Lateral 6 3/4" Hole TD 8,470'- 30,218' 4 WNS PROD CD5-25 ConocoP�II��I 5 Wen A@ribete P R reaNvuwl Max Angle " TD Alaska, inc. waloore snag •I ��.,.,.. CONDUCTOR, SURFP E. CM&LIFT. COm G99 VACNEN; 7. U.N SUOINOSLEE INTERMEDIATE; LINEF,EM 9E9n.O. I I LINEN; I9.ICS,7.XMo Lan WNS CD Conoc6MIilllps MellAttributE MaxAngle , Maska.lnc. ^rom arucwl mellM,e .— TO MO IXI .,D,.G LIXEP W EM CAS LIR', Com Com GNerations Summary (with Timelog Dtf,ths) CD5-25 Rig: DOYON 19 Time Log. Job: DRILLING ORIGINAL S=Tkne 1/24/2018 Ertl Titus 1/24/2018 Dur(hr) 1.25 Phase MIRU pp Code MOVE AcwlH �etle Tare P -T -x OparaEon Stan Depth (flka) Ertl DspN(ai(e) 18:00 19:15 MOB P Move shed. 0.0 0.0 1/24/2018 19.15 1/24/2018 21.30 2.25 MIRU MOVE MOB P Hold PJSM, move pit/motors, spot 0.0 wellhead in cellar, skid rig floor, raise 0.0 1/24/2018 1/24/2018 1.25 MIRU MOVE cellar windwalls, raise support f eet. 21:30 22:45 MOB P Raise Sub, remove shims, pull away 0.0 0.0 from CD5-23. Tum fires & crab, move MPD & wellhead equip to CD5-25 1/24/2018 1/25/2018 1.25 MIRU MOVE MOB cellar, crab to CDS-25. 22:45 00:00 P Set down Sub, tum fires to spot on 0.0 0.0 CD5-25. Clean CDS-23 cellar. Set 1/25/2018 1/25/2018 1.00 MIRU MOVE MOB hydraulic unit on Sub with crane. 00:00 01:00 P Wells G oup spot flow) ne manifold 0.0 0.0 1/25/2018 01:00 1/25/2018 02:00 1,00 MIRU MOVE MOB P behind rig. Spot/shim sub over CD5-25 0.0 0.0 well. 1/25/2018 02:00 1/25/2018 02:30 0.50 MIRU MOVE MOB P Lowerstompers/windwalls. 0.0 0 0 1/25/2018 02:30 125/2018 03:15 0.75 MIRU MOVE MOB -f5— Skid rig floor to drilling operations. 0.0 Suspended operations due to 0.0 Production need to my oroduntinn Operations Summary (with Timelog Depths) CDS-25 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Se End Time Dur ( Phase Op Code ACGWy Code Time P -T -X Operation Stan Depen (Me) End Depth(fll(B) 1/25/2018/2018 1/25/2018 0.7.7 5 MIRU MOVE SEOP P Fill Hole (39 bbls) & check for leaks. 84.0 84.0 23:00 23:45 Tighten lower Flange on riser /diverter. Test mud lines to 3500 psi. 1/25/2018 1/26/2018 0.25 MIRU MOVE REAM P Wash & ream f/ 84' to 115' at 450 gpm 84.0 115.0 23:45 00:00 w/ 570 psi, 40 rpm 1.5k TO. Shallow test MWD. Note: Landing ring to RKB = 36.98' GL to RKB = 36.58' 1/26/2018 1/26/2018 15.75 SURFAC DRILL DDRL P Drlg w/8.25"1.5'BH motor f/11Tic,F2,041.0 2,203.0 00:00 15:45 2203'. P/U-124k, S/0 -120k, RW - 120, TO -5.5k f/Ibs at 80 rpm, ADT=9.79 his, Rot hrs-8.17 hrs, Slide hrs-1.62 his, 800 gpm = 2290 psi 1/26/2018 1/26/2018 1.00 SURFAC CASING CIRC P Pump 29 bbl nut plug sweep, circ b/u 2,041.0 15:45 16:45 twice w/ 800 gpm w/ 2290 psi w/ 80 rpms while pulling from 2203' to 2041'. 1/26/2018 1/26/2018 0.50 SURFAC CASING OW -FF P Flow check well (static) w/ rotating @ 2,041.0 16:45 17:15 5 rpms. t/L6/2018 1/26/2018 1.50 SURFAC CASING PMPO P Pooh w/ pumps @ 800 gpm f/ 2041'to 1,380.0 17:15 18:45 1380'w/ 2200 psi. 1/26/2018 1/26/2018 0.25 SURFAC CASING CIRC P Circ b/u at 800 gpm w/ 2200 psi w/ 20 1,380.0 1,286.0 18:45 19:00 rpm at 1380 to 1286'. 1/26/2018 1/26/2018 0.25 SURFAC CASING TRIP T Attempt to pooh on elevators f/ 1286'. 1,286.0 1,286.0 19:00 19:15 Overpull of 20k to 25k. 1/26/2018 1/26/2018 3.00 SURFAC CASING PMPO P Pooh w/ pumps @ 50010 300 gpm f/ 1286.0 173.0 19:15 22:15 1286' to 173'. Flow check static. (attempt to pooh on elevators at 480', but swabbing) 1/26/2018 1/26/2018 0.25 SURFAC CASING SHAH P Pooh on trip tank f/ 173'to 84'. 173.0 84.0 22:15 22:30 1/26/2018 1/26/2018 0.25 SURFAC CASING CIRC P Circ @ 300 gpm w/ 270 psi. Flow 84.0 84.6- 22:30 22:45 check (stafic). Slowdown Topddve. 1/26/2018 1/27/2018 1.25 SURFAC CASING BHAH P Hold PJSM, L/d bha as per SLB N 84' 84.0 31.0 22:45 00:00 to 31'. (Calc fill -20 bbls, Actual fill= 95 bbls, losses over shakers) 1/27/2018 1/27/2018 0.25 SURFAC CASING SHAH P Finish I/d bha per SLB. 31.0 0.0 00:00 00:15 1/27/2018 1/27/2018 0.75 SURFAC CASING SHAH P Clear & clean dg floor, I/d bha tools & 0.0 0.0 00:15 01:00 P/u 10.75" casing tools via the B/S. 1/27/2018 1/27/2018 0.75 SURFAC CASING KURD P TUU to run 10 3/4" casing. R/u Volant 0.0 0.0 01:00 01:45 CRT, Bail extension, 10.75" elevators & 350t slips. Safety valve & crossover on floor and functioned same. 1/27/2018 1/27/2018 2.00 SURFAC CASING PUTB P Hold PJSM, Rih w/ 10.75" 45.5#, L-80 0.0 512.0 01:45 03:45 Hyd 563 Casing to 512'. Starting taking weight. 1127/2018 1/27/2018 0.75 SURFAC CASING PUTS P Wash down f/ 512'to 677'w/ 4 bpm, 512.0 677.0 03:45 04:30 80 psi. (hole unloading gravel at shakers) 1127/2018 1/27/2018 5.00 SURFAC CASING PUTS T Washing and spudding casing f/ 677' 677.0 698.0 04:30 09:30 to 698'w/ 1.5 to 7 bpm, 50-130 psi. Regain SOW at 682'. 1/27/2018 1/27/2018 0.25 SURFAC CASING CIRC T Circulate at 698' w/ 3-7 bpm w/60-220 698.0 698.0 09:30 09:45 psi. Slight packing off after break thru at 682'. Page 2139 Report Printed: 3/21/2018 DOYON 19 Phase Operations Summary (with Timelog Depths) CD5-25 Job: DRILLING ORIGINAL 09:45 111:00I I I I V V I r I unning detail f/ 698' to 14 j as per I 698.0 I 1,417.0 11:00 12:15 - ----- �1tu m o uprn wi izu psi ai 1 1,417.01 1,417.0 1d17' r6eou 1/27/2018 12:15 1/27/2018 14:00 1.75 SURFAC CASING PUTB P .-" p.'oc.n n, pmuc "w 9. RIH w/ 10.75" ceg f/ 1417' 2113'. 1,417.0 2,113.0 1/27/2018 14:00 1/27/2018 14:30 0.50 SURFAC CASING HOSO P M/U crossover it, hanger&landing it. 2,113.0 2,193.0 Land hanger at 2193' (shoe depth) (calc displacement -34 bbls, act disp- 15 bbls) 1 18 144:30:30 17:7/2018 17:00 2.50 SURFAC CEMENT CIRC P ro & Cond mud for cementi Cing 2,193.0 2,193.0 operations, staged pumps up to 8 bpm W/ 170 psi w/ reciprocating casing. No losses. 1/27/2018 17:00 1/27/2018 17:15 0.25 SURFAC CEMENT OWFF P Blow down topddve, r/u cmt hose, flow 2 ,1930. 2,193.0 check well. 1/27/2018 17:15 1/27/2018 18:15 1.00 SURFAC CEMENT SFTY P Hold PJSM for cementing operations 2,193.0 2,193.0 while eon8nue circulating & reciprocating @ 8 bpm. 1 18 18:158:15 1/27/2018 21:45 3.50 SURFAC CEMENT CMNT P Cement unit flood and pressure test 2,193.0 2,193.0 lines to 2500 psi w/ water. Pump 69.1 bbls of 10.5 ppg Mud push II @ 2.5 bpm w/ 245 psi. Drop top plug, Pump 316.7 bbls of 11.0 ppg DeepCrete lead @ 5.0 bpm w/ 800-1125 psi, followed by 61.7 bbls of 15.8 ppg tail cmt at 4.5 bpm at 720-1050 psi. Drop top plug. Dowell pump 20 bbls of water and switch to dg pump. Displace cement w/ 9.9 ppg wbm @ 8 bpm. Slow pump to 3 bpm after 173 bbls pumped. Cont displace at 3 bpm. Bump plug with 500 psi over. Pumped 1818 stks (.5 bbis over) Pressure up to 1120 psi and held for 5 min. Bled off and check floats, held ok. Cement in place at 21:40 hrs. Full returns. Approx 140 bbls of lead cement returns to surface. Reciprocated casing while cementing. Landed . hanger at 20:30 hrs as cement exited the shoe. 1/27/2018 21:45 1/27/2018 22:15 0.50 SURFAC CEMENT CIRC P Flush hanger&riser/diverter w/black 2,193.0 2,193.0 water. Function annular 3 times. Close annular (22:09 hrs.) and install 160 psi gauge for monitoring annulus pressure. 1/27/2018 22:15 1/27/2018 23:30 1.25 SURFAC CEMENT WOC P While WOC, dg down cement lines. 2,193.0 2,193.0 R/d Volant CRT & csg tools. Monitoring pressure beneath Annular - 10 psi. 1/27/2018 1/28/2018 23:30 00:00 0.50 SURFAC CEMENT WOC P While WOC, p/u SLB 9 718" x 11" bha 2,193.0 2,193.0 & rack back in derrick. Cleaning flowline & pits. 1/28/2018 1!28/2016 00:00 00:30 0.50 SURFAC CEMENT WOC P Wait on cement & monitor annulus 0.0 0.0 pressure -12 psi. Simops-P/U & rack back 88' of 9 7/8" x 11" bha per SLB, clean mud pits. Page 3/39 Report Printed: 3/21/2018 DOYON 19 04:00 Gperations Summary (with Timelog Depths) CD5-25 Job: DRILLING ORIGINAL pressure - 12 psi. Simops- Hold PJSM, & P/u & rack back 16 stds of new 14 ppf 4" DP (break in threads). Clean pits. Wait on cement & monitor annulus pressure - 12 psi. Simops - Service drwwks & ST80, change out dies, I/d down tools/equipment, clean mud pits. 05:00 09:00 -- "�� vVUUP Wait on cement & monitor annulus pressure - 18 psi. Simops - P/u & rack back 4" DP (41 stds, 51 stds total), 1/28/2018 1/28/2018 1.00 SURFAC CEMENT WOC Clean pits. 09:00 10:00 P Wait on cement & monitor annulus pressure - 16 psi. Simops - Prepare BOP test equipment, FOSV/Dart, test pump & fittings, connect choke lines, mechanic work on C/O manrider 1/28/2018 1/28/2018 0.50 SURFAC CEMENT OWFF winch on rig floor. 10:00 10:30 P OWFF, open annulus & OWFF (slight 1/28/2018 1/28/2018 0.50 SURFAC CEMENT RURD drip), open 20" annular. 10:30 11:00 P Release RT from hanger with right hand rotation. Back out and lay down 1/28/2018 1/28/2018 1.00 SURFAC CEMENT NUND 10.75" landing joint. 11:00 12:00 P Hold PJSM, pull & lay down 90' mouse hole. R/d flow bleeder/hole fill & drain 1/28/2018 1/28/2018 1.25 SURFAC CEMENT NUND lines. N/D surface riser. 12:00 13:15 P Lay down surface riser, function annular & clean same. Disconnect annular koomey hoses. Pull annular 1/28/20181/28/2018 1.00 SURFAC WHDBOP NUND and set on skid. 13:15 14:15 P N/U FMC wellhead. Test void & wellhead connector to 1000 psi for 10 1/7R/9M fJ oornn,.. __ _..__ min. CPAI witness. 14:15 15:30 1/28/2018 1/28/. 15:30 17:30 17:30 119:45 119:45 121:00 flow box, RCD clamp, 1502 MPD equip, bleeder/hole fill lines, Katch- Kan) install MPD test plug. Fill lines with water, test MPD equip to 250/1200 psi for 5/5/ min on chart. R/d down test equipment. Pull MPD test plug, install choke manifold and lines w/ water. Purge air from system. Test ROPE w/ 5" test it. Test Annu 4" Demco kill, valves #1, #2, #4-14, Auto & Man IBOP, choke bleeder, upper rams (3.5" x 6" VBR), HCR choke & kill, 5" FOSV & dart to 250/3500 psi. "Witness waived by AOGCC Rep Brian Bixby". Operations Summary (with Timelog Depths) CD5-25 • Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log StaM1Tima End Tme Dur (hd Phase Dp Code Activfly Code Thne P -T -X Operation Sbn Depen (ftKB) End DePM(Po(B) 1/29/2018 1129/2018 1.00 SURFAC WH DBOP BOPE P Continue testing w/ 5" TJ, Upper 0.0 0.0 00:00 01:00 Rams, man choketkill on stack, LPR to 250/3500 psi, for 5/5 min. (Note: troubleshoot speed head adapter leaking, tightened same with air impact) 1/29/2018 1/29/2018 Too SURFAC WHDBOP TOPE P Perform Accumulator test, FSP =2900 0.0 0.0 01:00 02:00 psi, PAC = 1550 psi, 200 psi attained in 38 sec, FSP attained in 144 sec, 4 N2 bottles average 2125 psi, tested remote panel in boiler room, Function flow meter & PVT alarms. Test blind rams & choke valve #3 to 250/3500 psi 5/5 min, perform poor boy gas buster flush w/ 1-3 bpm at 30 psi. Test super & manual chokes to 1100 psi, tested dg gas alarms. BOP test witness waived by Brian Bixby. 1/29/2018 1/29/2018 0.75 SURFAC WHDBOP RURD P Retrieve test plug, blow down choke & 0.0 0.0 02:00 02:45 kill lines, r/d test equip. Set FMC 10" I.D. wear bushing. Install 90' mousehole. 1/29/2018 1/29/2018 1.25 SURFAC CEMENT SHAH P Hold PJSM, M/U bha #2 & dh f/ 0 to 0.0 212.0 02:45 04:00 212'. Simops: Tested MPD equipment at 250/1200 psi 5/5 min. 1/29/2018 1/29/2018 0.75 SURFAC CEMENT TRIP P RIH w/ 5" HW & 5" DP f/ 212' to 19827. 212.0 1,982.0 04:00 04:45 (U/D/R = 122k) Cal/Act Disp = 26.82/26.5 bbis 1/29/2018 1/29/2018 0.50 SURFAC CEMENT DHEQ P7— Shallow test MWD w/450-850gpm, 1,982.0 1,982.0 04:45 05:15 890-1880 psi, 30 rpm, 2k TQ, Obtain SPRs #1 MP = 30/40 = 90/150 psi, #2 MP= 30/40 = 90/150 psi w/ 9.9 ppg, B/D Topdrive. 1/29/2018 1/29/2018 2.00 SURFAC CEMENT PRTS P Rig up & test 10.75" casing & 1,982.0 1,982.0 05:15 07:15 wellhead annulus valves to 3500 psi for 30 min on chart. Pumped 3.5 bbls. (Note: 1502 sensor failed), Blow down topddve & rid test equip. (Simops: PJSM on cut & slip) 1129/2018 1/29/2018 1.00 SURFAC CEMENT SLPC P Slip &cut 45' of drill fine. 1,982.0 1,982.0 07:15 08:15 1/29/2018 1/29/2018 0.50 SURFACCEMENT SVRG P Service topddve & drawworks & iron 1,982.0 1,982.0 06:15 08:45 roughneck. Adjust drum brakes. 1/29/2018 1/29/2018 0.75 SURFAC CEMENT COCF P Wash & ream f/ 1982 to 2102'w/ 650 1,982.0 2,102.0 08:45 09:30 gpm, 1890 psi, 50 rpm, 2k TQ, tag cmt stringers. 1/29/2018 1/29/2018 1.75 SURFAC CEMENT DRLG P7 Drilg cement, plugs, FC, shoetrack & 2,102.0 2,203.0 09:30 11:15 shoe & rathofe f/ 2102' to 2203'w/ 500 -650 gpm, 1210-2100 psi, 40-60 rpm, 2-7k TO, 3-20k WOB. (FC -2112', Shoe -2193') 1/29/2018 1/29/2018 0.25 SURFAC CEMENT DDRL P Drilling new formation f/220 —to 2,203.0 2,223.0 11:15 11:30 2223'. ADT=.14 hrs, TVD = 2210' 1/29/2018 1/29/2018 0.75 SURFAC CEMENT CIRC P Pump 29.5 bbls of HV spacer ahead & 2,223.0 2,223.0 11:30 12:15 displace to 9.6 ppg LSND mud. 1920 ICP & 1530 FCP. Obtain new sprs w/ 9.7 ppg mw. Flow check, static. Page 5/39 Report Printed: 3/2112018 • --- Operations Summary (with Timelog Depths) CD5-25 .. Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Depen Stsrt7we End Tena Du inn Phase Op Cade Activity Coda Tone P -T -x Operation (ftKB) EM Depth (f!10) 1/29/2018 1/29/2018 1.00 SURFAC CEMENT FIT P R/u for FIT at 2169'. Break circulation 2,223.0 2,223.0 12:15 13:15 down choke line & drill string. Shut in pipe rams. Pumping down annulus & drillstring simultaneously, perform FIT - to 980 psi (18.3 ppge max). After shut in for 10 min, pressure decreased to 915 psi. B/D lines & RID. 1/29/2018 1/29/2018 0.25 INTRMI DRILL REAM P Wash & ream f/ 2169'to 2223'@ 670 2,223.0 2,223.0 13:15 13:30 gpm, 1570 psi, 30 rpm, 1.5k TQ. 1/29/2018 1/29/2018 1.00 INTRMI DRILL DDRL P Drilling f/2223'to 2327'. 2,223.0 2,327.0 13:30 14:30 1/29/2018 1/29/2018 0.75 INTRMI DRILL CIRC P Drop 1.25" Todon ball to open reamer. 2,327.0 2,327.0 14:30 15:15 Pump down @ 150 gpm w/ 140 psi (420 stks), 250 gpm w/ 230 psi for 5 min, then stage pumps to 670 gpm w/ 1180 psi. Initial TRPM=2734 PSI =1620, After ball drop, TRPM=2148 PSI=1180 (indication of reamer open). Back ream to 2305 w/ 800 gpm 1640 psi. Shutdown RPMs, pull IOk overpull against shoe (indication reamer open). Ream down opening hole to 11"from bit depth to 2327', 1/29/2018 1/30/2018 8.75 INTRMI DRILL DDRL P Directional drill 97/8"x11" 2,327.0 3,975.0 15:15 00:00 intermediate section f/ 2327'to 3975' MD, (3943' TVD) with 800 gpm, 2160 psi, 10.5.11.0 ppg ECD, 20-30k WOB, 160 rpm, on btm TQ -9.5k, off btm - 2- 4k TQ. At 3773', U/D/R/=153/143/152k ADT=6.75 hrs. 1/30/2018 1/30/2018 12.00 INTRMI DRILL DDRL P Directional drilling 9 7/8" x 11" 3,975.0 6,076.0 00:00 12:00 intermediate section f/ 3975 to 6076' MD, (6025' TVD). (800 gpm w/ 2340 psi, 10.6. 10.8 ppg ECD, 15-20k WOB, 160-180 rpm, on btm TQ -10k, off btm TQ -3k, U/D/R=195/185/195k @ 6032'. ADT=8.55 hrs. 1/30/2018 1/30/2018 4.50 INTRMI DRILL DDRL P Directional drilling 97/8" x 11" 6,076.0 6,599.0 12:00 16:30 intermediate section f/ 6076' to 6600' MD w/ 800 gpm w/ 2570 psi, ECD - 10.83 ppg, RPMs -180, TQ -9.5k ft/lbs on btm, TQ -5k ftnbs off btm. ADT=3.6 hrs 1/30/2018 1/30/2018 0.75 INTRMI DRILL CIRC P Circulating blu @ 800 gpm w/ 2610 6,599.0 6,599.0 16:30 17:15 psi at 150 rpm w/ 5-8k TQ, reciprocating f/ 6600'-6505'. 1/30/2018 1/30/2018 0.25 INTRMI DRILL OWFF P Flow check - static. Blow down 6,599.0 6,599.0 17:15 17:30- topdrive. 1/30/2018 1/30/2018 0.50 INTRMI DRILL MPDA P Pull trip nipple & install RCD bearing 6,599.0 6,599.0 17:30 18:00 section. 1/30/2018 1/30/2018 0.25 INTRM1 DRILL MPDA P Wash down f/ 6505'to 6600' at 800 6,599.0 6,599.0 18:00 18:15 gpm w/ 2700 psi, 50-100 rpm, 3.5k to 4.5k TQ. Break in RCD bearing at 50/100 rpm. Calibrate MPD chokes. Page 6139 ReportPrinted: 3/21/2018 Operations Summary (with Timelog Depths) CD5-25 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Depth Siad Time End Tim Dur(hr) Phase Op Cade Activity Code Time P-T-X operation (flKB) End Dspth(Wfi) 1/30/2018 1/31/2018 5.75 INTRMI DRILL DDRL P Directional drilling 97/8"x11" 6,599.0 7,209.0 18:15 00:00 intermediate section f/ 6600' to 7209' MD, (TVD-7058') weighting up mud f/ 10.0 ppg to 10.5 ppg in two increments, w/ 800 gpm, 2850 psi, WOB-10-20k, RPM-160-180,10k TQ on btm, 5k TQ off btm, ECD 11.5 ppg, maintaining 11.3 ppg EMW during connections. U/D/R=2221180/180k 6977'. ADT=7.91 his 1/31/2018 1/31/2018 11.75 INTRMI DRILL DDRL P Directional drilling f/ 7209'to 8188' MD 7,209.0 8,188.0 00:00 11:45 (TVD-7483'), w/ 12-15k WOB, 180 rpms, 825 gpm w/ 3300 psi, 10.5k TO on btm, 7k TO off btm, ECD-11.48 ppg, U/D/R=225/200/210k, maintaining 11.25 ECD w/ MPDE on connections, Observed return flow out decrease f/ 49% to 23%. ECD also decreased f/ 11.49 ppg to 10.96 ppg. Mud losses of 300+ bhp initial loss rate. ADT-8.9 hrs. 1/31/2018 1/31/2018 3.75 INTRMI DRILL CIRC T Circulate at reduced rate of 500 gpm 8,188.0 8,188.0 11:45 15:30 w/ 1420 psi, 120 rpm, 6.5k TQ, monitoring losses of 300 bph initially for 5 min & reducing to 60 bph loss rate, lowering mud weight f/ 10.5 ppg to 10.3 ppg. Maintain ECD of 11.1 ppg. Losses continue to reduce to only 6 bph. Total losses of 78 bbls to formation. 1/31/2018 1/31/2018 4.50 INTRMI DRILL P Directional drilling f/ 8188'to 8470' MD 8,188.0 8,470.0 15:30 20:00 (TVD-75161 w/ 15k wob, 825 gpm w/ iDDRL 3350 psi, 11 k TQ on btm, 7k TQ off btm, ECD 11.2 ppg. 1131/2018 1/31/2018 0.25 INTRMI CASING SRVY P Take final on bottom survey w/ SLB & 8,470.0 8,470.0 20:00 20:15 take SPRs w/ 10.3 ppg mud wt. 1/31/2018 2/1/2018 3.75 INTRMI CASING CIRC P Circ btu cleanup cycles f/8470'to 8,470.0 8,298.0 20:15 00:00 8298'w/ 820 gpm w/ 3270 psi, 150 rpm, 6.9k to 9k TQ. Input into mud system 275 bbls of dilution, pumped 32 bbl LCM sweep. Racking one stand back every 2.5 B/U. ADT-3.63 his. 211/2018 2/1/2018 1.50 INTRMI CASING CIRC P Circulate w/ 800 gpm, 2960 psi, 120 8,298.0 8,204.0 00:00 01:30 rpm f/ 8298' to 8204' weighting up with spike fluid f/ 10.3 ppg to 10.6 ppg. Maintain 11.25 ppg ECD w/ MPD on connections. 2/1/2018 211/2018 3.50 INTRMI CASING CIRC P Circulate while continue to weight up f/ 8,204.0 8,110.0 01:30 05:00 10.6 ppg to 10.8 ppg w/ sack barite (bulk barite system plugged and packed off) f/ 8204' to 8110' w/ 800 to 635 gpm, 120 rpm, 2960-2000 psi. Obtain parameters to close rhino reamer. Obtain new spr's w/ 10.8 ppg mud. UID/R=23011931210K. 2/112018 2/112018 0.25 INTRM1 CASING OWFF P OWFF,Slatic. (simops: Blowdown 8,110.0 8,110.0 05:00 05:15 top drive). Page 7139 Report Printed: 3/2112018 Gperations Summary (with Timelog Drpths) CD5-25 • Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Stan Tana EM Time Dn av) Phase Op Code CASING ACIvitr Code CIRC Thee P -T -X P Opemtlon Drop 1.625" ball & pum w/ 250-150 MKB) 8,110.0 End Depth (lKB) 8,015.0 2/1/2018 2/1/2018 0.75 INTRMI gpm w/ 490-290 psi. Ball on seat wl 05:15 06:00 1050 stks pumped. Shear seen at 1790 psi & observe reamer shift dose. Pump w/ 625 gpm wl 2180 psi, MTRPM=2695, verifying the rhino reamer is closed. BROOH fl 8110 to 8015 wl 625 gpm w/ 2180 psi, 70 rpm, 6-8 TQ. Blow down top drive & line up MPD to SOON. 2/1/2018 2/1/2018 0.50 INTRMI CASING SMPD T SOOH holding 240/150 AP pull/slips f/ 8,015.0 8,015.0 06:00 06:30 8015' to 7987'. Pulling tight w/ 35k initial overpull @ 798T. Pull 80k over and unable to pass 7982'. Taking more SOW to break over going down each time. (50k more on down wt, after 80k over upwards) Prepare to Brooh. B/D MPDE (U/D=2501193k) 2/1/2018 211/2018 3.00 INTRMI CASING BKRM P BROOH fl 8015'to 7542'w/675 gpm, 8,015.0 7,542.0 06:30 09:30 1900 psi, 80 rpm, 6 k TQ. Pack off issues at 7542' wl 2000 psi. ECD spike fl 11.5 ppg to 11.98 ppg. 2/1/2018 2/1/2018 0.50 INTRMI CASING CIRC T Circulate w/ 430-150 gpm while 7,542.0 7,542.0 09:30 10:00 rotating & reciprocating pipe due to packed off section at 7542'-7571' wl 1180 to 1280 psi, 25 rpm w/ 5.5k TQ. 2/1/2018 2/1!2018 7.50 INTRMI CASING BKRM P Continue to BROOH w/ 500-650 gpm 7,542.0 6,977.0 10:00 17:30 f/ 7542' to 6977'W/ 1490-2320 psi, 80 rpm, 51k TQ at 1007hr. Shakers loaded with sloughing/splintering shales/clays. 2/1/2018 2/1/2018 INTRMI CASING CIRC T Circulate (3x) b/u at 650-690 gpm, 120 6,977.0 6,882.0 17:30 19:30 rpm, 5k TQ. f/ 6977' to 6882'. 2/1/2018 2/1/2018 INTRMI CASING SMPD P Blow down topdrive, line up MPD to 6,882.0 2,169.0 19:30 23:15 SOOH (holding 160 psi on well wl line up MPD), SOOH f/ 6882'to r3.75 2169'(holding 160 psi in slips & 240 psi w/ stripping out). 2/112018 211/2018 INTRMI CASING OWFF P Flush MPD lines, OWFF -static, Hold 2,1690 2,169.0 23:15 23:30 PJSM in simops for RCD removal. 211/2018 222018 INTRM1 CASING MPDA P Pull MPD element, install trip nipple. 2,169.0 2,169.0 23:30 00:00 212/2018 2/212018 0.75 INTRMI CASING CIRC P Circ blu @ 2169' MD, pumping 2 NP 2,169.0 2,169.0 00:00 00:45 sweeps around at 690 gpm w/ 1910 1 psi wl 120 rpm, 1.5k TQ. OWFF- static, B/D Topddve. 2!2/2018 2/2/2018 1.00 INTRMI CASING TRIP P Pooh on trip tank fl 2169'to 853'. 2,169.0 853.0 00:45 01:45 2/212018 2/2/2018 0.25 INTRMI CASING OWFF P OWFF-static. 853.0 853.0 01:45 02:00 2122018 2/2/2018 0.50 INTRM1 CASING TRIP P Pooh fl 853' to 212' on trip tank. 853.0 212.0 02:00 02:30 2122018 2122018 1.50 INTRMI CASING BHAH P Pooh & Vol BHA #2 fl 212' to surface. 212.0 0.0 02:30 04:00 (calclact fill '= 74.2/100.5 bbis) 2212018 2/22018 0.75 INTRMI CASING BHAH P Clean & clear rig floor f/ tithe handling 0.0 0.0 04:00 04:45 & wet trip. (simops: m/u stack washer and flush bop stack w/ 690 gpm, I/d stack washer & B/D mud line). Page 8/39 Report Printed: 312112078 Utierations Summary (with Timelog L�pths) CD5-25 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Time Er�B TBBB Daf(hd Phase W Code ACBNry DBtlB Time P -T-% op""m start Depth Me) Entl Dagh (aIQ)) 21212018 2/2/2018 1.00 INTRMI CASING BOPE P PJSM, Change out upper pipe rams f/ 0.0 0.0 04:45 05:45 3.5" x 6" VBRs to 7.625" casing rams. (simops: R/u Volant CRT, bail ext, clean mud pump suction chambers/screens & discharge screens). 2/2/2018 2/2/2018 1.00 INTRM1 CASING BOPE P FMC pull 10" I.D. wearbushing, set 0.0 0.0 05:45 06:45 test plug & 7 5/8" test joint. Fill stack w/ water, R/u test equipment. 212/2018 2212018 1.00 INTRM1 CASING BOPE P Test 7 5/8" test joint & Annular to 0.0 0.0 06:45 07:45 2502500 psi for 5/5 min. Test Casing rams against 7 5/8" to 250/3500 psi for 5/5 min. R/d test equip, FMC set 10.375" I.D. thin wall casing wear bushing, I/d landing P. 2/2/2018 0.50 INTRM I CASING RURD P R/u to run 7 518" casing. 0.0 0.0 07:45 07:45 08:15 2/22018 222018 10.75 INTRM1 CASING PUTS P PJSM, Run 7 518"29.7#, L-86TXP 0.0 4,005.0 08:15 19:00 rasing f/ Y to 4005'. Baker lock shoe track & test float equipment. Tenaris Rep on site utilizing Torque Tum equipment in conjuction with the Volant CRT. Fill casing each jt & top off every 10 its. (Compare top drive torque w/ Volant CRT torque values - good matching values). X -O & safety valve on rig floor for casing connections, functioned same (left open position). S/0=140k 22/2018 2/22018 1,00 INTRM1 CASING CIRC P Break circ @ 1 bpm w/ 200 psi, stage 4,005.0 4,005.0 19:00 20:00 pump up in .5 bbl increments to 5 bpm W/ 140 psi. Ciro b/u. Reciprocate f/ 4010' to 3970'. Max mud weight noted was 11.1 ppg while maintaining 10.8 ppg in. 22/2018 2122018 3.50 INTRM1 CASING PUTB P Continue running -7 5/8" casing to 4,005.0 5,875.0 20:00 23:30 5875'. P/u -200k, S/o-180k, Observed loss in pipe displacement, slow running speed from 2200 fUhr to 1300 fl/hr with no change in loss of displacement. Lost 11 bbls in the last 7Its ran. 2/2/2018 2/32018 0.50 INTRM1 CASING CIRC P M/U joint #148 in the 7 518" csg tally. 5,875.0 5,875.0 23:30 00:00 Break circ w/ 0.5 bpm w/ 260 psi. Stage pump slowly up to 1.8 bpm, while reciprocating csg f/ 5916'to 5891'. P/U=200k, S/0=190k. Pumped a total of 97 bbls. Losing 28% of mud returns pumped at 1.8 bpm. Lost a total of 28 bbls. 2/3/2018 2/3/2018 0.75 INTRM1 CASING CIRC P Break Circ & stage pump up to 1.8 5,875.0 5,875.0 00:00 00:45 bpm w/ 280 psi, reciprocating pipe f/ 5916' to 5891' pumped 97 bbls & lost 28 bbls (28% loss rate). 2/3/2018 2/3/2018 8.75 INTRM1 CASING PUTB P Continue running 7 5/8" 29.7# L80 5,875.0 8,423.0 00:45 09:30 TXP & 29.06# RYS110 Eagle SFH casing f/ 5875'to 8423' MD. Slowed rated f/ 22007hr to 700''/hr due to losses. (Noted improvement in loss rate). (Torque tum w/ Volant CRT w/ Tenaris & Eagle reps) SOW=190k Filling casing each It & topping off every 10 jts. Page 9139 Report Printed: 3/2112018 DOYON 19 10:00 10:00 118:00 LNerations Summary (with Timelog Depths) CD5-25 Job: DRILLING ORIGINAL landing it. Land casing on hanger at 8459.70'. break over w/ 2751k P/U & 2001k S/O. Stage up pumps to 2.5 bpm w/ 410 Psi. working casing string f/ 8459' to 8432' MD. Circ & cond mud for cmt job, cutting mud wt f/ 10.8 ppg to 10.6 ppg. Heaviest mud wt noted was 11.2 ppg w/ 2150 stks pumped. Cont staging up to 5.5 bpm w/ 270 psi. (Simops: R/d 7 5/8" csg elevators, bail ext, remove batteries f/ Volant CRT TT system, clean rig floor, L/d 350T slips) 18:00 18:30 UIKU P I R/u cement hose & continue circulating @ 5.5 bpm w/ 420 psi while hold PJSM for cementing operations. 18:30 21:30 rump cement as per plan: Mix & PUMP 37.1 bbls of 11.5 ppg mud push spacer @ 3 bpm, 380 psi. Drop btm Plug, pump 25.7 bbls of 12.2 ppg Lead @ 3.2 bpm w/ 500 psi & 63.4 bbls of 15.8 ppg tail @ 4.5 bpm w/ 750 psi. Load top plug. (Note: while loading top plug, observed the bottom plug was still in place with the rupture disc burst 4' down in casing) Kick out Plugs w/ 20 bbls of fresh water @ 5 bpm w/ 500 psi. ppg wbm @ 5.5 bpm initially trying to Catch cement (110 psi). Cont to reciprocate string w/ 260k P/U & 220k S/O. Landed on hanger after 150 bbls Pumped due to drag increasing. Staging pump rate down to 5 bpm w/ 100 psi at 234 bbls pumped, 4 bpm w/ 167 psi at 234 bbls pumped, Continuing slowing pump to 3.5 bpm, to 2.0 bpm. Bump plug w/ 361 bbls Pumped, apply 500 psi over (1000 Psi), pressure decreased to 700 psi. Pumped 2.3 bbls with a total of 3609 stks pumped (calculated stks-3642). Pressure held solid fors min. Bleed off pressure, check floats (holding). CIP at 21:33 hrs. Full returns, no losses. 21:30 2230 --- -'"' 11—F nunu r R/d cement equipment while OWFF. 8,459.0 8,459.0 2018 2/3/2018 0.50 INTRMI CEMENT RURD �D75/8'?Iandndrointain SPulk 22:30 23:00 P g 1 8,459.0 8,459.0 2018 2/3/2018 0.50 INTRMI CEMENT ywygP P wearbushing. 23:00 2330 Set 7 5/8" casing pack -off. Test to 8,459.0 0.0 2018 2/4/2018 0.50 INTRMI CEMENT RURD 5000 psi for 10 min. Good test. 23:30 00:00 P Hold PJSM &rig up floor to lay down 0.0 2/4/2018 2/4/2018 2.25 INTRMI CEMENT PULD 5" DP in mousehole. 0.0 00:00 02:15 P Lay dawn 5" DP & 5" hw[ in 0.0 mousehole (7 stds hwt & 15 stds DP). 0.0 (Simops: Cleaning mud pits) Page a Uverations Summary (with Timelog Dtpths) CD5-25 Rig: DOYON 19 Time Log Job: DRILLING ORIGINAL Start Time 2/4/2018 End Time 2/4/2018 Cur (hr) 0. 50 Phase INTRMI Cp Code CEMENT Activity Code SVRG Time P-T-XStart Operation Depth (flKB) End Depth (MS) 02:15 02:45 P Service rig, Drwwks, & ST80 w/ 0.0 0.0 replace fuse in pipe skate kickers. Simops: Cleaning mud pits. 2/4/2018 02:45 2/4/2018 08:00 5.25 INTRMI CEMENT PULD P Continue to LID 5" DP from derrick via 0.0 0.0 the 90' mousehole (81 stds total). Simops: Service choke manifold & stack valves, cleaning mud pits. 2/4/2018 08:00 2/4/2018 11:00 3.00 INTRMI CEMENT BOPE P Hold PJSM, change out UPR f/ 7 5/8" p,0 0.0 casing rams to 3.5"x6" VBRs. Simops: Change out saver sub f/ 4.5" IF to 4" XT -39, cleaning mud pits. Note: Freeze protected 10 3/4" x 7 5/8" annulus (performed LOT, then flushed with 300 bbls of water, followed by 81 bbis of diesel, 2/4/2018 11:00 2/4/2018 12:00 1.00 INTRMI WHDBOP RURD P P/u 4" test jt & Test plug, r/u to test 0.0 0.0 BOPE, FII choke/kill/stack & choke manifold with water & purge air f/ 2/4/2018 12:00 2/4/2018 16:30 4.50 INTRMI WHDBOP BOPE system. P Held PJSM, Test BOPE w/ 4" & 4.5" 0.0 test joints to 250/3500 psi for 5/5 min 0.0 each. Chokes tested to 1100 psi. On 4" TJ, tested Annular, 4" Demco, #1,12,13,14, upper IBOP, upper 3.5" VBR, HCR kill, #9,11, Man IBOP, #5,8,10, XT -39 Dart, #4,6,7, XT -39 FOSV, #2, HCR choke, Man choke/kill, Lower 3.5" x 6" VBR. On 4.5" TJ, tested Annular, upper 3.5"w' VBR, lower 3.5"x6" VBR, #3,4,6 Valves. Tested Blind rams. Flow test Hyd and man chokes. Accumulator test -system pressure=2850 psi, Annu - 750 psi, After function all components: Sys psi=1450 psi, Man psi=1200 psi, Ann psi=750 psi. 200 psi recovery=26 sec. TSR=149 sec, 4 bottle N2 avg=2150 psi, Testetl all rig gas alarms. Test witness waived by Brian Bixby AOGCC. 2/4/2018 16:30 2/4/2018 17:00 0.50 INTRMI WHDBOP RURD P Pull Test Plug, install FMC wear 0.0 2/4/2018 2/4/2018 0.50 INTRMI CEMENT RURD bushing. I.D. -7.125., P 0.0 17:00 17:30 Blow down lines, r/d testing 0.0 0.0 2/4/2018 17:30 2/4/2018 19:30 2.00 INTRMI CEMENT SHAH equipment. P Hold PJSM, P/U 6.75" bit & bha #3 to 0.0 344'. 344.0 2/4/2018 19:30 2/4/2018 20:30 1.00 INTRMI CEMENT TRIP P TIH to 2430' MD w/ new 4" #14 DP, f/ 344.0 2,430.0 2/4/2018 20:30 21:00 2/4/2018 0.50 INTRMI CEMENT SVRG derrick. P Service rig w/ reset faults on topdrive. 2,430.0 2,430.0 2/4/2018 2/4/2018 21:00 22:30 1.50 INTRMI CEMENT QEVL P Shallow test MWD. Downlink to MWD 2,430.0 2,525.0 & set to fast record motle. Log down with Sonic tool over "free ringing pipe" 112428 to 2525'. Attempt to downlink two times to set in slow record mode but could not get confirmation of the downlink. (Assume tool is still in fast record mode which has 27 hrs of memory at this usage rate) ReportPrinted: 3/21/201 Uo:4o U6:15 (,t erations Summary (with Timelog D ,,jths) -- "—"' ' " --a •- • —U ••• — ".'..' iaev psi if 8036' to 8081' MD (SO). RA tag @ 0'000.0 6,131.0 C D5-25 8074.63 (bit depth) 8013' actual depth. Rig: DOYON 19 Locate RA tag with RPMs, RA tag @ Time Log 2/5/2018 11:00 2/5/2018 11:15 0.25 INTRMI Job: DRILLING ORIGINAL Stan Time 2/4/2018 End Time 2/5/2018 Dur(hn 1.50 Phase INTRMI Op Code CEMENT Activny Code rime P -T -X Open' n Stan Depth (�I End Depth f%KB) 22:30 00:00 TRIP P Continue to TIH f/ 2525'to 4500' MD 2,525.0 4,500.0 2!5/2018 06:15 2!5/2018 07:30 1.25 INTRMI CEMENT QEVL P W/ 4" #14.0 DP f/ Drk. 8,131.0 8,321.0 00:0 018 OD:00 2/5/2018 00:30 0.50 INTRMI CEMENT TRIP P TIH w/ 6.75" bha f! 4500'to 5566'. 4,500.0 5,566.0 2/5/2018 00:30 215/2018 05:45 5.25 INTRMI CEMENT QEVL P Single in w/ 4" DP f/ pipe shed logging 5,566.0 8,036.0 8226'w/ 40 rpm, 4k TO. Continue w/ Sonicsoope to locate TOC @ 2/5/2018 12:00 0.50 INTRMI CEMENT DRLG P wash down to 8321' MD, verify ALP 8,363.0 8,374.0 2/5/2018 900''/hr max rate f/ 5566' to 8036' MD, 2.50 INTRMI CEMENT, DRLG P "C" depth in real time @ 8221' MD. 12:00 14:30 filling pipe each 20 stds. Verify (Simops: prepare for csg test) 8,374.0 8,470.0 Sonicscope In fast/high memory U/DtR=175/160/145k 2!5/2018 07:30 2/5/2018 07:45 0.25 INTRMI mode. QEVL P 2/5/2018 215/2018 0.50 INTRMI CEMFNT ni nr o slow/low memory mode. B/D tondrive Uo:4o U6:15 -- "—"' ' " --a •- • —U ••• — ".'..' iaev psi if 8036' to 8081' MD (SO). RA tag @ 0'000.0 6,131.0 8074.63 (bit depth) 8013' actual depth. Locate RA tag with RPMs, RA tag @ 2/5/2018 11:00 2/5/2018 11:15 0.25 INTRMI CEMENT CIRC P 8073.63' MD. (Impulse Sensor 8,321.0 8,321.0 located 61.13' above the bit. Cont sonic logging fl 8077' to 8131'. 2!5/2018 06:15 2!5/2018 07:30 1.25 INTRMI CEMENT QEVL P Wash down w/ 225 gpm —W/1380 psi f/ 8,131.0 8,321.0 8131' to 8145' MD. Tag up on cmt stringer w/ 10k down. W/R f/ 8145' to 8226'w/ 40 rpm, 4k TO. Continue 215/2018 11:30 2/5/2018 12:00 0.50 INTRMI CEMENT DRLG P wash down to 8321' MD, verify ALP 8,363.0 8,374.0 2/5/2018 2/5/2018 2.50 INTRMI CEMENT, DRLG P "C" depth in real time @ 8221' MD. 12:00 14:30 (Simops: prepare for csg test) 8,374.0 8,470.0 U/DtR=175/160/145k 2!5/2018 07:30 2/5/2018 07:45 0.25 INTRMI CEMENT QEVL P SLB switch mode on sonicsoope to 8,321.0 8,321.0 slow/low memory mode. B/D tondrive 107:45 10:00 30 min on chart. B/D lines & r/d test equip. (Simops: PSM on slip/cut drill line. auto driller drive line & adjust Crum 10:30 11:00 -- "—"' ' " a.eemet0 omcx negnt s MWD hook 8,321.0 8,321.0 load sensor. (Simops: build next std in 90' MH). 2/5/2018 11:00 2/5/2018 11:15 0.25 INTRMI CEMENT CIRC P Take SID w/#2 mutl pump=20 spm 8,321.0 8,321.0 =450 psi, 30 spm=640 psi @ 8321' w/ 10.4 ppg mud. 2/5/2018 11:15 2/5/2018 11:30 0.25 INTRMI CEMENT COCF P Was down f/ 8321'to 8363' MD w/ 8,321.0 8,363.0 240 gpm, 1680 psi. Tag ement stringers @ 8363'. (mode switch MWD W/ washing down). 