Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
218-093
ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Date: May 29, 2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W. 7th Ave Suite 100 Anchorage, AK 99501 COP reviewed cement evaluation activities for wells in response to AOGCC Industry Guidance Bulletin 25-001. There was no indication of cement evaluation logs being run for the following wells based on a review of all drilling files associated with well construction. Kuparuk River Unit/Field Well API #PTD #Comments 3G-13A 50103201370100 222-106 No cement bond logs run 2N-303A 50103203520100 214-088 No cement bond log run 2E-04 50029235050000 213-168 No cement bond log run TARN 2N-323A 50103202580100 213-159 No cement bond log run 1C-19 50029231490000 203-054 No cement bond log run By Gavin Gluyas at 9:48 am, Jun 02, 2025 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Colville River Unit/Field Well API # PTD # Comments CD3-303 50103205680000 208-013 No cement bond log run ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Greater Mooses Tooth Unit/Field Well API #PTD #Comments MT6-06 50103207730000 218-093 Production well, CBL was not run across 7”liner MT6-06 50103207730000 218-093 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 10, 2020 Commissioner Jesse Chmielowski Alaska Oil & Gas Commission 333 West 7`h Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jesse Chmielowski: RECEIVED Mpl,'Y 13 2020 AOCCC Enclosed are the spreadsheets with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement/sand if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement/sand was installed April 215f thru April 24`h, 2020. The corrosion inhibitor/sealant was pumped on April 22°d thru April 25`h, 2020. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerel !, � Roger Winter ConocoPhillips Well Integrity Field Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) Alpine Field Date 5/10/2020 CD2, 3, 4 & MT6 Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement/Sand top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal CD2 -02 *501032051300 2051090 30" 14 gals 9" 4/24/2020 1.5 4/25/2020 CD2 -73 *501032059000 2081960 11" 1 gal 6" 4/24/2020 0.5 4/2512020 CD2 -468 *501032058700 2081800 11" 1 gal 7" 4/24/2020 0.8 4/25/2020 CD3 -111A *501032052601 2170040 14" 4 gals V. 4/21/2020 1.3 4/22/2020 CD3 -198 *501032063700 2110240 10" 10" 3 4/22!2020 CD4 -215 *501032053900 2061570 40" 28 gals 9" 4/23/2020 1.4 4/23/2020 CD4 -291 *501032067200 2131100 2r 80 gals 6" 4/23/2020 0.5 4/23/2020 CD4 -321 *501032053600 2061420 18.5' 4 gals 6" 4/23/2020 0.5 4/23/2020 MT6-02 *501032079200 2181600 30" 14 gals 8" 4/23/2020 1 4/24/2020 MT6-03 *501032077000 2180160 49" 32 gals 10" 4/23/2020 1.7 4/24/2020 MT6-04 *501032077500 2181080 24" 17 gals 8" 4/23/2020 1 4/24/2020 MT6-05 *501032077100 2180450 30" 10 gals 7" 4/23/2020 1.3 4/24/2020 MT6-06 *501032077300 2180930 25' 7 gals 8" 4/23/2020 1 4/24/2020 MT6-08 *501032077200 2180480 12" 2.5 gals 7" 4/23/2020 1 4/24/2020 MT6-09 *501032077900 2181340 34" 15 gals 9" 4/23/2020 1.5 4/24/2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS by-.. ,.... .... ........ .. ._ _ MAY 3 0. 2019 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑+ Pull Tubingp ❑ Operations s Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing E] Change Approved�lQ Plug for Reddll ❑ ertorate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Omer. ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillipS Alaska, Inc. Development ❑+ Exploratory ❑ 218-093-0 3. Address: P, O. Box 100360, Anchorage, Alaska Stratigraphic❑ service ❑ 6. API Number: 99510 50-103-20773-00-00 7. Property Designation (Lease Number): a. Well Name and Number: AA081818, AA092348, AA061798, AA092342 MT6-06 9. Logs (List logs and submit electronic and printed tlais per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: N/A Greater -- Be Tooth Unit/Lookout Pool rola[ Depth measured 17,482 feet Plugs measured None feet true vertical 8,111 feet Junk measured None feet Effective Depth measured 17,482 feet Packer measured 9541, 11665 feet true vertical 8 111 feet true vertical 8650, 7928 fee[ Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 feet 20 115' MD 115' TVD SURFACE 2,081 feet 13 3/8 " 2,118' MD 2003' TVD INTERMEDIATE 10,282 feet 9 5/8 " 10,316' MD 7245' TVD 7" TIE -BACK 9,502 feet 7 9,534' MD 6544' TVD 7" LINER 2,313 feet 7 11,833' MD 7983' TVD 4 1 /2" LINER 5,162 feet 41/2" 16,826' MD 9085' TVD Perforation depth: Measured depth: 11903'- 16826' feet True Vertical depth: 8001'- 8085' feet Tubing (size, grace, measured and true vertical depth) 4.5 " L-80 11,675' MD 7,931