215/2018 11:30 2/5/2018 12:00 0.50 INTRMI CEMENT DRLG P Drilling cement &plugs, FC w/ 160 8,363.0 8,374.0 2/5/2018 2/5/2018 2.50 INTRMI CEMENT, DRLG P gpm, 880 psi, 40 rpm 5 kTQ. 12:00 14:30 Clean out shoe track f/ 8374', tag shoe 8,374.0 8,470.0 @ 8459' MD w/ 220 gpm, 1530 psi, 80 rpm 2-8k TQ, 2-14k WOB. Clean out Whole f/ 8459'to 8470'MD. 2/5/2018 14:30 15:00 2/52018 0.50 INTRMI CEMENT DDRL P Drill new formation f/ 8470'to 8490' 8,470.0 8,490.0 MD w/ 220 gpm, 1600 psi, 80 rpm.3 - k TQ, 4-8k OB. 2/5/2018 2/52018 15:00 16:00 7.00 INTRMI CEMENT CIRC P Circulate & condition mud for FIT at 8,490.0 8,490.0 230 gpm, 1680 psi, reciprocating pipe f/ 8458' to 8415' MD. Mud wt even at 10.3 ppg. Operations Summary (with Timelog Depths) CD5-25 Rig: DOYON 19 Time Log Job: DRILLING ORIGINAL Stat Time End Tme 2/5/2018 2/5/2018 Dur (hr) 1.00 Phase Op Cotle Activity Code Time P-T-xStart operation INTRMI CEMENT Depth (HKB) End Depih mKB) 16:00 17:00 FIT P R/u & perform FIT. Break circulation 8,490.0 8,490.0 down choke line and drill string. Shut in pipe rams. Pumping down annulus and drillstring simmultaneously, perform FIT to 12.5 ppge Mud wt. (apply 860 psi w/ 1.7 bbls pumped @ .5 bpm. 1 bbl of mud returned at bleed off. R/d test equip, monitor well, static. 2/5/2018 17:00 2/5/2018 17:30 0.50 PROD1 DRILL MPDA P Pull trip nipple, install RCD. 8,490.0 8,490.0 2/5/2018 17.30 2/5/2018 18.00 0.50 PROD1 DRILL MPDA P Stage pumps to 250 gpm, 1750 psi, 8,490.0 8,4 90 100 rpm & break in RCD while reaf/ m .0 8415' to 8490' MD. 2/5/2018 18:00 2/5/2018 23:30 5.50 PROD1 DRILL DDRL P Drill f/ 8490 to 9176' MD 7597' TVD, 8,490.0 9.176.0 ADT=4.26 hrs, P/U=173k, S/0=153k, Rot=163k, TO on btm=8k, off=3k, ECD=9.89 ppg, Displaced to 9.0 ppg FloPro while drilling started at -8512' MD. Had indication of the Alpine "A" sand. 2/5/2018 23:30 2/6/2018 00:00 0.50 PROD? DRILL CIRC P Circ b/u @ 250 gpm w/ 1480 psi, 100 9,176.0 rpm, 3k TQ, reciprocating if 9176' to 9,176.0 9081. 2/6/2018 00:00 2/6/2018 00:15 0.25 PROD1 DRILL CIRC P Continue circ blu w/ 250 gpm, 1480 9,176.0 9,176.0 Psi, 100 rpm, 3k TO off btm for fingerprinting. 2/6/2018 00:15 2/6/2018 00:30 0.25 PROD? DRILL OWFF p fingerprint. Shut down pump Perand ormwait 9,176.0 9,176.0 and wait 30 seconds, close MPD chokes and monitor for pressure increase for 3 min. Make connection while continue monitoring MPD chokes for a total of 8 minutes closed. No pressure build. No flow, well static. 2/6/2018 00:30 2/6/2018 12:00 11.50 PROEM DRILL DDRL P Directional drilling f/ 9176'to 10,885' 9,176.0 10,885.0 MD, 7616' TVD, wl 15k-WOB, 150- rpms, 275 gpms w/ 2050 psi, 10.2 ppg ECD, 7.7k -TQ on btm, 3k TO off btm. ADT=8.47 hrs. Closing MPD chokes on connections. U/D/R=170/1501160k. O/A = 260 psi. 2/6/2018 12:00 2/7/2018 00:00 12.00 PROD1 DRILL DDRL P Directional drilling f/ 10,885' to 12,937' 10,885.0 12,937.0 MD w/ 15k wob, 150 rpms, 275 gpm w/ 2355 psi, 10.55 ppg ECD, 8.7k TO on btm, 5k TO off btm, ADT=8.92 hrs, Closing MPD chokes on connections. U/D/R=177/133/160k. 0/A=250 psi @ 22:00 hrs. 2/7/2018 00:00 2/7/2018 12:00 12.00 PRODt DRILL DDRL P Directional drilling V 12,937'to 14,906' 12,937.0 14,906.0 MD, TVD -7694', w/ 270 gpm, w/ 2600 psi, 150 rpm w/ 10-12k TO on btm, 6k TO off btm, 15k WOB, 10.6-10.8 ppg ECD, MW=9.1-9.2 ppg, ADT -8.78 hrs. U/D/R=18511281160k. 2/7/2018 12:00 2/7/2018 20:00 8.00 PROD1 DRILL DDRL P Directiona l drilling f/ 14,906'to 16,213' 14,906.0 16,213.0 MD. (7711TVD) U/D/R=1901128/160k, 270 gpm, 2830 psi, 150 rpm, 11.9k TO on btm, ECD - 10.98 ppg Page 13/39 Report Printed: 3/21/2018 LNerations Summary (with Timelog Depths) CD5-25 Rig: DOYON 19 Time Log Job: DRILLING ORIGINAL Stan Time 2/7/2018 End Time 2/7/2018 Dor (hr) 1.00 Phase PROD1 Op Code DRILL Activity Code Time P-T-KStart operauon Depth (fiKB) End Depth (f KB) 20:0 21:00 CIRC p Circulate hole clean @ 270 gpm w/ 16,213.0 16,213.0 2800 psi w/ 100 rpm, 7.5k TQ, reciprocating pipe. (simops: prepare for RCD bearing change). 2/7/2018 21:00 2/7/2018 22:00 1.00 PROD1 DRILL MPDA P Flow check, -static. Change RCD 76,213.0 16,213.0 bearing. Break in w/ 50 & 100 rpm. (Observed mud level in annulus drop 2.47 bbls while changing RCD bearing.) 2/712018 22:02:00 2/8/2018 00:00 2.00 PROD1 DRILL DDRL P Directional drng f/ 16,213to 16,553' 16,213.0 16,553.0 MD, 7715' TVD w/ 150 rpm, 12.4k TO on btim, 7k TQ off btm, 265 gpm, 2670 psi, ECD -10.8 ppg w/ 9.1 ppg MW. 15k WOB, U/D/R=190/120/160k ADT=1.73 hrs O/A=200 psi @ 22:00 hrs. 018 00:0 00:00 2/8/2018 12:00 12.00 PROD1 DRILL DDRL P Directional Drng f/ 16,553to 18,579' 16,553.0 18,579.0 MD (TVD=7728') w/ 270 gpm, 3100 psi, 160 rpm, 13.5k TQ on btm, 1 Ok TO off btm, w/ 14k WOB, 9.1 ppg w/ 11.05 ppg ECD. U/D/R=195/110/155k. O/A=250 psi. ADT=9.45 hrs. 2/8/2018 12:00 2/9/2018 00:00 12.00 PROD1 DRILL DDRL P Directional drilling f/ 18,579'to 19,890' 18,579.0 19,890.0 MD (TVD=7762') w/ 268 gpm, 3170 psi, ECD -11.1 ppg, 160 rpm, 13.7k TO on btm, off btm TQ -91k, 10-15k WOB, U/D/R=200/100/158k, w/ 9.1 ppg MW. ADT=9.75 hrs, O/A=240 psi. Installing WWT SS since 14,974' MD. Avg losses of 22 bph while drilling. 2/9/2018 00:00 2/9/2018 12:00 12.00 PROD1 DRILL DDRL P Directionally drilling f/19,890'to 19,890.0 21,547.0 21,547' MD (TVD=7782') w/ 270 gpm w/ 3300 psi, 160 rpm, 15k WOB, 16k TQ on btm, 11.5k TO off btm, ECD - 11.43 Pp9 w/ 9.2 ppg MW. U/D/R=215/N/A/ 155k. (lost slack off weight at 20,800' MD with pumps on). ADT=9.05 hrs O/A=200 psi. 2/9/2018 12:00 2/10/2018 00:00 12.00 PROD1 DRILL DDRL P Directional drilling f/ 21,547'to 22, 688' 21,547.0 22,688.0 MD (TVD=7793') w/ 265 gpm, 3300 psi, 160 rpm, 16.3k TO on btm, 14k TO off btm, 10-15k WOB, ECD -11.2 to 11.4 PPg, 9.2 ppg MW, UID/R= 202/N/A/155k, ADT= 8.38 hrs O/A= 325 psi. Mud losses avg 21 bph. Total daily losses=510 bbls. 2/10/2018 00:00 2/10/2018 03:30 3.50 PROD1 DRILL DDRL P Directional drilling f/ 22,688'to 23,164' 22,688.0 23,164.0 MD (TVD -7795') w/ 260 gpm, 3400 psi, 10-14k WOB, 160 rpm, 17.5k TQ on btm, 12.5k TQ off btm, ECD -11.48 ppg, w/ 9.1 ppg MW U/D/R=212/NA/152k. ADT=3.21 hrs, 2/10/2018 2/10/2018 03:30 03:45 0.25 PROD1 DRILL SRVY P Obtain final directional survey, 23,164.0 23,164.0 downlink PD to neutral for tri PPing, take SPR's. Page 14139 Report Printed: 3/21/2018 Operations Summary (with Timelog Depths) C D5-25 Rig: DOYON 19 Job: DRILLING ORIGINAL Tim® Log start rung F10/2oP End Time Dur inn Phase Code Activity Code Time P -T -X Operation Stan Depen (ftKB) End Depth W) 2/10/2018 2.25 PROD1 DRILL CIRC P Circ b/u w/270 gpm, 3620 psi, 120- 23,164.0 23,164.0 03:45018 03:45 06:00 100 rpm, 12-13k TO, w/ reciprocating f/ 23,164' to 23,069' MD 2/10/2018 2/10/2018 2.50 PROD1 DRILL BKRM P BROOH f/ 23,164tto22,118' MD w/ 23,164.0 22,118.0 06:00 08:30 270 gpm, 3340 psi, 80 rpm, 13k TQ. Unable to obtain SOW w/ pumps on. Sucessfully obtain SIO without pumps w/ 90k down wt. 2/10/2018 2/10/2018 1.75 PROD1 DRILLCIRC P Circ b/u w/ 270 gpm, 3430 psi, 80 22,118.0 22,118.0 08:30 10:15 rpm, 12k TQ, while reciprocating pipe f/ 22,118'to 22,023' MD. U/D=235l100k 2110/2018 2/102018 0.25 PROD1 DRILL OWFF P BlD topddve, OWFF-static, w/ rotate 22,118.0 22,118.0 10:15 10:30 at 10 rpm w/ 11 k TQ. Prepare to SOOH. 2/10/2018 2/102018 1.50 PROD1 DRILL §MPD P SOOH f/ 22,118' to 20,783' -MD 22,118.0 20,783.0 10:30 12:00 w/360/80 psi out/in slips. P/U=224k. 2110/2018 12:00 2/10/2018 1.50 PROD1 DRILL SMPD P Continue SOOH f/ 20,873'to 19,315' 20,783.0 19,315.0 13:30 MD, 80/380 psi-in/out of slips. Observe 30k overpull at 19,315', Slack off to neutral wt at 19,346' MD. Make second attempt & had 40k overpull. Slade off to neutral weight of 170k. 2/10/2018 2/102018 0.50 PRODt DRILL CIRC P Break circulation, stage pump rate to 19,315.0 19,355.0 13:30 14:00 270 gpm, 3050 psi, 80 rpm, 11 k TO. Circ & wash to 19,355' MD. 2/10/2018 2/102018 3.00 PROD1 DRILL BKRM P BROOH f/ 19,355'to 19,070' @ 270 19,355.0 19,070.0 14:00 17:00 gpm, 3050 psi, 120 rpm, 10-13k TO, ECD -11.0 to 11.3 ppg. Observed micro packoffs during this interval. 2/102018 2/10/2018 1.00 PR0D1 DRILL CIRC P Circulate b/u @ 270 gpm wl 3050 psi. 19,070.0 19,070.0 17:00 18:00 ECD reducing 1111.16 to 10.77 ppg. 2/102018 2/112018 6.00 PROD1 DRILL §MPD P SOOH f/ 19,164' to 12,035' MD 19,070.0 12,035.0 18:00 00:00 holding 80/330 psi In/Out of slips. Observed overpull of 15k overpull at 13,757' MD. Work through one time to clear. O/A=175 psi. Lost 390 bbls to formation the last 24 hrs. 2111/2018 00:00 2/11/2018 2.75 15R0D1 DRILL SMPD P SOOH f/12,0357to 8415'MD as per 12,035.0 8,415.0 02:45 strip schedule holding 330/80 psi OuUln slips. P/U=170k 2111/2018 02:45 2/112018 1.00 PROD1 DRILL CIRC P Blow down MPD surface lines, Circ 8,415.0 8,415.0 03:45 BIU w/ 230 gpm, 1330 psi, 50 rpm, R/R 8415'to 8321' MD. (simops- PJSM on displacement) 2/11/2018 03:45 2/112018 1.25 PROD1 DRILL CIRC P Pump 32 bbl HiVis spacer, displace 8,415.0 8,415.0 05:00 wellbore f/ 9.0 ppg FloPro to 9.4 ppg Vis Brine w/ 240 gpm, 1060 psi, 50 rpm, 2k TO. U/D1R=165/156/162k. 2/112018 05:00 2/112018 0.50 PROD1 DRILL OWFF P OWFF-Static, obtain SPR's, blow 8,415.0 8,415.0 05:30 down topdrive. Simops: PJSM on removing RCD bearing. 2111/2018 05:30 2/112018 0.50 PR0D1 UPILL P Remove RCD bearing, install trip 8,415.0 8,415.0 06:00 nipple, line up on triptank. 2/11/2018 2/11/2018 06:00 11:45 5.75 PR01 DRILL TRIP P Pooh on triptank f/ 8415'10 344'. 8,415.0 344.0 Page 15139 Report Printed: 312112018 Riq: DOYON 19 C.Nerations Summary (with Timelog Drpths) CD5-25 Time Log JVU: UKILLINU VKIUINAL Stan Time 2/11/2018 End retie 2/11/2018 Dur (hr) 0.25 Phase PROD1 Op Cotle DRILL Activiy Code OWFF TMe p -T -X p annulus), SM Mpth (fl KB E��344.0 11:45 12:00 P OWFF-(slightdrep inn 344.0 Perform weekly BOPE function test (annular, UPR's, LPR's) 2/11/2018 12:00 2!11/2018 1.00 PR0D1 DRILL SHAH P PJSM, lay down bha #3 V 344'to 344.0 0.0 13:00 surface. (Pipe displacement=Cale(Act=140.2/244) 2/11/2018 13:00 2/11/201 B 0.50 PROD' DRILL SHAH P Clean rig floor. Simops: prepare for 0.0 0.0 13:30 bha #4. 2/11/2018 2/11/2018 1.00 PROD1 DRILL BHAH P WU bha #4 to 322' MD. 0.0 322.0 13:30 14:30 2/11/2018 14:30 2/11/2018 18:00 3.50 PROD1 DRILL PULD P RIH w/ 6.75" bha #4, picking up new 322.0 2,221.0 14# 4" DP in singles, breaking in connections to 2221' MD, filling every 20 stds. S/O=80k. 2/11/2018 18:00 2/11/2018 18:30 0.50 PROD' DRILL DHEQ P Shallow test MWD w/240 gpm, 940 2,221.0 2,221.0 psi. 2/11/2018 18:30 2/12/2018 00:00 5.50 PROD' DRILL PULD P Continue to A singles of 14# 4" DP, 2,221.0 6,020.0 breaking in connections f/ 2221' to 6020' MD. U/D=140/137k. Filling every 20 stds. O/A=50 psi @ 22:00 hrs. Lost 133 bbls to formation the last 24 hrs. 2/12/2018 00:00 2/12/2018 02:30 2.50 PROD1 DRILL PULD P RIH w/ #4 6.75" bha picking up new 4" 6,020.0 7,540.0 14# DP f/ 6020' to 7540' MD, breaking in each connection. Filling pipe each 20 stds. 2/12/2018 02:30 2/12/2018 03:00 0.50 PROD1 DRILL TRIP P TIH f/ tlrk w/ 4" 14# DP f/ 7540'to 7,540.0 8,015.0 80151. 2/12/2018 03:00 2/12/2018 03:30 0.50 PROD1 DRILL FLOG P Break circ w/ 265 gpm, 1250 psi, Log 6,015.0 8,110.0 RA tag @ 8013' casing depth, (bit depth 8073.6). Wash to 8110' 03:30 018 03:30 2/1212018 03:45 0.25 PROD1 DRILL TRIP P TIH f/tlrk w/ 4" 14# DP f/ 8110' to 8,110.0 8,395.0 8395' MD 2/12/2018 03:45 2!12/2018 05:00 1.25 PROD1 DRILL DISP P PJSM on displacement. Pump 28 bbl 8,395.0 8,395.0 HYs sweep, displace f/ 9.4 ppg KW Vis brine to 9.1 ppg FloPro w/ 225 gpm, 1380 psi, 30 rpm, 1.5k TQ. 2/12/2018 05:00 2/12/2018 05:30 0.50 PR0D1 DRILL OWFF P Obtain SPR's, OWFF-Static, blow 8,395.0 8,395.0 down topddve, Monitoring well on triptank, hold PJSM on cutting drill line. 05:30 018 05:30 06:30 018 06:30 1.00 PROD' DRILL SLPC P Slip &cut 53' of drill line. 8,395.0 8,395.0 2/12/2018 06:30 2/12/2018 07:00 0.50 PROD1 DRILL SVRG P Service rig: TOpddve, dr mks. 8,395.0 8,395.0 2/12/2018 07:00 2/12/2018 10:15 3.25 PROD1 DRILL '9'V -RG P Change out saver sub (SN -J6663),6,395.0 8,395.0 adjust shackles on topdrive counterbalance. 018 10:15 10:15 2/1212018 20:30 10.25 PROD1 DRILL TRIP P TIH w/ bha #4 on 4" 14# DP f/ 8395'to 8,395.0 15,045.0 15,045' MD laying out DP with worn hardbanding. (adjusting tally) & picking up replacement pipe. Laid out total Of 40 its of DP. 2/12/2018 2/12/2018 20:30 23:30 3.00 PRODt DRILL TRIP P TIH f/ dirk w/ Bha #4 V 15,045'to 15,045.0 19,394.0 19,394' MD. Tagged up w/ 50k down weight. U/D/R=200/125/157k. Page 16/39 Report Printed: 3/21/2018 Uverations Summary (with Timelog DtwNths) CD5-25 Rig: DOYON 19 Time Log Job: DRILLING ORIGINAL Start Tim End Time 2/12/2018 2/13/2018 Dur (hr) 0.50 Phase PROD1 Op Code DRILL Activity Code REAM Time P -T -X Start Depth Ena 23:30 00:00 T Break circulation, stage pump to 235 19,394.0 19p52 0) gpm w/ 2520 psi, 80 rpm, 6k TO, Wash 8 Ream f/ 19,394'to 19,520' MD w/ 5-8k WOB. Lost 71 bbls to formation in the past 24 hrs. O/A=70 2/13/2018 2/13/2018 00:00 01:30 1.50 PROD1 DRILL REAM T psi. Ream f/ 19,520' to 19,700 w/ 235 19,520.0 19,888.0 gpm, 2520 psi, 80 rpm, 8.3k TO. Continue washing (no rotary) to 19,888' through the fault (out of zone area). U/D=2001115k 2/13/2018 2/13/2018 01:30 05:15 3.75 PROD1 DRILL TRIP P TIH w/ 4" DP f/ drk f/ 19,888'to 19,888.0 22,934.0 22,934' MD, filling pipe each 20 stds & B/D topdrive. (installing W WT SS on each it V 22,208' to 22,906' MD) U/D=192/115k 2/13/2018 2/13/2018 06:15 1.00 PROD1 DRILL REAM P Ream f/ 22,934'to 23,164' MD w/ 250 22,934.0 23,164.0 1 2/3/2018 2/13/ 2/13/2018 5.75 PROD? DRILL DDRL gpm w/ 3090 psi, 80 rpm, 9k TO. 06:15 12:00 P Directional drilling f/ 23,164'to 23,817' 23,164.0 23,817.0 MD. TVD=7803') ADT=3.63 hrs, (lost down wt at 23,220) 15k TQ on b1m,1 Ok TO off btm, 8-10k WOB, 150 rpm, 260 gpm, 3400 psi, 11.68 ppg ECD (12.01 ppg max ecd) U/D/R=195/-1150k O/A=310 psi @ 11:30 hrs. 2/13/2018 2/14/2018 12:00 00:00 12.00 PROD1 DRILL DDRL P Directional drilling f/ 23,817'to 25,316' 23,817.0 2 5,316.0 MD (TVD=7819'), ADT=8.87 hrs, 266 gpm, 3330 psi, 11.58 ppg to 10.75 ppg ECD, 16k TO on btm, 10k TO off btm, WOB-10-15k, Max gas -1531 units w/ 9.0 ppg MW. U/D/R=200/-/152k, O/A=200 psi @ 22:00 hrs. Lost 390 bbls to formation past 24 hrs. 2/14/2018 2/14/2018 00:00 10:15 10.25 PROD1 DRILL DDRL P Directional drilling f/ 25,316to 26,649',3160 25,316.0 26,649.0 MD (TVD=7824), 270 gpm=3710 psi, 150 rpm, 17.5k TO on btm, 12.3k TO off btm, WOB-8k, ECD -11.47 ppg w/ 9.1 ppg MW. U/D/R=207/4153k, ADT=7.57 hrs. Had an increase in loss rate between 25,600' to 25,820' (50 bph losses). 2/14/2018 2/14/2018 10:15 11:15 1.00 PROD? DRILL CIRC T Trouble shoot downlinking for surveys, 26,649.0 26,649.0 BROOH f/ 26,649' to 26,554' wl 270 gpm, 3560 psi, 13k TO. 2/14/2018 2/14/2018 11:15 12:00 0.75 PROD1 DRILL DDRL P Directional drilling f/26,649'to 26,649.0 26,731.0 26,731'. (ND=7826), (ADT=.B hrs) ADT=8.37 hrs for tour 2/14/2018 2/14/2018 12:00 14:00 2.00 PROD1 DRILL DDRL P Directional drilling f/ 26,731'to 26,993' 26,731.0 26,993.0 MD (TVD=7835'), U/D/R=210/-/157k, 150 -rpm, 3520 psi, 265 gpm, 19.6k TO on btm, 13k TO off btm, ECD -11.3 ppg w/ 9.1 ppg MW, 2/14/2018 2/14/2018 14:00 15:30 1.50 PRODt DRILL CIRC T Troubleshoot Issues with MWD loss of 26,993.0 26,993.0 tool functionality, perform low flow step test, 120-260 gpm w/ 3400 psi. MWD not functioning. Paae 17/39 Report Pnntetl: C.Nerations Summary (with Timelog DtNths) C D5-25 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Torre 2114/2018 End rime 2114!2018 our(hi 2.00 Phase PRODt Op Code DRILL Activity Code CIRC Time P -T-% Operation Start Depth (fl%9) EM Deph(flKa) 15:30 17:30 T Pump 40 bbl anti -jamming sweep @ 26,993.0 26,993.0 270 gpm, 3400 psi, 100 rpm, 11k TO,. Circulate b/u, reciprocating pipe, take SPRs, Monitor well for 15 min. (2" drop in annulus) P/U=210k. 2/14/2018 17:30 2/14/2018 2.75 PR0D1 DRILL BKRM T BROOH f/ 26,993' to26,120' MD w/ 26,993.0 26,120.0 20:15 260 gpm, 3350 psi, 80 rpm, 13k TO, Observe pump pressure increase to 3450 psi & noted MWD tool turned back on. (fill=CalciAct=6.2/10 bbis) 2/14/2018 20:15 2/14/2018 22:00 1.75 PROD1 DRILL CIRC T Evaluating MWD data acquisition & 26,120.0 26,268.0 consulting with SLB SME on MWD status, perform MWD operational tests, downlink tests, while circulating & rotating. Noted a 200-250 psi increase in pump pressure as MWD started operating. (265 gpm=3560 psi), washing down to 26,268' MD. 2114/2018 22:00 2/15/2018 00:00 2.00 PROD1 DRILL REAM T Wash Re f126,268'to 26,743' 26,268.0 26,743.0 MD, w/ 270 gpm, 3600 psi, 80 rpm, 13k TO. Total mud losses for the 24 hr period=575 bbis. 2/15/2018 00:00 2/15/2018 00:45 0.75 PRODt DRILL REAM T Wash/Ream f/26,743'to 26,950' MD 28,743.0 26,950.0 w/ 250 gpm, 3120 psi, 80 rpm, 14k TO. Lost signal again with MWD & unable to obtain signal again. P/U=215k 2/15/2018 00:45 2115/2018 09:45 9.00 PROD1 DRILL BKRM T BROOH f/ 26,950'to 23,029' MD w/ 26,950.0 23,029.0 250 gpm, 3110 psi, 12.5k TO. 2/15/2018 09:45 2/15/2018 11:45 2.00 PROD1 DRILL CI RC T Circ BIU w/250 gpm, 3130 psi, 80 23,029.0 23,029.0 rpm, 12.5k TO, Attempt to obtain SOW without pump on, (unsuccessful). 2/15/2018 11:45 2/152018 14:00 2.25 PROD1 DRILL BKRM T Continue BROOH r/ 23,029to 22,172' 23,029.0 22,172.0 MD w/ 250 gpm, 2880 psi, 80 rpm, 13k TO. U/D/R=2101-/152k. Able to establish SOW @ 22,077'. S/0 -80k. Slack off to 22,172' MD. 2/15/2018 14:00 2115/2016 14:30 0.50 PROD7 DRILL OWFF T OWFF, Simops: du&perform 22,171.0 22,172.0 annulus test with Annular w/ 180 psi on annulus to test Sentinal float valves, (floats held). R/d equipment. 2/15/2018 14:30 2/15/2018 15:00 0.50 PROD? DRILL MPDA T Remove trip nipple, install RCD. 22,172.0 22,172.0 2/152018 15:00 2115/2018 15:30 0.50 PROD1 DRILL TMPD T SOOH f/22,172'to21,982'MD P/U- 22,172.0 21,982.0 215k, Holding 80/350 psi in/out slips, Sentinel floats started leaking. 16 15:30 15:30 2/152018 17:00 1.50 PROD1 DRILL DHEO T mpt Atteto seal Sentinel drill string 21,982.0 21,982.0 float valves by applying pressure to the annulus and equalize to a shut in drill string. Rapidly bleed off drill sting. Attempted 50/170 psi DS/Ann, then 150/350 psi-DS/Ann. Float valves still leaking. 2/15/2018 17:00 17:30 2/152018 0.50 PR051 DRILL 1 HEO T Changeconfiguration of rig up on 21,982.0 21,982.0 DnlipiPa. Apply 300 psi on annulus, pump down Drillpipe and apply 300 psi, then attempted 4001400 psi on DS/Ann, bleeding the Drillstring off rapidly each time. No success. Most valves still leaking. Page 18139 ReportPrinted: 3/21/2018 Rig: DOYON 19 Uperations Summary (with Timelog Depths) CD5-25 J Time Log ob. DRILLING ORIGINAL Start Time 2/15/2018 EM Time 2/15/2018 dr(hr) 1.50 Phase PROD1 Op Code DRILL Activily Cotle PMPO Time P -T -X O raaoa star Depat 982.0 EM 17:30 19:00 T Pump out of hole f/ 21,982 to 21,367' 21 21,367.0) MD w/ 250 gpm, 2850 psi. P/1.1 -205k, ECD -10.2 ppg. Observed an increase in pump pressure of 200 psi & ECD increase to 10.62 ppg. 2/15/2018 19:00 21812018 00:00 5.00 PRODt DRILL BKRM T BROOH f/ 21,367' to 19,693'MDw/ 21,367.0 19,693.0 250 gpm, 80 rpm, 2730 psi, 1 Ok TO. ECD -10.33 ppg. Lost 441 bbls of mud to the formation in the last 24 hrs. O/A=325 psi. 2/16/2018 00:00 2/16/2018 01:30 1.50 PR0D1 DRILL BKRM T BROOH f/ 19,693' to 19,130' MD w/ 19,693.0 19,035.0 250 gpm, 2670 psi, 80 rpm, 9.5k TO, Pump out of hole f/ 19,130'to 19,035' w/ 250 gpm. UID=190/100k. At 19,198 (at top of fault) observed a 300 psi increase in pump psi & 4k flubs increase in torque, No overpull. 2/16/2018 01:30 2/16/2018 02:00 0.50 PROD1 DRILL DHEQ T Blow down topdrive, Rlu manifold to 19,035.0 19,035.0 pump down DP, Pump down annulus w/ black water line to seat floats. Apply 250 psi down OF, with 250 psi on annulus, and rapidly bleed psi off DP. Floats appeared to seat off and hold pressure. Attempt to pull one std and float valves started leaking. Decision made to pump out of hole. 02:00 018 02:00 2/16/2018 08:45 6.75 TR-ODIDRILL PMPO T Pump out of hole f/ 19,035' to 15,235' 19,035.0 15,235.0 MD w/ 250 gpm, 210o psi. P/U=175k 2/16/2018 08:45 2/16/2018 09:30 0.75 PROD1 DRILL CIRC T Pump 35 bbl 11.5 ppg weighted pill, 15,235.0 15,235.0 followed by 10 bbls 12.2 ppg brine w/ 230 gpm, chase with 10 bbls of 9.1 ppg FIOPro. BID topdrive. Float valves appear to be holding. 2116/2018 09:30 2/16/2018 14:30 5.00 PROD? DRILL §MPD T SOOH f/ 15,235'to 8395' MD as per 15,235.0 8,395.0 strip schedule w/ 25/350 psi In/Out of slips. P/U=170k Noted 15k overpull at the top of fault #1 at 13,755'. Worked through once and pulled back through with no OP. 2116/2018 14:30 2/16/2018 16:00 1.50 FROD1 DISP T Pump 32 bbl HiVis spacer, displace 8,395.0 8,395.0 wellbore f/ 9.0 ppg FloPro to 9.4 ppg Vis brine w/ 230 gpm, 1450 psi, 50 rpm, 2k TO. Obtain SPR's. 2116/2018 16:00 2/16/2018 16:15 0.25 PROD1 DRILL OWFF T OWFF-static. Blow tlown topdrive. 8,395.0 8,395.0 PJSM on removing RCD bearing. 2/16/2018 16:15 2/16/2018 17:00 0.75 TROD1 MPDA T Remove RCD bearing, install trip 8,395.0 8,395.0 nipple, line up trip tank. 2/16/2018 7:00 2116/2018 21:00 4.00 PR0D1 DRILL TRIP T Pooh on trip tank f/ 8395 to 1744' 8,395.0 1,744.0 racking back in the drk. (full derrick) 16/2018 :00 2/16/2018 22:15 1.25 PROD? DRILL PULD T Pooh on trip tank f/ 1744'to 137' MD, 1,744.0 137.0 [2116/2018 laying down 4, DP to the pipe shed. :16 2/16/2018 :75 22:30 025 PROD DRILL OWFF T OWFF, (dropping in annulus slightly), 137.0 137.0 Simops: PJSM on laying down bha. Page 19/39 Report Printed: 3 /2112 01 8 e Operations Summary (with Timelog Drpths) CD5-25 • Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log BteM1Tims Ertl Time OWN) Phase OO Co's Activit' Cods Time P -T-% Operation sten Depth (BKB) EM Depth(nNB) 2116/2018 2/16/2018 1.00 PROD1 DRILL BHAH T Lay down 6.75" bha as per SLB fl 137' 137.0 0.0 22:30 23:30 to surface. Displacement=CalclAct=113.1 /266.5 bbls. Bit grading- 1-1- ER-S-X-0-NO-DTF. Damage was observed to both Sentinel Float Valves: one valve was missing one of the flappers, and the second one had erosion to the ball/seat area.. 2/16/2018 2/17/2018 0.50 PROD1 DRILL BHAH T Clean & clear rig floor. O1A=190 psi. 0.0 0.0 23:30 00:00 Total losses for 24 hr pedod=239 bbls to formation. 2/17/2018 2/17/2018 0.50 PROD1 WHDBOP RURD P Pull wearbushing, install test plug w! 0.0 0.0 00:00 00:30 4" test joint as per FMC Rep. 2/17/2018 211712018 1.50 PROD1 WHDBOP RURD P R/u BOPE test equipment, hold PJSM 0.0 0.0 00:30 02:00 on testing operations. Flood BOP stack/choke manifold with water, purge system of air. 2/17/2018 2/17/2018 4.75 PROD' WHDBOP TOPE P Test BOPE to 250/3500 psi for 5/5 min 0.0 0.0 02:00 06:45 w/ against 4" & 4.5" TJ: Annular, 3.5'x6" upper VBR's, lower VBR's, CM valves: 1-14#, 4" FOSV, Dart valve, auto/man IBOP, man kill/choke, HCR kill/choke, blind rams, needle valve. Perform accumulator test (FSP=3080 psi, PAC=1550 psi, 28 sec T/ 200 psi, 137 sec to FSP, 4 Nis avg=2000 psi), Test hyd/man choke to 1100 psi. Witness of test waived by AOGCC Rep Matt Herrera. Tested dg gas alarms. Monitor well on trip tank. Losses of 4.5 bph. 2/17/2018 2/17/2016 0.50 PROD1 WHDBOP RURD P Blow down chokelkill lines, R/D test 0.0 0.0 06:45 07:15 equipment. 2/17/2018 2!17/2018 0.75 PROD' WHDBOP RURD P Remove test plug, install 7.125" ID 0.0 0.0 07:15 08:00 wear bushing as per FMC, Monitor well on TT. 2/17/2018 2/17/2018 1.50 PROD1 DRILL BHAH T PJSM, Mlu 6.75" bha #5 as per SLB 0.0 317.0 08:00 09:30 DD to 317'. 2/17/2018 09:30 21'7/2018 1.50 PROD1 DRILL PULD T P/u 45 jts of 4" 14# DP V pipe shed l0 317.0 1,739.0 11:00 '739' MD. 2/17/2018 11:00 217/2018 0.25 PROD1 DRILL -TRI -P T TIH w/ bha 114- 14# DP f/ drk to 1,739.0 2,215.0 11:15 2215' MD. 2/17/2018 11:15 2117/2018 0.50 PROD1 DRILL DHEQ T Shallow test MWD w/ 250 gpm, 940 2,215.0 2,215.0 11:45 psi -good test. BID topdrive. U/D=90/93k 2117/2018 11:45 2!17!2018 3.25 PROD1 DRILL TRIP T TIH f/ drk w/ 4" DP & bha #5 f/ 2215' 2,215.0 8,390.0 15:00 to 8390' MD, filling pipe each 20 sttls. 2117/20182/17/2018 15:00 1.50 PROD1 DRILL FSP T PJSM, pump 29 bbl HIVI3 spacer, 8,390.0 8,390.0 16:30 displace 9.4 ppg KW vis brine to 9.0 ppg FloPro w/ 250 gpm, 1550 psi, 40 rpm 1.5k TQ. 2/17/2018 2/17/2018 1.00 PROD1 DRILL §LPC P PJSM, slip & cut 68' of drill line. 8,390.0 8,390.0 16:30 17:30 Simops: cond mud @ 3 bpm w! 530 psi. 2!1712018 2/17/2018 17:30 0.50 PROD1 DRILL SVRG P Service toptlrive & drwvrks, inspect 8,390.0 8,390.0 18:00 saver sub, perform overhead DROPs inspection. Page 20/39 ReportPrinted: 3/21/2018 1; Gperations Summary (with Timelog Depths) CD5-25 Rig: DOYON 19 Time Log Job: DRILLING ORIGINAL start Time 2/17/2018 End Tme 2/17/2018 our (hr) 2.50 Phase PROD1 Op Code DRILL Activity Code SVRG Time P -T -X operauo. Start Dep0 (fiKB) End DePth(flKB) 18:00 20:30 P PJSM, than eout saver sub on 9 8,390.0 8,390.0 topdrive due to wear. Monitor well on triptank, 2 bbls loss. 2/17/2018 20:300:30 2/18/2018 0000 3.50 PROD1 DRILL TRIP T TI H w/ bha #5 w/ 4" DP f/ drk f/ 8390' 8,390.0 12,190.0 to 12,190' MD Filling pipe every 20 stds R B/D topdrive. O/A=200 psi. Total mud losses for 24 hr interval=110 bbls to the formation. 2/18/2018 00:00 2/18/2018 06:30 6.50 PROD1 DRILL P TIHw/4" DPf/drkf/ 12,190'to 12,190.0 19,294O :REAM 19,294' MD, filling pipe each 20 stds, replacing 17 joints of worn DP in drillstring. 2/18/2018 06:30 2/18/2018 08:00 1.50 PROD1 DRILL FTWash/Reamf/l9,294'tol9,410'MD 19,294.0 19,865.0 (2nd fault out of zone area) w/ 250 gpm, 2500 psi, 40 rpm, 10k TQ. Attempted to wash down without rotation f/ 19,410' to 19,468' (unsuccessful w/ 90k on). Continue W/R f/ 19,468' to 19,965'w/ 240 gpm, 2470 psi, 40 rpm, 8k TO. Wash down f/ 19,695' to 19,885' without rotation w/ 225 gpm, 2100 psi (DN -115k). 2/18/2018 08:00 2/18/2018 11:45 3.75 PROD? DRILL TRIP T TIH f/ 19,985'to 23,907' MD, filling 19,885.0 23,907.0 pipe each 20 stds. U/D=225/100k. Lost SOW at 23,907' MD. 2/18/2018 11:45 2/18/2018 19:15 7.50 PROD? DRILL REAM T Wash &ream f/ 23,907tD 26,993' 23,907.0 26,993.0 MD, w/ 240 gpm, 2660-3150 psi, 40 rpm, 10k TO 2/18/2018 19:15 2/19/2018 00:00 4.75 PROD1 DRILL DDRL P Directional drilling f/26,993'to 27,463' 26,993.0 27,463.0 MD (TVD=7841'), w/ 270 gpm, 3800 psi, 150 rpm, 18.5k TO on btm, 14k TO off btm, ECD -11.65 ppg, Max gas - 4584 units, WOB-15k, ADT -2.95 hrs, O/A=400 psi, Jars -103.5 hrs, U/D/R=215/-/162k Lost 275 bbls to formation in the last 24 hrs. 2/19/2018 00:00 2/19/2018 12:00 12.00 PROD1 DRILL DDRL P Directional drilling f/ 27,463' to 28,644' 27,463.0 28,644.0 MD, (TVD -7854') w/ 270 gpm, 3490 psi, 150 rpm, 20.5k TO on btm, 12k TO off btm, 15k WOB, ECD 11.3 to 11.9 PPg w/ 9.1 PP9 MW, FO=22%, Jar hrs-112.2, ADT=8.7 hrs, U/D/R=222/-1160k. Running mud dilution as needed to manage ECD. 2/19/2018 12:00 2/20/2018 00:00 12.00 PROD? DRILL DDRL P Directional drilling f/ 28,644'to 30,168' 28644.0 , 30,168.0 MD (TVD -7870'), w/ 268 gpm, 3775 psi, 150 rpm, 20.7k TO on btm, 13.5k TO off btm, 8-10k WOB, ECD 11.45 to 11.5 ppg w/ 9.1 PPg MW, FO 23%, Jar hrs-120.2, ADT=8.07 hrs, U/D/R=235/ 4171 k, O/A=200 psi. Max gas -3808 units, Running whole mud dilutions as needed to manage ECD. Loss rate increased to 60 bph f/ 29,755' to 29,910' MD. Lost 720 bbls of mud to formation in the last 24 hrs. Page 21/39 Report Printed: 3/21/2018 : DOYON 19 Stan 2120120 00:00 00:30 00:45 2/20/2018 2/20/2 00:45 05:45 2/20/2018 2/20/2 05:45 06:15 2/20/2018 2/20/21 06:15 12:00 2/20/2018 2/20/21 12:00 23:45 -U 14:15 2121/, 15:30 :45 L07:30 2/21/2 08:00 2/21/2 14:15 2/21/21 15:30 15:45 17:00 2/21/2018 2/21/: 17:00 2/21/2018 17:30 2/21/2018 t23:15 17:45 2/21/2018 22:00 Operations Summary (with Timelog Depths) CD5-25 Job: DRILLING MD (TVD -7878) w/ 268 gpm, 3750 PSI, 150 rpm, 20.6k TQ on btm, 13.5k TQ off btm, FO -22%, U/D/R=235/ -/160k, ECD -11.6 ppg w/ 9.0 ppg MW, Max 98s-3190 units. "Set AK State record for first well over 30k' 8 longest SPR'S' _- - Ciro b/u w/ 260 gpm, 3720 psi, 80-10 I'm , 15-16k TQ, racking 1 std back Per b/u f/ 30,218' 030, 073'MD. OWFF-static, rotating at 10 rpm, Drof 2.1 hollow drift on std #314. BROOH f/ 30,218' to 27,595' MD w/ 250 gpm, 3270 psi, 80 rpm, 14.5k TQ Off btm, U/D/R=235/4160k. BROOHf/27,595'to22,167'MD w/ 250 gpm, 3270-2770 psi, 14.5-11 k TQ. Able to obtain SOW w/ 98k. U/D/R=205/98/152k 0/A=300 psi Circ b/u w/ 270 gpm, 3020 psi, 80 rpm, 11.5k TO. Total mud losses to formation in last 24 hrs=584 bbls. Circ b/u w/ 270 gpm, 3070 psi, 80 rpm, 11.5k TO, U/D/R=235/110/152k. Simops: hold PJSM on RCD install. OWFF (slight tlrop in annulus), Blow dow topddve, remove trip nipple, install RCD bearing, line up MPD, establish circ to SOOH. SOOH f/22,167'to 16,940' as per strip schedule holding 75/330 psi in/out of slips. Had 20k overpull at 19,336' in the #2 fault interval. Pump 35 bbl -1 17 ppg slug w/ 210 gpm, 1740 psi, blow down topddve. SOOH f/ 16,940' to 8390' MD as per stripping schedule holding 30/295 psi inlout of slips. Circ b/u w/ 270 gpm, 2020 psi, 40 rpm, 2k TO. PUmp 38 bbl spacer 8' displace to 9.4 ppg Vis Brine w/ 270 gpm, 1540 psi, 30 rpm, 2k TQ. OWFF-static, blow down topddve, cold PJSM uvv" on top tank w/ hold CPA/ photography session on dg floor with CPAI photographers. Pooh f/ 8390' to 1739' MD racking 4" DP in drk. Pumped a 30 bbl 10.6 ppg dry job. Pooh laying down 4" 14# DP to pipe ihed (45 its), V 1739'10 317'. (.Nerations Summary (with Timelog Depths) CD5-25 F4W C. Rig: DOYON 19 Time Job: DRILLING ORIGINAL End Time 2/21/2018 our (hr) 0.25 Phase PROD1 Dp Code CASING Activity code OWFF Tena P -T -X Operation smn Depth t+dcB End Depen (te(B) 23:30 p OWFF-dropped 2' in annulus in 10 317.0 317.0 2/22/2018 0.50 PROD? CASING BHAH P min. Simops: PJSM on bha. 00:00 LID 6.75" bha #5 as per SLB f/ 317'to 317,0 82.0 82'. Identified 4Its of HWT DP severly wom tool its. 59 jts of worn hardbanding on DP identified. O/A=200 psi. Daily losses to formation -154 bbls. 2/22/2018 00:00 2/2212018 00:45 0.75 PROD1 CASING B P LID 6.75" bra #5 as per SLB f/ 82' to 82.0 2122/2018 2/22/2018 0.50 PROD1 CASING SHAH surface. (CaldAct=189.4/648 bbls) 0.0 00:45 01:15 P Clear & clean dg floor, mobilize liner 0,0 0,0 2/22/2018 2/22/2018 1.00 COMPZI CASING SF TY P tools to floor. 01:15 02:15 Hold PJSM on running 4.5" liner. R/u 0.0 0.0 2/22/2018 2/22/2018 2.75 COMPZI CASING PUTB PRun 4.5" liner running tools. 02:15 05:00 4.5" 12.8# L80 TXP Orange peel 0.0 905.0 shoe, two perforated pupils, 23 jts of 4.5" liner (905.29') . P/u 67k, S/O 67k. 7522/2018 2/22/2018 05:15 0.25 COMPZI CASING -(5T-HR P M/u HRDE liner setting sleeve easy w/ 905.0 T22/ 2/22/2018 2/222018 0.50 COMPZI CASING CIRC o 3.5" u t, DP XO to 935'. ..„ pup I 935.0 -•--•� �, w,vu, Pump io 935.0 1,027.0 Cot bbls liner volume w/ 3 bpm 1100 psi, B/D TD, P/u 65k, S/O 70k. 11:00 run wi 4.5' 12.60 L80 TXP liner on 4" DP to 8437', installing split db hydroforns floating on every joint, monitoring displacement on tdptank. 11:00 112:00 12:45 1245 11415 tC0MPZ17 - ' ""w "'� r HJSM, Displace to 9.0 ppg FIoPm @I ; 2/22/2018 222/2018 0P C�c w/o tom SPRs,Obtain14:1514:30parameters: U/D/R=165/158/164K20 _ rpm, 1.5k TQ. 14:30 20,035' MD (setting depth), U/D=215/120k 8/0=9'., monitoring displacement to trip tank. 129/32" setting ball & pump 4 bpm w/ 1240 psi and slow to 2 bpm w/ 550 Psi. Ball landed on seat at 1752 stks, apply 3300 psi. P/u to 215k, no release, Slack off to setting depth. Apply 3500 psi, P/u to 215k, S/O at 130k. Apply 3800 psi and ball seat sheared, P/u to 205k w/ S/O at 135k, (indication of released f/ liner). TOL- 19,108.67', Bottom of liner -20,035'. MD (EDP). Blow down topddve. O/A=200 psi. Daily losses to formation -71 bbls. down topdrive. 00:15 00:45 Page 24139 Report Printed: 3/21/2018 F4 Time Log Rig: DOYON 19 Operations Summary (with Timelog Depths) CD5-25 Job: DRILLING ORIGINAL SM Tare EMNne 2/23/2018 2/23/2018 Dur(hr) Phase 0.50 COMPZt CASING CIRC M�� ppT-x oDe2tion Slam Depth (RKB End Depth(N(e) 00:45 01:15 Pump 34 bbl 11.7 ppg slug w/ 4 bpm, 19,207.0 1000 psi, B/D top irive. (no float in _19,027.0 2/23/2018 01:15 2/23/2018 09:30 8.25 COMPZI CASING SMPD P tlrillstring) SOOH f/ 19,027'to 8365' MD as per 19,207.0 stripping schedule, 80/330 psi In/Out 8,365.0 2/23/2018 09:30 2/23/2018 11:30 2.00 COMPZI CASING DISP P of slips. Break 01c, pump 37 bbl HiVis spacer, 8,365.0 displace 9.0 ppg FloPro to 9.4 ppg Viagpm, 8,365.0 brine w/ 250 680-420 psi. 2/23/2018 11:30 2/23/2018 11:45 0.26 COMPZJ CASING OWFF P OWFF, static. B/D topdrive. Simops: 8,365.0 8,365.0 2/23/2018 2/23/2018 0.50 COMPZI CASING MPDA P PJSM on removing RCD. 11:45 12:15 Remove RCD bearing, install trip 8,365.0 8,365.0 2/23/2018 12:15 2/23/2018 17:15 5.00 COMPZI CASING TRIP P nipple. Pooh w/ BOT RT on triptank f/ 8365' to 8,365.0 2/23/2018 2/23/2018 0.25 COMPZI CASING BHAH P 33' MD. 33.0 17:15 17:30 UD Baker running tool. Hole fill 33.0 0.0 2/23/2018 2/23/2018 1.25 COMPZI CASING RURD P Calc/Act--121.6/211.5 bbls. 17:30 18:45 R/u tools & equip to run 4.5" liner#2. 0.0 0.0 2/23/2018 18:45 2123/2018 20:30 1.75 COMPZt CASING PUTB P Hold PJSM, Rih w/ 4.5" 12.6# L80 0.0 TXP MIS, Perf pups, 4.5" liner, 1,066.0 installing floating hydroforms as per 2/23/2018 2/23/2018 1.25 COMPZ7 - CASING OTHR P liner detail to 1066.61' MD. 20:30 21:45 M/u HRD-E ZXP liner top packer, SBE, RS packoff seal nipple, DG 1,066.0 1,147.0 flexlock hanger, Bumper sub/pup it XO V 1066' to 114T MD, BOT mix & pour 2/23/2018 21.45 2/23/2018 22.15 0.50 COMPZI CASING CIRC P Zanplex. . M/u first std of 4" 74# circ& P, break circ 1,147.0 circ @ 4 bpm w/ 140 psi @ 1239' MD. 1,239.0 Liner Wt=73k. P/u-74k, S/0 -76k. 2/23/2018 22:15 2/24/2018 00:00 1.75 COMPZi CASING RUNL P RIH w/4.5"liner on 4"DPf/drkf/ 1239.0 1239' to 4953' MD. Daily losses to 4,953.0 2/24/2018 2/24/2018 1.75 COMPZ7 CASING RUNL P formation -97 bbls. 01:45 RIH w/ 4.5" 12.6# L80 TXP liner on 4" 4,953.0 8,273.0 2 2/24/ 214/2018 2/24/2018 0.25 COMPZ1 CASING CIRC DP f/ 4953' to 8273' MD. 01:45 02:00 P Break circ w/ 3 bpm w/220 psi. 8,273.0 8,273.0 2/24/2018 2/24/2018 1.00 COMPZ1 CASING RUNL P U/D=167/155k. 02:00 03:00 RIH w/ 4.5" liner on 4" DP f/ 8273'to 8,273.0 9,394.0 9394', break circ w/ 3 bpm, 230 psi, (calc/act displacement = 57.01/31.5 2/24/2018 2/24/2018 1.25 COMPZt CASING PACK P bbls) U/D=175/155k. 03:00 04:15 Set 4.5" liner on depth at 9394', (TOL 9,394.0 9,394.0 at 8269), Drop 1.625" ball to set liner hgr/ZXP pkr. Pump w/ 3 bpm w/ 230 psi for 540 stks, slow to 2 bpm, ball on seat with 562 stks pumped. Apply 2500 psi and hold for 5 min. S/O to 85k. Increase to 4000 psi & hold 1 min. P/u to 145k, bleed off psi. P/u 6' to expose dog sub w/ 175k, S/O to 105k. P/U to 175k, repeat twice. Set pkr. Pressure test annulus to 2000 psi, charted for 10 min, good test. 2/24/2018 04:15 2/24/2018 04:30 0.25 COMPZI WELLPR TRIP P Pooh 2 stds to 8130'. P/U 168k. 9,394.0 8,130.0 2/24/2018 04:30 2/24/2018 05:00 0.50 COMPZI WELLPR OWFF P OWFF(dropping slowly in annulus), 8,130.0 blow down kill line. 8,130.0 Page 24139 Report Printed: 3/21/2018 ,-..w m:IJ Uperations Summary (with Timelog Depths) ..._�_-__.._,..., .,..��4" DP.018 ....... CDS-25 224/2018 15:45 0.50 PROD2 WHPST Rig: DOYON 19 llow test MWD Q 250gpm, 6201,745.0 1,745.0 2242018 Time Log PROD2 WHPST TRIP Job: DRILLING ORIGINAL Start Time End Time 2/24/2018 Our(h4;Phase 1.00 ZI p Code LPR Actively Code Time P -T -X w SitoopN_2/24/2018 EW8130A05:00 06:00 2/242018 CIRC P Circ b/u w/ 6-8 bpm 610-850 psi8,130.0 WHPST DLOG 7' MD filling DP every 20 stds.21:30 21:30 Monitor well, slight dropping inannulus. 17.00 PROD2 WHPST WAIT P JW;ELLPR 8,1170 81660 2/24/2018 06:00 2/24/2018 09:45 3.75 ZI LPR TRIP P Pooh on elevators if 8130' to 244' on 8.130.0 244.0 triptank. (flow check -static). ated at 8186' bit depth. Final 2/24/2018 09:45 2/24/2018 10:15 0.50 COMPZ1 2/25/2018 17:30 SHAH P Pooh, Vd BOT liner RT f/ 244' to 244.0 0.0 P th of RA tag log=8012' casing rWashffi', 8,269.0 surface. (Calc/Act disp=50.4/63 bbls). 10:15 018 10:15 2/242018 11:15 1.00 COMPZI WELLPR SHAH P Clean & Gear dg floor, Vd liner tools, 0.0 Prepare for W/S as$y, monitor well on 0.0 22:00 2242018 22:45 0.75 PROD2 WHPST TT -lost 3 bbls. P sh down f/ 8166' ,remain oriented 224/2018 11:15 2242018 2.75 PROD2 WHPST BHAH P Hold PJSM, M/u milling whipstock 0.0"324 14:00 assy to 324', monitor well on TT, lost 8 at 8279' (liner swallow included) w/ bills. (scribe MWD/WS TFO = 16.73° RHS 2242018 21242018 1.25 PROD2 WHPST TRIP P ofu...:...:.:__.__,-____�........ ._._. n), P/u to 180k, set down10k,P/u ,-..w m:IJ ..._�_-__.._,..., .,..��4" DP.018 ....... 15:15 224/2018 15:45 0.50 PROD2 WHPST DHEO P llow test MWD Q 250gpm, 6201,745.0 1,745.0 2242018 5.75 PROD2 WHPST TRIP Good test, blow tlown topdrive.21242018 15:45 21:30 P w/Whipstock assyN 1745'to17450 8,1170 2/242018 0.50 PROD2 WHPST DLOG 7' MD filling DP every 20 stds.21:30 21:30 22:00 17.00 PROD2 WHPST WAIT P ab circ w/ 250 gpm w/ 980 psi, Log 8,1170 81660 RA tag at 8013' rasing depth. ated at 8186' bit depth. Final 225/2018 17:00 2/25/2018 17:30 0.50 PROD2 WHPST PRTS P th of RA tag log=8012' casing rWashffi', 8,269.0 th. Orient MWD to 35 deg RHS in ops. U/D=170/158k2/24/2018 22:00 2242018 22:45 0.75 PROD2 WHPST WPST P sh down f/ 8166' ,remain oriented 8,1660 82690 5° RHS, U/D=170/158k, Tag No at 8279' (liner swallow included) w/ set anchor (observe shear @ 18k n), P/u to 180k, set down10k,P/u 80k, shear whipstock bolt (observe r @ 32k dn), Pick up w/ 160k to rm release. ---- 17:30 20:00 �..� r Nola Yibm, position FloPro mud 8,269.0 8,269.0 trucks for displacement. Displace 9.4 ppg KW Ys brine to 9.1 ppg FloPro milling fluid at 5 bpm, 860 psi. Flow check well, take spr's. 2/252018 226/2018 4.00 PROD2 WHPST MILL P. Set milling parameters at 280 5 20:00 00:00 1490-1330 psi, 80 rpm w/ 2-6.k TO. 8,184'0 8,203.0 U/D/R=165/155/162k. Mill lug & window & cut rathole from 8184' to 8203' MD Pump Super sweep pills as needed (3x). TOW=8184' "- conditions. Winds gusting to 45 mph, ....... restricted visibilty. Install FOSV in drillstring and monitor well on triptank- static. O/A=400 psi. Daily losses to formation -52 bills. 225/2018 00:00 2/25/2018 17:00 17.00 PROD2 WHPST WAIT T Waiting on weather, Phase III 8,269.0 8,269.0 conditions, winds at 40-50 mph. Monitor well on trip tank -static. 225/2018 17:00 2/25/2018 17:30 0.50 PROD2 WHPST PRTS P Pressure test whipstock seals to 10008,269.0 8,269.0 psi for 10 min (2 bills), blow down kill ---- 17:30 20:00 �..� r Nola Yibm, position FloPro mud 8,269.0 8,269.0 trucks for displacement. Displace 9.4 ppg KW Ys brine to 9.1 ppg FloPro milling fluid at 5 bpm, 860 psi. Flow check well, take spr's. 2/252018 226/2018 4.00 PROD2 WHPST MILL P. Set milling parameters at 280 5 20:00 00:00 1490-1330 psi, 80 rpm w/ 2-6.k TO. 8,184'0 8,203.0 U/D/R=165/155/162k. Mill lug & window & cut rathole from 8184' to 8203' MD Pump Super sweep pills as needed (3x). TOW=8184' ,I Ul erations Summary (with Timelog D�Nths) CD5-25 Rig: DOYON 19 Time Log Job: DRILLING ORIGINAL sign rune 2/26/2018 End Time 2/26/2018 Dur IN) 0.75 Phase PROD2 op code WHPST Activity Code VI-LL Time P-T-xscan Operation Depth M(s)End Deplh(Rlm) 00:00 00:45 P mill window and eo 8,203.0 8,213.0 8213', 3' gauge hole belowow BOW. oleb W. 280 gpm, 1340 psi, 80-100 rpm, 3.5-7K tq, 10-12K wob TOW=8184 BOW=8198 2/26/2018 00:45 2/26/2018 01:30 0.75 PROD2 WHPST REAM P Circ w/ 280 gpm, 1350 psi, 100 rpm, 8 ,213.0 8,213.0 2.5k TO, Pump super sweep #3, Ream through window, work string through window 2 times with pumps off, smooth window. 2/26/2018 01:30 2/26/2018 01:45 0.25 PROD2 WHPST TRIP P Rack back stand to 8118', 170 PUW, 8, 213.0 8,118.0 165 SOW, 167 Rot 2/26/2018 01:45 2126/2018 02:00 0.25 PROD2 WHPST OWFF P Observe well for flow, slight flow back, 8,116.0 8,118.0 diminishing 2/26/2018 02:00 2/2612018 03:15 1.25 PROD2 WHPST DISP P Displace well to 9.4 ppg vis brine, 8,118.0 8,118.0 pumped 28 bbl spacer ahead, 280 gpm, 1340 ICP, 1220 FCP, obtained SPR's, blow down TD. Full returns 2/26/2018 03:15 2/26!2018 03:30 0.25 PROD2 WHPST OWFF P Observe well for flow, droppetl 4" in 8,118.0 8,118.0 annulus 2/26/2018 2126/2018 4.25 15ROD2 WHPST TRIP P POOH on trip tank 03:30 07:45 8,118.0 230.0 2/26/2018 07:45 2/26/2018 08:00 0.25 P7ROD2 WHPST OWFF P Observe well for flow, dropping in 230.0 230.0 annulus slighlly 2/26/2018 08:00 2/26/2018 09:15 1.25 PROD2 WHPST BHAH P LD milling BHA, clean magnets, upper 230.0 0.0 mill in gauge 2/26/2018 09:15 2126/2018 10:15 1.00 PROD2 WHPST W W WH P MU stack washer, magnets and DP. 0.0 0.0 Flush stack, function rams, flush again. SIMOPS, dear/clean floor, LD stack wash easy 2/26/2018 10:15 2/26/2018 11:00 0.75 PROM WHPST BHAH P LD mill assy from floor and PU motor 0.0 2/26/2018 2126!2018 1.00 PROD2 WHPST BHAH assy components via beaver slide 0.0 12:00 P MU motor kids-off asst' per SLB. 0.0 195.0 Verified offset. 2/26/ 2126/2018 12:00 2/26/2018 12:30 0.50 PROD2 WHPST BHAH P Continue MU motor kick-off assy per 195.0 718.0 SLB 2/26/2018 12:30 2/26/2018 13:00 0.50 PROD2 WHPST TRIP P RIH w/ 4" DP from derrick f/ 718'to 718.0 1,663.0 1663' 018 13:00 13:00 2/26/2018 13:15 0.25 PROM WHPST DHEO P Shallow test MWD, 250 gpm, 1040 1,663.0 1,663.0 Blow psi. tlown TO 2/26/2018 13:15 2/26/2018 16:45 3.50 PROM WHPST TRIP P RIHf/ 1663'to 7940' 1,663.0 7,940.0 2/26/2018 16:45 2/26/2018 17:15 0.50 PROM WHPST DLOG P Wash down 7940' to 8130', Log down 7,940.0 8,160.0 and aquire RA tag on depth, 250 gpm, 1430 psi, orient TF 35R 018 T26/17:15 17:15 2126/2018 17:45 0.50 PROM WHPST TRIP P RIH, no pump, across whipstock, no 8,160.0 8,213.0 2/26/2018 17:45 2/27/2018 00:00 6.25 PROD2 DRILL DDRL T excess drag. Drill f/8,213'to 8,398' MD. 7508' TVD, 8,213.0 8,398.0 AST=1.62, ART=1.84, ADT=3.46, P/U=174k, S/0=155k, RW=165k, TO 2.5 @ 837T 2/27/2018 00:00 2/27/2018 00:30 0.50 PROM DRILL DDRL T Cont drilling, attempting to kick off f/ 8,398.0 8,416.0 8398'-8416'. ADT=0.33 hrs, Rot=0.13 hrs, Slide=0.20 hrs. TVD=7517'. Survey indicating tracking casing. 2/27/2018 2/27/2018 00:30 02:15 1.75 PROD2 DRILL CIRC T C&C w/ 2-4 bpm (240-620 psi), 8,416.0 8,416.0 Consult office, Geo anal ycuttings. Decision made to POOH for increased for motor bend. Page 26139 Report Printed: 3/21/2018 C,perations Summary (with Timelog N-pths) CD5-25 • Rig: DOYON 19 lime Log Job: DRILLING ORIGINAL Starr Tone 2/27/2018 end rmre 2/27/2018 our(ep 1.00 Pnae PROD2 op code DRILL Stan D -Pm (1101) end Depth8, 02:15 03:15 T Pull out f/8416 -8113U Orient motor 8,416.0 OA 7ACUV4YCo:daTI=P-T-x 35°R. Pull through window with no pump or rotary. Saw 3-4K drag coming through window. flow check> slight drop. 2/27/2018 03:15 2/27/2018 04:15 1.00 PROD2 DRILL CIRC T CBU w/260 gpm 1520 psi. 40 mt, 8,130.0 8,130.0 2.5K Tq. Obtain SCR's w. 9.5 brine. 2/27/2016 0.25 PROD2 DRILL OWFF T Flow check, slightdrop. 04:15018 04:15 04:30 8,130.0 8,130.0 2/27/2018 04:30 2/27/2016 04:45 0.25 PROD2 DRILL CIRC T Pump 31.5 bbl of 10.0 ppg slug. B/D 8,130.0 8,130.0 TDS. 2/27/2018 04:45 2/27/2018 08:00 3.25 PROD2 DRILL TRIP T POOH on trip tank f/ 8130'-718'. 8,130.0 718.0 2/27/2018 2127/2018 0.25 PROD2 DRILL OWFF T Flow check, slight drop. 08:00 08:15 718.0 718.0 2/27/2018 08:15 2/27/2018 09:00 0.75 PROD2 DRILL SHAH T POOH f/ 718'-96', handle 1 change / 718.0 0.0 LD BHA to surface, (trip total hole fill = 50.66 (talc) / 64 (actual) bbl. 2/27/2018 09:00 2/27/2018 0.50 PROD2 DRILL BHAH T Change motor bend f/ 1.50` to 1.83°. 0.0 09:30 Scribe motor/MWD. 0.0 2/27/2018 2/27/2018 0.50 PROM DRILL BHAH T Clean and Gear dg floor 09:30 10:00 0.0 0.0 2/27/2018 2/27/2018 0.25 PROD2 DRILL BHAH T M/U bit and RIH w/ BHA to 659' 10:00 10:15 0.0 0.0 2/27/2018 2/27/2018 0.50 PROD2 DRILL TRIP T RIHV659'-2080'. 10:15 10:45 659.0 2,080.0 2127/2018 10:45 2/27/2018 11:15 0.50 PROD2 DRILL DHEO T Fill pipe and shallow test MWD (250 2,080.0 2,080.0 21:15 18 227/2018 2.75 PROD2 DRILL TRIP gpm, 990 ps) pumping brine 11:15 14:00 T RIH f/ 2080'-7975, filling pipe every 20 2,080.0 7,975.0 stands 2/272018 14:00 227/2018 14:30 0.50 PROD2 DRILL WASH T Wash down 7975'-8166'. w/ 250 gpm, 7,g75.p g,tgg.0 1380 psi. Orient motor 35°R. Log RA tag @ 8052' (bit depth) = 8013' (csg depth). (total trip disp = 47.72 / 37 bbl (CalciAct)). 2272018 14.30 2272018 15:15 0.75 5R0D2 DRILL CIRC T C&C w/250 gpm, 1350 psi. 8,166.0 8,166.0 21272018 15:15 2272018 15:30 0.25 PROD2 DRILL TRIP T RIH 8166-8352' (took 10K Wt @ 8,166.0 8,352.0 8352') 2/27/2018 15:30 2272018 16:00 0.50 PROD2 DRILL WASH T Wash down f/ 8352'-8416(250 gpm, 8,352.0 8,416.0 1500 psi) 2/27/2018 16:00 2/27/2018 18:00 2.00 PROD2 DRILL DDRL P Drill f/8416'-851 '. ADT=1.67 hrs, 8,416.0 8,510.0 Rot=0.64 hrs, Slide=1.03 hrs. TVD=7517'. Surveys indicate good separation from main bore. 2/27/2018 2/272018 19:45 1.75 PROD2 DRILL CIRC P Pump sweep, circ hole clean (265 8,510.0 8,510.0 227/2018 0.75 PROD2 DRILL TRIP gpm, 1600 psi). Orient motor 30°R. 20:30 P POOH f/ 8510'-8166' (verify motor 8,510.0 8,166.0 orientation prior to pulling across whipstock) Noted 4K OP whem bit crossed bottom of window, 2/27/2018 20:45 0.25 PROD2 DRILL OWFF P Fow check (inftial=slight trickle, 5 min, 8,166.0 8,166.0 T82/2 static, 10 min slight drop) 21:00 2/27/2018 0.25 PROD2 DRILL CIRC P Pump & chase 31 bbl of 10.0 ppg 8,166.0 8,166.0 slug. B/D TDS. 00 00:00 00 018 300 PROD2 DRILL TRIP P POOH f/ 8166'-4997' (Cu8,166.0 4,997.0 replacing w/ new 14# DP breaking in per Grand Prideco procedure) Page 27139 ReportPrinted: 3121/2018 Time Log Rig: DOYON 19 GNerations Summary (with Timelog Dtpths) CD5-25 Job: DRILLING ORIGINAL Start Time 2/28/2018 End Time 2/282018 our (W) Phase 2.25 PROD2 pp Code DRILL ACWHy Code Time P -T -X opBf8�0e TRIP Stan c � fnca) End oepm (flXa) 00:00 02:15 p Cont POOH F/ 4997'-659'. (L/D 13 4,997.0 659.0 228/2018 02:15 2/28/2018 0.25 PROD2 DRILL OWFF P total bad jts 4" DP) Flow check well static 02:30 , 659.0 659.0 2/28/2018 02:30 2/28/2018 03:00 0.50 PROD2 URILL P Pull, rack and LID BHA f/ 659' -surface. 659.0 0.0 (trip total caic/actual fill = 47/52.5 bbl) (Bit grade = 1 -1 -WT -A -E -1 -NO -BHA) 2/282018 03:00 2282018 03:30 0.50 PROD2 DRILL SHAH P Clean and clear rig floor p.p p p 2/28/2018 03:30 2/28/2018 04:00 0.50 PROD2 WHDBOP RURD P Pull wear bushing, set test plug 0.0 0.0 2/28/2018 04:00 2/282018 04:45 0.75 PROD2 WHDBOP RURD P R/Uto test ROPE. Fill choke 0.0 manifold, choke and kill lines w/ 8.33 0.0 2/28/2018 04:45 2282018 07:30 2.75 PROD2 WHDBOP BOPE P water. Test 4" , Annular, upper and lower 0.0 VBR'S ( (3.5X6', Auto/manual IBOP, 0.0 FOSV, Gray valve, 4" Demco kill, HCR choke/kill, needle valve above #1, choke man valves 1-14 250/3500 psi for 5/5 min. 7/28/2018 07:30 228/2018 07:45 0.25 PROD2 WHDBOP BOPE P Accumulator test: System pressure= 0.0 3000 psi, Pressure after functioning all 0.0 rams, annular and HCR's=1450 psi, Recharge: 200 psi attained = 29 sec, full recharge = 151 sec, 4 bottles N2 average = 2000 psi. 228/2018 07:45 228/2018 08:30 0.75 PROD2 WHDBOP BOPE P Test against 4.5" annular (2502500 0.0 psi 5/5 min), upper and lower VBR's 0.0 2/282018 2282018 0.75 PROD2 WHDBOP BOPE P (250/3500 psi 5/5 min). 08:30 09:15 Test blind rams to (250/3500 psi 0. 0 0.0 250/3500 5/5 min). Test super/ manual chokes to 1100 psi (well static throughout BOP testing). Test rig gas alarms, PVT's, flow meter & remote choke panel in boiler room. NOTE: AOGCC Adam Earl waived witness of BOP testing. 078 09:15 09:15 2/282018 10:00 0.75 PROD2 WHDBOP RURD P Pull test plug, KID test equipment & 0.0 2/28/2018 2/28/2018 0.50 PROD2 DRILL SVRG blow down lines. Set wear bushing 0.0 10:00 10:30 P Lubricate rig, service drawworks, iron 0.0 0.0 2/28/2018 2/282018 2.75 PROD2 DRILL SVR G P roughneck & crown cluster. 10:30 13:15 PJSM. Change saver sub. Adjust 0.0 0.0 2/282018 228/2018 1.00 PROD2 DRILL SLPC tlrum brakes &rollers. static). 13:15 14:15 P PJSM. Slip and cut 30'drill 0.0 0.0 2/28/2018 14:15 2/282018 15:00 0.75 PRO DRILL SVR G P Perform full block height calibration 0.0 0.0 2/28/2018 15:00 2/28/2018 16:00 1.00 PROD DRILL BHA H P PJSM. M/U 63/4" RSS BHA to 307'. 0.0 307.0 2/28/2018 2282018 16:00 0.50 PROD2 DRILL TRIP P RIH f/ 307'-1730'. 16:30 307.0 1,730.0 2/28/2018 2/282018 16:30 16:45 0.25 PROD2 DRILL DHEQ P Shallow test MWD (250 gpm, 1,730.0 7/28/2018 228/2018 4.50 PROD2 DRILL TRIP 10 psi). Blowdown TDS 1,730.0 16:45 21:15 P RIH f/ 1730'- 7999' (celGact disp = 1,730.0 7,999.0 48.5/46.5 bbl) Operations Summary (with Timelog Dvpths) CD5-25 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start rung 2/28/2018 EM 7me 2/28/2018 Durtnr) 0.50 Phase FROM Op Code DRILL Ach*Coe' DE Tune P -T-% Operation slaty Depth (fl Ka End Depth (fiKa) 21:15 2145 P Wash down to 8094'and log RA tag. 7,999.0 8,094.0 Found on depth @ 8012' casing depth, 8073' bit depth. 2/28/2018 21:45 228/2018 22:15 0.50 PROD2 DRILL MPDA T7 PJSM. Pull trip nipple, install RCD 8,094.0 8,094.0 bearing. 2/28/2018 22:15 2/28/2018 23:30 1.25 PROD2 DRILL DISP P PJSM. Pump 35 bbl spacer followed 8,094.0 8,094.0 by 8.9 ppg Flo -Pro mud. Displace well @ 250 gpm, (1680-1400 psi) 2/28/2018 23:30 3/12018 00:00 0.50 PR0D2 DRILL OWFF P Flow check. Initial shut in choke= 17 8,094.0 8,094.0 psi. Bled off and observe slight Bow, decreasing, well static. Blow down TDS 3/1/2018 00:00 3/1/2018 03:00 3.00 PR0D2 DRILL TRIP P Cont RIH F/ 8094'-8510. Saw only 8,094.0 8,510.0 flicker with bit crossing whipstock. Observed fight hole / obstructions at 83161, 83221, 83621, 8390', 8421', 8444'. Pump (84-215gpm) down, ream (10-20 rpm) down, and work pipe down. 311/2018 03:00 3/1/2018 12:00 9.00 PROD2 DRILL DDRL P Drill 6-3/4" Alpine CLateral f/8510'- 8,510.0 9,840.0 9840'. TVD=74901. 270 gpm, 1500- 1800 psi, 140-150 rpm, 6-7k TQ on btm, 2.53k TO off trim, 15-18k WOB, ECD=9.6-10.05 ppg w/ 8.9-8.95 ppg MW, ADT=6.47 hrs, U/D/R=1721142/155K, O/A=450 psi. 3/1/2018 12:00 3/22018 00:00 12.00 FROD2 DDRL P Drill 6-3/4" Alpine C Lateral f/ 98401- 9,840.0 11,609.0 11609. TVD=7505'. 270 gpm, 1700- 2100si, 150 rpm, 7-9k TO on btm, 3- 41 TQ off btm, 12-16k WOB, ECD=9.83-10.16 ppg w/ 8.9 ppg MW, ADT=8.36 his, U/D/R=173/134/154K, O/A=450 psi. 018 00:00 00:0 32/2018 12:00 12.00 PROD2 DRILL DDRL P Drill 63/4" Alpine C Lateral f/ 11609'- 11,609.0 13,782.0 13782'. TVD=7532'. 270 gpm, 2150- 2440psi, 140-150 rpm, 9-12k TQ on btm, 45k TQ off btm, 12-16k WOB, ECD=10.06-10.57 ppg w/ 8.9-9.0 ppg MW, ADT=9.07 hrs, U/D/R=180/130/150K, O/A=425 psi. Faults @ 13620' & 13724' 3/2/2018 12:00 3/2/2018 19:30 7.50 PROD2 DRILL DDRL P Drill 6-3/4" Alpine C Lateral f/ 13782'- 13,782.0 14,833.0 14633'. TVD=7545'. 270 gpm, 2350- 2550psi, 140 rpm, 10-12k TQ on trim, 5-6k TO off btm, 12-15k WOB, ECD=10.32-10.55 ppg w/ 8.9-9.0 ppg MW, ADT=4.93 hrs, U/D/R=180/125/150 K, O/A=425 psi. Page 29/39 Report Printed: 3/21/2018 (,verations Summary (with Timelog Depths) CD5-25 Time Log Rig: DOYON 19 Job: DRILLING ORIGINAL start Mune 3/2/2018 End Time 3/2/2018 our (M 3.75 Phase PROD2 Op Cotle DRILL Activity Code CIRC The PTX O start Depth End 19:30 23:15 T Due to ImPulse modulator current 14,633.0 1144,,633.0 level increasing, tlownlink to switch to slower data rate (2HL3bps) to reduce current level. During downlink MWD signal was lost. Troubleshoot signal loss. Swap out manifold pressure transducer. Add defoamer to mud. Pump three anti -jam pills, alter flow rates. MWD signal improving but not perfect. Downlinks were sent to switch MWD to 12 Hz/3bps. Perform anit- jam pump rate schedule by slowing to 120 gpm to tum off ImPulse then stage to 270 gpm. MWD signal improved at 210 gpm and was perfect at 220 gpm. When increasing to 270 gpm the signal was very poor and SPP fluctuations were observed indicating ImPulse was having trouble demodulating at higher flow. Poor to no signal over 230 gpm. T2-1218 23:15 23:15 3/312018 00:00 0.75 PROD2 DRILL DDRL P Drill 6-3/4" Alpine C Lateral f/ 14633'- 14,633.0 14,685.0 14685'. TVD=7545'. 220-250gpm, 1800-2100psi, 140 rpm, 8-1 Ok TO on btm, 5-6k TO off btm, 7-1 Ok WOB, ECD=10.05-10.11 ppg w/ 8.9 ppg MW, ADT=0.21 hrs, U/D/R=180/125/150 K, O/A=425 psi. Losses +/-20 bblthr before crossing faults @ 13620' & 13724' and +/. 30- 35 bbVhr after faults. losses to formation: 626 bbls TT -Daily 00:0 018 00:00 3/3/2018 05:00 5.00 PROD2 DRILL DDRL P Drill 6314" Alpine C Lateral f/ 14685'- 14,685.0 15,238.0 15238'. TVD=7548'. 220-225 gpm, 1900-2055psi, 140 rpm, 9-11 k TQ on btm, 6k TO off btm, 7-12k WOB, ECD=10.12-10.37 ppg w/ 8.9-9.0 ppg MW, ADT=3.55 hrs, U/D/R=180/137/155 K, Unable to pump over +/- 230 gpm (pressure fluctuations and no MWD signal). Eventualy no MWD signal (off 200-220 gpm. 3/3/2018 05:00 3/3/2018 05:15 0.25 PROD2 DRILL BKRM T Backream out F/ -15238'-152201(270 15,238.0 15,220.0 gpm, 2400 psi, 130 rpm, 7.5K TO. Obtain SCRS. 3/3/2018 05:15 3/3/2018 05:45 0.50 PROD2 DRILL OWFF T Flow check, Well static. 15,220.0 15,220.0 3/3/2018 05:45 3!3/2016 09:00 3.25 PROD2 DRILL BKRM T Backream out fl 15220'-13850'. 270 15,220.0 13,850.0 gpm, 2250-2090 psi, 100 rpm Ramping annulus pressure on connections W1 MPD 3/3/2018 09:00 3/3/2018 10:00 1.00 PROD2 DRILL PMPO T Pump out f/ 13850'-13490'. 270 gpm, 13,850.0 13,490.0 2090 psi. Had pressure spike 13490f (2090 psi up to 2670 psi). Assume hole packing off. 3/3/2018 3/3/2018 10:00 11:15 1.25 PROD2 DRILL BKRM T Backream out fl 13490'-13224' 270 13,490.0 13,224.0 gpm, 2090-2410 psi, 60-80 rpm, 5.5- 6K TO. Still having pressure spikes and eratic pump pressure. Torque and P/U weight smooth. MWD is likely cause. Page 30/39 ReportPrinted: 3/21/2018 Operations Summary (with Timelog Depths) CD5-25 Rig: DOYON 19 Time Log Job: DRILLING ORIGINAL Stan Time 3/3/2018 Eno Time 3/3/2018 cur (ho 2.25 Phase PROD2 Dp COde DRILL Activity Code CIRC Time P -T -X �efahon Slat Depth (aKB) Eno Depth (W) 11:15 13:30 T At 13224', circulate hole clean. 270 13,224.0 13,224.0 gpm, 2400-2100 psi, 100 rpm, 5.5K TQ. 3/3!2018 13:30 3/3/2018 17:30 4.00 PROD2 DRILL SMPD T Strip out of hole f/ 13224'-8810'. 140 / 13,224.0 8,850.0 360 psi in /out slips. Had 15-25K OP @ 8810'. Slack off to 8850' 3/3/2018 17:30 3/3/2018 19:00 1.50 PROD2 DRILL BKRM T Backream f/ 8850'-8663'(220 gpm, 8,853.0 8,663.0 1360 psi, 80 rpm, 3-4K TO. 3/3/2018 19:00 3/3!2018 19:30 0.50 PROD2 DRILL SMPD T Line up and strip out f/ 8663-8630'. 20 8,663.0 8,660.0 -25K OP. Slack off to 8660'. 3/3/2018 19:30 3/3/2018 21:00 1.50 PROD2 DRILL BKRM T Backream out 88660'-8515', 8,660.0 8,515.0 200gpm, 1180 psi. Seeing pressure spikes. Decrease flow to 150 gpm, pressure smooth @ 860 psi. 21:0 018 21:00 3/3/2018 22:00 1.00 PROD2 DRILL PMPO T Pump out w/ 8515'-8300' w/ 150 gpm, 8,515.0 8,330.0 870 psi. (15K OP @ 8415', 10K @ 8410) 3/3/2018 22:00 3/3/2018 23:00 1.00 PROD2 DRILL SMPD T Strip out f/ 8300' abovevdndow to 8,330.0 8,094.0 8094'. Max overpull crossing window w/ BHA stabs and bit = 5K. 3/3/2018 23:00 3/4/2018 00:00 1.00 PROD2 DRILL DISP T PJSM. Pump 35 bbl high vis spacer 8,094.0 7,999.0 and displace hole w/ 9.4 ppg Ys Brine @ 240 gpm, 1760 psi, 40 rpm, 2K TQ, Recip pipe 8094'-7999' 3!4!2018 00:00 314/2018 00:30 0.50 PROD2 DRILL DISP T Cont to displace hole w/ 9.4 ppg Vis 7,999.0 8,094.0 Brine @ 240 gpm, 1760 psi, 40 rpm, 2K TQ, Recip pipe 8094'-7999'. 3/412018 00:30 3/4/2018 01:00 0.50 PROD2 DRILL OWFF T Flow check, well static 8,094.0 8,094.0 3/4/2018 01:00 3/4/2018 01:30 0.50 PROD2 DRILL MPDA T Pull RCD element, install trip nipple 8,094.0 8,094.0 3/4/2018 01:30 3/4/2018 05:00 3.50 PROD2 DRILL TRIP T POOH f/ 8094-7619', pump slug, 8,094.0 307.0 POOH to 307' 3/4/2018 05:00 3/4/2018 05:15 0.25 PROD2 DRILL OWFF T Flow check, slight losses. 307.0 307.0 3/4/2018 05:15 3/4/2018 06:00 0.75 PROD2 DRILL SHAH T Pull, handle and UD BHA It 307'- 307.0 0.0 surface. Bit Grade= 1 -3 -CT -S -X -1 -BT -DTF. (alsol partially plugged noale) 3/4/2018 06:00 3/4/2018 06:30 0.50 PROD2 DRILL SHAH T Clean and Gear dg floor. UD and P!U 0.0 BHA tools and Eqpt via Beaver Slide 0.0 3/4/2018 06:30 3/4/2018 07:00 0.50 PROD2 DRILL SVRG T Service TDS. (SIMOPS PJSM on WU 0.0 BHA) 0.0 314/2018 07:00 3/4/2018 0.75 PROD2 DRILL BHAH T M/U BHA to 306 07:45 0.0 306.0 3/4/2018 3/4/2018 0.75 PROD2 DRILL TRIP T RIH to 1729' 07:45 08:30 306.0 1,729.0 3/4/2018 08:30 3/4/2018 08:45 0.25 PROD2 DRILL DHEQ T Shallow testMWD. 1,729.0 1,729.0 3/4/2018 3/4/2018 08:45 11:45 3.00 PROD2 DRILL TRIP T RIH to 8002', wash down and log RA 1,729.0 8,053.0 tag on depth @ 8053' bit depth. 3/4/2018 3/4/2018 11:45 12:00 0.25 PROD2 DRILL MPDA T Pull trip nipple, install RDC element. 8,053.0 8,053.0 3/4/2018 3!4/2018 12:00 13:30 1.50 PROD2 DRILL DISP T Pump 35 bbl hi -vis spacer and 8,053.0 8,053.0 displace brine with 9.0 ppg mud. Page 31139 Report Printed: 3/21/2018 DOYON 19 End CGNerations Summary (with Timelog Njiths) CDS-25 Job: DRILLING 13:30 19:30 �.JU�IL` � rtlN IT 1R1_H to 15127', max 5K seen with BHr over whipstock, 10K seen @ high dogleg area (+/- 8417', no drag seen across fault or high gamma formation. 19:30 ME 12:00 12:00 100:00 12:00 12:00 20:00 2470 psi, 100 rpm, 7K TO. inking to tools to set up for 15789'. ND=7554'. 270 gpm, 2250- 2475psi, 140 rpm, 10-12 k TQ on btm, 7k TO off btm, 12-17k WOB, ECD=10.00-10.37 ppg w/ 8.9-9.0 ppg MW, ADT=2.66 hrs, U/D/R=180/125/160 K. Shutting chokes on connections. Pressure build-up = 9-44 psi. 17620. ND=7557'. 270 gpm, 2450- 2800psi, 140 rpm, 12-16 k TQ on btm, 8-9k TO off btm, 12-18k WOB, ECD=10.27-10.75 ppg w/ 8.9-9.0 PPg MW, ADT=8.75 hrs, U/D/R=195/107/150 K. Drilling w/ returns through poor -boy degasser 18834'. ND=7606'. 270 gpm, 2720- 3010psi, 140 rpm, 13-18 k TQ on btm, 9-11 k TQ off btm, 10-17k WOB, ECD=10.51-11.00 ppg w/ 8.9-9.0 ppg MW, ADT=7.93 hrs, U/D/R=203/95/155 K. Drill w/ returns to normal flowline after 17840' Line up directionally to cross 2nd fault. Increase Lube 776 concentration from 1.25% to 1.75% to lower torque. Nut Plug Fine added to active system to slow losses. Daily losses to formation: 534 bbis 20072. ND=7618'. 270 gpm, 2950- 3175psi, 140 rpm, 14-17 k TQ on btm, 9-11 k TQ off btm, 10-16k WOE, ECD=10.48-11.21 ppg w/ 8.9-9.1 ppg MW, ADT=9.01 hrs, U/D/R=230/NA/150 K. NOTE: Lost SOW @ 19977' 20973'. ND=7599.25'. 265-270 gpm, 3050-3320psi, 120-140 rpm, 14-17 k TO on btm, 9-11k TQ off btm, 8-16k WOB, ECD=10.67-11.33 ppg w/ 9.0- 9.1 ppg MW. ADT -5-69 hrs, U/D/R=220/NA/160 K. End 23:00 DOYON 19 l.Nerations Summary (with Timelog Dtpths) CDS-25 Job: DRILLING change frequency. Lost signal, trougleshoot, pump antijam sequence and fluids, downlink to restore original settings. No signal. R/B stand to CS:SU 00:00 --- """"' r�cruv' H Backreamout f/20834-20738'. 250 gpm, 2550 psi, 100 rpm.9K TO. Daily mud losses to formation: 575 3/7/2018 00:00 3/7/2018bbls 09:00 9.00 PROD2 CASING BKRM p Backream out f/ 20738'-18929'. 220- 250 gpm, pump pressure eratic 2770- 2450-2170 psi (likely due to failed MWD), 100 RPM, torque spiking at times with minor pack -offs @ 19619, 3/7/2018 3/7/20183.50 PROD2 CASING 19613, 19573, 19529, 19445. 09:00 12:30 CIRC p Circulate hole clean. 270 gpm (eratic PUMP @ 2810-3520 psi) 100 rpm, 10.5k TO, backream while circ to 18834' (SIMOPS>> UD 19 stands of 4" 14# OP from drillers side of derrick) 3/7/2018 12:30 3/7/2018 1.00 PROD2 CASING SMPD P 13:30 Blow down lines, line up to strip. Strip out f/ 18834'-18235'. Tight @ 18235', 3/7/2018 3/7/2018 3.50 PROD2 CASING tried 25K,OP, tried 45K OP. 13:30 17:00 BKRM p Backream out f/ 18235-18072'. 250 gpm, eratic pump 2500-3200 psi, 100 rpm, 8K TO. minor tight and packing 3/7/2018 17:00 3/7/2018off 0.25 PROD2 CASING SMPD spots 17:15 T Line up and attempt to strip out. 3/7/2018 3/7/20182.50 PROD2 CASING CIRC Pulled up to 45K OP. 17:15 19:45 p Circulate hole clean. 250-270 gpm (eratic pump @ 2810-3520 psi) 100 rpm, 10.5k TO, backream while circ to 3/7/2018 19:45 3/7/201818072-17881' 0.25 PROD2 CASING BOPE P 20:00 Function test BOP rams and annular. 3/7/2018 20:00 3/7/2018 20:15 0.25 PROD2 CASING SMPD 7 Line up and attempt to strip out. Overpulled up to 35K, slack off string free down @ 100K. OP 50K. Jars 3/7/2018 3/7/2018 2.25 PROD2 CASING fired indicating tight @ SHA/Bit. .20:15 22:30 BKRM P Backream out f/ 17881-16926'260- 7881-16926'260-270 270gpm, eratic pump 2500-3200 3/7/2018 3/8/2018 1.50 PROD2CASING psi, 100 rpm, 8-1 OK TO. 22:30 00:00 CIRC P Circulate hole clean. 250-270 gpm (eratic pump @ 2810-3520 psi) 100 rpm, 7 TO, Backream slowly while 3/8/2018 00:00 3/8/2018circ 0.75 PROD2 CASING CIRC 16926'-16789' 00:45 P Circulate hole clean. 270 gpm (eratic PUMP @ 2900-3450 psi) 100 rpm, 7- 8k TO, Backream slowly while circ 3/8/2018 oo:as 3/8/2018 0.25 PROD2 CASING SMPD 16789'-16740'. P o1:00 Line up and strip out f/ 16740'-16645'. Holding 380/100 psi annulus pressure 3/8/2018 01:00 3/8/2018 0.50 PROD2 CASING MPDA (in/out slips). 01:30 T MPD element failed. Slow lines, change element. C.Nerations Summary (with Timelog Depths) CD5-25 Rig: DOYON 19 a,rown, complete weekly MP2 3/10/2018 Time Log 2.00 COMPZ2 CASING inspection, calibrate block height. Job: DRILLING Start roe 3/9/2018 End rare 3/10/2018nn Dar(hri phase 11.00 COMMCOMPZ2 Op Dote Addv' Coen p -r -x operation CASING 4.00 COMPZ2 CASING TRIP I Stan pB�' 13:00 00:00 RUNL p Run liner on 4" DP f/ 13937'-19551. 13,937.0 3/11/2018 0.25 COMPZ2 CASING OWFF 50.4170.5 bbl) Fill DP on the fly. Tight / difficult 04:15 P Flow check, slight drop. running in F/ 18995'-19551'. (through high gamma ray formation). Float leaking. Circulate down DP @ 100- 150 gpm (500-750 psi) to wash float 3/10/2018 3/10/2018 3.50 COMPZ2 while RIH. CASING RUNL P 00:00 03:30 Cont running liner on 4" DP f/ 19551- 19,551.0 19797. Tight / difficult running in. having to work liner down. Float leaking. Circulate down DP @ 100- 150 gpm (500-750 psi) to wash float 3/10/2018 3/10/2018 2.00 COMPZ2 while RIH. CASING HOSO P 03:30 05:30 Drop 29/32" phenolic ball and pump 19,797.0 down w/ 4 bpm, 920 psi. Slow to 2 bpm, 420 psi @ 1160 slits. Slack off to set liner shoe @ 19800' and running tool in compresion.Land setting ball and pressure up to 3450 Psi to release liner. Pick up, liner dd not release. Work string up/down and repressors to release runnig tool several times. Break single, blow down TDS. WU single 018 05:30 05:30 3/10/2078 07:45 2.25 COMPZ2 CASING HOSO T Work pipe to attempt to obtain solid set down and compression at liner 19,800.0 running tool. Break single, M/U stand. Run in to 19829', pressure up to 3600 Psi. pick up. lost 16K from previous PIU weight indicating tool released. (TOL = 13269', Shoe=19829') Pressure up to 4360 psi and blow ball seat. Pick up to 13169'. 3/10/2018 07:45 3/10/2018 08:15 0.50 COMPZ2 CASING MPDA P Pull trip nipple, install RCD bearing. 19,829.0 3/10/2018 08:15 3/10/2018 09:00 0.75 COMPZ2 CASING SMPD T Attempt to strip out of hole. Floats not holding. Attempt to Gose float W/O 13,169.0 3/10/2018 3/10/2018success. 9.00 COMPZ2 CASING PMPO 09:00 18:00 P Pump out of hole f/ 13169'-8026' 210- 13,169.0 3/10/2018 3/10/2018 0.75 COMPZ2 125 gpm, 950-400 psi CASING DISP 18:00 18:45 P Pump 30 bbl hi -vis spacer and 8,026.0 3/10/20183/10/2018 0.25 COMPZ2 displace hole to 9.4 ppg vis brine CASING OWFF 18:45 19:00 P Flow check, well static 8,026.0 3/10/2018 19:00 3/10/2018 19:30 0.50 COMPZ2 CASING MPDA P Flush MPD equipment w/ clean water. SIMOPS> PJSM for RCD removal 8,026.0 a,rown, complete weekly MP2 3/10/2018 3/11/2018 2.00 COMPZ2 CASING inspection, calibrate block height. 22:00 00:00 TRIP P POOH w/ 8026- 5645(Calc/act fill = 3/11/2018 00:00 3/11/2018 4.00 COMPZ2 CASING TRIP P 46/84 bbl) 04:00 POOH w/ 5645'-39' (CalGact fill = 3/11/2018 3/11/2018 0.25 COMPZ2 CASING OWFF 50.4170.5 bbl) 04:00 04:15 P Flow check, slight drop. DOYON 19 04:45 Operations Summary (with Timelog Depths) CDS-25 Job: DRILLING i.iean, Gear n poor. tuu to fun 2ntl 0.Q 04:45 05:30 0.0 3/11/2018 05:30 3/11/2018 2.75 COMPZ2 CASING PUTB P PJSM, run TXP liner f/0-993'. 0.0 06:15 packer M/U Baker packer (tlisabled) and 1,038.0 running tool. M/U bumper sub and X/O to DP to 1038'. 3/11/2018 08:15 3/11/2018 08:30 0.25 C0MPZ2 CASING CIRC P M/U stand 1 DP. Break circulation, circ 1,038.0 1,038.0 Q 3 bpm 120 psi. BID TDS. 3111/2018 08:30 3/11/2018 14:30 6.00 COMPZ2 CASING RUNLP . RIH w/ 4-1/2" liner on 4" DP f/ 1038' - 1,038.0 9,243.5 9245'. P/U=170K, S/0=155K. Pick up single DP, run in to set depth. 3!11/2018 14:30 3/11/2016 15:00 0.50 COMPZ2 CASING CIRC P Circulate 2.5-3.0 bpm, 230-300 psi, 9,243.5 9,243.5 circulate 82 bbl 3/11/2018 15:00 3H 1/2018 16:00 1.00 COMPZ2 CASING HOSO P Drop 29!32 ball. Pum - w/ 3 9,243.5 8,227.0 bpm, 300 psi. after 60 bbl slow to 2 bpm, 200 psi. Land ball on seat. Bleed off pressure, Slack off to put hanger in compassion. Pressure up to 3600 psi to setirelease liner. P/U to check, liner released. (TOL=8227, shoe=9243.5'. Pressure up and blow ball seat @ 4350 psi. 3/11/2016 16:00 3/11/2018 16:30 0.50 COMPZ2 WELLPR OWFF P UD single, flow check, slight drop. 8,227.0 8,140.0 B/D TDS. 3/11/2018 16:30 3/11/2018 21:00 4.50 COMPZ2 WELLPR TRIP P POOH f18140-54. 8,140.0 54.0 3/11/2018 21:00 3/112018 21:30 0.50 COMPZ2 WELLPR BHAH P UD liner running tool. 54.0 0.0 3/112018 3/112018 0.50 COMPZ2 WELLPR SHAH P Clean and clear dg floor 21:30 22:00 0.0 0.0 3/11/2018 22:00 3/11/2018 1.50 COMPZ2 EVALWB ELOG P PJSM, Spot a -line truck, Mob 0,0 23:30 equipment to dg floor and pipe shed. Q.0 R/U E -line sheaves, Prep toolstring. 3/112018 23:30 3/122018 00:00 0.50 COMPZ2 EVALWB ELOG P Assemble SLB USIT with WellTech 0.0 tractor to 40'. 40.0 3/12/2018 00:00 3/12/2018 12:00 12.00 COMPZ2 EVALWB ELOG P M/U and run in w/ SLB USIT with 40.0 8,108.0 Welfrech tractor. Log up repeat pass 8105-7670, RIH, Log main pass 8108 -surface in Corrosion Mode (for casing wear). (well losing 2-3 bbl/hr while logging) 3/12/2018 12:00 3/122018 14:45 2.75 COMPZ2 EVALWB ELOG P R/D a -line equipment. SIMOPS» 8,108.0 0.0 Mob completion tools to dg floor, cleaning pits. 3/12/2018 14:45 3/122018 15:00 0.25 COMPZ2 FISH SHAH P Mob Bakerwhipstock retrieval tools to 0.0 floor 0.0 3/122018 15:00 3/122018 16:00 1.00 COMPZ2 FISH SHAH P PJSM. M/U Baker whipstock retrieval 0.0 238.0 BHA including SLB MWD tool to 238' 3/12/2018 3/122018 16:00 17:00 1.00 50MPZ2 FISH TRIP P Tdp in hole to 1850'. 238.0 1,850.0 18 3/12/2018 17:30 ;17:30 0.50 COMPZ2 FISH DHEO P Shallow test MWD. 270 gpm, 950 psi 1,850.0 1,850.0 18 3/1212018 21:00 3.50 COMPZ2 FISH TRIP P Cont RIH f! 1850'-8038'. Calc/Adi disp 1,850.0 8,038.0 =49/41 bbl Page 36/39 Report Printed: 312112018 Operations Summary (with Timelog Depths) CD5-25 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Time 3/12/2018 End Timo 3/122018 DurM 1.00 phageOp COMPZ2 Code FISH Activity Cotla Tmw P -T -x Operation ��th t8 End 21:00 22:00 FISH P Log RA tag on depth @ 8013'. Orient 133.0 8,196.0 hook jet to 145° left. Wash down to 8196', jet across whipstock slot to clean same 2x. Orient to 35° right, slack off and set down 3K on whipstock, pick up and verify latch, OP 20K, slack off, OP 40K, jars fired, OP 35-40K and whipstock free. 018 22:D0 22:00 3!1212018 22:30 0.50 COMPZ2 FISH TRIP "157- POOH w/ whipstock to 8133'. 8,196.0 8,133.0 3/122018 22:30 3/122018 23:00 0.50 COMPZ2 FISH CIRC T57- CBU 290 gpm, 1250 psi. No gas on 8,133.0 8,133.0 BU. 018 23:00 23:00 3/122018 23:15 0.25 50MPZ2 FISH OWFF P Flow check, V drop 8,133.0 8,133.0 18 23:15 23:15 3/132018 00:00 0.75 PZ2 COMSH FI TRIP P POOH f! 8733'-7500' calGac fill = 8,133.0 7,500.0 3.118.0 bbl 3/13/2018 00:00 3/13/2018 04:15 4.25 COMPZ2 FISH TRIP P POOH V 7500'-993' 7,500.0 993.0 3!13/2018 3!13/2018 0.25 COMPZ2 FISH OWFF P Flow check, slight drop 04:15 04:30 993.0 993.0 3/1 04:!Ifo18 3/13204:45018 0.25 50MPZ2 FISH TRIP P POOH H 993'-332' celclact fill = 993.0 332.0 45.1/89.5 bbl 3/132018 04:45 3/132018 07:15 2.50 COMPZ2 FISH BHAH P UD retrieval BHA and whipstock f/ 332.0 D.D 332' -surface. 3/13/2018 07:15 3/13/2018 08:00 0.75 COMPZ2 FISH SHAH P Clean/clear rig floor. UD BHA 0.0 components f/ rig floor. 0.0 3/13/2018 08:00 3/13/2018 09:00 1.00 COMPZ2 RPCOMP RURD P R/U to run TBG. MIU X/O to TIW 0.0 0.0 3/13/2018 09:00 3/132018 09:30 0.50 COMPZ2 RPCOMP W W WH P M/U stack washer, flush BOP 2X, blow 0.0 0.0 down top drive 3/13/2018 09:30 3/132018 1.00 COMPZ2 RPCOMP RURD P Pull drilling wear bushing (no unusual 0.0 10:30 wear). Run 9" ID wear bushing. 0.0 3/13/2018 10:30 3/132018 20:00 9.50 COMPZ2 RPCOMP PUTB P PJSM. Run 4-12", 12.6#, 1.80, 0.0 8,229.0 TSH563 upper completion f/ surface to 8229'. (calclact disp = 37 / -39 bbl). 3/13/2018 20:00 3/13/2018 21:30 1.50 COMPZ2 RPCOMP HOBO P M/Ujoint# 200. Wash down @ 1bpm, 8,229.0 8,319.0 50 psi. Observe seals entering liner top sealbore. Stop pump. Slack off. M/U jt 201, run in and locate on no-go. Mark neutral position (EOT@ 8318.64), Set 30K down. 3/132018 21:30 3/13/2018 22:00 0.50 COMPZ2 RPCOMP HOBO P Pick up and pull joints 201-200-199 to 8,319.0 8,226.0 8226'. 3/13/2018 22:00 3/132018 22:30 0.50 COMPZ2 RPCOMP RURD 15 Pull 9" ID wear bushing 8,226.0 8,226.0 3/13/2018 22:30 3/132018 23:00 0.50 COMPZ2 RPCOMP HOBO P M/U Ix 9.79'space out pup. Run in jt 8,226,0 8,277 0 199 to 8277' 18 23:00 23:00 3/142018 00:00 1.00 COMPZ2 RPCOMP CRIH - P PJSM. Pump 48 bbl corrosion inhib 8,277.0 8,277.0 brine followed by 125 bbl 9.4 Vis brine. 3/14/2018 3/142018 00:00 00:30 0.50 COMPZ2 RPCOMP RURD P RID circ lines, B/D choke/kill lines 8,277.0 8,277.0 3/142018 3/14/2018 00:30 01:30 1.00 COMPZ2 RPCOMP THGR P M/U hanger and landing Jt "A". 8,277.0 8,277.0 3/14/2018 3/142018 01:30 03:00 1.50 COMPZ2 RPCOMP THGR P Run in and land hanger in wellhead. 811,277.0 8,315.0 Test M2M seals to 250/5000 psi for 5/10 min on chart. Page 37139 Report Printetl: 3/21/2018 DOYON 19 07:00 107:00 08:00 108:30 109:30 112:00 12:00 21:00 3/14/201 -...... 13:00 r 3114/2018t3/14/2 17:00 119:30 Operations Summary (with Timelog Depths) CD5-25 Job: DRILLING and test to 4300 i Pressure upon tubpsing to set packer (packer depth = 7281'), Pressure test tubing to 4200 psi for 30 min on chart. Bleed tubing to 2000 psi. Pressure up on annulus to test casing & packer to 3300 psi for 30 min on chart. Bleed off casing and tubing. Pressure up on annulus to activate shear out valve. Shear @ 2200 psi. Observed returns up tubing. shut sown, UD lending joint "'A", blow down lines MIU HP-BPV, Install w/ T -Bar. M/U landing Joint "B". Test BPV in direction of flow to 2500 psi for 15 min on chart. Bleed off, UD landing Jt "B". B/D lines Wash BOP. B/D top drive, choke/kill, hole fill, mud lines. EL/Deasing UD trip nipple. Remove RCD remove flow -box, remove ve, disconnect hole fill, line., DeenergL koomey casing tools antl equipment floor. UD mousehole. Mob valves to cellar. emove choke line remove and replace kill side manual and HCR valves. SIMOPS> Break ram doors for between well maintenance. Remove kill line, remove and replace kill side manual and HCR valves. SIMOPS> Replace accumulator hydraulic line connections. R/D 20:00 21:00 --- -...... '""'°" r NID BOP stack, move to stump and secure. SIMOPS> change saver sub 3/14/2018to 21:00 3/14/2018 22:30 1.50 COMPZ2 WHDBOP NUND P 0. P p end NU tree. Test hanger neck 3/14/2018 3/14/2018 0.50 COMPZ2 WHDBOP NUND P seal to 250/5000 psi. 22:30 23:00 R/U tree sceffold 3/14/2018 23:00 3/15/2018 00:00 1.00 COMP72 WHDBOP PRTS P Fill tree with diesel. Work out air, install tree cap. SIMOPS> Cont 3/15/2018 3/15/2018 1.75 COMPZ2 WHDBOP SVRG changing saver sub. 00:00 01:45 P Cont change oul saver sub to NC50. 3/15/2018 3/15/2018100 . COMPZ2 WHDBOP PRTS Prep tree for testing. 01:45 02:45 P Test tree to 250/5000 for 10/70 min on 3/15/2018 02:45 3/15/2018chart. 04:00 1.25 COMPZ2 WHDBOP MPSP P R/U to pull bpv, Check pressure, bleed off on annulus. R/U lubricator and pull DOYON 19 06:15 10:30 10:30 00:00 112:15 3/16/2018 3/165 12:15 12:45 3/16/2018 3/17/2 5 00:00/2018 3/17/20 01:002018 3/17/210 01:452018 3/17/2( g 04:452018 3/17/20 09:30018 3/17/20 11:30018 3/17/20'12:00 Operations Summary (with Timelog Depths) CD5-25 Job: DRILLING u�Z ones a oan mm pump to wellheatl and tree back to pits. Pressure test lines. PJSM. Pump 84 bbl diesel down IA @ 1.5 bpm, 460-800 psi. Shut in and 'U-tube diesel down tubing and allow well to balance. Final pressure = 50 psi on tubing and annulus. R/U lubricator. Set HP-BPV. Test in direction of flow to 2300 psi for 15 min on chart. Bleed back pressure to 150 psi on IA. Shut in. OA pressure = 250 lines. R/D lines and lubricator. Install 90' mousehole. UD 4" DP from derrick to pipe shed, 87 stands laid out. Removing Super Sliders. Culled 12 joints damaged / excessively wom 15.7# DP. SIMOPS> Cleaning pits, disassemble mud pumps for dg move, finish replacement of accumulator 75 stands laid out. Removed Super Sliders. Culled damaged / excessively worn DP. 103 stands laid out. Culled damaged / excessively worn DP. floor. PJSM on removing SLB "Te Piece" from standpipe. Remove kelly hose from standpipe Remove SLB tee piece and transducer. Re -install kelly hose. Remove SLB transducer cables. Clean piperacks, pollution pans. P sub & ppe shed for dg move Blow down ball mill, water lines, ste lines from sub. Disconnect service Rig off HighLine @ 06:00. Rig released @ 12:00 hrs. Final report. Moving dg to MT6-03. NADConversion Western North Slope C135 Alpine West Pad CD5-25L1 CD5-251_1 ConocoPhillips Definitive Survey Report 14 March, 2018 Final Definitive Survey Verified and Signed -off All targets and/or weirposition objectives have been achieved. LL' Yes '-; No 1 have checked to the best of my ability that the following data is correct. -1 Surface Coordinates `I Declination & Convergence L:i GRS Surrey Corrections Eij Survey Tool Codes SLB DE Brandon Temple Digitally sgred by Brandon Templm Date: 2018,03A41015:19 -08W' Client Representatives Welfeng Dal W9ei311ignedbYWeifngDai' Date: 3M4118 ConocoPhillips ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well CD5-25 Project Site: Western Norm Slope TVD Reference: CD5-25 actual @ 70 28usft (Doyon 29) Well: CD5 Alpine West Pad CD5-25 MD Reference: COS -25 actual @ 70.28usft (Doyon 29) Wellbore: CDS-25L1 Norm Reference: True Design: CD5-251-1 Survey Calculation Method: Minimum Curvature 36.58 Database: OAKEDMP2 Projem Western Norm Slope, Norm 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 CD5-25 Well Position +WS 0.00 usft Northing: 5,965,786.04 usft Latitude: 70° 18'49.000 N +E/ -W 0.00 usft Basting: 349,077.13 usft Longitude: 151° 13'23.470 W Position uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 33.70 usft Wellborn CD5-251-1 Magnetics Model Name Sample Data Declination Dip Angle filed strength BGGM2017 2/10/2018 16.76 80.78 57,438 CD5-25L1 From To lust) 100.00 384.97 2,235.73 8,134.54 8,698.47 15,252.91 LNotes: 1.0 Phase: ACTUAL Tre On Depth: 8,134.54 TVDSS Depth From (TVD) (usft) +NI -S lady +BI -W (usft) Direction P) 36.58 0.00 0.00 152.15 Survey Program Date From To lust) 100.00 384.97 2,235.73 8,134.54 8,698.47 15,252.91 (usft) Survey (Wellbore) 349.00 C05-25 Srvy 1 - SDI GYD-GC-SS (CD5 2,138.06 CDS-25 Srvy 2-SLB_MWD+GMAG(CD 8,134.54 CD5-25 Srvy 3-SLB_MWD+GMAG (CD 8,603.78 CD5-25L1 Sivy 1 - SLB -INC -Only -Filler ( 15,159.42 CD5-2511 Sivy 2-SLB_MWD+GMAG(C 20,867.34 C135-251-1 Srvy 3 -SLB MWD+GMAG (C Tool Name Description GYD-GC-SS Gyrodata gyro single shots MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD -INC ONLY (INC>10°) MWD -INC_ ONLY_ FILLER ( INC>10°) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC MWD+IFR-AK-CAZ-$C MWD+IFR AK CAZ SCC Survey Date 1/26/2018 10:15. 1/26/2018 10:201/29/2018 7:29a 2/25/2018 11:58: 3/1/2018 11:21:0 3/4/2018 10:19:[ Survey MD Inc Azi TVD TVDSS +WS+BIW Map Map Vertical luau rl 11 fusty fusty fusty Northing Basting DLS Section fust) (t) (t) (°1100') (ft) Survey Tool Moms 36.58 0.00 0.00 36.58 -33.70 0.00 0.00 5,965,788.04 349,077.13 0.00 0.00 UNDEFINED 100.00 0.33 229.01 100.00 29.72 4).12 -0.14 5,965,785.93 349,076.99 0.52 0.04 GYD-GCSS(1) 115.00 0.31 224.15 115.00 44.72 -0.18 4)20 5,965,785.87 349,076.93 0.22 0.06 GYD-GCSS(1) 200.00 024 235.84 200.00 129.72 -0.44 41.51 5.965.765.61 349,076.81 0.11 0.15 GYD-GC-SS(1) 300.00 0.51 225.11 300.00 229.72 -0.87 41.99 5,965,785.19 349,078.12 0.28 0.31 GYD-GCSS(1) 349,00 0.64 238.56 348.99 278.71 -1.17 -1.38 5,965,784.90 349,075]2 0.38 0.39 GYD-GCSS(1) 384.97 0.65 222.01 384.96 314.68 -1.43 -1.69 5,965,784.65 349,075.41 0.52 0.47 MWD+IFR-AK-CAZ-SC(2) 476.04 0.73 228.44 478.02 405.74 -2.20 -2.47 5,965,783.90 349,074.81 0.12 0.79 MWD+IFR-AK-CAZ-SC(2) 567.44 0.25 211.50 587.42 497.14 -2.75 301 5,985,783.35 349,074.06 0.54 1.03 MWD+IFR-AK-CAZSC(2) 859.13 0.01 54.50 659,11 588.83 -2.92 3.11 5,965,783.19 349,073.96 0.28 1.13 MWD+IFR-AK-CAZSC(2) Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-25 Project Western Norm Slope +E, Map Site: CD5 Alpine West Pad TVD Reference: CDS-25 actual @ 70.28usft (Doyon 29) Well: CDS-25 MD Reference: CD5-25 actual @ 70.28usft (Doyon 29) Wellbore: CD5-251.1 Norm Reference: True Design: CD5-251.1 Survey Calculation Method: Minimum Curvature Database: OAKEOMP2 (Survey (R) IRI (°1100') MD Ine AL1 TVD TVDSS +W.S +E, Map Map Vertical (MO fo.88 (°) PI (ustq (usfy (usfp NOMing Easting US Section (use (R) IRI (°1100') (ft) Survey Tool Name 749.1 0.56 7949 749.84 679.58 -2.83 -2.67 5,965,7M 27 349,074.41 0.61 1.26 MWD+IFR-AK-CAZSC(2) 84343 1.00 6966 843.40 773.12 -2.47 -145 5,965,783.81 349,075.63 0.49 1.50 MWD+IFR-AK-CAZ-SC(2) 938.92 1,06 81.67 938.88 868.60 -2.05 0.20 5,965,783.99 349,077.29 0.23 1.91 MWD+IFR-AK-CAZ-SC(2) 1,033.39 1.56 112.60 1,033.32 963.04 -2.42 2.26 5,965,783.58 349,079.33 0.90 3.19 MWDHFR-AK-CAZSC (2) 1,127.67 2.10 13444 1,127.55 1,057.27 x.12 4.67 5,965,781.83 349,081.72 0.93 5.82 MWD+IFR-AK-CAZSC(2) 1,221.37 3.11 150.49 1,221.16 1,150.88 4.53 715 5,965,778.37 349,084.13 1.32 10.00 MM.IFR-AKCA2.4C(2) 1,314.73 4.11 157.89 1,314.33 1,244.05 -12.84 966 5,965,773.02 349,086.53 1.18 15.86 MWD+IFR-AK-CAZ-SC(2) 1,409.76 5.94 160.87 1,408.99 1,338.71 -20.64 12.55 5,955,765.16 349,089.26 1.94 24.11 MWD+IFR-AK-CAZ-SC(2) 1,504.61 7.37 166.08 1,503.20 1,432.92 31.18 15.62 5,965,754.56 349,092.12 1.64 34.87 MWD+IFR-AK-CAZSC(2) 1,599.23 8.77 169.02 1,596.88 1,526.60 -44.15 1846 5,965,741.53 349,094.69 1.54 47.66 MWD+IFR-AK-CAZ-SC(2) 1,692.63 9.38 168.76 1,689.11 1,618.83 -58.61 21.30 5,965,727.02 349,097,24 065 61.77 MWD+IFR-AKCAZ.SC(2) 1,787.07 10,10 172.72 1,782.19 1,711.91 -74.37 23.85 5,965,711.21 349,099.47 1.04 76.90 MWD+IFR-AK-CAZ-SC(2) 1,881.45 9.66 172.30 1,875.14 1,804.86 -90,59 25.98 5,965,694.96 349,101.28 0.27 92.23 MWD+IFR-AK-CAZSC(2) 1,975.40 10.28 170.95 1,967.65 1,897.37 -106.84 28.38 5,965,678.67 349,103.35 0.51 107.72 MWD+IFR-AKCAZSC(2) 2,068.89 10.41 172.71 2,059.62 1,989.34 -123.45 30.76 5,965,662.01 349,105,40 0.37 123.52 MWD+IFR-AK-CAZ-SC(2) 2,138.06 10.23 175.99 2,127.67 2,057.39 -135.78 31.98 5,965,649.68 349,106.37 0.89 134.99 MWD+IFR.AKCAZSC(2) 2,235.73 10,46 176.97 2,223.75 2,153.47 -153.29 33.06 5,965,632.14 349,107.09 0.30 150.97 MWD+IFR-AK-CAZ-SC(3) 2,268.39 9.88 175.18 2,275.58 2,205.30 -162.56 33.69 5,965,622.85 349,107.54 1.25 159.47 MWD+IFR-AK-CAZ-SC(3) 2,38348 9.26 189.67 2,369.35 2,299.07 -178.22 35.75 5,965,607.16 349,109.28 1.16 174.27 MWD+IFR-AKCAZSC(3) 2,477.76 8.36 165.15 2,462.52 2,392.24 -192.30 38.86 5,965,593.01 349,112.12 1.20 188.18 MWD+IFR-AKCAZSC(3) 2,571.70 7.92 158.84 2,555.51 2,48523 -204.94 42.95 5,965,580.29 349,115.95 1.06 201.27 MWD+IFR-AKCAZ-SC(3) 2,666.10 8.60 154.61 2,648.94 2,578.66 -217.38 48.32 5,965,567.75 349,121.07 0.97 214.78 MWD+IFR-AK-CAZ-SC(3) 2,760.82 8.55 154.66 2,742.60 2,672.32 -230.15 54.37 5,965,554.67 349,126.86 0.05 228.89 MWD+IFR-AK-CAZ-SC(3) 2,855.34 8.59 154.53 2,836.06 2,765.78 -242.87 60.42 5,965,542.03 349,132.65 0.05 242.96 MWD+IFR-AKCAZSC(3) 2,949.34 8.56 153.95 2,929.01 2,858.73 -255.49 66.51 5,965,52929 349,138.48 0.10 256.97 MWD+IFR-AKCAZSC(3) 3,043.51 8.62 154.57 3,022.12 2,951.64 -268.16 72.62 5,965,516.50 349,144.33 0.12 271.02 MWD+IFR-AKCAZSC(3) 3,138.12 8.64 156.78 3,115.66 3,045.38 -281.09 78.46 5,965,503.45 349,149.92 0.35 285.19 MWD+IFR-AK-CAZSC(3) 3,232.76 8.50 157.82 3,209.25 3,138.97 -294.10 83.91 5,965,490.33 349,155.10 0.22 299.23 MWD+IFR-AK-CAZ-SC(3) 3,326.85 8.56 158.59 3,302.30 3,232.02 307.06 89.09 5,965,477.27 349,160.02 0.14 313.11 MWD+IFR-AKCAZSC(3) 3,421.03 8.50 155.14 3,395.44 3,325.16 -319.90 94.57 5,965,464.33 349,165.24 0.55 327.03 MWD+IFR-AKCAZSC(3) 3,515.95 8.57 151.66 3,489.30 3,419.02 332.49 100.88 5,965,451.81 349,171.30 0.55 341.11 MWD+IFR.AKCAZSC(3) 3510.52 8.38 151.50 3,582.84 3,512.56 -34415 107.51 5,965,439.23 349,177.68 0.20 W&W MWD+IFR-AK-CAZ-SC(3) 3,704.08 8.57 153.16 3,675.38 3,605.10 356,96 113.91 5,965,426.89 349,183.83 0.33 368.83 MWD+IFR-AK-CAZ-SC(3) 3,798.76 8.51 15,144 3,769.01 3,698.73 369.58 120.12 5,965,414.15 349,18978 0.21 3,890.22 8.58 153.20 3,85946 3,789.18 381.77 382.88 MWD+IFR-AKCAZ-SC(3) 126.11 5,965,401.84 349,195.53 0.22 396.47 MWD+IFR-AKCAZSC(3) 3,984.46 8.52 152.18 3,952.65 3,882.37 394.22 132.54 5,965,369.27 $49,201.71 0.17 410.48 MWD+IFR-AKCAZSC(3) 4,078.35 8.36 151.67 4,045.52 3,97524 406,36 139.02 5,965,376.98 349,207.95 0.19 424.26 MWD+IFR-AKCAZSC(3) 4,172.19 8.54 150.09 4,138.34 4,068.06 418.43 145.74 5,965,364.80 349,21441 0.31 4,266.15 8.48 150.33 4,231.27 4,160.99 430.49 438.04 MWD+IFR-AKCAZSC(3) 4,361.38 152.64 5,965,352.60 349,221.08 0.07 451.94 MWD+IFR-AKCAZ-SC(3) 8.43 152.17 4,325.46 4,255.18 442.77 159.38 5,965,340.19 349,227.56 0.29 465.94 MWD+IFR-AKCAZSC(3) 3/1402018 8:52:51AM Page COMPASS 5000.14 Budd 85 ConocoPhillips Definitive Survey Report Company: NADConwmion Local Coordinate Reference: Well CDS-25 Project: Western North Slope TVD Reference: CD5-25 actual @ 70.28usft (Doyon 29) Site: Well: CD5 Alpine West Pad MD Reference: CDS-25 actual @ 70.28usft (Doyon 29) (ustt) C05-25 North Reference: True Wellbore: CD5-251-7 Survey Calculation Method: Minimum Curvature Design: C05.251-1 Database: OAKEDMP2 Sunyr 8.61 156.83 4,511.71 MD Inc AZI TVD TVDSS +NIS +E/ -W Map Northing (Wf) 1°) r) (usR) (ustt) (nsm (usfa 4,455.96 8.42 15442 4,419.02 4,348.74 455.14 165.60 5,965,327.70) 4,549.68 8.61 156.83 4,511.71 4,441.43 18718 171.33 5,965,314.95 4,642.01 8.48 160.15 4,603.02 4,532.74 480.54 176.36 5,965,302.09 4,736.44 8.35 160.79 4,696.43 4,626.15 .493.56 180.98 5,965,28898 4,830.24 7.80 16043 4,789.30 4,719.02 -505.99 185.35 5,965,276.46 4,924.82 7.80 159.90 4,883.00 4,81272 -518.07 189.71 5,965,264.31 5,019.19 7.89 162.63 4,976.49 4,906.21 530.26 193.84 5,965,25263 5,112.65 7.61 175.76 51069.10 4,998.82 542.58 196.21 5,965,239.69 5,207.39 8.00 178.55 5,162.97 5,092.69 -555.40 196.84 5,985,226.84 5,301.91 8.12 163.05 5,256.56 5,186.28 -568.37 198.W 5,965,213.84 5,397,10 7.52 159.28 5,350.87 5,280.59 -580.82 203.12 5,965,201.50 5,491.76 6.52 158.17 5,044.82 5,374.54 591.41 207.31 5,965,19083 5,586.57 7.11 158.71 5,538.96 5,468.68 501.87 21144 5,985,180.09 5,680.35 6.80 156.63 5,632.05 5,561.77 812,37 215.75 5,965,169.50 5,774,44 7.83 145.31 5,725.38 51655.10 822.76 221.61 5,965,159.00 5,869.20 9.08 135.63 5,819.11 5,748.83 833.41 230.51 5,965,148.17 5,963.06 8.71 135.97 5,911.84 5,841.56 843.81 240.63 5,965,137.57 6,058.21 8.93 142.39 6,005.87 5,935.59 854.85 250.15 5,985,126.35 6,152.52 9.60 156.65 6,098.96 6,028.68 867.87 257.73 5,965,113.18 6,246.39 10.91 157.73 6,191.33 6,121.05 683.27 26420 5,965,097,65 6,341.09 13.03 148.68 6,283.97 6,213.69 -700.69 273.15 5,965,080.06 6,436.04 17.49 146.37 6,375,55 6,305.27 -721.72 288.62 5,965,058.76 6,531.16 19,69 150.59 6,465.71 6,395.43 -747.59 302.41 5,965,032.58 6,624.79 21.53 159.49 6,553.36 6,483.08 477.43 316.18 5,965,002.47 6,719.07 22.89 162.22 6,640.65 6,570.37 811.10 327.84 5,964,988.58 6,813.14 26.12 158.01 6,726.24 6,655.96 -847.73 341.19 5,964,931.69 6,908.24 29.12 155.94 6,810.49 6,740.21 -88828 358.46 5,964,890.80 7,002.81 33.21 155.09 6,891.40 6,821.12 -932.80 378.76 5,964,845.89 7,096.49 37.51 156.59 6,967.78 6,897.50 -982.27 400.91 5,964,795.99 7,191.34 41.90 157.70 7,000.74 6,970.46 -1,038.10 424.41 5,964,73910 7,285.32 46.93 156.25 7,107.85 7,037.57 -1,098.59 450.16 5,964,678.70 7,380.07 49,73 155.06 7,170.83 7,100.55 -1,163.06 479.35 5,964,613.67 7,473.47 53,33 153.93 7,228.93 7,158.65 -1,229.00 510.85 5,964,547.07 7,567.82 56.80 153.37 7,282.95 7,212.67 -1,298.34 545.18 5,954,477.11 7,662.38 59,00 153.54 7,333.20 7,262.92 -1,369.99 580.97 5,954,404,75 7,756.82 64.57 152.95 7,377.83 7,30255 -1,444.27 618.43 5,954,32914 7,851.24 70.12 151.59 7,414.19 7,343.91 -1,521.35 658.98 5,964,251.86 7,945.17 75.12 150.53 7,442.24 7,371.96 -1,599.77 702.35 5,964,17260 8,040.72 79.63 149.65 7,463.11 7,392.83 -1,680.57 748.84 5,964,090.89 8,134.54 83,40 148.13 7,476.96 7,406.68 -1,759.99 796.78 5,964,010,52 Map Pasting DLS 349,233.54 0.35 349,239.01 0.43 349,24378 0.55 349,248.14 0.17 349,252.26 0.59 349,256.37 0.08 349,260.26 0.41 349,262.38 1,91 349,262.76 0.57 349,264.61 2.30 349,268.52 0.83 349,272.50 1.07 349,276.42 0.63 349,280.51 0.43 349,286.18 1.88 349,294.85 1.99 349,304.75 0.40 349,314.04 1,06 349,321.37 2.53 349,327.52 141 349,336.12 2.98 349,349.16 4.74 349,364.43 2.71 349,377.59 3.88 349,388.58 1.81 349,401.18 3.90 349,417.84 3.31 349,437.04 4.35 349,458.18 4.68 349,460.56 4.69 349,505.08 5.46 349,532.97 3.10 349,563.13 3.97 349,596.06 3.71 349,630.41 2.33 349.666,36 5.92 349,70535 6.03 349,747.13 5.43 349,791.98 4.80 349,838.31 4.33 Vertical Section (ft) Survey Tool Name 479.79 MWD+IFR-AK-CAZ-SC(3) 493.64 MWD+IFR-AK-CAZ-SC (3) 507.27 MWD+IFR-AK-CAZSC (3) 520.94 MWD+IFR-AK-CAZSC(3) 533.97 MWD+IFR-AK-CAZ-SC(3) 546.88 MWD+IFR-AK-CAZ-SC(3) 559.40 MWD+IFR-AK-CAZ-SC (3) 571.35 MWD+IFR-AK-CAZSC (3) 683.03 MWD+IFR-AK-CAZSC(3) 595.48 MWD+IFR-AK-CAZ-SC(3) 60826 MWD+IFR-AK-CAZ-SC(3) 619.75 MWD+IFR-AKCAZSC(3) 630.93 MWD+IFR.AK-CAZSC(3) 642.23 MWD+IFR-AK-CAZ-SC(3) 654.15 MWD+IFR-AK-CAZSC(3) 667.73 MWD+IFR-AKCAZSC(3) 681.65 MWD+IFR-AKCAZSC(3) 695.85 MWD+IFR-AK-CAZSC(3) 710.91 MWD+IFR-AK-CAZ-SC(3) 727.55 MWD+IFR-AK-CAZSC(3) 747.13 MWD+IFR-AKCAZSC(3) 772.03 MWD+IFR-AKCAZ-SC(3) 602.27 MWD+IFR-AK-CAZ-SC(3) 835.09 MWD+IFR-AK-CAZSC(3) 870.30 MWD+IFR-AK-CAZ.4C(3) 908.93 MWD+IFR-AKCAZSC(3) 952.85 MWD+IFR-AK-CAZ-SC(3) 1,001.70 MWD+IFR-AK-CAZ.SC(3) 1,055.78 MWD+IFR-AK-CAZ.SC(3) 1,116.12 MWD+IFR-AK-CAZ-SC(3) 1,181.64 MWD+IFR-AKCAZ-SC(3) 1,252.28 MWD+IFR-AK-CAZ-SC (3) 1,325.33 MWD+IFR-AKCAZSC(3) 1,402.64 MWD+IFR-AKCAZSC(3) 1,482.72 MWD+IFR-AK-CAZ-SC(3) 1,665.89 MWD+IFR-AK-CAZ-SC(3) 1,652.96 MWD+IFR-AK-CAZSC(3) 1,742.58 MWD+IFR-AKCAZSC(3) 1,835.73 MWD+IFR-AKCAZ-SC(3) 1,928.38 MWD+IFR-AK-CAZ-SC (3) 3/142018 Br52:51AM Page COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well CDS-25 Project Western North Slope TVD Reference: CD5-25 actual @ 70.28usft (Doyon 29) Site: C05 Alpine West Pad MD Reference: C05-25 actual @ 70.28usft (Doyon 29) Well: CDS-25 North Reference: True Wellbore: CD5-25L1 Survey Calculation Method: Minimum Curvature Design: CD5-251-1 Database: OAKEOMP2 Survey 1) MD Inc Azi TVD TVDSS •9743 +EI.MI Map Map Vertical Iu (°) (°) (usip (usft) (us(q Northing Easting DLS Section (usR) (LU (it) (°1100) (ft) Survey Tool Name 8,184.00 83.33 147.29 7,482.67 7,412.39 -1,801.52 823.02 5,963,96647 349,863.71 1.69 1,977.34 MWD -INC ONLY (INC>10') (4) 6,198.00 85,15 148.60 7,484.08 7,413.80 -1,813.33 830.4 5,963,956.52 349,870.87 15.99 1,991.23 MWD -INC ONLY (INC>10-) (4) 8,276.11 84.42 145.92 7,491.18 7,420.90 -1,878.75 872.48 5,963,890.27 349,911.60 3.54 2,068.73 MWD -INC -ONLY (INC>10') (4) 8,371.56 83.16 145.13 7,501.50 7,431.22 -1,956.98 926,19 5,963,810.99 349,963.73 1.56 2,162.98 MWD -INC ONLY (INC>10') (4) 8,412.73 83.44 145.09 7,506.31 7,436,03 -1,990.51 949.58 5,963,776.99 349,986.43 0.69 2,203.56 MWD -INC -ONLY (INC>10-) (4) 8,458.11 89.13 145.09 7,509.24 7,438.96 -2,027.64 975.48 5,963,739.36 350,011.59 12.54 2,246.48 MWD -INC ONLY (INC>10-)(4) 8,508.40 9302 145.09 7,508.30 7,438.02 -2,068.88 1,004.25 5,963,697.57 350,039.52 7.74 2,298.37 MWD -INC ONLY (INC>10°)(4) 8,60318 91.00 147.92 7,504.96 7,43468 -214834 1,05685 5,963,61705 350,090.50 364 2,393.22 MWD-INC_ONLY(INC>10')(4) 8,698.41 91.33 150.77 7,503.03 7,432.75 -2,229.72 1,10508 5,963,534.73 350,137.09 3.03 2,487.71 MWD+IFR-AK-CAZ-SC(5) 8,793.69 91.96 152,69 7,500.30 7,430.02 -2,313.60 1,150.19 5,963,449.97 350,180.50 2.12 2,582.94 MWD+IFRAK-CAZSC(5) 8,888.96 91.90 153.98 7,497.09 7,426.81 -2,398.69 1,192.92 5,963,36404 350,221.50 1.35 2,678.13 MWD+IFR-AK-CAZSC(5) 8,983.94 90.75 154.86 7,484.89 7,424.81 -2,484.26 1,234.06 5,963,277.67 350,260.92 1.41 2,773.02 MWD+IFR-AKCAZSC(5) 9,079.59 8980 155.57 7,494.43 7,424.15 -2,571.03 1,274.31 5,963,190.12 350,299.41 1.38 2,868.54 MWD+IFR-AK-CAZ-SC(5) 9,174.24 WA4 155.99 7,494.23 7,423.95 -2,657.34 1,313.14 5,963,103.04 350,336.50 0.81 2,962.99 MWD+IFR-AKCAZSC(5) 9,268.90 91.17 154.92 7,492.90 7,422.62 -2,743.44 1,352.46 5,963,016.18 358374.07 1.37 3,057.49 MWD+1FR-AKCAZ-SC(5) 9,364.09 91.51 154.36 7,490.68 7,420.40 -2,629.43 1,393.22 5,962,929.39 350,413.09 0.69 3,152.56 MWD+IFR-AKCAZ-SC(5) 9,458.97 91.55 154.05 7,488.14 7,417.86 -2,914.83 1,434.49 5,962,843.19 350,452.64 0.33 3,247.34 MWD+IFR-AK-CAZSC(5) 9,554.22 90.87 153.57 7,486.13 7,415.85 3,000.28 1,476.52 5,962,756.92 350,492.94 0.87 3,342.53 MWD+IFR-AKCAZ-SC(5) 9,648.94 89,44 153.02 7,485.88 7,415.60 -3,084.89 1,519.08 5,962,671.47 350,533.79 1.62 3,437.23 MWD+IFR-AK-CAZ-SC(5) 9,743.90 8647 154.00 7,487.61 7,417.33 3,189.87 1,561.43 5,962,585.67 350,574.42 1.45 3,532.14 MWD+IFRAK-CAZSC(5) 9,837.66 89.11 153.22 7,489.59 7,419.31 3,253.84 1,603.10 5,962,500.89 350,614.38 1.08 3,62585 MWD+1FR-AK-CAZSC(5) 9,933.70 89.57 152.48 7,49069 7,420.41 3,339.29 1,646.92 5,962,41458 360,656.47 0.91 3,721.88 MWD+1FR-AKCAZ-SC(5) 10,028.89 89,04 151.79 7,491,65 7,421.57 -3,423.43 1,691.40 5,962,329.56 350,699.26 0.91 3,817.06 MWD+IFRAK-CAZSC(5) 10,123.73 66.35 151.38 7,494.01 7,423.73 -3,506.82 1,736.52 5,962,24529 350,74269 0.85 3,911.87 MWD+IFR-AK-CAZSC(5) 10,218.77 90.27 150.83 7,495.15 7,424.87 -3,590.02 1,782.44 5,962,161.19 350,786.92 2.10 4,006.88 MWD+IFRAK-CAZ-SC(5) 10,313.56 90.47 150.81 7,494.54 7,424.26 3,672.78 1,828.68 5,962,077.52 350,831.46 0.21 4,101.64 MWD+1FRAK-CAZSC(5) 10,408.61 89.43 151.10 7,494.62 7,424.34 3,755.88 1,874.80 5,961,993.52 350,875.92 1.14 4,196.67 MWD+1FR-AKCAZ-SC(5) 10,503.54 89.41 151.99 7,495.59 7,425.31 3,839.33 1,920.03 5,961,909.18 350,919.46 0.94 4,291.59 MWD+IFR-AKCAZ-SC(5) 10,598.80 89.48 151.51 7,496.51 7,426.23 -3,923.24 1,965.12 5,961,824.39 350,962.85 0.51 4,386.64 MWD+IFRAK-CAZSC(5) 10,693.53 89.66 152.37 7,497.22 7,426,94 4,006.83 2,009.67 5,961,739.92 351,005.71 0.93 4,481.57 MWD+IFR-AKCAZ-SC(5) 10,788.70 89,73 152.69 7,497.73 7,427.45 4,091.27 2,053.57 5,961,654.63 351,047.91 0.34 4,576.74 MWD+1FR-AKCAZ-SC(5) 10,683.79 89.37 152.38 7,498.47 7,428.19 4,17564 2,097.43 5,961,569.40 351,090.05 0.50 4,671.82 MWD+IFRAK-CAZSC (5) 10,978.19 89.45 150.94 7,499.44 7,429.16 4,258.72 2,142.24 5,961,485.44 351,133.18 1.53 4,766.21 MWD+1FR-AKCAZ-SC(5) 11,073.16 89.27 149.99 7,500.51 7,430.23 4,341.34 2,189.05 5,961,401.90 351,178.32 1.02 4,861.13 MWD+1FR-AKCAZ-SC(5) 11,16652 89.27 148.92 7,501.72 7,431.44 4,423.46 2,237.51 5,961,318.83 351,225.11 1.12 4,956.38 MWD+IFRAK-CAZSC(5) 11,263.58 89.45 149.17 7,5D2.78 7,432.50 4,504.98 2,286.40 5,961,236.35 351,272.35 0.32 5,051.29 MWD+IFR-AKCAZSC(5) 11,358,40 89.41 150.03 7,503.73 7,433.45 4,586.76 2,334.38 5,961,153.63 351,318.68 0.91 5,146.01 MWD+IFRAKCAZ-SC(5) 11,453.51 89.56 149.70 7,504.58 7,434.30 4,66901 2,362.13 5,961,070.44 351,364.76 0.38 5,241.04 MWD+IFRAK-CAZSC(5) 11,548.27 89.44 149.31 7,505.41 7,435.13 4,750.66 2,430.21 5,960,987.85 351,411.19 0.43 5,335.70 MWD+IFR-AKCAZ-SC(5) 11,643.65 89.59 149.15 7,506.21 7,435.93 4,832.61 2,479.01 5,980,904.94 351,456.32 0.23 5,430.95 MWD+1FRAKCAZ-SC(5) 311412018 8:52:51AM Page 5 COMPASS 5000.14 Build 85 Conocoftillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well C135-25 Project: Western North Slope TVD Reference: CDS-25 actual @ 70.28us%(Doyon 29) Site: CD5 Alpine West Pad MD Reference: CDS-25 actual Q 70.28usft (Doyon 29) Well: CD5-25 North Reference: True Welltlore: CD5-251.1 Survey Calculation Method: Minimum Curvature Design: CD5-251-1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc AidTVD 7VDSS +W43 +E/ -W Northing Easting DLS Section (usfry (°) (°) (ui (usft) (usf) (uslq (ft) (R) (°1700•) (M Survey Tool Name 11,739,66 8951 151.24 7,508.97 7,436.69 -0,915.91 2,526.72 5,960,820.71 351,504.35 2.18 5,526.90 MWD+IFR-AK-CAZSC(5) 11,834.09 89.56 153.18 7,507.74 7,437.46 4,999.44 2,570.75 5,960,736.31 351,548.68 2.06 5,621.32 MWD+IFR-AK-CAZ-SC(5) 11,928.86 89.24 154.80 7,508.73 7,438.45 5,084.61 2,612.30 5,960,650.34 351,586.51 1.74 5,716.03 MWD+IFR-AK-CAZ-SC(5) 12,024.21 89.18 156.44 7,510.4 7,439.76 -5,171.44 2,651.66 5,980,562.73 351,624.11 1.72 5,811.20 MWD+IFR-AK-CAZSC(6) 12,119.23 88.96 154.35 7,511.59 7,441.31 5,257.82 2,69121 5,960,475.59 351,661.92 2.21 5,906.04 MWD+IFR-AK-CAZ-SC (5) 12,214.34 69.10 155.11 7,513.20 7,442.92 -5,343.82 2,731.81 5,960,388.80 351,700.78 0.81 6,001.04 MWD+IFR-AK-CAZSC(5) 12,306.91 89.60 106.47 7,514.27 7,403.99 5,430.06 2,770.58 5,960,301.80 351,737.81 1.63 6,095.41 MWD+IFR-AK-CAZ-SC(5) 12,403.97 89.06 156.50 7,515.38 7445.10 -5,517.22 2,808.51 5,960,213.90 351,773.97 0.57 6,190.20 MWD+IFR-AK-CAZ-SC(5) 12,499.19 89.07 155.96 7,516.93 7,448.85 5,604.35 2,846.88 5,960,126.02 351,810.59 0.57 6,285.16 MWD+IFR-AK-CAZ-SC(5) 12,594.20 89.11 155.26 7,518.44 7,448.16 -5,690.87 2,866.11 5,960,038.74 351,848.06 0.74 6,379.99 MWD+IFR-AK-CAZSC(5) 12,688.96 88.85 152.43 7,520.13 7,449.85 5,775.90 2,927.87 5,959,952.89 351,888.10 3.00 6,474.68 MWD+IFR-AK-CAZSC(5) 12,783.63 89.70 151.37 7,521.33 7,451.05 -5,859.41 2,972.46 5,959,868.51 351,931.00 1.44 6,569.34 MWD+IFR-AK-CAZSC(5) 12,878.85 89.65 150.36 7,521.87 7,451.59 5,942.58 3,016.82 5,959,784.43 351,975.67 1.06 6,664.53 MWD+IFR-AK-CAZ-SC (5) 12,973.67 89.76 150.73 7,522.36 7,452.08 5,025.14 3,065.44 5,959,700.96 352,020.63 0.41 6,759.31 MWD+IFR-AKCAZSC(5) 13,068.96 89.73 150.07 7,522.78 7,452.50 5,107.99 3,112.51 5,959,617.18 352,066.01 0.69 6,854.66 MWD+IFR-AK-CAZ-SC(5) 13,163.73 89.21 148.57 7,523.66 7,453.38 5,189.49 3,160.66 5,959,534.73 352,112.72 1+68 6,949.20 MWD+IFR-AK-CAZSC(5) 13,258.59 88.73 145.17 7,525.36 7,455.08 5,268.91 3,212.69 5,91 352,162.93 3.62 7,043.63 MWD+IFR-AKCAZ-SC(6) 13,353.20 88.30 142.70 7,527.81 7,457.53 5,346.35 3,268.36 5,959,376,75 352,217.06 2.65 7,137.23 MWD+IFR-AKCAZSC(5) 13,448,89 88.89 143.06 7,530.16 7,459.88 5,421.63 3,328.09 5,959,299.34 352,273.24 0.72 7,231.65 MWD+IFR-AK-CAZ-SC (5) 13,544.34 89.74 145.64 7,531.30 7,461.02 5,499.18 3,381.72 5,959,220.69 352,327.28 2.85 7,326.20 MWD+IFR-AKCAZSC(5) 13,639.15 89.75 150.04 7,531.72 7,461.4 5,579.42 3,432.17 5,959,139.46 352,376.11 4.64 7,420.72 MWD+IFR-AKCAZ-SC(5) 13,734.59 89.98 152.23 7,531.95 7,461.67 5,663.00 3,478.24 51959,054.98 352,420.49 2.31 7,516.13 MWD+IFR-AKCAZSC(5) 13,829.40 87.66 153.24 7,53390 7,463.62 5,747.25 3,521+66 5,958,969.88 352,462.20 2.67 7,610.91 MWD+IFR-AK-CAZ-SC(5) 13,924.51 88.23 164.26 7,537.31 7,467.03 5,832.49 3,563.70 5,958,883.81 352,502.52 1.23 7,705.92 MWD+IFR-AKCAZ-SC(5) 14,019.51 90.23 155.68 7,538.59 7,468.31 5,918.56 3,603.88 5,958,796.96 352,540.96 2,56 7,800.79 MWD+IFR-AK-CAZ-SC(5) 14114.25 90.91 154.14 7,537.65 7,467.37 4,004.35 3.64.06 5,958,710.39 352,579.40 1,78 7,895.41 MM+IFR-AKCAZSC(5) 14,208.26 88.88 154.95 7,537.82 7,467,54 -7,089.23 3,684.46 5,958,624.72 352,618.08 2.32 7,989.33 MWD+1FR-AK-CAZ-SC(5) 14,304.13 68.62 155.43 7,539.91 7,469.63 -],176.23 3,724.68 5,958,535.93 352,656.54 0.57 8,085.05 MWD+IFR-AK-CAZ-SC(5) 14,398.91 88.69 155.30 7,642.13 7,471.85 -7,262.38 3,764.17 5,958,450.03 352,694.30 0.16 8,179.65 MWD+IFR-AK-CAZSC(5) 14,493.40 89.14 153.11 7,543.92 7,473.64 -7,347.41 3,805.28 5,958,364.18 352,733.68 2.37 8,274.06 MWD+IFR-AK-CAZ-SC(5) 14,589.18 89.63 150.34 7,544.95 7,474.67 -7,431.75 3,850.85 5,958,278.95 352,777.34 2.94 8,389.82 MWD+IFR-AK-CAZSC(5) 14,683.62 89.59 149.78 7,545.60 7,475.32 -7,513.59 3,897.78 5,958,196.19 352,822.82 0.59 8,464.19 MWD+IFR-AKCAZ-SC(5) 14,779.15 89.44 150.96 7,546.40 7,476.12 -7,596.62 3,945.01 5,958,11223 352,858.36 1.25 8,55987 MWD+IFR-AK-CAZSC(5) 14,873.58 89.61 150.65 7,547.19 7,476.91 -7,679.05 3,991.07 5,958,028.90 352,912,75 0.37 8,654.07 MWD+IFR-AKCAZ-SC(5) 14,989.54 90.00 148.46 7,547.51 7,477.23 -7,761.77 4,039.69 5,957,94522 352,959.70 2.32 8,749.93 MWD+IFR-AK-CAZSC(5) 15,064.22 90.04 147.01 7,547.48 7,477.20 -7,841.83 4,09023 5,957,864.17 353,006.62 1.53 8,844.33 MWD+IFR-AKCAZ-SC(5) 15,15111 89.68 147.18 7,547.71 7,477.43 -7,921.76 4,141,95 5,957,783.22 353,058.71 042 8,939.15 MWD+IFR-AKCAZSC(5) 15,252.91 89.69 147.90 7,54823 7,477.95 5,000.64 4,192.12 5,957,703.35 353,107.29 0.77 9,032.34 MWD+IFR-AKCAZ-SC(6) 15,348.47 89.62 148.98 7,548.80 7,478.52 5,082.07 4,242.13 5,957,620.95 353,155.65 1.13 9,127.70 MWD+IFR-AKCAZSC(6) 15,442.75 69.59 150.27 7,549.45 7,479.17 5,163.40 4,289.81 5,957,538.68 353,201.68 1.37 9,221.88 MWD+IFR-AK-CAZ-SC(6) 3/142018 8:52:51AM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well CD5-25 Project: Western North Slope TVD Reference: CDS-25 actual C 70.28usft (Doyon 29) Site: CD5 Alpine West Pad MD Reference: CDS-25 actual @ 70.28usft (Doyon 29) Well: CD5-25 North Reference: True Wellbore: CD5-251-1 Survey Calculation Method: Minimum Curvature Design: CD5-2511 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD NDSS +WS +Ef4N Northing Basting DI.S Section (usfl) (°) (I (ush) Wait) (usfq (usft) (ft) (R) (°/700') (ft) Survey Tool Name 15,537.45 88.95 152.35 7,550.68 7,480.38 5,246.46 4,335.26 5,957,454.73 353,245.45 2.30 9,316.56 MWD+IFR-AK-CAZ-SC(6) 15,632.12 89.14 153.13 7,552.24 7,481.96 5,330.61 4,378.62 5,957,369.73 353,287.10 0.85 9,411.21 MWD+IFR-AK-CAZSC(6) 15,727.49 89.09 153.50 7,553.71 7,483.43 5,415.81 4,42144 5,957,28369 353,328.20 0.39 9,506.55 MWD+IFR-AK-CAZSC(6) 15,823.03 89.59 152.72 7,554.81 7,484.53 5,501.01 4,464.65 5,957,197.65 353,369.68 0.97 9,602.07 MWD+IFR-AK-CAZ-SC(6) 15,918.18 89.55 153.31 7,555.52 7,485.24 5,565.80 4,507.82 5,957,112.01 353,411.14 0.62 9,69720 MWD+IFR-AK-CAZSC(6) 16,013.57 89.65 152.43 7,556.19 7,485.91 5,670.69 4,551.32 5,957,026.27 353,452.92 0,93 9,792.58 MWD+IFR-AK-CAZ-SC(6) 16,108.30 90.03 151.78 7,556.46 7,486.18 5,75441 4,59564 5,956,941.68 353,495.55 0.79 9,887.31 MWD+IFR-AK-CAZSC(6) 16,203.22 90.06 154.09 7,556.38 7,486.10 5,838.93 4,638.a3 5,956,856.32 353,537.02 2.43 9,982.22 MWD+IFR-AK-CAZ-SC(6) 16,297.91 90.06 152.97 7,556.28 7,486.00 5,923.69 4.681,03 5,956,77033 353,577.51 1.18 10,076.88 MWD+IFR-AK-CAZSC(6) 16,393.92 90.03 153.04 7,556.21 7,465.93 -9,00924 4,724.61 51956,684.33 353,619.36 0.08 10,172.88 MWD+1FR-AK-CAZ-SC(6) 16,489.05 89.99 150.11 7,556.19 7,485.91 -9,092.90 4,769.89 5,956,599]9 353,662.94 3.06 10,267.99 MWD+IFR-AK-CAZ-9C(6) 16,584.21 90.14 150.41 7,556.08 7,485.80 -9,175.52 4,81709 5,956,516.24 353,708.48 0.35 10,363.10 MWD+IFR-AK-CAZ-SC(6) 16,679.21 90.03 149.38 7,565.94 7,48566 -9,257.70 4,864.74 5,956,433.12 353,754.46 1.09 10,458.02 MWD+IFR-AK-CAZSC(6) 16,774.60 89.99 149.52 7,555.92 7,485.64 5,339.85 4,913.23 5,956,350.02 353,801.28 0.15 10,553.31 MWD+IFR-AK-CAZ-SC(6) 16,870.26 89.99 150.64 7,555.94 7,485.66 -9,422.76 4,960.94 5,956,265.17 353,847.32 1.17 10,648.90 MWD+IFR-AK-CAZSC(6) 16,964.22 90.28 151.43 7,555.72 7,485.44 -9,504.97 5,006.45 5,956,183.08 353,891.15 0.90 10,742.85 MWD+IFR-AK-CAZ-SC(6) 17,059.54 87.94 148.82 7,557.20 7,486.92 -9,587.60 5,053.91 51956,099.51 353,936.95 3.68 10,839.08 MWD+IFR-AK-CAZSC(6) 17,155.05 88.91 149.65 7,559.83 7,489,55 -9,669.64 5,102.75 5,956,01652 353,984.12 1.34 10,93343 MWD+IFR-AK-CAZ-SC(6) 17,250.24 90.96 151.78 7,559.93 7,489.65 -9,752.65 5,149.30 5,955,932.59 354,028.99 3.11 11,028.58 MWD+IFR-AK-CAZSC(6) 17,345,48 90.01 151-64 7,559.13 7,488.85 -9,836.51 5,194.44 5,955,84765 354,072,43 1.01 11,123.81 MWD+IFR-AK-CAZ-SC(6) 17,440.38 90.48 150.82 7,558.72 7,488.44 -9,919.70 5,240.11 5,955,763.77 354,116.42 1.00 11,218.70 MWD+IFR-AK-CAZSC(6) 17,535.27 90.49 153.87 7,557.92 7,48].64 -10,003.73 5,284.15 5,955,678.87 354,158.76 3.21 11,313.57 MWD+1FR-AK-CAZSC(6) 17,629.52 89.23 155.55 7,558.15 7,487.87 -10,088.94 5,324.41 5,955,592.87 354,197.29 2.23 11,407.72 MWD+IFR-AK-CAZSC(6) 17,723.67 88.66 158.38 7,559.86 7,489.60 -10,175.56 5,361.24 5,955,505.54 354,232.37 3.07 11,501.51 MWD+IFR-AK-CAZ-SC(a) 17,819.66 89.62 158.35 7,561.32 7,491.04 -10,264]8 5,396.63 5,955,415.63 354,265.96 1.00 11,596.93 MWD+IFR-AK-CAZSC(6) 17,914.83 90.25 158.85 7,661.43 7,491.15 -10,353.39 5,431.35 5,955,326.35 354,298.89 0.85 11,691.49 MWD+1FR-AK-CAZ-SC(6) 18,010.60 90.07 168.58 7,561.16 7,490.88 -10,44262 5,466.12 5,955236.44 354,331.85 0.34 11,786.63 MWD+IFR-AK-CAZSC(6) 18,107.02 85.10 156.29 7,564.38 7,494.10 -10,531.59 5,503.08 5,955,146.76 354,36]02 475 11,882.56 MWD+IFR-AK-CAZ-SC(6) 18,201.24 86.29 157.04 7,570.64 7,500.36 -10,617.91 5,540.32 5,955,059.71 354,402.51 0.82 11,976.28 MWD+IFR-AK-CAZSC(6) 18298.32 86.22 158.08 7,576.98 7,506.70 -10,707,45 5,577.30 5,954,969.46 354,437.68 1.07 12,072.72 MWD+IFR-AK-CAZ-SC(6) 18,391.93 85.94 157.35 7,583.38 7,513.10 -10,793.86 5,612.71 5,964,882.35 354,471.35 0.83 12,165.67 MWD+IFR-AK-CAZ-SC(6) 18.486,00 85.98 156.69 7,590.01 7,519.73 -10,88025 5,649.35 5,954,795.25 354,506.24 070 12,269.17 MWD+IFR-AK-CAZSC(6) 18,582.04 86.01 155.44 7,595.04 7,524.76 -10,967.91 5,688.26 5,954,706.64 354,543.37 248 12,354.85 MWD+IFR-AK-CAZSC(6) 18,677.12 67.16 151.49 7,599.05 7,528.77 -11,052.88 5,730.69 5,954,621.04 354,584.08 4.25 12,449.60 MWD+IFR-AK-CAZSC(6) 18771.93 87.32 149.13 7,603.81 7,533.33 -11,135.14 5,777.59 5,954,537,86 354,629.32 2.49 12,544.44 MWD+IFR-AK-CAZSC(6) 18,868.50 8978 146.71 7,606.06 7,53578 -11,216.92 5,828.85 5,954,455.06 354,678.93 3.57 12,64070 MWD+IFR-AK-CAZ-SC(6) 18,962.24 89.75 145.54 7.606.44 7,536.16 -11,294.75 5,881.10 5,954,37821 354,729.60 1.25 12,733.92 MWD+IFR-AK-CAZ.SC(6) 19,057.42 89.74 146.24 7,606.87 7,536.69 -11,373.56 5,934.48 5,954,296.35 354,781.37 0.74 12,826.64 MWD+1FR-AK-CAZ-SC(6) 19,153.21 90.55 148.42 7,606.62 7,536.34 -11,454.18 5,986.18 5,954,214.71 354,831.44 2.43 12,923.98 MWD+IFR-AK-CAZSC(6) 19,249.13 90.73 146.33 7,605.55 7,535.27 -11,534.96 6,037.89 5,954,132.91 354,881.51 2.19 13,019.56 MWD+IFR-AK-CAZ-SC(6) 31142018 &52:51AM Page 7 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-25 Project: Western North Slope TVD Reference: CDS-25 actual @ 70.28usft (Doyon 29) Site: CD5 Alpine West Pao MD Reference: CD5-25 actual @ 70.2ausft (Doyon 29) Well: CDS-25 North Reference: True Wellbore: C135-251.1 Survey Calculation Method: Minimum Curvature Design: CDS-251-1 Database: OAKEDMP2 3/142018 8,52:51AM Page 8 COMPASS 5000.14 Build 85 Inc AZJ TVD TVDSS +NIS +E7-yy Map Map VeNcal F�44 (°) P) lusty (uI (uslt) lu%h) NOMIng Easfing DLS Section (it) Ift) (°1100) (ft) Survey Tool Name6 9011 146.37 7,604.85 7,534.57 -11,614.56 6,090.88 5,954,052.27 354,932.88 0.65 13,114.69 MWD+IFR-AK-CAZ-SC(6) 9 90.75 148.12 7,604.14 7,533.66 -11,60.65 6,143.73 5,953,972.14 354,964.14 0.72 13,209.32 MWD+IFR-AK-CAZSC(6) 4 91.16 147.93 7,60255 7,532.27 -11,773.55 6,195.57 5,953,891.23 355,034.35 1.95 13,304.17 MWD+IFR-AK-CAZ-SC(6) 19,631.52 91.79 151.87 7,600.07 7,529.79 -11,856.88 6,243.88 5,953,806.94 355,080.97 4.14 13,400.42 MWD+IFR-AK-CAZ-SC(6) 19,725.72 91.36 153.23 7,597.48 7,52720 -11,940.45 6,287.28 5,953,722.53 355,122.69 1.51 13,494,58 1AW0+1FR-AK-CAZSC(6) 19,820.55 89.40 154.73 7,596.85 7,526.57 -12,02585 6,328.88 5,953,636.51 355,162.56 260 13,589.35 MWD+IFR-AK-CAZ-SC(6) 19,913.94 88.74 153.38 7,598.37 7,528.09 -12,109.61 6,36915 5,953,551.75 355,201.73 1.63 13,682.68 MWD+IFR-AK-CAZ-SC(6) 20,011.21 89.57 152.35 7,599.80 7,529.52 -12,198.16 6,414.12 5,953,48434 355,241.35 1.34 13,779.93 MWD+IFR-AK-CAZSC(6) 20,106.36 90.71 152.34 7,599.57 7,529.29 -12,280.43 6,45828 5,953,37920 355,28&80 1.20 13,875.08 MWD+IFR-AK-CAZ-SC(6) 20,201.32 69.85 153.37 7,599.10 7,528.82 -12,384.93 6,501.60 5,953,293.85 355,328.42 1.41 13,970.03 MWD+IFR-AK-CAZSC l6) 20,297.23 89.54 152.75 7,599.61 7,529.33 -12,450.43 6,545.06 5,953,207.50 355,370.14 0.72 14,065.92 MWD+IFR-AK-CAZSC (6) 20,392.32 89.96 153.31 7,600.03 7,529.75 -12,535.18 6,586.18 5,953,121.91 355,411.55 0.74 14,161.00 MWD+IFR-AK-CAZ-SC(6) 20,488.00 90.18 154.03 7,599.91 7,529.63 -12,620.93 6,630.62 5,953,035.33 355,45225 0.79 14,256.64 MWD+IFR.AK-CAZSC(6) 20,582.60 89.71 154.25 7,600.00 7,529.72 -12,708.06 6,671.88 5,952,949.40 355,491.79 0.55 14,351.19 MWD+IFR-AK-CAZSC (6) 20,677.36 90.24 154.83 7,600.4 7,529.76 -12,791.62 6,712.82 5,952,863.04 355,530.80 0.83 14,445.86 MWD+IFR-AK-CAZ-SC(6) 20,771.83 90.60 153.75 7,599.35 7,529.07 -12,878.73 6,753.60 5,952,777.13 355,570.05 1.21 14,540.26 MWD+IFR-AK-CAZ-SC(6) 20,867.34 89.85 152.30 7,598.98 7,528.70 -12,961.85 6,796.92 5,952,691.17 365,611.65 111 14,035.76 MWD+IFR-AK-CAZSC (6) 20,973.00 89.85 152.30 7,599.25 7,528.97 -13,055.40 6,846.03 5,952,596.66 355,858.87 0.00 14,741.42 PROJECTED WTD 3/142018 8,52:51AM Page 8 COMPASS 5000.14 Build 85 Page 111 Report Printed: 10/1012018 Cement Detail Report CD5-25 Job: String: Surface Casing Cement DRILLING ORIGINAL, 1/24/2018 18:00 Cement Details Description Surface Casing Cement 11127/201818:15 Cementing start Date Cementing End Date 1/27/2018 21:45 Wellbore Name CD5-25 Comment Cement Stages Stage # <Stage NumbeYta Description Surface Casing Cement Objective Top Depth (ttK6) Bring cement to surface 37.0 Bottom Depth (ttKB) 2,193.4 Full Retem? Ves Vol Cement... 140.0 Top PIug7 Yes Btm Plug? Yes Q Pump Imt (bblim... IQ 5 Pump Final (bbV... 8 Q Pump Avg (bbil... I 6 P Pump Final (psi) 620.0 P Plug Bump (psi) 1,120.0 Reclp? Yes Stroke (tt) 30.00 Rotatetl? No Pip¢ RPM (rpm) Tagged Depth (ttKB) 2.112.0 Tag Mai Drill Bit Depth Plug Drilled Out To (HKB) 2,203.0 Drill 9 Out Diameter (in) 718 Comment Cement Fluids &Additives Fluid Fluid Type Lead Cement Flultl Description 6t1mated Top (RKB) 36.5 Eat Btm (ItKB) 1,693.0 Amount (sacks) 927 Class G Vdume Pumpatl (bbq 316.7 Yleltl (1P/98ck) 1.92 Mix H2O Ratio (gal/sa... 6.88 Free Water (%) Density IIcig&II 11.00 Plastic Viscosity (cle) Thickening Time (hr) 4.08 CmprStr 1 (psi) Additives Additive Type Concentration Con: Unit label Fluid Fluid Type Tail Cement Fluid Description estimated Top (ttKB) 1,693.0 6t earn (fIKB) 2,193.0 Amount (sacks)Class 299 G Volume 61.7 Pumped (bbl) Yield (ft'/sack) 1.16 Mix H2O Ratio (gauss... 5.11 Free Water (%) Density (lbigal) 15.80 plastic Viscosity (cP) Thickening Time (hr) CmprStr 4.13 1 (psi) Additives Additive Type Concentration Conc Unitlabel Page 111 Report Printed: 10/1012018 Page 1/1 Report Printed: 4/16/2018 Cement Detail Report CD5-25 String: Surface Casing Cement Job: DRILLING ORIGINAL, 1/24/201818:00 Cement Details DescriptionSurfac Casing Cement Cementing Start Date Cementing End Data Wellbore Name 1/27/201818:75 1127/201821:45 -25 Comment Comme Cement Cement Stages Stage # <Stage Number?> Description Objective Surface Casing Cement Top Depth If KB) Bottom Depth (HKB) Full Return? Vol Cement... Top Plug? Btm Plug? O Pump Init (bbl/m... O Pump Final (bbl/... O Pump Avg (bbl/... P Pump 37.0 2,193.4 Yes Final (psi) P Plug Bump (psi) Recip? Stroke (ft) 140.0 Yes Yes Rotated? Pipe RPM (rpm) 5 8 Tagged Depth (ftKB) 6 Tag Method 620.0 1,120.0 Yes Depth Plug Drilled Out To (ftKB) 30.00 No Drill Out Diameter No 2,112.0 Drill Bit 2,203.0 97/81 Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (Wlsack)Mix H2O Ratio (gausa... Free Water (%) Density (ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) I Cmprstr 1 (psi) Additives Additive Type Concentration Conic Unit label J� Page 1/1 Report Printed: 4/16/2018 Report Printed: 4/16/201 Cement Detail Report CD5-25 String: Intermediate Casing Cemen Cement Details Job: DRILLING ORIGINAL, 1/24/201818:0( Description intermediate Casing Cement Cementing Start Date Cementing Entl Date Wellbore Name Comment 2/3/2018 18:30 2/3/2018 21:30 CD5-25 Cement Stages Stage # 1 Description Objective Intermediate Casing TOC at 7067' Top Depth (ftKB) Bottom Depth (kKB) Full Return? Vol Cement... Top Plug? Btm Plug? Cement 7,067.0 8,459.7 Yes Yes Yes Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump 3 2 Final (psi) P Plug Bump (psi) Recip? Stroke(ft) o Pipe RPM (rpm) 1 ) Rotatetl. 4 Tagged Depth (ftKe) Tag Method 450.0 970.0 Yes 15.00 No Depth Plug Drilled Out To kKB ( 1 Drill Out Diameter (in) Comment Cement Fluids 8 Additives Fluid Fluid Type Intermediate Cement Fluitl Description Estimated Top (ftKB) Est Btm ftKBim ( 1 Amount (sacks) Class Volume (bbl) Pumped Yield (ft'/sack) 2.30 Mix H2O Ratio (gal/sa... 7,067.0 Free Water (/) 7,474.0 Density (Ib/gal) 61 Plastic Viscosi Paas G Thickenin Time hr 25.7 Cm 13.50 rStr t Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluitl Description Intermediate Cement Estimatetl Top (kKB) Est Btm kKB ( ) Amount (Sacks) Class Volume Pumped (bbl) Yield (ft'/sack) Mix H2O Ratio (gal/ 1 16 7,474.0 Free Water (°°/,) 8,459.0sa... 301 g 63.0 Densi ty (Ib/gal) Plastic Viscosity a•s) Thickening Time (hr) CmprStr t (psi) 5.00 Additives 15.80 Atltlitive Type Concentration Conc Unit label Report Printed: 4/16/201 (212k c8 S-z, LZ 2( 71620 Regg, James B (DOA) From: Brooks, Phoebe L (DOA) Sent: Thursday, March 1, 2018 9:28 AM To: Doyon 19 Tool Pusher // Cc: Regg, James B (DOA) Subject: RE: Emailing: Doyon 19 CD5-25 2-28-18.xlsx Attachments: Doyon 19 02-28-18 Revised.xlsx Attached is a revised report changing the test type to Initial as this is the first report for CD5-25L1. Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 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 taw. 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 Phoebe Brooks at 907-793- 1242 or phoebe.brooks@alaska.gov. -----Original Message ----- From: Doyon 19 Tool Pusher <doyonl3@conocophillips.com> Sent: Wednesday, February 28, 2018 10:33 AM To: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe. bay@alaska.gov>; Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com>; Dai, Weifeng <Weifeng.Dai@conocophillips.com>; Doyon 19 Company Man <doyonl@conocophillips.com>; Doyon 19 Tour Pusher <doyon9@conocophillips.com>; Doyon 19 Tool Pusher <doyonl3@conocophillips.com>; Regg, James B (DOA) <jim.regg@alaska.gov>; Kneale, Michael L (SolstenXP) <Michael.L.Kneale@contractor.conocophillips.com>; Jolley, Liz C <Liz.C.Jolley@conocophillips.com>; Lou Laubenstein <Lou.labenstein@alaska.gov>; Anderson, Nina M <Nina.Anderson@conocophillips.com>; Brooks, Phoebe L (DOA) <phoebe.brooks@alaska.gov>; Samuell, John G <John.G.Samuell@conocophillips.com>; Stinson, Rob D <Rob.D.Stinson@conocophillips.com>; Driskill, Todd (Doyon Drilling) <tdriskill@doyondrilling.com>; Worthy, Michael S <Michael.S.Worthy@conocophillips.com> Subject: Emailing: Doyon 19 CD5-25 2-28-18.xlsx Your message is ready to be sent with the following file or link attachments: Doyon 19 CD5-25 2-28-18.xlsx Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report *All BOPE reports are due to the agency within 5 days of testing* Submit to: jim regg(d)alaska gov AOGCC Inspectors(cDalaska gov phoebe brooks(a),alaska gov Contractor: Doyon - Rig No.: 19 DATE: 2/28/18 Rig Rep.: Evans / Williams Rig Phone: 670-4352 Operator: CPAI Op. Phone: 670-4350 Rep.: Harding / Wojciechowski E -Mail doyonl3@conocophillips.com Well Name: CRU CD5-251_1 - PTD # 2171620 - Sundry # Operation: Drilling: X Workover: Test: Initial: X Weekly: :sure (psi): Rams: 250/3500 - Annular Explor.: Bi -Weekly: Valves: 250/3501 2571 Nlw�. INarec i IVNS: Quantity I EST DATA FLOOR SAFETY VALVES: Stripper 0 Test Result NA Test Result Quantity Test Result Location Gen. P Well Sign P Upper Kelly 1 P Housekeeping P Rig P Lower Kelly 1 P . PTD On Location P Hazard Sec. P Ball Type 1 P - ling Order Posted P Misc. NA Inside BOP 1 P NA Choke Ln. Valves 1 3.125 FSV Misc 0 NA BOP STACK: Quantity Sizerrype Test Result Stripper 0 No. Valves 14 - P . NA Annular Preventer 1 135/8 P #1 Rams I 3.5x6 P #2 Rams I Blinds P - #3 Rams 1 3.54 P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3.125 P HCR Valves 2 3.125 P - Kill Line Valves 2 3.125 P Check Valve 0 NA BOP Misc 0 NA MUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Meth Gas Detector H2S Gas Detector MS Misc Visual Quantity Inside Reel valves 0 ACCUMULATOR SYSTEM: Time/Pressure Test Results Number of Failures: 0 Test Time: 4_5 - Hours Repair or replacement of equipment will be made within 0 days. Notify the AOGCC of repairs with written confirmation to AOGCC Ince Alarm Test Result Test Result P - I est using 4 and 4.5 -inch test joints, upper test plug. All tests to 250/3500psi for 5 minutes on chart. Test on Manual a. Super choke to 1100 psi. Functioned flow meter, PVT and alarms. Performed Accumulator draw down test, functioned BOP remote panel. Tested gas alarms. 24 hr Notice Yes Date/Time Test Start DaterTime: 2/28/2018 (dale) rest Finish Daterrime: 2/28/2018 By 4:45 (time) I I Witness Form 10424 (Revised 03/2017) Doyon 19 02-28-18 Revised System Pressure (psi) CHOKE MANIFOLD: _ Pressure After Closure (psi) Quantity Test Result _ 200 psi Attained (sec)_ No. Valves 14 - P . Full Pressure Attained (sec)_ Manual Chokes I P Blind Switch Covers: Hydraulic Chokes 1 P Nitgn. Bottles # & psi (Avg.): 4 CH Misc 0 NA ACC Misc Test Results Number of Failures: 0 Test Time: 4_5 - Hours Repair or replacement of equipment will be made within 0 days. Notify the AOGCC of repairs with written confirmation to AOGCC Ince Alarm Test Result Test Result P - I est using 4 and 4.5 -inch test joints, upper test plug. All tests to 250/3500psi for 5 minutes on chart. Test on Manual a. Super choke to 1100 psi. Functioned flow meter, PVT and alarms. Performed Accumulator draw down test, functioned BOP remote panel. Tested gas alarms. 24 hr Notice Yes Date/Time Test Start DaterTime: 2/28/2018 (dale) rest Finish Daterrime: 2/28/2018 By 4:45 (time) I I Witness Form 10424 (Revised 03/2017) Doyon 19 02-28-18 Revised THE STATE °fALASKA GOVERNOR BILL WALKER Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Colville River Field, Alpine Oil Pool, CRU CD5-25L1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-162 Surface Location: 432' FNL, 2900' FEL, Sec. 18, TI IN, R4E, UM Bottomhole Location: 374' FNL, 2419' FEL, Sec. 4, TI IN, R4E, UM Dear Mr. Alvord: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Enclosed is the approved application for permit to drill the above referenced service well. The permit is for a new wellbore segment of existing well Permit No. 217-161, API No. 50-103- 20765-00-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy. . FOerster �� Commissioner DATED this / Z day of January, 2018. STATE OF ALASKA AL :A OIL AND GAS CONSERVATION COMM(. ON PERMIT TO DRILL RECEIVED NOV 2 1 2017 1a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas M V 11 GU.000 Service - WAG ❑' Service - Disp ❑ ICA I Drill ❑ Lateral • 0 Stratigraphic Test ❑ Development -Oil ❑ Service- Winj ❑ Single Zone � • P Posed for: ale Ga as Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Cas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: Blanket Single Well 11, Well Name and Number: 3. Address: Bond No. 59-52-180. CRU CD5-25L1 P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: 12. Field/Pool(s): 4a. Location of Well (Governmental Section): MD: 29805, TVD: 7683 Colville River Unit Surface: 432' FNL, 2900' FEL, Sec. 18, Ti1N, R4E, UM 7. Property Designation: I ASRC-NPR4,ASRC-AA092344;ASRC-NPR2 . Alpine Pool SII V7L I I� Top of Productive Horizon: 8. DNR Approval Number: 13. Approxi a Spud Date: 3336' FNL, 1448' FEL, Sec. 18, T11N, R4E, UM 932669 932128, 340757 12/ 017 Total Depth: 374' FNL, 2419' FEL, Sec. 4, T11 N, R4E, UM 9. Acres in Property: 14 (stance to Nearest Property: 5032, 8837, 3122 • 4905'to ASCR-NPR5 4b. Location of Well (Stale Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 70 15. Distance to Nearest Well Open Surface: x- 349077 y- 5965786 Zone -4 ' GL / BF Elevation above MSL (ft): 33.7. to Same Pool: 1398' CD5-20L7 16. Deviated wells: Kickoff depth: 8323 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: 3034 Surface: 2571 r 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length 42 -79-36 MD TVD MD TVD (including stage data) 20° 78.6 B Welded 36 115 115 10 yds 13.5" 10.75" 45.5 L-80 H-563 2198 36 36 2234 2185 960sx 11.0ppg, 271sx 15.8ppg G 9.875x11" 7.625 29.7 L-80 TXP 8587 36 36 8623 7531 341 sx 15.Sppg Class G 12.2 780 TXP 4477 8423 7502 12900 7532 Partially lined with perforated pup 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD ND 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 Drilling Program B Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program B 20 AAC 25.050 requirements B✓ 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: Weifeng Dai AuthorizeName: Chip Alvord Contact Email: Weifen .Dai CO .Cool Authorizedd Title: Drilling Manager Contact Phone: 907-265-1077 z L. AL-IfC)OV Authorized Signature: 4 Date: / V /Z / �Zp� -':4 Commission Use Only Permit to Drill API Number: _ Permit Approval See cover letter for other Number: - /6 50- I O3 O Q Date:I I requirements. S Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed ethane hydrates, or gas contained in shales: Other: 36IP 7'Y$f�O Samples req'd: Yes ❑ No Mud log req'd: Yes❑ Noar is 7- r(J/�CI/fvr �"lrfrS�' %�6 y,j GO�S/ measures: Yes P1 No E] Directional svyreq'd: YesNoO 9/'q r feC1 -,"C 4 //c>WSpacing exception req'd: Yes ❑ No Lh Inclination -only svy req'd: Yes ❑ No �r tyle pu c k��-/0 b -C /Q crd N 86,01,4 -ID q h0 V C Post initial injection MIT req'd: Yes FEI'No❑ fhc tom VC-17F(aoC.,4Czs"4izcb)), `W'�' APPROVED BY Approved b . COMMISSIONER THF Crinnnniecinki _. I _ 12 Form 10101 Rev's 5/2 / / Th� 1 oe�rrrmmmlt is valid for 24 months from t e dd��ta o a r al per 20 AAC 25.005 Submit Form and 11 . V/ ,sy In /7 n R I � IN �� p 19) AnachmeMs in Duplicate ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 November 15, 2017 Alaska Oil and Gas Conservation Commission 333 West 7ht Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CRU CD5-25L1 Dear Sir or Madam: ConocoPhillips ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the CD5 drilling pad with rig Doyon 19. /The intended spud date for this well is 12/25/2017. CRU CD5-25L ] is planned to be an Alpine C Sand upper lateral injector out of the CD5-25 parent well (covered in separate PTD). When the CD5-25L 1 is commenced, the parent well will have run and cemented 10-3/4" surface casing to above the C30 Sand. 7-5/8" intermediate casing will have been run and cemented to 500' above the uppermost hydrocarbon bearing interval. A 6-3/4" lateral will have been drilled in the Alpine A Sand and lined with a 4-3/4" liner, with a whipstock set above for the CD5-25L1 kickoff in the Alpine C Sand. The CD5-25L 1 lateral will then be drilled in the Alpine C Sand and partially lined with 4-3/4" liner. The well wilk be completed with a 4.5" upper completion. A waiver is requested to set the production packer approximately above the casing shoe as per 20 AAC 25.412(b), � USI M D Please find attached the information required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information(l�l) 1,74 V6�1 attached to this application includes the following: 1. Form 10401 Application For Permit to Drill per 20 AAC 25.005 (a) 2. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 AAC 25.035 (d)(2) 6. Directional drilling / collision avoidance information as required by 20 AAC 25.050 (b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 AAC 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 Weifeng Dai at 263-4324 (weifeng.dai@ConocoPhillips.com) or Chip Alvord at 265-6120. Sincerely, cc: t CD5-25L1 Well File / Ann Haggerty -Sherrod ATO 1530 Johnson Njoku ATO 1720 Chip Alvord ATO 1570 Weifeng Dai Viet Nguyen ATO 1788 Staff Drilling Engineer Lanston Chin Kuukpik Corp Applicatio Permit to Drill, Well CRU CD5-25L1 Saved: 16 -Nov -17 CLS—GSL I Application for Permit to Drill Document Drilling aweus ConocoPhillips '- Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f)) ............................. 2. Location Summary (Requirements of20AAC25.005(c)(2))............... ............................ 3 Requirements of 20 AAC' 25.050(b) ............................................................................................................. 3 3. Blowout Prevention Equipment Information (Requirements of20AAC25.005(c)(3)) 3 4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) ........................4 5. Procedure for Conducting Formation Integrity Tests (Requirements of20AAC 25.005 (c)(5))......................................................................................................................... 5 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) .......... 5 7. Diverter System Information (Requirements of20 AAC 25.005(c)(7)) ......................... 5 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) ................................... 6 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ................................................................................................................................... 7 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) .........................................7 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) ........................ 7 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) ...................................7 13. Proposed Drilling Program (Requirements gf20AAC 25.005 (c)(13)) .........................7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 8 (Requirements of 20AAC 25.005 (c)(14)) ............... 8 .................. 15. Attachments .............. . Attachment7 Cement Summary................................................................................................................. 9 CD5-25L1 APD Page 1 of 14 Printed 16 -Nov -17 Applicatiot Sea it to Drill, Well CRU CD5-25L1 Saved: 16 -Nov -17 Attachment 2 Drilling Hazards Summary ................................................................................................... 9 Attachment 3 Completion Schematic.......................................................................................................... 9 Attachment 4 Directional Plan, 9 CD5-25L1 APD Page 2 of 14 Printed: 16 -Nov -17 I Applicatid ?ermit to Drill, Well CRU CD5-25L1 Saved: 16 -Nov -17 1. Well Name (Requirements of20AAC25.005 (n) The well for which this application is submitted will be designated as CRU CD5-197L1. 2. Location SUmmary (Requirements of20AAC25.005(c)(2)) NAD 1927 Northings: 5,965,786 Pad Elevation I 33.7' AMSL NAD 1927 Northings: 5,962,853 Eastings: 350.482 374' FNL, 2419' FEL, Sec. NAD 1927 Measured De th Northings. 5,944,515 Total Vertical Depth, Eastings: 359,774 Requirements of 20 AA 25.050(6) Please see Attachment 4: Directional Plan The Applicant is the only affected owner. T1 3. Blowout Prevention Equipment Information(Requirementsof2oAAC25.005(c)(3)) Please reference BOP and diverter schematics on file for Doyon 19. CD5-25L1 APD Page 3 of 14 Printed., 16 -Nov -17 Applicatior permit to Drill, Well CRU CD5-251-1 Saved: 16 -Nov -17 4. Drilling Hazards Information (Requirementsof2OAAC25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size (in) Csg Setting Depth Fracture Pore pressureN571 MD D ft Gradient si 20 115 115 10.9 51 10.75 2,194 / 2,185 14.5 977 7.625 from CDS-25 PTD 8 623 7 531 12.5 3 180 7.626 C Sand Window 8 323 7 494 12.5 3 034 4.75 29 805 7 683 12.5 3 339 PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE ASP ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: I) ASP= [(FGx0.052)-0.1]*D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from Ib./gal to psi/ft 0.1 =Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP=FPP-(O.1xD) Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD I. ASP CALCULATIONS Drilling below 20" conductor ASP = [(FG x 0.052) - 0.1] D OR =[(10.9x0.052) -0.11x 116=54 psi ASP = FPP - (0.1 x D) = 977 - (0.1 x 2185') = 759 psi 2. Drilling below 10-3/4" surface casing ASP = [(FG x 0.052) - 0.1] D OR _ [(14.5 x 0.052) - 0.1 ] x 2185' = 1429 psi ASP = FPP -(0.1 xD) = 3034 - (0.1 x 7494') = 2285 psi Drilling below 7-5/8" intermediate casing window ASP = [(FG x 0.052) - 0.1] D OR _ [(12.5 x 0.052) - 0.11 x 7494 = 4122 psi ASP= FPP-(0.1 x D) = 3339- (0.1 x 7683') = 2571 psi CD5-25L1 APD Page 4 of 14 Printed: 16 -Nov -17 Applicatior 'ermit to Drill, Well CRU CD5-25L1 Saved: 16 -Nov -17 (B) data on potential gas zones, The well bore is not expected to penetrate any gas zones. (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation zones, and zones that have a propensity for differential sticking, Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests (Requirementsof2t)AA(25.005(0)(5)) Drill out surface casing shoe and perform LOT test or FIT in accordance with the Alpine LOT / FIT procedure that ConocoPhillips Alaska has on file with the Commission. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) 7. Diverter System Information (Requirements of20AAC25.005(c)(7)) This PTD refers only to the CD5-25L1 production lateral, where the BOPE will be rigged up. The CD5-25 PTD details surface section and request for waiver of the diverter requirement under 20 AAC 25.035 (h) (2). CD5-25L 1 APD Page 5 of 14 Printed: 16 -Nov -17 Hole - •• . �•• �•,�•�r rru ram Detailed in CD5-25 PTD Csg/Tbg OD in () Size iz Weight (lam) Grade Conn. Len Length Top MD/TVD Btm MD/TVD (ft) (ft) (ft) Cement Program 20 42 94 H-40 Welded 79 36/36 115/115 10 yards 10.75 13.5 45.5 L-80 HYD 563 2,158 36/36 2,194/ 2,185 face with 960 x D epCre Cement to Mead I ppg, 271 sx Class G Tail Slur 15.8PPg 7.625 X815 29.7 L-80 TXP 8,587 36 /36 8,623/ 7,531 341 x Class G at 15.8 ppg 4.5 6.75 12.2 L-80 TXP 2,000 8,423/ 7,502 10,423 / 7,516 No cement - short liner 4.5 n/a 12.6 L-80 TXP 12,864 36 / 36 12,900 / 7,532 N/A - production tubing 7. Diverter System Information (Requirements of20AAC25.005(c)(7)) This PTD refers only to the CD5-25L1 production lateral, where the BOPE will be rigged up. The CD5-25 PTD details surface section and request for waiver of the diverter requirement under 20 AAC 25.035 (h) (2). CD5-25L 1 APD Page 5 of 14 Printed: 16 -Nov -17 Applicatiod 'ermit to Drill, Well CRU C135-251-1 Saved: 16 -Nov -17 S. Drilling Fluid Program(Requiremenrsof20AAC25.005(c)(8)) Production Hole: The Alpine C Sand horizontal production interval will be drilled with a water-based mud drill -in fluid (FloPro) weighted to 8.8-9.5 ppg with calcium carbonate and KCl. Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. CD5-25L 1 APD Page 6 of 14 Printed: 16 -Nov -17 Production ize in. 6.75 Size in. 4.5 PPG 8.8-9.5 CP 10 CpH lb./100 ftz 10-15 Viscosity s/qt. 40-50 els Ib./100 ftz 6 te Gels Ib./100 ftz 8 id Loss cc/30 min. 4.0 luid Loss cc/30 min. 10.0 9.0 — 9.5 Production Hole: The Alpine C Sand horizontal production interval will be drilled with a water-based mud drill -in fluid (FloPro) weighted to 8.8-9.5 ppg with calcium carbonate and KCl. Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. CD5-25L 1 APD Page 6 of 14 Printed: 16 -Nov -17 Application 'ermit to Drill, Well CRU CD5-25L1 Saved: 16 -Nov -17 9. Abnormally Pressured Formation Information (Requtrementsof20AAC25.005(x)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of10AAC25.005 (c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of20AAC25.005 (c)(I1)) N/A - Application is not for an offshore well. 12. Evidence of Bonding (Requirements of20 AAC 25.005 (c)(/2)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of20AAC25.005 (c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. 1. End PTD for CD5-25 and begin PTD for CD5-25LL 2. Pick up and run in hole with 6-3/4" drilling BHA. 3. Drill 6-3/4" hole to section TD (LWD Program: GR/RES) 4. Pull out of hole with drilling BHA. 5. Run 4.5" perforated pup liner, plop and drop in Alpine C lateral. 6. Run in hole whipstock retrieval BHA and retrieve whipstock. 7. RIH with 4.5" tubing with Baker Premier production packer. 1 IUDt t✓, Yc� y a. NOTE: A waiver is requested to set the production packer approximately MD above the intermediate casing shoe as per 20 AAC 25.412(b). This is to set the packer above the C sand window and maintain slickline accessibility to secure the well in the future. 8. Space out and land hanger. 9. Pressure test hanger seals to 5000 psi. 10. Drop ball and rod to set production packer, test tubing to 4,200 psi, chart test. 11. Bleed tubing pressure to 2,200 psi and test IA to 3,300 psi, chart test. 12. Install HP-BPV and test to 2,500 psi. 13. Nipple down BOP. 14. Install tubing head adapter assembly. N/U tree and test tree to 5000 psi/10 minutes. 15. Freeze protection tubing and annulus. 16. Secure well. RDMO. CD5-25L1 APD Page 7 of 14 Printed: 16 -Nov -17 Applicatio� 0ennit to Drill, Well CRU CD5-25L1 Saved: 16 -Nov -17 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20AAC25.005 (c)(14)) Incidental fluids developed from drilling operations on well CD5-25L1 will be injected into a permitted surface casing x production casing annulus on CD5. The CD5-25 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. Significant hydrocarbon zones include only the Alpine and Kuparuk sand based on pre -drill interpretations. There will be 500' of cement fill placed above the top of the Kuparuk reservoir. Once CD5-25 and CD5-25L1 have been drilled and completed, consideration may be given to permit this well for annular injection. An application for Sundry Operations form 10403 will then be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080 could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,185') + 1,500 psi = 2864 psi Pore Pressure = 1,049 psi Therefore Differential = 2864 —1049 = 1815 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (Ppf) Grade Range Connection Type Collapse P 85%*of Collapse Burst 85% of Burst 10-3/4" 45.5 L-80 3 HYD563/BTCM 2470 psi 2100 psi 5210 psi 44_ 29 Dsi 7-5/8" 29.7 L-80 3 HYD563/BTCM 4790 psi 4071 psi 6890 psi 5856 psi C05 -25L I APD Page 801`14 Printed: 16 -Nov -17 15. Attachments Attachment 1 Cement Summary Attachment 2 Drilling Hazards Summary Attachment 3 Completion Schematic Attachment 4 Directional Plan Applicatioi 3ermit to Drill, Well CRU CD5-251-1 Saved: 16 -Nov -17 CD5-25L1 APD Page 9 o1-14 Printed: 16 -Nov -17 Applicatic Permit to Drill, Well CRU CD5-25L1 Saved: 12-Jan-18 Attachment 1 — Cement Summary CD5-251-1 WD17 Cementing Program: CD5-251-7 Wp17 Schematic 20" 94# H-40 Welded Conductor to 115' 9-7/8" x 11" Hole 10-3/,V'45.5# L-80 HYD563/BTCM 2,194' MD / 2,185' TVD @ 8° inc. ............................................... Top of Cement 7,535' MD / 7,215' TVD ................................ Alpine C 8,309' MD / 7-5%8",29.7 L-80 HYD563 X BTCM Casing ` 8;623' MD / 7,531' TVD @ 83° Alpine A \. 9,256' MD / 7,605' TVD ` I � � I I ' 6-3/4" C Lateral 6-3/4" A Lateral Hole i 29,805' MD / 7,683 @ 89- 29,812- MD / 7,825 @ 89° CD5-25L1 APD Page 10 of 14 Printed: 12 -Jan -18 Applicatic Permit to Drill, Well CRU CD5-25L1 Saved: 16 -Nov -17 Attachment 1 — Cement Summary CD5-25L1 wa17 Cementing Program: CD5-25L1 wp17 Schematic 20" 94# H-40 Welded Conductor to 115' 9-7/8" x 11" Hole Alpine C 8,309' MD / 7,423' TVD Alpine A 9,256' MD / 7,605' TVD .............................. . 6-3/4" A Lateral Hole 29,812' MD / 7,825 @ 89° 10-3/4" 45.5# L-80 HYD563/13TCM 2,194' MD / 2,185TVD @ 8° inc. ............................... . ............... ry,�r spa Top of Cement 7,809' MD/ 7,351' TVD ..................... 7-5%8",29.7 L-80 HYD563 X BTCM Casing 8623' MD/ 7,531' TVD @ 83° ateral I 29,805' MD / 7,683 @ 89" i CD5-25L1 APD Page 10 of 14 Printed.: 16 -Nov -17 Applioatil 'Permit to Drill, Well CRU CD5-251-1 Saved: 12 -Jan -18 10.75" Surface Casing run to 2.194' MD / 2,1851 TVD Cement from 2194' MD to 16941(500' of tail) with Class G + Adds. @ 15.8 PPG, and from 1694' to surface with 11.0 ppg DeepCrete. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (1325' MD), zero excess in 20" conductor. Lead slurry from 1,694' MD to surface with Arctic Lite Crete @ 11.0 ppg Conductor (115'- 361 X 1.3645 W/ft X 1.0 (0% excess) = 108 ft3 Permafrost to Conductor (1,325'-1151 X 0.3637 ft3/ft X 3.5 (250% excess) = 1,541 ft3 Top of Tail to Permafrost (1,694'- 1,3251 X 0.3637 ft3/ft X 1.5 (50% excess) = 202 ft3 Total Volume = 108 + 1,541 + 202 = 1,851 ft3 => 960 sx of 11.0 ppg DeepCrete 0 1.93 ft3 /sk Tail slurry from 2,194' MD to 1,694' MD with 15.8 ppg Class G + additives Shoe to Top of Tail (2,194'-1,6941 X 0.3637 ft3/ft X 1.50 (50% excess) = 273 ft3 Shoe Joint (801 X 0.5400 ft3/ft X 1.0 (0% excess) = 43 ft3 Total Volume = 273 + 43 = 316 ft3 => 271 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8% 5002 accelerator 0 1.17 ftr/sk 7.625" Intermediate Casing run to 8,623' MD / 7,8091 TVD Top of slurry is designed to be at 7.535' MD, which is 278' TVD above the prognosis shallowest hydrocarbon bearing zone Alpine C. Assume 40% excess annular volume. *I I" Under reamer is 90' above the 9-7/8" bit. Tail slurry from 8,623' MD to 7,535' MD with 15.8 ppg Class G + additives Shoe to top of 9-7/8" Hole (8,623'- 8,533) X 0.2148 f 3/ft X 1.40 (40% excess) = 27 ft3 11" Hole to to Top of Cement (8,533'- 7,535) X 0.3428 ft3/ft X 1.40 (40% excess) = 479ft3 Shoe Joint (801 X 0.2578 ft3/ft X 1.0 (0% excess) = 21 ft3 Total Volume = 27+ 479 + 21 = 527 ft3 => 341 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8% 5002 accelerator @ 1.16 ft3/sk CD5-25L1 APD Page 11 of 14 Printed..' 12 -Jar -18 Applicatid Permit to Drill, Well CRU CD5-25L1 Saved: 16 -Nov -17 10.75" Surface Casing run to 2,194' MID / 2,185' TVD Cement from 2194' MD to 1694'(500' of tail) with Class G + Adds.J5.8 PPG, and from 1694' to surface with 11.0 ppg DeepCrete. Assume 250% excess annular volume in perm and 50% excess below the permafrost (1325' MD), zero excess in 20" conductor. Lead slurry from 1,694' MD to surface with Arctic Lite Crete @ 11.0 ppg \ Conductor (115'- 36� X 1.3645 ft3/ft X 1.0 (0% excess) = 108 ft3 Permafrost to Conductor (1,325'-115) X 0.3637 ft3/ft X 3.5 (250% excess) = 1,541 ft3 Top of Tail to Permafrost (1,694'- 1,325) X 0.3637 ft3/ft X 1.5 (50% excess) = 202 ft3 Total Volume = 1 8 + 1,541 + 202 = 1,851 ft3 => 960 sx of 11.0 ppg DeepCrete @ 1.93 ft3 /sk Tail slurry from 2,194' D to 1,694' MD with 15.8 ppg Class G + additives Shoe to Top of Tail Shoe Joint (2,194'-1,694) X 0.3637 ft3/ft X 1.50 (50% excess) = 273 ft3 (80� X 0.5400 ft3/ft X 1.0 (0% excess) = 43 ft3 Total Volume = 273 + 43 =V16 ft3 => 271 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0 % D065 dispersant and 0.8% 5002 accelerator @ 1.17 ft3/sk 5VV Top of slurry is designed to be at 7,809' MD, whicis 500' MD above the prognosis shallowest hydrocarbon bearing zone Alpine C. Assume 40% excess annular \i fume. * 11" Under reamer is 90' above the 9-7/8" bit. Tail slurry from 8,623' MD to 7,809'N.8pg Class G +additives Shoe to top of 9-7/8" Hole (8.2148 ft3/ft X 1.40 (40% excess) = 27 ft311" Hole to to Top of Cement (8. 428 ft3/ft X 1.40 (40% excess) = 347ft3 Shoe Joint (8X 1. (0%. excess) = 21 ft Total Volume = 27+ 347 + 21 = 395 ft3 => 341 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8% 5002 accelerator @ 1.16 ft3/sk CD5-25L1 APD Page 11 of 14 Printed., 16 -Nov -17 Applicant Permit to Drill, Well CRU CD5-251-1 Saved: 16 -Nov -17 Attachment 2 — Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 6-3/4" Open Hole Production Interval Event Risk Level Miti ation Strate Reduced pump rates, reduced trip speeds, real time equivalent Lost circulation Low circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbin on tri s Low Annular ressure a lied b maria ed ressured rillin a ui ment. Abnormal Reservoir Pressure Low Well control drills, increased mud weight. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers CD5-25L1 APD Page 12 of 14 Printed., 16 -Nov -17 Applicatiti Permit to Drill, Well CRU CD5-251-1 Saved: 16 -Nov -17 Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in the following attachments. Drilling Area Risks: Reservoir Pressure: Offset production has the potential to reduce the reservoir pressure. LCM material will be on location to deal with losses. CD5-25L1 APD Page 13 of 14 Printed. 16 -Nov -17 Attachment 3 — Completion Schematic CD5 - 25 Alpine A & C Multi-Lat Injector 20" SU H -4O Welded ConducWr 10 114' Landing Nippie, 3 813' X 1"4- BON LA0 H563 Saniade casing r nented to surface Gas Lift Matlml 4-172" 12.69 LA0 FIYD563 7 S8" 299 LA0 Hyd 56313TCM Ylteirred4le Csg 8.623' Applicati • Permit to Drill, Well CRU CD5-25L1 Saved: 12 -Jan -18 Upper Urnplewn: 1) 4-712.MRTXP 2) Shallow npple ladle 3) 4-V x 1- Carried KBMG GLM (xx') wrDCK2 pinned for 2500 psi casing m ft shear 4) Baker Premier Patina 5j CMU sliding sheen 8) Tandem Wedge for C sand CTD Latera Lover Completion: 7) Two 4.5' 12.09 L90 TXP Liners wM Ped Pups 8) ZXP Inver tap packer 8 Flexiock Liner Hanger XO 5 FWN 521 Box X 4- TXP pin Ta Bern Wedge w 1h DB M%. br future A Sand CTD Lateral Gas Lib Mandrel 412" 12.69 LA0 TXp Liners C sand Latera with Perf Pups 8 3A- 8323 ' Hole TD 8323'-2980 —1 o o e 0 0 0 0 o Baker Premier Production Packer 7,&10' CMU Sbding Sleeve 7,850' 2XP Beer tip packer 8,43Q 8 Zr823-20,817 CD5-250 APD Page 14 of 14 Printed. 12 -Jan -18 Attachment 3 — Completion Schematic CD5 - 25 Alpine A & C Multi-Lat Injector 20" 94# H.40 Welded Conductor m t 74 Landing Nipple, 3.813" X 1041/4" 606 L-90 H593 Surface Casing cemented to surface Gas Lift Mandrel 4-112" 12.6# 7 5f8" 296 L-80 Hyd 5631ETCM Intermediate Csg 9,026' Baker Premier Production Packer 7.fW CMU Sliding Sleeve 7,555' 2XP liner top SAM Gas Lift Mandrel Applicatic Permit to Drill, Well CRU CD5-2511 Saved: 16 -Nov -17 Upper Completion 1) 4'/_' 12.154A TXP 2) Shallow nipple profile 3) 9-%" x 1" Carrico KBMG GLM (n`) >.yMCK2 pinned for 2500 psi casing to tbg shear 4) Baker Premier Packer 5) CMU sliding sleeve 6) Tandem Wedge for C sand CTD Lateral Lm r Campletion.- j Two 4.5' i2.@#L80 TXP Liners tv7h Parf pups 81 ZXP liner top packer& Plodock Liner Hanger XO 5" Hyddl 521 Boz X 4-%' TXP pin Tandem Wedge with 09 profile for future A Sand CTD Lateral 4-112" 12.6CL-OOTXPLiners With Perf Pups C sand Lateral 8 314" Hol- TO 8,5BP-29,808' r-------------------------------- / 1 / a o 0 0 0 0 0 o I I ker V y �bP ate a O 8,4" Hale TD ^ 0203'-29,808' CD5-25L1 APD Page 14 of 14 Printed 16 -Nov -17 10:26, November 14 2077 DI CD5-25L1 wp17 7DD8 Plan Summa 7-5/8" x 9-7/8' -- -- 5 0 12375 16500 20625 24750 9RR7R Measured Depth 0 0 0 Ian: 33.7+36.3 (Copy) @ 70.00usft (Doyon 1 ) 7 -. gi e I n m o o m o$ ry N o Om N o I" X 9-7/8' on 4-1/2" x 6-3/4' 0 0 8 8900 9000 240 0 Measured Depth _... 0 _.. 0323 3000 6000 9000 12000 15000 18000 21000 24000 0.00 0.00 2362.7] eplM1 Fmm Oe th To0000 SuMC05-2myn 3830 1000.00 (10aq (Plan: CDS-25) GYD+IF-aa O,G 48500.51 89.67 151.91 7504.66 -2248.34 1112.09 e3z3 - Oslo 1600.06 2193.56 COS25wp16.1 (IDBC) (Plan: CDS25) MWDHFR-AK-CAZ-sC Horizontal Departure 330 30 CDS2%pl6.1 2193.56 8323.00 Ws-25wp18.1(IOBC)(Plan : C05-25)MWD+IFR-AK-CAZ-SC 0]23.00 8700.00 CDS25L1wp17(PIan: CD5-25L1) MWD-INC-ONLY(INC>10°) 8s1B - No T- MO 9/ne '<94.388324.00 7-5/8"X8 8]00.0010200.00 WS25Liwp1](Ran: CDS25Li) MWD ]683.0129805.30 q -1/2"%&3/d" 1 8700.0000 29805.18 CD5.25uwp17(Ran: CDS-251.1) MWD+IFRAK-CAZSc 8690 0070 0.00 CD5-23P81 Toe 072517 DK Magnetic North is 16.73' East of True North (Magnetic Declination) Magnetic Dip & Field Stren the 80.78° 57436nT Sec MD Inc AZi TVD +N/ -S +E/ W DI 8970 9050 CD5-25wp16.2 / 9050 - 9230 300 1 60 9230 - 9420 Equivalent Magnetic Distance rm.>xo el '� 9424 - B800 1- 9800 - 10440 -` '• 10440 11280 11280 - 12110 i 270 96 12110 - IN50 - I 12950 - 13790 13790 - 14620 14820 15480 15460 16300 300 8400 8500 8600 8700 8800 eg TF 8900 9000 240 16300 - 179eo Measured Depth 15.90 -22.00 2342.86 - 120 17990 - 19680 19680 - 21360 21350 - 23040 23040 24740 SURVEY PROGRAM 0.00 0.00 2362.7] eplM1 Fmm Oe th To0000 SuMC05-2myn 3830 1000.00 (10aq (Plan: CDS-25) GYD+IF-aa O,G 48500.51 89.67 151.91 7504.66 -2248.34 1112.09 210 150 Start 3.5°/100' DLS, 10.51° TF, for 144.71' 1600.06 2193.56 COS25wp16.1 (IDBC) (Plan: CDS25) MWDHFR-AK-CAZ-sC 810606J9 89.67 151.91 ]516.97 -0106.46 2103.8] 0.00 0.00 4613.50 24740 26430 CDS2%pl6.1 2193.56 8323.00 Ws-25wp18.1(IOBC)(Plan : C05-25)MWD+IFR-AK-CAZ-SC 0]23.00 8700.00 CDS25L1wp17(PIan: CD5-25L1) MWD-INC-ONLY(INC>10°) 180 26430 - -- 20120 20120-28805 T- MO 9/ne '<94.388324.00 7-5/8"X8 8]00.0010200.00 WS25Liwp1](Ran: CDS25Li) MWD ]683.0129805.30 q -1/2"%&3/d" Magnetic Model & Date: BGGM201171-Mar-18 8700.0000 29805.18 CD5.25uwp17(Ran: CDS-251.1) MWD+IFRAK-CAZSc 829805 30 89.50 151.97 7683.0021052.6711125.02 0.00 CD5-23P81 Toe 072517 DK Magnetic North is 16.73' East of True North (Magnetic Declination) Magnetic Dip & Field Stren the 80.78° 57436nT Sec MD Inc AZi TVD +N/ -S +E/ W DI 1 8323.00 82.60 151.75 7494.28 -2092.83 1027.28 vsect Target 0.00 0.00 2330.14 Annotation ccepted by. 2 8335.80 84.68 150.99 7495 88 -2104.00 1033.37 15.90 -22.00 2342.86 KOR 15.9°/100' DLS, -22° TF, for 12.8' Lithology Column 3 Q355.80 ed.68 150.99 7497.53 -2121.42 1043.03 0.00 0.00 2362.7] Hold for 20' 48500.51 89.67 151.91 7504.66 -2248.34 1112.09 3.50 10.51 250] 28 Start 3.5°/100' DLS, 10.51° TF, for 144.71' 810606J9 89.67 151.91 ]516.97 -0106.46 2103.8] 0.00 0.00 4613.50 Hold for 2100.27' 60611.61 89.60 151.94 7517.00-4110.71 2106.14 1.50 1547.05 start 1,5'1100' OILS, 154.5° TF, for 4.82' 4116,64 2109.29.504618.31710618.32 8950 1 50 160.0@3811.21.57 28; Adjust TF to 161.5]', for 6.71' 829805 30 89.50 151.97 7683.0021052.6711125.02 0.00 CD5-23P81 Toe 072517 DK TD 2f9805188.98' .3 MD, 7683 TVD ..,P rmit Pac TCRW will be required for sidetracking out of _ the main bore. also, should have a TCRW • • for CD5-313, as the SF is 1.03 correct, ensured HIS completeness, and all surrounding wells are assigned to the proper position, UFRI 3and I approve the scan and collision avoidance plan as set out in the audit pack.l approve it as the Steen basis for the final well plan and wellsde drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. Prepared by Checked by: ccepted by. Approved by: CS DeUapp V Osara Erik Sterk DE Name 00:48, November 14 20111 (Sun 5) CD5-316PB1 CD5-316 Easting CD5 Alpine West 1 ustt/in) CD5 1 � cos -01 CD5-05 �%-_WL1 7L1 CD5-99A \A�(�Sliver2) CD5- wp01 3 (12B)CD5_- CD5-17 D5-315__CD5-19wp10.1 __`CD5-24wp16 (9C) CD5-24L1wp16 (9C) - CD5-314X ,CD5-25wp16.2 CD5.27wp01 v3 (12C)CD5-25L1wP17 CDS•26wp01 v3 (13C)CD5.26wp01 v3 (11C) CD5-35wp0 CD5-34wp01 v3 (Slivert) Easting (4000 usftrin) -3500 -7000 n t `0 z1 0 0 -1 -21 CD5-25L1wp17 While drillina nrnrtuctinn -10500 -7000 within 100 feet laterally of plan, unless notified otherwise. 10-3/4" x 13-1/24 20" x 42" 0000 7-5/8" x 9-7/8" 10000 11000 12000 0 1300 14000 10000 10000 1*I000 1-60130 19000 20000 21000 22000 00 230 4000 2 0 2000 10 4-1/2" x 6-3/4" 0 2�001'I OOp �1`Np 3500 0 3500 7000 10500 14000 17500 West( -)/East(+) 21000 CD5-25L1wp17 Section View -3000 20" x 42" 0 - WOO 10-3/4" x 13-1/2" 0- 3000 3000- — - 3000 .0 4000 N 0 a� 12` U 5000 7-5/8" x 9-7/8" 4-1/2" x 6-3/4"; ~ 6000 0 6 0 ®�Ooo D 0 0 0 0 Qo ,'0 00 0 0 0 0 �b 0 LO m o 00 0 0 ® 0 0 0 0 0 0 0 0 o 0 0' 0 0 0 o . Ln 8 rn 0 -� Cm N 0 N N CO N N N N N N' N , 9000 N fD d Mj N 12000 0 0 3000 6000 9000 12000 15000 18000 21000 24000 Vertical Section at 152.00° Conoco Ph illi ps(Alaska) Inc. -WNS Western North Slope CD5 Alpine West Pad Plan: CD5-25 (1 OBC) - Slot 25 50103xxxxx00 Plan: C135-251-1 Plan: CD5-25L1wp17 Standard Proposal Report 14 November, 2017 ConocoPhillips ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips(Alaska) Inc.-WNS Project Western North Slope Site: CD5 Alpine West Pad Well: Plan: CD5-25 (10BC) Wellbore: Plan: CD5-25L1 Design: CD5-25L1wpl7 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Plan: CD5-25 (I OBC) -Slot 25 Plan: 33.7+36.3 (copy) @ 70.00usft (Doyon 19) Plan: 33.7+36.3 (copy) @ 70.00usft (Doyon 19) True Minimum Curvature Project Western North Slope, North Slope Alaska, United States Nap System: System Datum: Mean Sea Level Seo Datum: Using Well Reference Point Nap Zone: Using geodetic scale factor Site CD5 Alpine West Pad Depth From Site Position: Northing: Latitude: From: Map Easting: Tool Name Remarks Longitude: Position Uncertainty: Slot Radius: — MWD-INC–ONLY (INC>10°) Grid Convergence: MVJD-INC_ONLV_FILLER (IN, 2 6,700.00 Well Plan. CDS-25(1OBC) -Slot 25 MWD Well Position +N/S Northing: MWD - Standard Latitude: 29,805.16 +E/ -W Easting: MVJD+IFR-AK-CAZ-SC Longitude: Position Uncertainty Wellhead Elevation: MWD+IFR AK CAZ SCC Ground Level: Wellbore Plan: CD5-25L7 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1) (1) (nT) BGGM2017 3/1/2018 16.73 80.78 57,436 Design CD5-25Ltwp17 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,323.00 Vertical Section: Depth From (TVD) +N/S +E/ -W Direction (usft) (usft) (usft) (•) 36.30 0.00 0.00 152.00 Plan Survey Tool Program Date 11/14/2017 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 8,323.00 8,700.00 CD5.25Liwp17 (Plan: C135-2511 MWD-INC–ONLY (INC>10°) MVJD-INC_ONLV_FILLER (IN, 2 6,700.00 10,200.00 CD525L1wp17 (Plan: C135-2517 MWD MWD - Standard 3 8,700.00 29,805.16 CD5-25L1wp17 (Plan: CD5-25L1 MVJD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 111142017 10.54:02AM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Database: DAKEDMP2 Comparry: ConomPhillips(Alaska) Inc. -V/NS Project Western North Slope SRO: CDs Alpine West Pad Well: Plan: ODS -25 (10BC) Wellbore: Plan: CD5-25L1 Design: CD5-25L1wp17 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Plan: CDS-25 00BC)-Slot 25 Plan: 33.7+36.3 (copy) 0 70.00usft (Doyon 19) Plan: 33.7+36,3 (copy) @ 70.00usft (Doyon 19) True Minimum Curvature Plan Sections Measured Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +N/.S +E/ -W Rate Rate Rata (usft) (1) (1) (usft) (usft) (usft) (•1100usft) (1100usft) ('1100"M TFO (7 Target 8,323.00 82.80 151.75 7,494.28 -2,092.83 1,027.28 0.00 0.00 0.00 0.00 8,335.80 84.68 150.99 7,495.68 -2,104.00 1,033.37 15.90 14.75 -5.96 -22.00 8,355.80 84.68 150.99 7,497.53 -2,121.42 1,043.03 0.00 0.00 0.00 0.00 8,500.51 89.67 151.91 7,504.66 -2,248.34 1,112.09 3.50 3.44 0.64 10.51 10,606.79 89.67 151.91 7,516.97 -4,106.46 2,103.87 0.00 0.00 0.00 0.00 10,611.61 89.60 151.94 7,517.00 -4,110.71 2,106.14 1.50 -1.35 0.65 154.50 10,618.32 89.50 151.97 7,517.05 -4,116.64 2,109.29 1.50 -1.42 0.47 161.57 29,805.30 89.50 151.97 7,683.00 -21,052.67 11,125.02 0.00 0.00 0.00 0.00 11/14/201710:54.:02AM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Local Coordinate Reference: Company: Conoco Phillips(Alaska) Inc. -WNS Verd"I Dogleg TVD Reference: Project Western North Slope MD Reference: Site: CDS Alpine West Pad North Reference: Well: Plan: C135-25 (1 OBC) Survey Calculation Method: Wellbore: Plan: CD5-25L1 (h Design: CD5-25L1wp17 Neff) Planned Survey ConocoPhillips Standard Proposal Report Well Plan: CDS-25 (1013C) - Slot 25 Plan: 33.7+36,3 (COPY) @ 70.00ush (Doyon 19) Plan: 33.7+36.3 (Wpy) 070.00ush (Doyon 19) True Minimum Curvature Measured Vertical Verd"I Dogleg Build Tum Depth Inclination Azimuth Depth +N1S +E/4N Section Rate Rab Rate (usft) (h (°) (usR) Neff) (usft) (usR) (°HOOusR) (°HOOusR) (°HOOusR) 8,323.00 82.80 151.75 7,494.28 -2,092.83 1,027.28 2,330.14 3.50 3.50 -0.02 KOP: 16.9°1100' DLS, -226 TF, for 12.8' 8,324.00 82.94 151.69 7,494.41 -2,093.71 1,027.75 2,331.13 15.90 14.74 -6.00 7-W x 9.718- 8,335.80 84.68 150.99 7,495.68 -2,104.00 1,033.37 2,342.86 15.90 14.75 -5.98 Hold for 20- 8,355.80 84.68 150.99 7,497.53 -2,121.42 1,043.03 2,362.77 0.00 0.00 0.00 Start 3.6°1100' DLS, 10.61° TF, for 144.71- 8,400.00 86.21 151.27 7,501.04 -2,160.00 1,064.31 2,406.83 3.50 3.44 0.64 8,500.00 89.65 151.91 7,504.66 -2,247.88 1,111.85 2,508.74 3.50 3.44 0.64 8,500.51 89.67 151.91 7,504.66 -2,248.34 1,112.09 2,507.26 3.50 3.44 0.64 Hold for 2106.27' 81600.00 89.67 151.91 7,505.24 -2,336.10 1,158.94 2,606.74 0.00 0.00 0.00 8,700.00 89.67 151.91 7,505.83 -2,424.32 1,206.02 2,706.74 0.00 0.00 0,00 8,800.00 89.67 151.91 7,506.41 -2,512.54 1,253.11 2,806.74 0.00 0.00 0.00 8,900.00 89.67 151.91 7,507.00 -2,600.76 1,300.20 2,906.74 0.00 0.00 0.00 9,000.00 89.67 151.91 7,507.58 -2,688.97 1,347,28 3,006.74 0.00 0.00 0.00 9,100.00 89.67 151.91 7,508.17 -2,777.19 1,394.37 3,106.73 0.00 0.00 0.00 9,200.00 89.67 151.91 7,508.75 -2,865.41 1,441.46 3,206.73 0.00 0.00 0.00 9,300.00 89.67 151.91 7,509.33 -2,953.83 1,488.54 3,306.73 0.00 0.00 0,00 9,400.00 89.67 151.91 7,509.92 -3,041.85 1,535.63 3,406.73 0.00 0.00 0.00 9,500.00 89.67 151.91 7,510.50 -3,130.07 1,582.72 3,506.73 0.00 0.00 0.00 9,600.00 89.67 151.91 7,511.09 -3,218.29 1,629.80 3,606.72 0.00 0.00 0.00 9,700.00 89.67 151.91 7,511.67 -3,306.50 1,676.89 3,706.72 0.00 0.00 0.00 91800.00 89.67 151.91 7,512.26 -3,394.72 1,723.98 3,806.72 0.00 0.00 0.00 9,900.00 89.67 151.91 7,512.84 -3,482.94 1,771.06 3,906.72 0.00 0.00 0.00 10,000.00 89.67 151.91 7,513.42 -3,571.16 1,818.15 4,006.72 0.00 0.00 0.00 10,100.00 89.67 151.91 7,514.01 -3,659.38 1,865.24 4,106.71 0.00 0.00 0.00 10,200.00 89.67 151.91 7,514.59 -3,747.60 1,912.32 4,206.71 0.00 0.00 0.00 10,300.00 89.67 151.91 7,515.18 -3,835.81 1,959.41 4,306.71 0.00 0.00 0.00 10,400.00 89.67 151.91 7,515.76 -3,924.03 2,006.50 4,406.71 0.00 0.00 0.00 10,500.00 89.67 151.91 7,516.35 -4,012.25 2,053.58 4,506.71 0.00 0.00 0.00 10,600.00 89.67 151.91 7,516.93 -4,100.47 2,100.67 4,606.71 0.00 0.00 0.00 10,606.79 69.67 151.91 7,516.97 -4,106.46 2,103.87 4,613.50 0.00 0.00 0.00 Start 1.6°1100' DLS, 164.6° TF, for 4.82' 10,611.61 89.60 151.94 7,517.00 4,110.71 2,106.14 4,618.31 1.50 -1.35 0.65 Adjust TF to 161.67°, for 6.71' 10,618.32 89.50 151.97 7,517.05 4,116.64 2,109.29 4,625.03 1.50 -1.42 0.47 Hold for 19186.98' 10,700.00 89.50 151.97 7,517.76 4,188.73 2,147.67 4,706.70 0.00 0.00 0.00 10,800.00 89.50 151.97 7,518.62 4,277.00 2,194.66 4,806.70 0.00 0.00 0.00 10,900.00 89.50 151.97 7,519.49 4,365.27 2,241.65 4,908.69 0.00 0.00 0.00 11,000.00 89.50 151.97 7,520.35 4,453.54 2,288.64 5,006.69 0.00 0.00 0.00 11,100.00 89.50 151.97 7,521.22 4,541.81 2,335.63 5,106.69 0.00 0.00 0.00 11,200.00 89.50 151.97 7,522.08 4,630.07 2,382.62 5,206.68 0.00 0.00 0.00 11,300.00 89.50 151.97 7,522.95 4,718.34 2,429.60 5,306.68 0.00 0.00 0.00 11,400.00 89.50 151.97 7,523.81 4,806.61 2,476.59 5,406.68 0.00 0.00 0.00 11,500.00 89.50 151.97 7,524.68 4,894.88 2,523.56 5,506.67 0.00 0.00 0.00 11,600.00 89.50 151.97 7,525.54 4,983.15 2,570.57 5,606.67 0.00 0.00 0.00 11,700.00 89.50 151.97 7,526.41 -5,071.42 2,617.56 5,706.66 0.00 0.00 0.00 11 800.00 89.50 151.97 7,527.27 -5,159.68 2,664.55 5,808.66 0.00 0.00 0.00 1111412017 f0:54:02AM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Local Coordinate Reference: Company: ConocoPhillips(Alaska) Inc. -WNS TVD Reference: Project Western North Slope MD Reference: Site: CD5 Alpine West Pad North Reference: Well: Plan: CDS-25 (1013C) Survey Calculation Method: Wellbore: Plan: CD5-251-1 DoBuild Design: CD5-25L1wpl7 Depth ConocoPhillips Standard Proposal Report Well Plan: CD5-25 00BC)-Slot 25 Plan: 33.7-36.3 (copy) @I 70.00usft (Doyon 19) Plan: 33.7+36.3 (copy) @ 70.00usft (Doyon 19) True Minimum Curvature Planned Survey Measured Vertical Vertical DoBuild Tum Depth Inclination Azimuth M Depth +N13 +E1 -W Section Rata Rate Rate Rafe Rate (usR) CI P) (usR) (usl) (usR) (usB) CMOOus@) I'M00"It) (oj100"fQ 11,900.00 89.50 151.97 7,528.14 -5,247.95 2,711.54 5,906.66 0.00 0.00 0.00 12,000.00 89.50 151.97 7,529.00 -5,336.22 2,758.53 6,006.65 0.00 0.00 0.00 12,100.00 89.50 151.97 7,529.67 -5,424.49 2,805.52 6,106.65 0.00 0.00 0.00 12,200.00 89.50 151.97 7,530.73 -5,512.76 2,852.50 6,206.65 0.00 0.00 0.00 12,300.00 89.50 151.97 7,531.60 -5,601.03 2,899.49 6,306.64 0.00 0.00 0.00 12,400.00 89.50 151.97 7,532.46 -5,689.29 2,946.46 6,406.64 0.00 0.00 0.00 12,500.00 89.50 151.97 7,533.33 5,777.56 2,993.47 6,506.63 0.00 0.00 0.00 12,600.00 89.50 151.97 7,534.19 -5,865.83 3,040.46 6,606.63 0.00 0.00 0.00 12,700.00 89.50 151.97 7,535.06 5,954.10 3,087,45 6,706.63 0.00 0.00 0.00 12,800.00 69.50 151.97 7,535.92 6,042.37 3,134.44 6,806.62 0.00 0.00 0.00 12,900.00 89.50 151.97 7,536.79 -6,130.64 3,181.43 6,906.62 0.00 0,00 0.00 13,000.00 89.50 151.97 7,537.65 -6,218.91 3,228.41 7,006.62 0.00 0.00 0.00 13,100.00 69.50 151.97 7,538.52 -6,307.17 3,275.40 7,106.61 0.00 0.00 0.00 13,200.00 89.50 151.97 7,539.38 -6,395.44 3,322.39 7,206,81 0.00 0.00 0.00 13,300.00 89.50 151.97 7,540.25 -8,483.71 3,369,38 7,308,60 0.00 0.00 0.00 13,400.00 89.50 151.97 7,541.11 -6,571.98 3,416.37 7,406.60 0.00 0.00 0.00 13,500.00 89.50 151.97 7,541.98 -6,660.25 3,463.36 7,506.60 0.00 0.00 0,00 13,800.00 89.50 151.97 7,542.84 -6,748.52 3,510.35 7,606.59 0.00 0.00 0.00 13,700.00 89.50 151.97 7,543.71 -8,836.78 3,557.34 7,706.59 0.00 0.00 0.00 13,800.00 89.50 151.97 7,544.57 -6,925.05 3,604.32 7,80&59 0.00 0.00 0.00 13,900.00 89.50 151.97 7,545.44 -7,013.32 3,651.31 7,906.58 0.00 0.00 0.00 14,000.00 89.50 151.97 7,546.30 -7,101.59 3,698.30 8,006.58 0.00 0.00 0.00 14,100.00 89.50 151.97 7,547.17 -7,189.86 3,74529 8,106.57 0.00 0.00 0.00 14,200.00 89.50 151.97 7,546.03 -7,276.13 3,792.28 8,206.57 0.00 0.00 0.00 14,300.00 89.50 151.97 7,548.90 -7,366.39 3,839.27 8,306.57 0.00 0.00 0.00 14,400.00 89,50 151.97 7,549.76 -7,454.66 3,886.26 8,406.56 0.00 0.00 0.00 14,500.00 89.50 151.97 7,550.63 -7,542.93 3,933.25 8,506.56 0.00 0.00 0.00 14,600.00 89.50 151.97 7,551.49 -7,631.20 3,980.23 8,606.56 0.00 0.00 0.00 14,700.00 89.50 151.97 7,552.35 -7,719.47 4,027.22 8,706.55 0.00 0.00 0.00 14,800.00 89.50 151.97 7,553.22 -7,807.74 4,074.21 8,806.55 0.00 0.00 0.00 14,900.00 89.50 151.97 7,554.08 -7,896.00 4,121.20 8,906.54 0.00 0.00 0.00 15,000.00 89.50 151.97 7,554.95 -7,980.27 4,168.19 9,006.54 0.00 0.00 0.00 15,100.00 89.50 151.97 7,555.81 -8,072.54 4,215.18 9,106.54 0.00 0.00 0.00 15,200.00 89.50 151.97 7,556.68 -8,160.81 4,262.17 9,208.53 0.00 0.00 0.00 15,300.00 89.50 151.97 7,557.54 -6,249.08 4,309.16 9,306.53 0.00 0.00 0.00 15,400.00 89.50 151.97 7,558.41 -8,337.35 4,356.14 9,406,53 0.00 0.00 0.00 15,500.00 89.50 151.97 7,559.27 -8,425.61 4,403.13 9,506.52 0.00 0.00 0.00 15,600.00 89.50 151.97 7,560.14 -8,513.88 4,450.12 9,606.52 0.00 0.00 0.00 15,700.00 89.50 151.97 7,561.00 -8,602.15 4,497.11 9,706.51 0.00 0.00 0.00 15,800.00 89.50 151.97 7,561.87 -8,690.42 4,544.10 9,806.51 0.00 0.00 0.00 15,900.00 89.50 151.97 7,562.73 -8,778.69 4,591.09 9,906.51 0.00 0.00 0.00 16,000.00 89.50 151.97 7,563.60 -8,866.96 4,638.08 10,006.50 0.00 0.00 0.00 16,100.00 89.50 151.97 7,564,46 -8,955.23 4,685.07 10,106.50 0.00 0.00 0.00 16,200.00 89.50 151.97 7,565.33 -9,043.49 4,732.06 10,206.50 0.00 0.00 0.00 16,300.00 89.50 151.97 7,566.19 -9,131.76 4,779.04 10,306.49 0.00 0.00 0.00 16,400,00 69.50 151.97 7,567.06 -9,220.03 4,826.03 10,406.49 0.00 0.00 0.00 16,500.00 89.50 151.97 7,567.92 -9,308.30 4,87102 10,506.48 0.00 0.00 0.00 16,600.00 89.50 151.97 7,568.79 -9,396.57 4,920.01 10,606.48 0.00 0,00 0.00 16,700.00 89.50 151.97 7,569.65 -9,484.84 4,967.00 10,706.48 0.00 0.00 0.00 16,800.00 89.50 151.97 7,570,52 -9,573.10 5,013.99 10,806.47 0.00 0.00 0.00 16,900.00 89.50 151.97 7,571.38 -9,661.37 5,060.98 10,906.47 0.00 0.00 0.00 17,000.00 89.50 151.97 7,572.25 -9,749.64 5,107.97 11,006.47 0.00 0.00 0.00 1111412017 1o54:02AM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Local Co-ordinate Reference: Company: ConocoPhillips(Alasks) Inc. -WNS TVD Reference: Project: Western North Slope MD Reference: Site: CD5 Alpine West Pad North Reference: Well: Plan: CDS-25 (1 OBC) Survey Calculation Method: Wellbore: Plan: CD5-251-1 Dogleg Design: CD5-25Ltwpl7 Depth ConocoPhillips Standard Proposal Report Well Plan: CDS-25 (108C) - Slot 25 Plan: 33.7+36,3 (ropy) @ 70.00usft (Doyon 19) Plan: 33.7+36.3 (copy) @ 70.00usft (Doyon 19) True Minimum Curvature Survey - __-- Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +WS +E74N Section Rate Rate Rate (usft) F (1) (q (usft) (usft) (usft) (usft) ('1100usft) ('1100usft) (°/100usft) 17,100.00 89.50 151.97 7,573.11 -9,837.91 5,154.95 11,106.46 0.00 0.00 0.00 17,200.00 89.50 151.97 7,573.98 -9,926.18 5,201.94 11,206.46 0.00 0.00 0.00 17,300.00 89.50 151.97 7,574.84 -10,014.45 5,248.93 11,308.45 0.00 0.00 0.00 17,400.00 89.50 151.97 7,575.71 -10,102.71 5,295.92 11,406.45 0.00 0.00 0.00 17,500.00 89.50 151.97 7,576.57 -10,190.98 5,342.91 11,506.45 0.00 0.00 Moo 17,600.00 89.50 151.97 7,577.44 -10,279.25 5,389.90 11,606.44 0.00 0.00 0.00 17,700.00 89.50 151.97 7,578.30 -10,367.52 5,438.89 11,706.44 0.00 0.00 0.00 17,800.00 89.50 151.97 7,579.17 -10,455.79 5,483.88 11,806.44 0.00 0.00 0.00 17,900.00 89.50 151.97 7,580.03 -10,544.06 5,530.86 11,906.43 0.00 0.00 0.00 18,000.00 89.50 151.97 7,580.90 -10,632.32 5,577.85 12,006.43 0.00 0.00 0.00 18,100.00 89.50 151.97 7,581.76 -10,720.59 5,624.84 12,106.42 0.00 0.00 0.00 18,200.00 89.50 151.97 7,582.63 -10,808.86 5,671.83 12,206.42 0.00 0.00 0.00 18,300.00 89.50 151.97 7,583.49 -10,897.13 5,718.82 12,306.42 0.00 0.00 0.00 18,400.00 89.50 151.97 7,584.36 -10,985.40 5,765.81 12,406.41 0.00 0.00 0.00 18,500.00 89.50 151.97 7,585.22 -11,073.67 5,812.80 12,506.41 0.00 0.00 0.00 18,600.00 89.50 151.97 7,586.09 -11,161.93 5,859.79 12,606.41 0.00 0.00 0.00 18,700.00 89.50 151.97 7,586.95 -11,250.20 5,906.77 12,706.40 0.00 0.00 0.00 18,800.00 89.50 151.97 7,587.82 -11,338.47 5,953.76 12,806.40 0.00 0.00 0.00 18,900.00 89.50 151.97 7,588.68 -11,426.74 6,000.75 12,906.39 0.00 0.00 0.00 19,000.00 89.50 151.97 7,589.55 -11,515.01 6,047.74 13,006.39 0.00 0.00 0.00 19,100.00 89.50 151.97 7,590.41 -11,603.28 6,094.73 13,106.39 0.00 0.00 0.00 19,200.00 89.50 151.97 7,591.28 -11,691.54 6,141.72 13,206.38 0.00 0.00 0.00 19,300.00 89.50 151.97 7,592.14 -11,779.81 6,188.71 13,306.38 0.00 0.00 0.00 19,400.00 69.50 151.97 7,593.01 -11,868.08 6,235.70 13,406.38 0.00 0.00 0.00 19,500.00 89.50 151.97 7,593.67 -11,956.35 6,282.68 13,506.37 0.00 0.00 0.00 19,600.00 89.50 151.97 7,594.73 -12,044.62 6,329.67 13,606.37 0.00 0.00 0.00 19,700.00 89.50 151.97 7,595.80 -12,132.89 6,376.66 13,706.36 0.00 0.00 0.00 19,800.00 89.50 151.97 7,596.46 -12,221.16 6,423.65 13,808.36 0.00 0.00 0.00 19,900.00 89.50 151.97 7,597.33 -12,309.42 6,470.64 13,906.36 0.00 0.00 0.00 20,000.00 89.50 151.97 7,598.19 -12,397.69 6,517.63 14,006.35 0.00 0.00 0.00 20,100.00 89.50 151.97 7,599.06 -12,485.96 6,564.62 14,106.35 0.00 0.00 0.00 20,200.00 89.50 151.97 7,599.92 -12,574.23 6,611.61 14,206.35 0.00 0.00 0.00 20,300.00 89.50 151.97 7,600.79 -12,662.50 6,658.60 14,306.34 0.00 0.00 0.00 20,400.00 89.50 151.97 7,601.65 -12,750.77 6,705.58 14,406.34 0.00 0.00 0.00 20,500.00 89.50 151.97 7,602.52 -12,839.03 6,752.57 14,506.33 0.00 0.00 0.00 20,600.00 89.50 151.97 7,603.38 -12,927.30 6,799.56 14,606.33 0.00 0.00 0.00 20,700.00 89.50 151.97 7,604.25 -13,015.57 6,846.55 14,706.33 0.00 0.00 0.00 20,800.00 89.50 151.97 7,605.11 -13,103.84 6,893.54 14,806.32 0.00 0.00 0.00 20,900.00 89.50 151.97 7,605.98 -13,192.11 6,940.53 14,906.32 0.00 0.00 0.00 21,000.00 89.50 151.97 7,606.84 -13,280.38 6,987.52 15,006.32 0.00 0.00 0.00 21,100.00 89.50 151.97 7,607.71 -13,368.64 7,034.51 15,106.31 0.00 0.00 0.00 21,200.00 89.50 151.97 7,608.57 -13,456.91 7,081.49 15,206.31 0.00 0.00 0.00 21,300.00 89.50 151.97 7,609.44 -13,545.18 7,128.48 15,306.30 0.00 0.00 0.00 21,400.00 89.50 151.97 7,610.30 -13,633.45 7,175.47 15,406.30 0.00 0.00 0.00 21,500.00 89.50 151.97 7,611.17 -13,721.72 7,222.46 15,506.30 0.00 0.00 0.00 21,600.00 89.50 151.97 7,612.03 -13,809.99 7,269.45 15,806.29 0.00 0.00 0.00 21,700.00 89.50 151.97 7,812.90 -13,898.25 7,316.44 15,706.29 0.00 0.00 0.00 21,800.00 89.50 151.97 7,613.76 -13,986.52 7,363.43 15,806.29 0.00 0.00 0.00 21,900.00 89.50 151.97 7,614.63 -14,074.79 7,410.42 15,906.28 0.00 0.00 0.00 22,000.00 89.50 151.97 7,815.49 -14,163.06 7,457.40 16,006.28 0.00 0.00 0.00 22,100.00 89.50 151.97 7,616.36 -14,251.33 7,504.39 16,106.27 0.00 0.00 0.00 22200.00 89.50 151.97 7617.22 -14,339.60 7551.36 16,206.27 0.00 0.00 0.00 1111412017 10..54:02AM Page 8 COMPASS 5000.14 Build 85 ConocoPhillips I ConocoPhillips Standard Proposal Report Database: Company: OAKEDMP2 ConomPhillips(Alaska) Inc -WNS Local Coordinate Reference: Well Plan: CD5-25 (10BC) - Slot 25 TVD Reference: Plan: 33.7+36.3m ( py) @ 70.00usft (Doyon Project: Western North Slope 19) MD Reference: Plan: 33.7+36.3 (copy) @ 70.00usft (Doyon Site19): CDS Alpine West Pad North Reference: Tnre Well: Plan: CDS-25 (I OBC) Survey Calculation Method: Minimum Curvature Wellbore: Plan: CDS-251-7 Design: CD5-25L1wp17 Fp-lannetl Survey-- Measured Depth Vertical Vertical Dogleg Build Tum (usft) Inclination Azimuth Depth +N/-S +E/-W Section Rate Rate Rate V) (•) (usft) (usft) (usft) (usft) (°1100usft (°AOOusft) (°1100usft) 22,300.00 22,400.00 89.50 151.97 7,618.09 -14,427.86 7,598.37 16,306.27 0.00 0.00 0.00 22,500.00 89.50 89.50 151.97 7,618.95 -14,516.13 7,645.36 16,406.26 0.00 0.00 0.00 151.97 7,619.82 -14,604.40 7,692.35 16,506.26 0.00 0.00 0.00 22,600.00 22,700.00 89.50 151.97 7,620.68 -14,692.67 7,739.34 16,606.26 0.00 0.00 0.00 22,800.00 89.50 89.50 151.97 7,621.55 -14,780.94 7,786.33 16,706.25 0.00 0.00 0.00 22,900.00 89.50 151.97 151.97 7,622.41 -14,869.21 7,833.31 16,806.25 0.00 0.00 0,00 23,000.00 89.50 151.97 7,623.28 7,624.14 -14,957.47 -15,045.74 7,880.30 7,927.29 16,906.24 0.00 0.00 0.00 17,006.24 0.00 0,00 0,00 23,100.00 23,200.00 89.50 151.97 7,625.01 -15,134.01 7,974.28 17,106.24 0.00 0.00 0.00 23,300.00 89.50 89.50 151.97 7,625.87 -15,222.28 8,021.27 17,206.23 0.00 0.00 0.00 23,400.00 89.50 151.97 7,626.74 -15,310.55 8,068.26 17,306.23 0.00 0.00 0.00 23,500.00 89.50 151.97 7,627.60 -15,398.82 8,115.25 17,406.23 0.00 0.00 0.00 151.97 7,628.47 -15,487.09 8,162.24 17,506.22 0.00 0.00 0.00 23,600.00 89.50 151.97 7,629.33 -15,575.35 8,209.22 17,606.22 0.00 0.00 0.00 23,700.00 23,800.00 89.50 151,97 7,630.20 -15,663.62 8,256.21 17,706.21 0.00 0.00 0.00 23,900.00 89.50 151.97 7,631.06 -15,751.89 8,303.20 17,806.21 0.00 0.00 0.00 24,000.00 89.50 151.97 7,631.93 -15,840.16 8,350.19 17,90621 0.00 0.00 0.00 89.50 151.97 7,632.79 -15,928.43 8,397.18 18,006.20 0.00 0.00 0.00 24,100.00 24,200.00 89.50 151.97 7,633.66 -16,016.70 8,444,17 18,106.20 0.00 0.00 0.00 24,300.00 89.50 89.50 151.97 7,634.52 -16,104.96 8,491.16 18,206.20 0.00 0.00 0.00 24,400.00 89.50 151.97 7,635.39 -16,193.23 8,538.15 18,306.19 0.00 0.00 0.00 24,500.00 89.50 151.97 151.97 7,636.25 -16,281.50 8,585.14 18,406.19 0.00 0.00 0.00 7,637.11 -16,369.77 8,632.12 18,506.18 0.00 0.00 0.00 24,600.00 89.50 151.97 7,637.98 -16,458.04 8,679.11 18,606.18 0.00 0.00 0.00 24,700.00 89.50 151.97 7.638.64 -16,546.31 8,726.10 18,706.18 0.00 0,00 0.00 24,800.00 89.50 151.97 7,639.71 -16,634.57 8,773.09 18,806.17 0.00 0.00 0.00 24,900.00 89.50 151.97 7,640.57 -16,722.84 8,820.08 18,906.17 0.00 0.00 0.00 25,000.00 89.50 151.97 7,641.44 -16,811.11 8,867.07 19,006.17 0.00 0.00 0.00 25,100.00 25,200.00 89.50 151.97 7,642.30 -16,899.38 8,914.06 19,106.16 0.00 0.00 0.00 25,300.00 89.50 89.50 151.97 7,643.17 -16,987.65 8,961.05 19,206.16 0.00 0.00 0.00 25,400.00 89.50 151.97 7,644.03 -17,075.92 9,008.03 19,306.15 0.00 0.00 0.00 25,500.00 89.50 151.97 7,644.90 -17,164.18 9,055.02 19,406.15 0.00 0.00 0.00 151.97 7,645.76 -17,252.45 9,102.01 19,506.15 0.00 0.00 0,00 25,600.00 89.50 151.97 7,646.63 -17,340.72 9,149.00 19,606.14 0.00 0.00 0.00 25,700.00 89.50 151.97 7,647.49 -17,428.99 9,195.99 19,706.14 0.00 0.00 0.00 25,800.00 89.50 151.97 7,648.36 -17,517.26 9,242.98 19,806.14 0.00 0.00 0.00 25,900.00 89.50 151.97 7,649.22 -17,605.53 9,289.97 19,906.13 0.00 0.00 0.00 26,000.00 89.50 151.97 7,650.09 -17,693.79 9,336.96 20,006.13 0.00 D.DO 0.00 26,100.00 89.50 151.97 7,650.95 -17,782.06 9,383.94 20,106.12 0.00 0.00 0.00 26,200.00 89.50 151.97 7,651.82 -17,670.33 9,430.93 20,206.12 0.00 0.00 0,00 26,300.00 89.50 151.97 7,652.68 -17,958.60 9,477.92 20,306.12 0.00 0.00 0.00 26,400.00 89.50 151.97 7,653.55 -16,046.87 9,524.91 20,406.11 0.00 0.00 0.00 26,500.00 89.50 151.97 7,654.41 -18,135.14 9,571.90 20,506.11 0.00 0.00 0.00 26,600.00 8950 151.97 7,655.28 -18,223.40 9,618.89 20,606.11 0.00 0.00 0.00 26,700.00 89.50 151.97 7,656.14 -18,311.67 9,665.88 20,706.10 0.00 0.00 0.00 28,800.00 89.50 151.97 7,657.01 -18,399.94 9,712.87 20,806.10 0.00 0.00 0.00 26,900.00 27,000.00 89.50 151.97 7,657.87 -18,488.21 9,759.85 20,906.09 0.00 0.00 0.00 89.50 151.97 7,658.74 -18,576.48 9,806.84 21,006,09 0.00 0.00 0.00 27,100.00 27,200.00 89.50 151.97 7,659.60 -18,664,75 9,853.83 21,106.09 0.00 0.00 0.00 27,300.00 89.50 151.97 7,660.47 -18,753.02 9,900.82 21,206.08 0.00 0.00 0.00 27.400M 89.50 A9 An 151.97 .0 e1 7,661.33 -.�� -- -18,841.28 -_--- _- 9,947.81 ___. _. 21,306.08 0.00 0.00 0.00 11/74l201710:54:02AM Page 7 COMPASS 5000.14 Build 85 ConocoPhillips Vertical Local Coordinates Depth I Cono R +FJ -W (nsl) (usR) (usit) (MR) comment Standard Proposal Proposal Report port Database: OAKEDMP2 KOP: 15.9°/100' DLS, -22' TF, for 12.8' 8,335.80 7,495.68 -2,104.00 1,033.37 Hold for 20- 8,355.80 Company: ConocoPhillips(Alaska) Inc.-WNS Local Co-ordinate Reference: Web Plan: CD5-25 (1013C) -Slot 25 8,500.51 7,504.66 -2,248.34 TVD Reference: Hold for 2108.27' Plan: 33.7+38.3 (copy) (8j 70.00us6 (Doyon Project Western North Slope 2,103.87 Start 1.5°/100' DLS, 154.5° TF, for 4.82- 10,611.61 7,517.00 19) 2,106.14 Adjust TF to 161.57*, for 6.71' 10,618.32 7,517.05 -4,116.64 MD Reference: Hold for 19186.98' Plan: 33.7+36.3 (copy) @ 70.00us0 (Doyon Site: CD5 Alpine West Pad 11,125.02 TD: 29805.3' MD, 7663' TVD 19) Well: Plan: CDS-25 (1OBC) North Reference: True Wellbore: Plan: CD5-251-7 Survey Calculation Method: Minimum Curvature Design: CD5-25L1wp17 d Sumay Measured Depth Vertical Vertical Dogleg Build Tum (WR) F Inclination Azimuth Depth +Kv-S + FJ-0N Section Rate Rale Rate O C) (usR) (-it) (call" (usft) ('M00usR) ('1100usR) (°/100usR) 27,500,00 89.50 151.97 7,663.06 -19,017.82 10,041.79 21,506,07 0.00 0.00 27,600,00 27,700.00 89.50 151.97 89.50 7,663.93 -19,106.09 10,088.78 21,606.07 0.00 0.00 0.00 0.00 27,800.00 151.97 89.50 7,664,79 -19,194.36 10,135,76 21,706.06 0.00 0.00 0.00 27,900.00 151.97 89.50 7,665.66 -19,282.63 10,182.75 21,806.06 0.00 0.00 0.00 28,000.00 151.97 89.50 7,666.52 -19,370.89 10,229.74 21,908.06 0.00 0.00 0.00 151.97 7,667.39 -19,459,16 10,276.73 22,006.05 0.00 0.00 0.00 28,100.00 28,200.00 89.50 151.97 7,668.25 -19,547.43 10,323.72 22,106.05 0.00 0.00 28,300.00 89.50 151.97 7,669.12 -19,635.70 10,370.71 22,206.05 0.00 0.00 0.00 0.00 28,400.00 89.50 151.97 69.50 7,669.98 -19,723.97 10,417.70 22,306.04 0.00 0.00 0.00 28,500.00 151.97 89.50 151.97 7,670.85 -19,812.24 10,464.69 22,406.04 0.00 0.00 0.00 7,671.71 -79,900.50 10,511.67 22,506.03 0.00 0.00 0.00 28,600.00 28,700.00 89.50 151.97 7,672.58 -19,988.77 10,558.66 22,606.03 0.00 0.00 0.00 28,800.00 89.50 151.97 89.50 7,673.44 -20,077.04 10,805.85 22,708.03 0.00 0.00 0.00 28,900.00 151.97 89.50 7,674.31 -20,165.31 %652.64 22,806.02 0.00 0.00 0.00 29,000.00 151.97 89.50 151.97 7,675.17 -20,253.58 10,699.63 22,906.02 0.00 0.00 0.00 7,676.04 -20,341.85 10,746.62 23,006.02 0.00 0.00 0.00 29,100.00 29,200.00 89.50 151.97 89.50 7,676,90 -20,430.11 10,793.61 23,108,01 0.00 0.00 0.00 29,300.00 151.97 89.50 151.97 7,677,76 -20,518.38 10,840.60 23,206.01 0,00 0.00 0.00 29,400.00 89.50 151.97 7,678.63 7,679.49 -20,606.65 10,887.59 23,308.00 0.00 0.00 0.00 29,500.00 89.50 151.97 7,680.36 -20,894.92 -20,783.19 10,934.57 23,406.00 0.00 0.00 0.00 10,981.56 23,506.00 0.00 0.00 0.00 29,600.00 29,700.00 89.50 151.97 89.50 7,681.22 -20,871.48 11,028.55 23,605.99 0.00 0.00 0,00 29,800.00 151.97 89.50 7,682.09 -20,959.72 11,075.54 23,705.99 0.00 0.00 0.00 29,805.30 151.97 89.50 151.97 7,682.95 -21,047,99 11,122.53 23,805.99 0.00 0.00 0.00 TD: 29805.3' MD, 7683' TVD 7,683.00 -21,052.67 11,125.02 23,811.29 0.00 0.00 0.00 Casing Points Measured Vertical Depth Depth Casing Hole (uslp (usR) Diameter Diameter Name nCI 115.30 115.30 20" z 42" 2,193.56 2,185.00 10-3/4"x 13-1/7' 20 42 8,324.00 7,494.36 7-5/8'x9.7/8' 10-3/4 131/2 29,805.30 7,683.00 4-1/2" x 8-3/4" 7-5/8 9-7/8 41/2 6-3/4 Plan Annotations Messured Vertical Local Coordinates Depth Depth +N/ S +FJ -W (nsl) (usR) (usit) (MR) comment 8,323.00 7,494.28 -2,092.83 1,027.28 KOP: 15.9°/100' DLS, -22' TF, for 12.8' 8,335.80 7,495.68 -2,104.00 1,033.37 Hold for 20- 8,355.80 7,497.53 -2,121.42 1,043.03 Start 3.5'/100' DLS, 10.51° TF, for 144.71' 8,500.51 7,504.66 -2,248.34 1,112.09 Hold for 2108.27' 10,606.79 7,516.97 -4,106.46 2,103.87 Start 1.5°/100' DLS, 154.5° TF, for 4.82- 10,611.61 7,517.00 -4,110.71 2,106.14 Adjust TF to 161.57*, for 6.71' 10,618.32 7,517.05 -4,116.64 2,109.29 Hold for 19186.98' 29,805.30 7,683.00 -21,052.67 11,125.02 TD: 29805.3' MD, 7663' TVD 111141201710,S4:02AM Page 8 COMPASS 5000 14 Build 85 ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD5 Alpine West Pad Plan: CD5-25 (I 013C) Plan: C135-251-1 50103xxxxx00 CD5-25L1 wp17 ConocoPhillips Clearance Summary Anticollision Report 14 November, 2017 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CDS Alpine West Pad - Plan: CDS-25 (1013C) - Plan: CD6-261-1 - CDS-26Lf Wp17 Well Coordinates: Datum Height: Plan: 33.7.36.3 (copy) @ 70.00usft (Doyon 19) Scan Range: 8,323.00 to 29,806.30 usft. Measured Depth. Scan Radius Is 3,176.90 usft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation Is Unlimited Geodetic Scale Factor Applied Version: 5000.14 Build: 86 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 ConocoPhillips ConocoPhillips Anticollision Report for Plan: CD5-26 (1013C) - CD6-25L1wp17 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CDs Alpine West Pad -Plan: CD6-26 0013C) -Plan; CD6-26L7 -CDS-26L1wp17 Scan Range: 8,323.00 to 28,806.30 usft. Measured Depth. Scan Radius Is 3,176.90 usft. Clearance Factor cutoff Is Unlimited. Max Ellipse Separation Is Unlimited Site New Measured Minimum @Measuretl Ellipse @Measured Comparison Well Name - Wellbore Name - Design Depth (usft) Distance Depth Separation Depth 12.225 Clearance Factor (usft) (usft) (usft) usft CD6 Alpine West Pad 4.302 Centre Distance 29,790.50 1,548.67 29,790.50 CDS-20-CD5-20-CD5-20 27,318,84 2.301 Clearance Factor 15,001.43 1,313.40 CDS-20-CD5-20-CD5-20 12,502.90 1,433.41 12,502.90 1,169.28 22,875.00 CD5.20-CDS-201_1-C05.201_1 12,702.68 1,435.02 12,702.88 1,166.55 23,075.00 CDS-313-CD5313-CD5-313 12,143.98 1,398.46 12,143.98 1,144.47 22,523.00 CD&313 - CDS-313 - CD5-313 21,177.45 300.47 21,177.45 13.44 18,700.00 2.281 21,698.16 243.29 21,698.16 90.39 19,250.00 CDS-313-CDS-313P81-CD5-313PB1 12.632 Centre Distance 11,830.99 2,534.97 11,830.99 CDS-313 - CD5.313PB7 - CD5.313PB1 18,488.07 1,312.31 18,489.07 933.05 15,425.00 CDS315-CD5.315-C05.315 18,621.11 1,313.63 18,621.11 930.83 15,575.00 CD5-315-CDS-315-CDS-315 12,558.37 3,072,29 12,558.37 2,891.09 9,825.00 CDS-315-CDS-315PB1-CD5-315PB1 12,680.15 3,074.65 12,680.15 2,868.44 10,000.00 CD5315 - CD5-315P81 - CD5.315PB7 12,603.07 3,085.87 12,603.07 2,903.34 9,825.00 12,953.51 3,091.10 12,953.51 2,895.85 10,250.00 Plan: CD5-19 - Plan: CD5-19 - CDS-19Wp10.1 Plan: CDS-19 - Plan: CD5-19 - CD5.19wp10.1 Plan: CDS-24 (9C) - Plan: CDS24 (9C) - CDS-24wp16 Plan: CD5.24 (GC) - Plan: CD5-24 (9C) - CDS-24wp16 Plan: CDS-24 (9C) - Plan: CD8.241_1 - CDS-24Ltwpl6 Plan: CDS-24 (9C) - Plan: CD5-241_1 - CD5-24L1wp16 Plan: CD5.25 (108C) - Plan: CD5.25 - CD5.25Wp16.2 Plan: CD5.25 (108C) - Plan: CD5-25 - CD5-25wp16.2 Prelim: CD5-26 (11 C) - Prelim: CD5-26 - CDS-28Wpo1 Prelim: CD5-26 (11 C) - Prelim: CD5-26 - CD5-26wp01 Prelim: C135-27 (12C) -Prelim: CD5.27-CD5-27wp01 Prelim: CD5.27 (12C) - Prelim: CDS27 - CD5-27Wp01 Prelim: CD530 (12B) - Prelim: CD5-30 - CD5-3owp 11 14 November, 2017 - 9:59 ConocoPhillips(Alaska) Inc. -WNS Clearance Summary Based on Factor Minimum 5.427 Centre Distance 5.345 Clearance Factor 5.506 Clearance Factor 1.047 Clearance Factor 1.591 Centre Distance 3.460 Centre Distance 3.432 Clearance Factor 16.955 Centre Distance 16.512 Clearance Factor 16.906 Centre Distance 15.831 Clearance Factor 11,510.70 2,475.85 11,510.70 2,284.79 9,300.00 12.958 Centre Distance 11,789.14 2,481.95 11,769.14 2,278.94 9,625.00 12.225 Clearance Factor 15,001.43 1,313.40 15,001.43 1,008.10 12,425.00 4.302 Centre Distance 29,790.50 1,548.67 29,790.50 875.70 27,318,84 2.301 Clearance Factor 15,001.43 1,313.40 15,001.43 1,008.02 12,425.00 4.301 Centre Distance 29,769.17 1,544.35 29,789.17 868.28 27,318.83 2.284 Clearance Factor 11,131.91 1,389.71 11,131.81 - 1,167.11 8,300.00 6.761 - Centre Distance 27,940.47 1,540.33 27,940.47 865.19 26,260.91 2.281 Clearance Factor 11,681.54 2,531.13 11,681.54 2,330.75 9,250.00 12.632 Centre Distance 11,830.99 2,534.97 11,830.99 2,327.40 9,450.00 12.213 Clearance Factor 11,915.57 3,034.99 11,915.57 2,700.90 22,424.41 9.084 Clearance Factor Page 2 of 5 Western North Slope Separation blaming Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass- Major Risk Pass- Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk TCR required Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk COMPASS ConocoPhillips Anticollision Report for Plan: CD5-25 (1013C) - CD5-25L1wp17 Survey tool Program From To Survay/Plan (usft) (usft) 36.30 1,600.00 1,600.00 2,193.56 2,193.56 8,323.00 6,323.00 8,700.00 CD5.25L1wp17 8,700.00 10,200.00 CD5.25Liwpl7 8,700.00 29,805.16 CD5-25L1wp17 Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles- Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 14 November, 2017 - 9:59 Page 3 0! 5 ConocoPhillips(Alaska) Inc. -WNS Survey Tool GVD-GCSS MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZSC MWD-INC_ONLV (INC>10-) MWD MWD+IFR-AK-CAZ-SC Western North Slope COMPASS 0 CD5-25L1wp17 he efe �etnaoc dder Vloieggw rror EllipsesTareRtheSumeo fethe1R.rerence handXOffset Well Errors 0 u Displayed interval could be less than entire well.Measured Dept'8323.00 To 29805.30 LOVVV Depth From Depth To Survey/Plan Tool 36.30 1600.00 CD5-25wp16.1 006C) (Plan: CD5(RYD-GC-SS 7494.3E324 -TVD MD Name 1600.00 2193.56 CD5-25wp16.1 (10BC) (Plan: CD5M YD+IFR-AK-CAZ-SC 74 9 7683IM05.030 4-1/2" x 6-3/4" 2193.56 8323.00 CD5-25wpl6.1 (10BC) (Plan: CD5MWD+IFR-AK-CAZ-SC 8323.00 8700.00 CD5-25L1wp17 (Plan: CD5-251-1) MWD-INC_ONLY (INC>10°) 8700.0010200.00 CD5-25L1wpl7 (Plan: CD5-251-1) MWD 8700.00 29805.16 CD5-25L1wpl7 (Plan: CD5-251-1) MWD+IFR-AK-CAZ-SC rdi udi measurea ueptn 19 M Easting (3000 usR/in) Easting (3000 usfrin) CD5-24L1wp16 (9C) A \v --- CD5-24wp16 (9C) wp .2 CD5-24L1wp17 11.33, November 14 201] CD5-25L1wp17 TC View SURVEY RAM Tool MD Inc Azi TVD Dleg TFace Target Annotation 36.30r1600.0To 0 GYD GC -SS 8323.00 82.80 151.75 7494.28 0.00 0.00 KOP: 15.9°/100' DLS, -22° TF, for 12.8' 1600.00 2193.56 MWD+IFR-AK,CAZ-SC 8335.80 84.68 150.99 7495.68 15.90 -22.00 Hold for 20' 2193.56 8323.00 MWD+IFR-AK-CAZ-SC 8355.80 84.68 150.99 7497.53 0.00 0.00 Start 3.5°/100' DLS, 10.51° TF, for 144.71' 323.00 8700.00 MWD-INC_ONLY (INC>10°) 8500.51 89.67 151.91 7504.66 3.50 10.51 Hold for 2106.27' 8700.00 10200.00 MWD 10606.79 89.67 151.91 7516.97 0.00 0.00 Start 1.5°/100' DLS, 154.5° TF, for 4.82' 8700.00 29805.16 MWD+IFR-AK-CAZ-SC 10611.61 89.60 151.94 7517.00 1.50 154.50 Adjust TF to 161.57°, for 6.71' 10618.32 89.50 151.97 7517.05 1.50 161.57 Hold for 19186.98' 29805.30 89.50 151.97 7683.00 0.00 0.00 CD5-23PB1wpl3 2. Toe 0725TUM119805.3' MD, 7683' TVD CASING DETAILS TVD MD Name 7494.36 8324.00 7.5/8' x 9-7/8" 7683.00 29805.30 4-1/2"x 6-3/4" 0 330 30 250 0 8323 200 8323 8510 8510-8690 300 15 60 8690-8870 29394 8870 - 9050 D5-25wp16. - 9050 - 9230 --- •110 9230 - 9420 9420 - 9600 8896 9600 - 10440 10440 11280 270 4 90 11280 - 12110 12110 - 12950 12950 - 13790 13790 - 14620 14620 - 15460 15460 - 16300 16300 - 17990 17990 - 19680 240 120 19680 - 21360 1367 21360 - 23050 20 23050 - 24740 24740 26430 26430 28120 210 2 0 8 1 150 28120 - 29805 CD -313 ----- 180 ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD5 Alpine West Pad Plan: CDS-25 (1013C) 50103xxxxx00 Plan: CD5-251-1 Plan: CD5-25L1wp17 Error Ellipse Survey Report 14 November, 2017 ConocoPhillips Error Ellipse Report Company: ConocoPhillips(Alaska) Inc.-WNS Local Co-ordinate Reference: Well Plan: CDS-25(1OBC) -Slot 25 Project: Western North Slope TVD Reference: Plan: 33.7+36.3 (copy) @ 70.00usft (Doyon Site: CD5 Alpine West Pad MD Reference: 19) Plan: 33.7+36.3 (copy) @ 70.00usft (Doyon Position Uncertainty Wellhead Elevation: 19) Wag: Plan: CDS-25 (106C) North Reference: True Wellbore: Plan: CD5-251_1 Survey Calculation Method: Minimum Curvature Design: CD5-25L1wp17 Output errors are at 1.00 sigma Database: OAKEDMP2 Project Western North Slope, North Slope Alaska, United States 16.73 Map System: System Datum: Mean Sea Level Gan Datum: Design CD5-25Ltwpl7 Using Well Reference Point Map Zone: Audit Notes: Using geodetic scale factor We CD5 Alpine West Pad ;Its Position: Northing: Latitude: `rem: Map Easting: Longitude: 'oalUon Uncertainty: Slot Radius: Grid Convergence: Well Plan: CD5-25 (1 OBC) -Slot 25 Well Position +N/ -S Northing: Latitude: +E1 -W Easting: Longitude: Position Uncertainty Wellhead Elevation: Ground Level: Wellbore Plan: C135-251-1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1 r) (nn BGGM2017 3/1/2018 16.73 80.78 57,436 Design CD5-25Ltwpl7 Audit Notes: Nkrelon: Phase: PLAN Tie On Depth: 8,323.00 Vertical Section: Depth From (TVD) +NIS +EI -W Direction (usft) (waft) (usft) (1) 36.30 0.00 0.00 152.00 Survey Tool Program Date 1111412017 From To (usft) (usft) Survey (Wellbore) Tool Name Description 36.30 1,600.00 CD5-25wpl6.1 (10BC) (Plan: CD5-25) GYD-GC-SS Gyrodata gym single shots 1,600.00 2,193.56 CDS-25wp16.l(10BC)(Plan: CD5.25) MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC 2,193.56 8,323.00 CD5-25wp16.l(108C)(Plan: CD5-25) MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC 8,323.00 8,700.00 CD5-25L1wp/7(Plan: CDS-25Ll) MWD -INC _ ONLY (INC>10-) MWD-INC_ONLY FILLER(INC>10°) 8,700.00 10,200.00 CD5-25L1wp17(Plan: CD5-25Li) MWD MWD -Standard 8,700.00 29,805.16 CD5-25L1wp17(Plan: CD5.251-7) MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC 11/14/2017 11.'45:54AM Page 2 COMPASS 5000.14 Build 85 Company: Con=Phillips(Alaska) Inc.-WNS Project: Western North Slope She: CDs Alpine West Pad Well: Plan: CDS-25 (tOBC) Wellbore: Plan: CDS-251-7 Design: CD5-25L1wp17 ConocoPhillips Error Ellipse Report Local Coordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Plan Survey Tool Program Daft 11/14/2017 Depth From Depth To (usft) (usft) Survey (wellbore( Tool Name Remarks 1 36.30 1,600.00 CD5-25wpl6.1 (108C) (Plan: CD GYD-GC-SS Gyrodata gyro single shots 2 1,600.00 2,193.56 CD5-25Wp16.1 (108C) (Plan: CD MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3 2,193.56 8,323.00 CDS25wp16.1 0013C) (Plan: CD MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4 8,323.00 8,700.00 CD5-25L1wpl7 (Plan: CDS-251-1 MWD-INC.ONLY (INC>10°) MWD -INC ONLY_FILLER(it 5 8,700.00 10,200.00 CD5-251-1wp17 (Plan: CD5-251-7 MVJD MWD - Standard 6 8,700.00 29,805.16 CDS-25L1Wp17(Plan: CD5-251.7 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Well Plan: CD5-25 (1 OBC) - Slot 25 Plan: 33.7+36.3 (copy) @ 70.00usft (Doyon 19) Plan: 33.7+36.3 (copy) @ 70.00usft (Doyon 19) True Minimum Curvature 1.00 sigma OAKEDMP2 Position uncertainty and blas at survey station Muau26 Oep6, fust" Ncautlon Y) lames, M wraael 1Mpth tura) NI9Baid. Error Bias (use) (--ft) uw.l Ener NMI Bia. (..R) wrOral Error Blas lu.") (..ft) aagfl u of Bias (elm s.Jor Ener (-M 8.mlml Error lush) . Arinulh Toal fl 8,323.00 8,921.00 8,335.80 8,355.80 8,400.00 82.80 82.91 84.80 Sam 8831 151.75 151.69 laces 150.99 151.2]7,501.0 7,19430 ],494.1 7,495.68 7,10.53 3.94 3.90 3.78 3,79 3.65 -686 AM15.08 S.r -6.77 -6.66 15.0 15.07 15.07 15.14 0.07 0.0] 0.11 0.11 0.09 326 3.26 326 3.28 3.28 7,68 7.08 7.08 7,08 7.08 7.69 7.89 7.70 7,71 7]3 15.11 15.11 15.11 15.12 15.18 7,00 7.00 7.00 7.00 7.00 165.65 SINCONLY QW.10)(1, 4) 155.65 PIN0_0NLY QNC>101(1. 4) i55.86 NNC ONLY QNC>101(1, 4) 155.85 0.INC ONLY QNC>101(1, 4) 155.8004t4C_ONLY QNC>W)(1,4) 8,500.00 6500.51 8,600.00 8,700.0 8,800.00 89.65 89.87 88.87 89.67 89.67 151.91 151.91 151.91 151.91 151.91 7,514,89 7,504.66 7,505.2/ 7,50.5.83 7,506,41 3.36 3.36 3.46 3.52 3.56 .7.07 4.07 4.07 -7.07 4.07 16.00 16.00 19.09 21.85 22.35 0.08 0.06 0.05 026 0.66 3.33 3.33 3.42 3.49 3.53 7.09 7.09 7.09 7.09 7.09 7.78 7.78 7.82 ).87 7.94 16.02 16102 19.10 21.88 22.36 7.02 7.02 7.05 7.07 7,07 IM27 SING ONLYQN6101(1,Q 155.27 NNC _ONLY QNC]101 (1, 1) 154.8 ?INC ONLY QN6101(1. 4) 153.50 MWD (1, 5) 153.45 MVA (1, 6) 6900.00 9,000.00 9,100.00 9,200.00 9.300.00 89.67 89.87 a9.67 89.67 119.67 151.91 151.91 151.1 151.91 151.91 7,507.0 7,50250 7,506.17 7,508.75 7,509.33 3,63 3.74 3.88 4.0 425 -7,07 -7.07 4.07 -7.07 -7.07 2296 23.65 24.43 252a 26.21 1.07 1.48 1.88 219 2.69 3.07 3.71 3.86 4,03 422 7.09 7.9 7.09 7.09 7.9 602 8.13 Bea 641 8.58 22.96 23.66 24.44 25.29 26.21 7.08 7.9 7.10 7.11 7.11 153.39 MNA(1. 5) 15333 am n. 5) 15315 MWD(1, 5) 18.10 am (1, 5) 153.10 MM (1, 5) 9,400.00 91500.00 9,600.00 9,700.00 91800.00 Seen 89.67 89.87 SSW 89.67 151,91 151.91 151.91 151.91 151.91 7,509.92 71510.50 7,511.8 7,511.67 7,61228 4.46 4.70 4.95 5.21 5.49 -0.07 -7.07 -7.07 -7.07 -7.07 27,19 28.23 29.32 90.45 31.83 3.10 3.51 3.91 4.32 4.]2 4.44 4.68 4.93 5.19 5,0 7,09 7.09 7.09 7.09 7.09 an 8.96 9.17 9.40 9.64 2720 28,24 29.32 30.48 31.63 7.12 7,13 7,14 7.15 7,16 153.03 am (1. 6) 152,96 am (1, 5) 152.90 MM (1, 5) 152.84 am (1. 5) 152.78 ~(1, 5) 9,900.00 10,000.00 101100.00 10,200.0 101300.00 89.87 8997 89.87 89.87 Stan 151.91 151.91 151.91 151.91 151.91 7,512.84 7,513.42 7,514.01 7,514.59 7,515.18 5]8 6.07 6.37 4,48 4.59 4.07 .7.07 4.07 -7.07 4.07 3283 34.07 35.34 25.04 25.15 513 5.54 5.94 0,05 0.5 5.76 am 6.36 4.46 4.57 7.0 7,09 7.10 7.10 7.10 999 10.16 10.43 am 8.69 32.64 34,07 35.34 25.04 25.36 7.17 7,17 7.18 7.18 7.19 152.73 am n. 5) 152.68 MM (1. 5) 152.63 am (1. 5) 153.19 M JFR-AK-OI p.6) 153.16 MW IFR -BK -C .W (2. 5) 10,400.00 119.67 151.91 7,515.76 4.71 -7.07 25.67 Bos 499 7.10 8.75 2598 7.20 153.13 MWO>1FR-AE-C c(2, 5) 111141201711:45.'54AM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips Error Ellipse Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well Plan: CD5-25 (1OBC) -Slot 25 Project: Western North Slope TVD Reference: Plan: 33.7+36.3 (copy) Q 70.00usft (Doyon Wanted 914alalbn 19) Site: CDS Alpine West Pad MD Reference: Plan: 33.7+36.3 (copy) Q 70+00usft (Doyon wrlMal Magnitude 19) Well: Plan: CD5-25 (1 OBC) North Reference: hue Wellbore: Plan: CO5-251-1 Survey Calculation Method: Minimum Curvature Design: CD5-25L1wp17 Output errors are at 1.00 sigma Error Error Database: OAKEDMP2 Position uncertainty and bias at survey station Wanted 914alalbn rimae) walla) Ri9nsiae labral wrlMal Magnitude semlmajor semiminor nation nepM Error Bias Ener Bias E. Biu or Bias Error Error Aeid Wh T0.1 (a.N 41 (1 (a.n) (usi) (aril (an) (nss) (u•14 (USM (um) lean) hail 1'1 10,500.00 8947 151.91 7,516.35 4.83 9.07 25.00 0.05 4.01 7.10 8.81 26.01 721 15111 MMMIFR-AK-0AZ-M(2, 5) 1.600.00 8967 151.91 7,516.93 4.96 -7.07 28134 0.05 4.94 7.10 8.87 26.35 752 153.08 MR IFR -AK- -SG(2,5) 10,606.79 seen 151.91 7,516.97 4.97 4.07 26.36 0.05 4.84 7.10 8.87 28.37 7.22 Issas MVA.IFR-MC C(2,5) 10,811.61 No 151.94 7,517.00 4.98 9.00 26.38 0.05 4.95 7.10 8.88 26.38 7.22 153.8 M%Y>OFR-AK-CA2.50(2,5) 10,618.32 89.50 151.97 7,517.05 4.99 4.05 2659 0.05 4.98 7.10 8.88 26.40 7.22 153.08 6M7.lFR-AK-C-SCp,5) 10700.0 89.50 151.97 7,517.76 510 -7.05 28.61 0.05 5.08 7.10 8.93 26.62 7.23 153.06 MV IFR -AK -LA ". 5) 1.800.00 saw 151.97 7,518,62 5.23 -7.05 26.97 0.05 5.20 7.10 8.98 28.97 7.24 153.04 MRD+1FR MA AZ -SC (2, 5) 10,900.0 89.00 151.97 7,519.49 5.36 -7.05 27.33 0.05 5.33 7.10 Bw 27.33 7.24 15101 MWD.IFR-MW-W(2,5) 11,000.0 89.50 151.97 7,520.35 5.50 -7.05 27.89 0.05 5.47 7.10 9.12 27.70 7.25 152.99 MM -IFR -AK -0A -SC (2, 5) 11,100.00 saw 151.97 7,521.22 5.63 4.5 28.07 0.05 5.61 7.10 9.18 28.07 718 152.96 M'MAIFR-N(-CALSC p, 6) 11,200,00 89.50 151.87 7,522.08 5.78 -7.05 28.45 0.05 5.75 7.10 9.25 28.45 7.27 15284 MV IFR -MK -SC (2.5) 11,300.00 89.50 151.97 7,522.95 5.82 -7.05 28.84 0.05 5.89 7.10 9.32 29.84 7.28 152.92 MM.IFR-AK- SC (Z 5) 11,400.00 09.50 151.97 7,523.81 6.08 4,05 29.23 0.05 8.04 7.11 9,38 29.23 719 152.09 MV,D+IFR-AK-CAZ-SC (2, 5) 11,600.00 saw 151.97 7,524.89 6.21 4.05 29.83 0.05 6.18 7.11 9.45 29.63 7,30 152.87 MVID+IFR-AK-OAZSC (2, S) 11,600.00 89.50 151.97 7,525.51 8.36 4.05 30.03 0.05 6.33 7.11 8.52 30.04 7,31 152.85 Mi MIFR-AK- ,Ut-W (2, 5) 11,700.00 89.50 151.97 7,528,41 6.51 4.05 30.45 0.05 848 7.11 9.58 30.45 7.32 152.83 MND.IFR-AK-CAZSC(2,5) 11,aoi 89.50 151.97 7,52717 6.66 4.05 30.86 0.05 6,63 7.11 9.65 30.67 7.33 152,81 MVID.IFR-AK-O C(2,S) 111900.00 89,60 151.97 7,526.14 6.61 9.05 31.28 0.05 639 7.11 9.72 3119 7.34 162.79 MIVDAFR-A1(- -$C p, 6) 12,000.00 89.60 151.97 7,529.00 6.97 -745 31.71 0.05 6.94 7.11 9.79 31.71 7.35 152.7] MV IFR -M CAZ-SC (2, 5) 12,100.0 88.50 151.97 7,52947 7.12 -7.05 32.14 0.05 7.10 7.11 9.85 32.14 7.36 152.75 MND+IFR-AK-(W-B0(2. 5) 12,200.00 89.50 151.97 7,530.73 7.26 9.05 32.58 0.05 7.25 7.11 9.94 32.58 7.37 152.73 MIADNFR-Ali CA G 5) 12,300.00 89.50 151.97 7,531.60 7.43 4.05 33.02 0.05 7.41 7.11 10.01 33.02 7.38 152.72 MR IFR -MK AZ -$C (2.5) 12,400.00 89.50 151.97 7,532.46 7.59 -7.05 33.46 0.05 757 7.11 10.08 33.46 7.38 15270 MND.IFR-ML .BC (2.5) 12,500.00 89.50 151.97 7,533.33 7.75 -0.05 33.81 0.05 7.73 7.11 10.15 33.91 7.40 152.68 MN0+1FR-AK- 4i(c (2, 8) 12,800.0 89.50 151.97 7,534,19 7.91 -7.00 34.36 045 749 7.12 10.23 34.36 7.41 152.87 MMAFR-N4-CASSC p, 6) 12,700.00 89.50 151.97 7,635.08 8.07 -7.05 34.82 0.05 8.05 7.12 10.30 34.82 7.42 15265 MS IFR -MR -0 .SC (2, S) 12,800.00 89.50 151.97 7,535.92 6.23 4.05 35.26 0.05 8.21 7.12 10.37 35,28 7.43 152.63 MND.IFR-AK-CAZ-BC (2,5) 12,900.00 88.50 151.97 7,536.79 8.40 4.05 35.74 0.06 8.38 7.12 10." 35.74 7,44 152.62 MND+IFR-AK-0AZ-SC (2,5) 13,000.00 89.50 151.97 7,537.85 8.66 4.05 38.20 0.05 8.54 7.12 10.52 38.21 7.45 152.81 MRD+IFR-AK-CAZSC p, 5) 13,100.00 assn 151.97 7,538.52 832 -7.05 36.67 0.05 8.70 7.12 10.60 36.60 7.46 152.59 MRD.IFR-MK- -SC (2, 5) 13,200.00 sew 151.97 71539.38 8,89 4.05 WAS 0.05 8.87 7.12 10.60 37.15 7.47 152.58 MND+IFR-M-CA W (2,5) 13,300.00 69.50 151,87 7,540.25 9.05 -7.05 37.62 0.05 9.03 7.12 10.75 37.62 7,48 152.56 MV IFR -AK -L (2,5) 13,400.00 69.50 151.97 7,541.11 8.22 -7.5 30.10 0.05 9.20 7.12 10.83 30.10 7.49 152.65 MNM1FR-AK-0.1-57 (2. 6) 13,500.00 89.50 151.97 7,541.98 938 -7.05 38.58 0.05 9.37 7.12 10.91 38.50 7,50 152.54 Mw0d1iR-AK-CAZ-SC (2, 5) 13.600.00 saw 151.07 7,642.84 9.55 -7.05 39.08 0.05 sw 7.12 10.98 39.06 7.51 152.53 MND.IFR-MK -BC (2. 5) 13700.00 89.60 151.97 7,54171 9.72 -7.05 39.55 0.05 930 7.13 11.06 39.55 7.52 152.52 MVVD.IFR-AK-CAZSL (2,5) 13,800.00 89.50 151.97 7,644.57 9.88 -7.05 40.04 0.05 9.87 7.13 11.14 40.04 7.53 152.50 MR IFR-N(-OAZSC (2, 5) 13,900.0 89.50 151.97 7,545.44 10.05 -7.05 40.53 am 10.0 7.13 1112 40.53 7.54 152.49 MR9.IFR-MK -SC (2. 5) 14,000,00 89,50 151.87 7,546.30 10.= -7.05 41.02 0.05 10." 7.13 1150 41.02 7.65 152.48 MND+IFR-AK-CAi-SL (2, 5) 14,100.00 89.50 151.97 7,57.17 1059 4.05 41.51 0.05 10.37 7.13 11.38 41.52 7.60 152.47 MND.IFR-AK-1-.250 p, 51 14,200.00 89.50 151.97 7,540.3 10.56 4.06 42.01 0.05 10.54 7.13 11.46 4201 7.57 15246 MMAM-AK-CAZSC (2,6) 14,300.00 89.50 151.97 7,548.90 10.72 -7.05 42.51 005 10.71 7.13 11.54 42.51 7.58 15245 MODNFR-AS-0 C (2, 5) 14.400.00 Sew 151.97 7,549.76 10.89 4.05 43.01 0.5 10.88 7.13 11.62 43.01 7.59 152." MN IFR -ML -SC (2, 5) 14,500.00 69.50 151.97 7,550.83 11.08 -7.05 43.51 0.05 11.5 7.13 11.70 43.52 740 152.43 MM.IFR-AK-CAZSC (2, 5) 14,800.00 89.50 151.97 7,551.49 1113 -7.05 44.02 0.05 11.2 7.13 11.70 44.02 7.62 152.43 MNDNFR-AK-CAZSC (2, 5) 14)00.00 89.50 151.97 7,552.35 11.40 -7.05 ".53 0.05 11.9 7.13 11.87 44.53 7.63 15242 MVrt3+IFnA AZ -SC (2, 5) 14.600,00 8850 151.07 7,55312 11.57 -7.65 45.03 0.05 11.56 7,14 11.95 45.03 7.64 15241 MN IFR-AK-Cg2-SC (2, 5) 14,900.00 69,50 151.97 7.554.08 11.75 -7.05 45.54 0.05 11.73 7.14 1203 45.54 7.65 152.40 MNO+IFR-AK-CAZ-SL(2, 5) 15,000.00 89.50 151.97 7,554.95 11.92 4.05 46.00 0.05 11.90 7.14 1211 18.06 7.96 152.39 MW WR -M -C C(2,5) 15.100,00 Saw 151.97 7,55541 1209 -7.05 16.57 0.05 1207 7.14 1210 46.57 7.00 152.39 MND.IFR-A1(-CAZ-SC (2.5) 1120000 89.50 151.97 7,556.88 1218 -7.05 47.8 0.05 1215 7.14 12.29 47.00 748 152.38 MVV0+IFR-AK- -SC (2, 6) 15.600.00 89.50 151.97 7,557.64 12.43 -7.05 7.60 0.05 12.42 7.14 12.38 7.60 7.70 152.37 MND.IFR-MK SC (2, 5) 1.400.00 88.60 151.87 7,558.11 12.80 -7.05 48.11 0.05 12.59 7.14 12,45 48.12 7.71 152.36 MVgNFR-4840.251- p, S) 1111412017 11:45:54AM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Error Ellipse Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well Plan: CD5-25 (1 OBC) -Slot 25 Project: Western North Slope TVD Reference: Plan: 33.7+30.3 (copy) @ 70.00usft (Doyon Maanurae 19) Site: CDs Alpine West Pad MD Reference: Plan: 33.7+30.3co ( py) @ 70.00usft (Doyon VeMca1 Wgnsu8r 19) Well: Plan: CDS-25 (1 OBC) North Reference: True Wellbore: Plan: CDS-251-1 Survey Calculation Method: Minimum Curvature Design: CD5.25L1wp17 Output errors are at 1.00 sigma Error E., Database: OAKEDMP2 Position uncertainty and bias at survey station Maanurae Mclinetlon Admu01 1rMCM HIyMMa {neral VeMca1 Wgnsu8r Seral+neier Seml+nlnor Mail, MPM E. Elan E. Bias Eno, Blar of Biu Error E., Aulaurh Tool (sets 11 r) (non) 4,e11t) (elft) (unit (naft) (ns61 (ura) (asn) (-rt) (--in r) 15,600.00 89.50 151.97 7,559,2) 12]8 -7.05 48.63 0.05 1236 7.14 12.53 48.63 7.72 152.36 MWD•IFR-AK-CAZ-SC (2, 6) 15,600.00 09.50 151.97 7,560,14 12.95 -7.05 49.15 0.05 12.93 7.14 12.62 49.15 7,73 152.35 UM-JFR-N(-CA2-W(2, 5) 15,700.00 89.50 151.97 7.WIM 13.12 -7.05 49.67 0.05 13.11 7.14 12.70 49.88 7.74 152.34 MW IFR-AKSAZSC(2, 5) 15,800.00 09,50 151.97 7,561.87 1319 .7.05 97,00 0.05 13.28 7.14 12.79 5010 7.75 152.34 MM -IFR -MK- -SC (2, 5) 15,900.00 89,50 151.97 7,562.73 13.47 4,05 W.72 0.05 13.45 7.14 12.87 W.72 7.77 152.33 MID -IFR -M -C (2, 5) 161000.00 89.W 151.97 7,563.0 13.64 -7.05 5114 0.05 13.63 7.15 12.96 5125 7.78 15233 MWDAFR-AK-CAZSC(2, 5) 16,100.00 89.50 151.97 7,564,46 13.81 4.05 51.77 0.05 13.60 7,15 13.04 51.77 7.79 152.32 MWD -IFR -AK- .97(2. 5) 16,200.00 89.50 151.97 7,565.33 13.99 4.05 am 0.05 13.97 7.15 13.13 an 7.00 15281 MMAFR-AK- -X(2,5) 16.300.00 89.97 151.97 7,568.19 14.16 -7.05 52.83 0.05 14.15 7.15 13.22 5283 7.81 152.31 MWDNFR-AWCAZ40(2, 5) 16,{00.00 89.50 151.97 7,587.06 14.33 4.05 53.35 0.05 14.32 7.15 13.30 53.36 7.83 152.30 MWDMFR-AK-cA (2, 5) 16,500.00 89.50 151.97 7,567.92 14,51 4.05 53.8 0.05 14.49 7.15 13.39 53.89 7.84 15230 M=-IFR-AK-CA2-SC(2,5) 16,970.00 8897 151.97 7,560.79 14.60 -7.05 54.42 0.05 14.67 7.15 1148 54.42 7,05 Ian Ml4D+IFRN4 AZS0(2,5) 16,700.00 89.50 151.97 7,60865 14,85 4.05 54.95 0.05 14.04 7.15 13.W 54.95 7.86 152.29 MM+[FRAK-CAZSC (2, 5) 1&600.00 89.50 151.97 7,570.52 15.03 -7.05 55.8 0,05 15.02 715 13.65 55.48 7.87 152.28 MMAFR-MK- .SC (2, 51 18,900.00 89.50 151.97 7,571.36 1510 A.0 W.01 0.05 15.19 7.15 13.74 56.01 7.89 1522814 D1FR-AWCAZS0(2,6) 17,000.00 89.97 151.97 7,572.25 15.38 4.05 56.55 0.05 15.37 7.15 13.83 56.55 700 152.27 MVANFR-AK-C/SSC (2, 5) 17,100.00 89.50 151.97 7,573.11 15.55 AAS 57.00 0.05 15.54 7.16 13.92 57.00 7.91 15227 MI IFR✓0(- 40(2,5) 17,200.00 aeW 151.97 7,93.98 15]3 4.05 57.62 0.05 1532 7.16 14.01 57.62 7.92 152.28 MWDAM-AK-OAZSC(2, 5) 17,300,00 MW 151.97 7,574.84 15.90 -7.05 M16 0.05 1589 7.16 14,09 50.16 7,94 152.2651NNHFRAWCA2-SC(2,5) 17.400.00 89.50 151.97 7,575.71 18.08 -7.05 58.89 0.05 16.06 7.16 14.18 WAS 7.95 162.28 1,1 N11FR-AK-CAZ-ec (2,5) 17,500.00 89.50 151.97 7,576.57 1625 .7.05 59.23 0.05 16.24 7.16 14.27 59.23 7.96 152,25 MW IFR-A&CAZSC(2, 5) 17,600.00 W.W 151.97 7,577.44 18.43 -7.05 59.77 0.05 16AI 7,16 14.W 59.77 7.97 152.25 MWDIIFR-AK-CAZ-W(2, 5) 17,700.00 sew 151.97 7,578.30 16.60 -7.05 60,31 0.05 16.59 7.16 14.45 60.31 7.98 15224 MWD-IFR-A&CA2SC(2, 5) 17,970.00 89,W 151.97 7,579.17 16.78 4.05 M85 0.05 16." 7.16 14.54 60.85 8.00 152.24 MWD*IFR-AK .sc(2, 5) 17,900.00 89.97 151.97 7,500.03 18..45 3.05 61.39 0.05 16.94 7.16 14.63 61.39 8.01 162.24 MWDNFR-AK-CP2-SC(2, 5) 18,000.00 89.50 151.97 7,5W.00 17.13 -7.06 61.93 0.05 17.12 7.16 14.n 81.94 8.03 15213 lJM-IFR-AWCAZ-&C(2, 6) 18.100.00 89.97 151.97 7,501.76 17.W 4.05 6240 0.05 1719 7.16 14.01 62,48 8.04 152.23 MW IMAK-C -sc(2,5) 18100.00 89.97 151.97 7,582.63 17.48 4.06 W.02 0.05 17.47 7.17 14.90 no 6.05 Ian M=+1FR-M-CAZSC(2.5) 10,300.00 89.W 151.97 7,583.49 17.65 4.97 W.W 0.05 17.64 7.17 14.99 605 BAB 152.22 MW0NFR-AK-CAZSC(2, 5) 18,400.00 89.W 151.97 7,584.36 17.83 -7.05 U.11 0.05 17.82 7.17 15.08 64.11 8.08 15222 UV IFR-AK-CAZSC (2.5) 181500.00 89.50 151.97 7,5512 18.00 4.05 61.65 0.05 17.99 7.17 15.17 64.65 8.09 15222 MVA+Iffl WCA 97(2,5) 18,600.00 M.W 151.97 7,586.09 18.18 -7.05 65.20 0,05 18.17 7.17 1517 65.20 8.10 152.21 MWDNFR-MW -a0(2,5) 19,70.00 89.50 151.97 7,508.95 law 1.05 65.74 0.05 18.35 7.17 law 65.74 8.12 15211 MV IFR-AWCAZSC(2,5) 18,800.00 89.97 151.97 7,57.02 18.5 -7.05 9729 0.05 18.52 7.17 15.45 W19 8.13 152.21 MM+[M ,o- .ac(2,5) 18900.00 89.W 151.97 7,588.68 18.71 4.03 %.0 0.05 18.70 7.17 15.54 97.64 8.14 16227 MWDdFR-AK--97(2,5) 19,000.00 89.50 151.97 7,589.55 taw -7.05 67.39 0.05 18.87 7.17 1563 67.39 8.16 152.20 MW IFR -MW 4;C(2, 5) 19,100.00 W,50 151.97 7,590.41 19.06 -7.05 67.93 0.05 19.05 7.17 15.n 67.93 8.17 15.20 UM+IFR-MK -SC (2, 6) Ismo.00 89.50 151.97 7,591.28 1914 -7.05 68.48 0.06 1913 7.17 15.82 60.48 8.18 152.20 MM-IFR-AK-CAZSC (2,5) 19,300.00 69.50 151.97 7,592.14 19.41 4.05 69.03 0.05 19.40 7.18 15.91 69.03 810 152.19 M1 IFR -MK- SC (2, 5) 10,400.00 69.50 151.97 71693.01 19.5 -7.05 69.58 0.05 19.58 7,18 16.00 W.5 8.21 152.19 MWOHFR-AKLALSC(2, 5) 19,500.00 89.50 151.? 7593.87 19,76 -7.05 70.13 0.05 19.76 7.1a 16.09 70.13 8.23 15219 M -IFR-AK-CA2•15C (2, 5) 18800.00 89.50 151.97 7.594.73 19.94 -7.05 70.68 0.05 19.93 7.18 16.19 70.68 8.24 152.18 MW IFR-AK-CAZSC (2. 5) 19,700.00 89.97 151.97 7,595.W 20.12 -7.05 7113 0.05 20.11 7.18 16.28 7123 8.25 152.18 MM+JFR-AK ,5C(25) 19,300.00 e850 151.97 7,596.46 2019 4.05 71.78 0.0.5 20.29 7.16 16.37 71]8 8.27 197,18 IJADAFR-AK-C X(2,5) 19,900.00 89.50 151.97 7,57.33 20.47 4.05 ran 0.05 20.46 7,18 16.47 72.33 8.20 152.18 MW IFR-AK-CAZSC(2, 5) 20.000.00 69.50 151.97 7,598.19 20.W -7.05 72.88 0.05 2044 7.18 16.W 72.89 819 197.17 MWDHFR.AWCAZSC(2, S) 201100.00 8950 151.97 7,599.05 20.2 3.05 73.44 0.05 20.82 7.18 less 73.44 881 15217 MWD4IFR-AWCAZ-SC(2, 5) 2820000 89.97 151.97 7,599.92 21.00 -7.05 73.99 0.05 2099 7.10 16.75 73.99 8.92 152.17 is O IFR -MC ,BC (2. 6) 20900.00 89.97 151.97 7.Wan 21.18 -7.05 74.54 0.05 21.17 7.18 16.84 74.54 8.34 152.17 MW9+IFR-AK-CA (2,5) 20.400.00 89.50 151.97 7,W1,W 21M 3.05 75.10 0.05 21.35 7.18 16.93 75.10 885 152.17 MWD-JFRAK-CAZ-W(2,5) 20.970.00 89.50 151.97 7,602.52 21.W 4.05 75.0 0.05 2152 7.19 17.03 75.85 6.98 152.16 MW IF&AKA C(2,6) 20600.00 89.W 151.07 7,603.38 21,71 4.05 76.20 0.97 21.70 7.19 17.12 76.20 836 15218 MMe[FR-A&CAZ-W(2,5) 111141201711:45:54AM Page 5 COMPASS 5000.14 Build 85 Company: ConocoPhillips(Alaska) Inc.-WNS Project: Western North Slope Site: CDs Alpine West Pad Well Plan: CD5-25 (10BC) Wellbore: Plan: CDS-251-1 Design: CD5.25Ltwpl7 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: Well Plan: CD5-25 (1 OBC) - Slot 25 TVD Reference: Plan: 33.7+36.3 (copy) @ 70.00usft (Doyon 19) MD Reference: Plan: 33,7+36.3 (copy) ® 70.00usft (Doyon 19) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: OAKEDMP2 Position uncertainty and bias at survey station Meaaur d Incltwbo. Atl48uM V.rectl Rl9K9id. S nl Witicai Ma9011uCa 8MnImMw eunim0lw Minh o.Mh Emir W. Eeor Bial E. Sia. Bram Ermr Error AWnuth Tool Was) (1) rl N9ft) (uas) tuft) (nm) (.am ("aft) (mft) (wft) (me luu4 r) 20,70100 89.50 151.97 7,604.25 2188 4.05 76]8 0.05 21.88 7.19 17,2 76.76 8.39 152.16 MM+[M-AK-C -$C (2, 5) 20,800.00 89.50 151.97 7,605.11 22.08 -7.05 "Al 0,05 22.05 7.19 17.31 77.31 8.41 162.16 MW IMAK-CA (2, 5) 211,900.00 Saw 151.97 7,605.98 2224 4,05 77.87 0.05 22.23 7.19 17AI r.87 &42 152.16 MW IFR -M -C 97(2,5) 21,000.00 89,50 151.97 7,006.84 2242 4.05 78.42 0.05 2241 7,19 17.50 MA2 a.M 152.15 a IFR -AK -CA 40(2,5) 21,100.00 89.50 151.97 7,807.71 22.59 4.00 7&98 0.05 M.w 7.19 17.60 78.90 8.45 15215 MWDNFR-AK-LA25C(2,5) 21,200.00 Sew 151.97 7,808.57 22.77 -7.05 79.54 0.05 22.76 7.19 17.69 79.54 8,46 15215 M\ IFR -M -CA SC (2, 5) 21.300.00 89.50 151.97 7,609.4 Mee -7.05 Was 0.0.5 22.94 7.19 17.79 8&09 8Aa 152.15 MM+IFR-MK-0 .SC (2. 6) 21400,00 8&50 151.97 7,610.0 2112 -7.05 3.86 0.05 23,12 7.19 17.88 Saw 8.49 152.15 MWD-1FRA-CAZ-W(2,5) 21,500-00 89.50 151.97 7,611.17 23.30 -7.05 81.20 0.05 23.29 7.19 17.98 81.21 &51 15214 MW IFR-AKL -W (2, 5) 21,800.0 89.97 151.97 7,812.03 23.48 4,05 81.76 0.05 23.47 710 18.07 81.76 8.52 152.14 MPIDtlFR-d&CAZSC(2, 5) 21,700.00 89.50 161.97 7,612,90 23.65 445 8212 0.05 23,65 TM 18.17 8232 0.54 15214 MWSAIFR-AK-CAZ4C(2, 5) 21,800.00 89.50 151.97 7.613.76 23.83 -7,05 82.88 0.05 23.2 7.23 18.26 82.88 8.55 152.14 MWLMIFR-AH- -sc(2, 5) 21,900.00 Sew 151.97 7,814.63 24.01 -7.05 83.44 0.05 24.0 7.4 18.30 83.4 8.57 152.14 MWDIFR-AWCAZSC(2,5) 22.000.00 saw 151.97 7,615.49 24.19 4.05 8999 0.5 24.18 7.20 18.45 3.99 8.58 162.14 MWIAIFR-AK-CAZ4C(2, 5) 2.locw 09.50 151.97 7,618.% 24.36 4.05 04.55 0.05 24.36 7,20 18.55 64.55 &3 152.13 UW IFR -AK- -so (2,5) 22.200.00 Saw 151.97 7,61722 24.54 -7.05 05.11 0.05 24.53 7.20 18.86 05.11 8.61 152.13 MM.IFR-AK-CA SC (2, 5) 2$300.0 Saw 151.97 7,618.09 24.72 -7.05 85,57 0.05 2431 7.20 18.74 85.67 8.63 152.13 MKD•IM-MK AZ4C(2, 5) 22.400.0 89.50 151.97 7,818.95 24.90 4.05 8613 0.05 Nee 7.0 1814 8623 8.64 16213 MM+]FR-AK-CA ,W (1, 5) 22500.00 Sew 151.97 7.619.82 25.07 4.5 W79 &0.5 25.07 710 10.93 86.79 &3 152,13 MWTAIFR-AWCA2SC(2, 5) 221000.00 saw 151.97 7,62&60 25.25 -7.05 87.35 0.05 2514 7,0 19.03 87.35 8.67 152.13 MM+IMAKCA C(2.5) 22700.00 89,50 151.97 7,621.55 25.43 -7.05 87.91 0.05 25.42 721 19.13 87.91 8+69 152.13 MWDNFR-M-CAZ-a0 (2, 5) 22,000.00 89.50 151.97 7,622A1 25.61 4.05 88.47 0.05 25.80 711 1822 80.47 8.70 152.12 MW IFR -AK -C 4C(2, 5) 2200&00 3.50 151.97 7,623.28 25.78 -7.05 89.03 0.05 25.78 7.21 19.32 89103 8.72 152.12 MWV+FR-AK-CAZSC(2,5) 23.000.00 89.50 151.97 7,624.14 25.96 4.05 89.59 0.05 25.95 1-21 19.42 89.59 8.73 15212 MM.]M-AK.0 .ac (2, 5) 23.100.00 8955 151.97 7,825.1 26.14 4146 0.15 0.05 28.13 7.21 19.51 WAS 875 152.12 MWTRIFR-N(-CAZSC(2, 5) 23200.00 89.50 151.97 7,625.87 28.32 4.05 9071 0.05 28.31 7.21 19.61 90]1 8.76 15212 MM.IFR-AWCAZSC(2, 5) 23,300.00 8&50 161.97 7,626.74 36.49 -7.05 9117 0.05 4.49 7.21 19.71 91.27 8.78 162.12 (2, 5) 23400.00 few 151.97 7,027,60 26.67 -7.05 91.09 0.05 28.88 711 19.81 91.3 879 152.12 MWTHIFR-AWCAZSC(2,5) 23,500.00 89.50 151.97 7,628.47 26.85 -7.05 92.39 0.05 M.4 711 Ism 92.39 8.81 152.12 MWWIFR-MK -SG (2, 6) 23,600.00 Saw 151.97 7,629.33 27.03 4.05 92.98 0.05 27.2 7.21 20.00 9296 8.02 15211 MNANFR-AK-CA2-SC (2, 5) 23700.00 89.50 151.97 7,63.4 274 4,05 93.62 0.05 27.4 721 0,10 93.62 8.84 153.11 MM FR -AK -CA W(2,5) 23,800.00 flew 151.97 7,631.08 27.38 4.0.5 94.08 0.05 27,38 TM 20.20 64,08 8.85 152.11 UW IFR-Al(-CAZSC(2, 5) 23.900.00 89.50 151.97 7,631.93 27.58 4.05 94.64 GAS 27.55 7.22 M.M 97,84 8.87 152.11 MWDMFR-Aa-CAZSC (2, 5) 24,000.00 89.50 151.97 7,83279 27,74 4.05 95.20 0.05 2773 7,22 20.39 95.21 8.3 15211 MWTAIFR-AK-C sc (2, 5) 24,100.00 69.50 151.97 7,6a6S 27.82 -7.05 95.77 0.05 27.91 722 4.49 95.77 8.90 152.11 MW IFR-AK-CAZ-BC(2,5) 24.200.00 89.50 151.97 7,634.52 28,09 -7,05 9&33 0.05 28.09 7= 20.59 96.33 8.92 162.11 MW IFR -MK -SC (2, 5) 24,300.00 89.50 151.97 7,635.39 2027 -7.05 98.89 0.05 28.26 7.22 20.68 96.89 8.93 15211 M IFR-AK-CAZ-W (2, 5) 24,400.00 Saw 151.97 7,636M 2&45 -200 97,48 0.05 234/ 722 4.78 97.4 0.95 152.10 M=+IFR-AK-C X(2,5) 24,500.00 89.50 161.97 7,837.11 28.3 -7.05 98.02 0.05 28,62 722 M.3 98.02 8.90 152.10 MW IFR-AI(-CAZSC(2, 5) 24,600.00 89.50 151.0 7,637.98 28.80 -7.05 9&58 0.05 28.00 7.22 4.98 98.58 8.90 15210 MWn4FR- CA&W(2, 6) 24,700.00 89.50 151.97 7,838.84 4,88 -7,05 99.15 0.05 20.98 712 21,08 89.15 8.99 152.10 MWD.FR-AK-CA2-6C(2, 5) 24,800.00 89.50 151.97 7,639.71 29,16 -7.05 99.71 0.05 4.15 712 21.18 9971 9.01 152.10 MW IFR-AK-CAZ-SC(2, 5) 24,90040 Saw 151.97 7.640.57 29.34 4.00 100.27 0.05 29.3 723 21.27 100.27 9.03 15240 MWD+IFR-AK-CAZSC(2.5) 25,000.00 89.50 151.97 7,841,4 29.52 4.05 100.84 0.05 28.51 713 21.37 100.64 9.04 15210 MVA) WXAK-CAZ-BC (2, 5) 25,100.00 99,60 151.97 7,84235 29.89 -7.05 101.40 0.05 29.89 723 21.47 101,40 am 152.10 MW FR -MW .So (2, 5) 4200.00 89.50 151.97 7,643.17 29.87 4.05 101.97 0.05 29.87 7.23 21.57 101.97 9.07 152.10 MWDaIFR-AWCA2SC(2, 5) 4.300,00 89.50 151.97 7,64.03 30.05 -7.05 102.53 0.05 30.4 713 21.67 102.53 9.09 152.10 MWD-FR41(A W(2, 5) 26.400.00 89.50 151.97 7,844.90 3123 -7.05 103.10 0.05 3022 723 21.77 103.10 9.11 15249 MW WR-AWCA2-aC(2, 5) 25,500.00 Baa 151.97 7,fi45.78 30.41 -7.05 103.8 0.05 30,40 7.M 21.87 law 9.12 15209 MWIMWRMA A2 -SC (2, 5) 4,600.00 Sew 151.97 7.846.63 3,58 -7.05 10413 0.05 3.58 723 21.97 104.23 9.14 152.03 MW FRJJ(-CAZ.W(2, 5) 25,700.00 89.50 151.97 7,64749 3,23 -7.05 104.79 0.05 3.76 7.23 2206 101.79 9.15 152.09 MW IFR-AK4;A2SC(2, 5) 25.00.00 89.50 151.97 7,648.3 30.94 4.05 105.3 0.05 30.93 7,23 22,16 105.36 9.17 152.9 MW IFR -N( ,Sc, (2.5) 25,90.00 Sew 151.97 7,64922 31.12 -7.05 105.92 0.06 31.11 7,23 22.26 105.92 9.19 152.8 MM.IFR-AK-CAZSC (2 5) 1111412017 11:4654AM Page 6 COMPASS 5000,14 Build 85 Company: ConocoPhiOips(Alaska) Inc-WNS Project: Western North Slope Site: CD5 Alpine West Pad Well: Plan: CD5-25 (I OBC) Wellbore: Plan: CDS251-1 Design: CD5-25L1wpl7 Position uncertainty and bias at survey station Cor ocolphillips Error Ellipse Report Local Cocrdlnata Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: CD5-25 (1 OBC) - Slot 25 Plan: 33.7+36.3 (copy) @ 70.00usft (Doyon 19) Plan: 33.7+36.3 (copy) @ 70.00usft (Doyon 19) True Minimum Curvature 1.00 sigma OAKEDMP2 Measures 1.1iiiaBon Atlmuar wniO RI909We UW.1 Vertical VeMal M q.n Sew,.r SeM.M.r W981 Diameter Oep18 Eno, ak9 E. Biu E. SW Maks Error Emir A Iei,iR MWI W-111 r) 17 MRI (iiia) tusft) Icon) W) W1 Ukftl W) W) Naa) r) 26.000.00 also 151.97 700.09 11.30 -705 106.49 0.05 3129 7.24 22.36 106A9 9.20 152.09 MWD•IFR-AK4AZSC(2,5) 26,100.00 89.50 151.97 7,650.95 31.47 -7.05 107.0 0.05 31.47 7.24 22.48 107.05 9.22 15209 M=•IFR-AK-C C(2,5) 28,200.00 89.50 151.87 7,651.82 31.65 4,05 107.62 0.05 11.86 7.24 22.58 107.62 9.24 152.09 MWDHFR-AKC 41C (2 5) 26,300.00 89.50 151.97 7,65268 31.0 4.0 108,18 0.05 31.82 7.24 22.65 108.18 9.25 152.08 MW IFR-AKCA2-SC (2, 5) 26,40910 89.50 151.97 7,653.55 32.01 -7.05 108.75 0.05 32.0 724 22.76 108.75 9.27 152.09 MW JFR.MK Cf -SC (2, 5) 2,500.00 89.50 151.97 7,654A1 3219 4.05 109.32 0.0 32.18 7.24 2186 109.12 919 152.09 MWD•IFR-AKCAZ-SC(2,5) 28,600.00 89.50 151.97 7,65528 32.37 -7.05 109.% 0.05 32.36 7.24 2298 109.88 9.30 152.% MWD•IFR-MK- -SC (2. 5) 26,700.00 89.50 151.97 7,656.14 12.54 -7.05 110.45 0.05 3211 7.24 23.06 110A5 9.32 15208 MV IFR-AKCAZSC (2,5) 2,80010 09.50 151.97 7,657.01 32.72 -7.05 111.01 0.06 n.72 7.24 23.16 111.01 9.33 152.08 MWD•IFR-AKCAZSC(2,5) 28.900.00 69.50 151.97 7,857.87 32.90 4.05 111.58 0.05 32.89 7.24 23.26 111.50 9.35 152.08 MWD•IFR-AKCAZSC (2, 5) 27,000.00 89.50 151.97 7,658.74 33.0 4.0 11215 0.05 33,07 7.24 am 112.15 9.37 152.08 MWD•1FR-AI(-CA24;0(2, 5) 27.100.00 89.50 151.97 7,859.80 33.26 -7.05 112.71 0.0 3315 7.25 2346 112.71 9.38 152.08 MWWIFR-AK-CAZ-SC(2,5) 27100.00 89.50 151.97 7,650.47 33.43 .7.05 113.28 0.03 33A3 7.25 2156 113.28 910 152.06 UW IFR -AK- -SC (2. 5) 27,300.00 89.50 151.97 7,681.33 33.61 4.05 113% 0.05 33.81 7.25 23.66 MAD 9.42 152.% MW IFR-MCAZSC (2, 5) D,400.00 89.50 151.97 7,86210 33.79 4.05 114.42 0.05 33.79 7.25 23.76 114.42 913 15208 MV IFR-M4C SC (2, 5) 27,500.00 89.50 151.7 7,883.06 33.97 -7.05 114.98 0.05 33.% 7.25 23.84 114.98 9.45 152.06 MW IFR-AKCAZSC(2, 5) 27,800.0 09.50 151.97 7,86393 34.15 -7.05 115.55 0.0 14.14 7.25 23.26 115.65 9.47 152.08 MWDNFR-AI(CAZSC (2,5) 27,700.00 89.50 151.97 7,664.79 31.33 -7.0 116.12 0,05 34.32 Ms 2416 116.12 918 Isles MWD•IFR-AKCA2SC(2, 5) 27.800.00 89.50 151.97 7,665.66 31.50 -7.0 116.68 0.06 34.50 7.25 24.16 116.88 9.50 152.08 IMD-IFR-MX SC (2,5) 27,%0.00 89.50 151.97 7.866.52 31.68 -7.05 11725 0.% 31.68 7.25 2428 11715 9.52 152.08 MWD•IFR-PJ(-CAZ-W(2, 5) 28.%.00 89.50 151.97 7,667.39 31.% -7.05 117M 0.05 34.85 7.25 24.38 117.82 9.64 152.07 MW IFR-AR-CA2-SC (2. 5) 23,100.00 89.50 151.97 7,688.25 35.04 -7.05 118.39 0.05 Wes 7.25 24A6 118.39 9.55 15207 MW IFR -MCA -SC (2,5) 28.200.00 89.50 151.97 7,669.12 35,22 4.05 118.95 0.05 35.21 7.28 24.58 110.95 9.57 152.07 MW IFR-AKCAZSC (2, 5) 28,300.00 89.50 151.97 7.669.98 35.40 -7.0 119.52 0.05 35.39 7.26 24.88 119M 9.59 152.07 MW IFR -MC SC (2.5) 26.400.00 89.50 151.97 7,670.85 35.57 -7.05 120.09 ,% 35.57 7.26 24.77 120.09 9.00 152.07 MWDNFR-AHCA2SC(2, 5) 2,500.00 sew 151.97 7,671.71 35.75 -7.05 120.66 0.05 35.75 718 24.87 120.646 9.62 152.07 MWD•IFR-MK -SC (2, 5) 28,600.00 89.50 151.97 7,872.58 35.93 4.05 12113 0.05 35.93 7.28 24.97 121.3 9.64 152.07 MWD•IFR-AKCAZSC(2,8) 28,700.00 89.50 151.97 7,873.0 36.11 4.05 121.79 0.05 35.10 7.0 25.07 121.79 9.65 152.07 MW IFR -M -CA C(25) 28,00000 89.60 151.97 7,674.31 3819 -7.05 122.38 0.05 3618 7.26 25.17 122.38 9.67 152.07 MM-IFR-AI(CAZSC (2, 5) 20.900.00 89.50 151.97 7,875.17 36.47 4.05 122.93 Des 38.46 7.28 25.27 122.93 9189 152.07 MVID•IFR-AKCAZSC (2, 5) 2,000.00 89.50 151.97 7,876.04 36.64 -7.05 123.50 0.05 38.64 7.26 25.37 123.50 R71 152.07 MV IFR-AKCAZSC (2. 5) 29,100.00 69.50 151.97 7,676.90 36.82 -7.5 124.07 0.05 36,82 716 25A7 124.07 9.72 15207 MW IFR-AKCAZSC(2, 5) 29,200.00 89.50 151.97 7.677.76 37.00 -7.0 124.4 0,05 37.00 716 25.67 124.64 9.74 152.07 MW IFR-AKCAZSC (2,5) 29300,00 89.50 151.97 7,678.63 37.18 -7.05 125.21 0.05 37.17 7.27 25.68 125.21 9.76 152.07 MW IFR -MC 40(2,5) 29,400.00 89.50 151.97 7,679.49 37.36 -7.05 125.77 0.05 37.35 7.27 25.78 125.77 9.78 152.07 MWD•IFR-AK-CAZ-SC (2, 5) 29,500.00 89.50 151.97 7,68,36 37.54 -7.05 126.34 0.05 37.53 7.27 25.88 126.1 9.79 162.07 MWDNFR-AK-CAb8C (2, 5) 291600.00 89.50 151.97 7,881.22 37.71 4,05 128.91 O.5 37.71 717 25,98 128.91 9.81 152.08 MM•IFR-A&CAZ-SC(2, 5) 29,700.00 89.50 151.97 7,882.09 37.89 -7.05 127Aa 0.05 37.89 7.27 26.08 127A8 9.83 Isles MWD•IFR-AKCAZSC(2. 5) 29,800.00 89.50 151.7 7,662.95 36.07 4.05 120.0 0.05 38.07 7.27 26.18 128.05 9.64 152.% MWCNIFR-AK-CAZSC (2, 5) 29.805.30 89.50 151.97 7,68310 38.0 -7.05 law 0.0 38.% 7.27 26,19 128.08 9.% 152.05 6 IFR-AWCAZSC(2, 5) Casing Points Measured Vertical Casing Hale Depth Depth Diameter Diameter (MRM (tuPo Name 115.30 115.30 20" x 4T 20 42 2,193.56 2,185.00 10 -314"x13 -W" 10-3/4 13-1/2 8,324.00 7,494.36 7.51&'x 9-7/8" 7-5/8 9-7/8 29,805.30 7,683.00 4-1/2"x6-3/4" 4-1/2 6-314 11/14/201711:45.,54AM Page 7 COMPASS 5000.14 Build 85 Company Project: Site: Well: Wellbore: Design: Plan Annotations ConomPhillips(Alaska) Inc. -VMS Western North Slope C05 Alpine West Pad Plan: CDS-25 (108C) Plan: CD5-251-1 CD5-25Ltwpl7 Measured Depth (usft) 8,323.00 8,335.80 8,355.80 8,500.51 10,606.79 10,611.61 10,618.32 29,805.30 ConocciPhillips Error Ellipse Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Vertical Local Coordinates Depth +NI -S +E/ -W (usft) (usft) (usft) 7,494.28 -2,092.83 1,027.28 7,495.68 -2,104.00 1,033.37 7,497.53 -2,121.42 1,043.03 7,504.66 -2,248.34 1,112.09 7,516.97 4,106.46 2,103.87 7,517.00 4,110.71 2,106.14 7,517.05 4,116.64 2,109.29 7,683.00 -21,052.67 11,125.02 Comment Well Plan: CD5-25 (108C) - Slot 25 Plan: 33.7+38.3 (copy) @ 70.00usR (Doyon 19) Plan: 33.7+38.3 (copy) ® 70.00usft (Doyon 19) True Minimum Curvature 1.00 sigma OAKEDMP2 KOP: 15.9°/100' DLS, -22° TF, for 12.8' Hold for 20' Start 3.5°/100' DLS, 10.51° TF, for 144.71' Hold for 2106.27' Start 1.5°/100' DLS, 154.5° TF, for 4.82' Adjust TF to 161.57', for 6.71' Hold for 19186.98' TD: 29805.3' MD, 7883' TVD Checked By: Approved By: Date: I 11/142017 11:45:54AM Page 8 COMPASS 5000.14 Build 85 CDS -25 and CD5-25L3 Area of Review This Area of Review is required as CD5-25 and CD5-25L1 is being permitted as an Alpine A and C injector. This AOR discussed the wells that fall within''/6 mile of the wells entry point into the Alpine A and C sand. The table below review the wells that fall within the Y mile radius of CD5-25. WELL E RMS CftH ]ep plC-UW TQWGSana Ta ""men[ TPPuff m T"&C dIPoM MD dl Poul MD OM M OeM�nlnedB RbnrenL M. lPyl 4olrtlon � MOperallqu=mxI1MY Mtt1uMW Open bole TOC@ I CBS]D Pma % 7-5/H" am. ],0]& I&M llnerfm am-& W�WM9661z35$Md.G Rg/p �nkb H W. .m M.Md6mgp.Bl.1bWSMS Pxhr@ �1],Pusing IPFu A&C Alpinep&C P 11,)86' OBaex GPemanl MITIA MmoN CDSILi Pmaudlg ]-5/H' NIA Np / GpnlbWe Ilnerf' Cebdale aToc 7/29/0, 7 -VW 1;890' ]•26Y GlakRa 12,890'& ]SOxDS15.smd.SSGc nl �nHPrexure ,:CIO KupamkC PaMer@ [eilga to 3.5W q1 13.}56• for30mins CD5-20/CDS-201_19-7/8" x 11" intermediate section was drilled and cased with 7-5/8" casing down to 12,291' MD. The Alpine C zone was penetrated at 11,969' MD. The intermediate casing was cemented to isolate the Alpine pool with 102.9 bbl of Class G cement (plugs bumped and floats held) and top of cement was measured with a Sonic LWD at 10,742'. A second stage job was then performed to isolate the Qannik using 61.1 bbl Class G cement; the plug bumped and stage tool successfully closed. A horizontal production section was drilled in the Alpine A to 24,119' MD and completed with frac ports. A second lateral was then drilled in the Alpine C to 22,523' MD and completed with a partial pre - perforated liner. The well is completed as a dual lateral producer in the Alpine A and C sand. A passing MITIA to 3000 psi was completed on 3/8/2017. CD5-313 9-7/8" x 11" intermediate section was drilled and cased with 7-5/8" casing down to 13,422' MD. The Alpine C zone was NOT penetrated in this wellbore as the objective formation was the Kuparuk C (shallower). The intermediate casing was cemented to isolate the Alpine pool with 51 bbl of Class G cement (plugs bumped and floats held). Full returns were maintained during the job and the top of cement is calculated to be at 12,890' MD. A second stage job was then performed to isolate the Qannik using 90 bbl Class G cement; the plug bumped and stage tool successfully closed. A horizontal production section was drilled in the Kuparuk sand to a TD of 20,835' MD. The well was completed as a producer using slotted liner. A passing MITIA to 3500 psi was completed on 7/28/2015. 11:53, November 14 2017 CD5-25L1wpl7 Quarter Mile View Main°CD5-25L1 TD TD CD5-25L1 TD QM CD5-25L1 Tgt CDS-2$L1 Tgt QM rvD .0p 768] 7603.00 7517.00 75P.0p ,P CiMe(Ratliur Cirtk (RaUius. 1320.00) l.¢.(M.Ul:s100.00) CI¢k (Ratliux: 1J20.00) 0 - -4000 c Z -8000— O ( _ i CD69�3e01 I fl 2000 - - — — -- I z I ..J 7 (016000 — —� - -- i � i `gGl 16 G 6 2A�P G\ `g -20000 I Go524� J2 01 P 1� Q Nb - I CD9• , -8000 -4000 0 4000 8000 12000 16000 20000 24000 u CD5-25w 16.2 Surface Location 4%. CPAI Coordinate Converter �J Frnm.. Datum: NAD83 + Region: alaska + r Latitude/Longitude IDecimalDegrees r UTM Zone: I r— South f' State Plane Zone: Units: us -ft + ( Legal Description (NAD27 only) Datum: NAD27 + Region: alaska + C" Latitude/Longitude Decimal Degrees (' UTM Zone: True r South State Plane Zone: F—':-] Units: us -ft + C Legal Description (NAD27 only) Starting Coordinates: Ending Coordinates: X 11489110.28 X: 349077.125728549 Y: 5965532.01 Y: 5965786.05478869 Transform ! Quit Help CD5-25wp16.2 Surface Location =LoIJ Datum: NAD83 + Region: alaska + (' Latitude/Longitude IDecimalDegrees + r UTM Zone: — r South G State Plane Zone: I' J Units: us ft + C Legal Description (NAD27 only) Starting Coordinates: X: 1489110.28 Y: 5965532.01 Datum: NAD27 jj Region:alaska + i Latitude/Longitude iDecimalDegrees (' UTM Zone: True r South (` State Plane Zone:I q � Units: us -ft + G Legal Description (NAD27 only) - Legai Township: 011 Range: 004 E + Meridian: �]� Section: 18 FNL 431.55441 FEL El 2900.0121 ........................................................... I _ Quit p .Transform ..................i Hel CD5-25wp17 Kick-off Point Alpine C 04CPAI Coordinate Converter _ _lol xl Datum: NAD83 ::j Region: alaska (' Latitude/Longitude IDecimalDegrees r UTM Zone: — r South f• State Plane Zone: lq ,j Units: fu7f Tt r Legal Description [NAD27 only)r Starting Coordinates: X. 11490095.1 y 15963419.06 Datum: NAD27 Z Region: alaska zi l' Latitude/Longitude IDecimalDegrees T UTM Zone: True r South r State Plane Zone: I q � Units: usft D- (— Legal Description (NAD27 only) Ending Coordinates: X: 350061.872150306 Y: 5963673.06015991 ........................................................... Transform Quit Help CD5-25wp17 Kick-off Point Alpine C FCRAI =L1 xl Datum: INAD83 .I Region: alaska A r Latitude/Longitude IDecimalDegreas r UTM Zone: — r South G State Plane Zone: F----:1 Units: us -ft (' Legal Description (NAD27 onlyj Starting Coordinates: X: 11490095.1 Y: 15963419.06 Datum: NAD27 7 Region: alaska C Latitude/Longitude Decimal Degrees r UTM Zone: True r South f State Plane Zone: F-3- q � Units: usft G Legal Description (NAD27 on_I_y_)r - Legal Township: 011 IJ Range: 004 E Meridian: JU _� —� Section: 18 FNL 2524.5417 FEL 1881.0913 Transform Quit Help C015-25wpV TD N%.. CPAI Coordinate Converter Datum:NAD83 Region: alaska Latitude/Longitude Decimal Degrees l" UTM Zone: F — r" South T State Plane Zone: F----3 Units: us -ft (" Legal Description (NAD27 only) Starting Coordinates: X: 11499808 Y: 15944261 Datum: NAD27 Region: alaska T Latitude/Longitude I Decimal Degrees f UTM Zone: True r South f• State Plane Zone: F----] Units: us -ft i Legal Description (NAD27 only) Ending Coordinates: X: 359774.060456823 Y: 5944514.53213171 ............................................................ Transform :.......................................................... Quit Help • t %_ CPAI Coordinate Converter �y Datum: FN -A --D-8-3 Region: alaska r LatitudelLongitude IDecimalDegtees r UTM Zone:I — r" South F State Plane Zone Units: us -Ft r Legal Description (NAD27 only) Starting Coordinates: X: 1499808 Y: 5944261 Datum: NAD27_j Region: alaska C Latitude/Longitude IDecimalDegrees C UTM Zone: True r South C Stake Plane Zone: 4 . Units us -ft r Legal Description (NAD27 only) - Legal Township: 010 [F'_3 Range: 004 Meridian: U - Section: F4— FNL - 373.66753 FEL � 2419.0929 ..................................... ansform ...................... I TrHelp REVDATE BY CK APP DESCRIPTION REV DATE BY C6 APP DESCRIPTION 1 4/24/15 CZ DB C. A. I UPDATED PER K150003ACS 12 15/2/161 CZ I GD C. A. 1 UPDATED PER K160003ACS ALPINE SATELLITE DEVELOPMENT LOCATION OF - THIS SURVEY T12 C PAD Q T11 N CD5CD4 TO ALPINE D ,,,,,.••""' -., ACCESS ROAD ICD NI a m CD1 - r - L IT VICINITY MAP NOT TO SCALE LEGEND: O PROPOSED CONDUCTOR • EXISTING CONDUCTOR SECTION 18, T. 11 N., R. 4 E., U.M. Ppp CD -5 OF PAD SHOUVpER ��ooa��� tot O� tT �\ 1 x N N W N X •�. H PLANT N N 0 NOTE: 15.40 52" -00, CONDUCTOR CD5-x14 WAS PLUGGED AND ° '\ ABANDONED APRIL 2016. WMF - v KUUKPIK Z UMIAQ ALPINE SURVEY OFFICE PHONE: 907-670-0739 ALPINE MODULE:CD50 UNIT: CD ConocoPhillips ALPINE PROJECT CD -5 WELL CONDUCTORS Alaska, Inc. AS—BUILT LOCATIONS CAD FILE NO. DRAWING N0: PART: REV: 15-03-02-1 04/18/2015 CE—CD50-1025 1 of 3 2 1 4/24/15 1 CZ I DB I C. A.I UPDATED PER K150003ACS 12 15/2/161 CZ I GD C p II DESCRIPT ON PDATED PER K160003ACS ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC. 18, T 11 N, R 4 E, U.M WELL 'Y' 'X' I AT inn SEC.LINE O/S FVIQT NOTES 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.) 3. CONDUCTOR CD5—x14 WAS PLUGGED AND ABANDONED APRIL, 2016. KUUKPIK UMIAQ ALPINE SURVEY OFFICE PHONE :907-6)04739 nL MODULE:D50 UNIT: CDConoco-Phillips ALPINE PROJECT Alaska, Inc. CD -5 WELL CONDUCTORS 4DD FILE N0. AS -BUILT LOCATIONS 15—n3—n9_1 nA/10i.,.., DRAWING N0: ____ -CD50-1025 3I 2 ■ Tier 1: Standard ■ Intervals without issues noted for Tier 2 or 3 ■ Tier 2: Challenging Orientation ■ Drilling within 30' of horizontal inclination AND drilling within 301of 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 CDS -25 and CD5-25L3 Area of Review This Area of Review is required as CDS-25 and CD5-25L1 is being permitted as an Alpine A and C injector. This AOR discussed the wells that fall within')/, mile of the wells entry point into the Alpine A and C sand. The table below review the wells that fall within the Ye mile radius of CD5-25. dflI E AAM CftlU Topo1[-sant dl Pool MD Tep O1 UW dl Pool TWMCement MR TPpMC . TapeE Cement DeYemsiretlR Reservo'v 3bN¢ jmyl GmE114Upe++Yiau9ummary g nW holaRen M Opm Mle TIX G mSID Pmtludng h9/e" ]I.9fi9' ) A1R' iP.]e] fi9A' 9onkbg Rner Mr W7] & 15ts4ege:3R29 hbN89.e PPB CWSG 3/8/17,Pnsng pmdutlfon In Pa[W meMa]ntl Mage�l.I EEIS II.R neA& Alp C IL]8R' pmd.sG...M MlTAb BdOpsi OPun late GlwNte dra CRS3f4 Pmtl.0n8 Ne" ]- NIA N/A ]),R911' ],9a8' Glwlatetl R nttbr 12.R9R"& gMMo119&ppg WsiG cement ®sln8prgssure ^" produmbnln PU v lasted Yo RSRDPs1 Ruparu4C �� Fm3Pmins CD5-20/CD5-20L1 9-7/8" x 11" intermediate section was drilled and cased with 7-5/8" casing down to 12,291' MD. The Alpine C zone was penetrated at 11,969' MD. The intermediate casing was cemented to isolate the Alpine pool with 102.9 bbl of Class G cement (plugs bumped and floats held) and top of cement was measured with a Sonic LWD at 10,742'. A second stage job was then performed to isolate the Qannik using 61.1 bbl Class G cement; the plug bumped and stage tool successfully closed. A horizontal production section was drilled in the Alpine A to 24,119' MD and completed with frac ports. A second lateral was then drilled in the Alpine C to 22,523' MD and completed with a partial pre - perforated liner. The well is completed as a dual lateral producer in the Alpine A and C sand. A passing MITIA to 3000 psi was completed on 3/8/2017. CD5-313 9-7/8" x 11" intermediate section was drilled and cased with 7-5/8" casing down to 13,422' MD. The Alpine C zone was NOT penetrated in this wellbore as the objective formation was the Kuparuk C (shallower). The intermediate casing was cemented to isolate the Alpine pool with 51 bbl of Class G cement (plugs bumped and floats held). Full returns were maintained during the job and the top of cement is calculated to be at 12,890' MD. A second stage job was then performed to isolate the Qannik using 90 bbl Class G cement; the plug bumped and stage tool successfully closed. A horizontal production section was drilled in the Kuparuk sand to a TO of 20,835' MD. The well was completed as a producer using slotted liner. A passing MITIA to 3500 psi was completed on 7/28/2015. CD5-25wp16.2 °a Quarter Mile View —] -4000 L -kms i gi-8000 0 ok0 I 1 a 2000 r 6000 O -20000 -24000 -8000 -4000 0 4000 8000 12000 16000 20000 24000 I L -kms i I I 1 Loepp, Victoria T (DOA) From: Dai, Weifeng <Weifeng.Dai@conocophillips.com> Sent: Thursday, January 11, 2018 3:05 PM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]RE: CD5-25(PTD 217-161); CD5-25L1(PTD 217-162) Injector Attachments: 3. CD5-251-1 PTD.doc; 3. CD5-25 PTD.doc Follow Up Flag: Follow up Flag Status: Flagged Sorry about that, I should have done it at the first time. Please see the attached. Weifeng Office: (907)-263-4324 Cell Phone: (907)-342-9508 From: Loepp, Victoria T (DOA)[mailto:victoria.loepp@alaska.gov] Sent: Thursday, January 11, 2018 2:37 PM To: Dai, Weifeng<Weifeng.Dai@conocophillips.com> Subject: RE: [EXTERNAL]RE: CD5-25(PTD 217-161); CD5-25L1(PTD 217-162) Injector Weifeng, Please show changes in re,_S in the PTD you have modified and send it to me. Thanx, Victoria From: Dai, Weifeng [mailto•Weifeng Dai@conocophillips com] Sent: Thursday, January 11, 2018 2:32 PM To: Loepp, Victoria T (DOA) <victoria.foe pp@alaska.gov> Subject: RE: [EXTERNAL]RE: CDS-25(PTD 217-161); CD5-25L1(PTD 217-162) Injector Victoria, Thanks for pointing it out as I was still using the old 500' rule. Revision has been made as per request. Please see the attached revised PTD. The TOC is now 278' TVD above the hydrocarbon bearing zone Alpine C. The production packer is now 265' MD below the TOC. Weifeng Office: (907)-263-4324 Cell Phone:(907)-342-9508 From: Loepp, Victoria T (DOA) [mailto:victoria.loepo@alaska eov] Sent: Thursday, January 11, 2018 10:40 AM To: Dai, Weifeng <Weifena.Dai@conocophillips com> Subject: [EXTERNAL]RE: CD5-25(PTD 217-161); CD5-25L1(PTD 217-162) Injector Weifeng, The intermediate cement planned is insufficient: 1. The TOC should be ^'250' TVD above the intermediate casing shoe. 2. The TOC needs to be above the production packer. Please revise. 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 Vlctona.LoeDD(Walaska oov 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 VictoCia.Loer)p@alaska.gov Patricia K From: Dai, Weifeng <Weifeng.Dai@conocophillips.com> Sent: Thursday, November 30, 2017 6:53 AM To: Bettis, Patricia K (DOA) Subject: RE: [EXTERNAL]FW: CRU CDS-25 (PTD 217-161) Permit to Drill Application Morning Patricia, Yes, we plan to pre -produce it for about 1 year before put it on injeciton. Weifeng Office: (907)-263-4324 Cell Phone:(907)-342-9508 From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Tuesday, November 28, 2017 10:56 AM To: Dai, Weifeng <Weifeng.Dai@conocophillips.com> Subject: [EXTERNAL]FW: CRU CD5-25 (PTD 217-161) Permit to Drill Application Weifeng, Did you receive this email? From: Bettis, Patricia K (DOA) Sent: Friday, November 24, 2017 12:20 PM To: Dai, Weifeng (Weifene DaiCcilconocoohillips com) <Weifeng.Dai(apconocoohillios com> Subject: CRU CD5-25 (PTD 217-161) Permit to Drill Application Good afternoon Weifeng, Does ConocoPhillips plan to pre -produce CRU CDS-25 and if so, what will be the duration? 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.bettisCdalaska.eov. TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: o -,/;Z Development Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: <z)u &- 91y4r POOL: (fbILIC11i Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter MULTI / LATERAL The permit'new wellbore segment of existing wIPermit I/ (If last two digits No. API No. 50-��- (:) Production should continue to be reported function in API number are as a of triginal API number stated above. between 60-69 In accordance with 20 AAC 25.005(fl 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 ermit . The permit is approved subject to full compliance with20 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. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first can t and 10' sample intervals through tar et 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. Com an Name) must contact the AOGCC to obtain advance approval of such water well testingProgram. 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(dx2)(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 COLVILLE RIVER, ALPINE OIL - 120100 Well Name: COLVILLE RIV UNIT CD5-251_1 Program SER Well bore seg ❑N PTD#:2171620 Company CONDC 'PHILLIPALASKA INC Initial Classrrype SER / PEND GeoArea 890 Unit 50360 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven, gas conforms to AS31.05,030(61.A).OZA-D) _ _ _ _ _ _ _ _ _ _ _ .....NA ...... _ _ 1 Permit fee attached _ _ _ _ _ _ _ _ _ _ _ _ .. _ _ _ _ NA- . _ _ - - - - - ... _ _ _ _ ... .... . ........ . 2 Lease number appropriate . . . . . . . .. . .... . .... . ............. Yes _ _ _ FEEOONPRA4, Surf, Top Prod &.TD; FEEOONPRA2, Portion Prod;_AA0092344, Portion Prod._ 3 Unique well name and number _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes ... - CRU CD5-25L1..... _ .... .... ......... ....... 4 Well located in a defined pool _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ . COLVILLE. RIVER, ALPINE OIL - 120100, governed by Conservation Order No. 443C.. 5 Well located proper distance from drilling unit. boundary...... _ ... - _ _ _ _ Yes _ _ _ CO 443C contains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance from other wells _ _ _ _ _ _ ... .. Yes _ _ _ CO 443C has no interwell 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 50V from an external property line where ownership or landownership changes._ 10 Operator has appropriate_ bond in force _ - - - - - - - - - - - - - - - - - - - - - - - - Yes ................... _ _ ...... _ ..... .... .... _ _ ... _ _ _ . .. _ Appr Date 11 Permit can be issued without conservation order _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 12 Permit can be issued without administrative approval . ......................... Yes PKB 11/3012017 13 Can permit be approved before 15 -day Walt _ _ _ ----------------------- Yes . ......................... 14 .Well located within area and strata authorized by Injection Order # (put 10# incomments).(For. Yes ....... AID. 18D ....................... 15 All wells within 1/4 mile area -of review identified (For service well only).... _ _ _ _ _ _ _ _ _ Yes _ CRU C05-20, C105-201_1, C05-313 _ _ 16 Pre -produced injector; duration of pre -production less then 3 months. (For service well only) . - Yes .. - _ - _ Plan topre-produce for 1 year (Dai 11/30/17). 18 Conductor string. provided _ _ _ ____ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ______ NA ...... Conductor setfor CRU C05-25 ..... Engineering 19 Surface casing protects all known USDWs ___ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ - _ .... Surface casing set in CRU CD5-25 .. - 20 CMT. vol adequate to circulate on conductor & surf csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ Plans. are to cement surface casing to surface...... _ 21 .. _ - . .......NA CMT vol adequate to tie-in long string to surf csg_............. 22 CMTwillcover all known-productiye horizons _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. _ No_ ...... _ Productive_ interval will be completed with uncemented liner with pert pups 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_ _ ____ NA_ _ _ _ _ Appr Date 28 Drilling fluid program schematic & equip list adequate .............. . ... . _ Yes - _ Max formation pressure is 3368 psig(8.3 ppg EMW); will drill w/8.8-9.5 ppg EMW, VTL 1/10/2018 29 BOPEs,.dothey meet regulation . . . . . . . . . ................. . . . . . . . . Yes _ _ _ _ _ _ _ _ _ _ _ _ _ .. _ 30 BOPE_press rating appropriate; test to (put prig in comments) . . . . . . ..... . . . . . Yes MPSP is 2571 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 H2$ gas probable . . . . . . . . . . . . ..................... _ Yes .. _ _ _ 112S measures required 34 Mechanical condition of wells within AOR verified (For service well only) ........ _ _ _ _ Yes _ _ _ _ _ _ _ Wells in AOR*,CRU CDS-20, CD5-2QL1, C05-313; mechanical condition acceptable . . . . . . . . . ....... . . 35 Permit can be issued w/o hydrogen sulfide measures . . . . . . . . ............No........ 112S measures required, Geology 36 Datapresented on potential overpressure zones. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ - _ . Expected reservoirprassure is 8.37 ppg EMW; will be drilled using 8.8 to 9,5 ppg mud... Appr Date 37 Seismicanalysis of shallow gas_ zones_ - - - _ - - _ ... _ _ _ _ _ _ _ _ _ _ NA PKB 11/24/2017 38 Seabed condition survey (if off -shore) . ........... . .. . _ _ _ _ _ _ NA _ _ _ _ _ _ _ 39 Contact name/phone for weekly progress reports [exploratory only] ... .... _ _ . _ _ _ NA - - _ _ _ _ Onshore service lateral to be drilled, _ _ _ _ _ _ _ _ _ _ Geologic Engineering Public Commissioner: Date: Date Date Commissioner: Commissioner t✓—A-v
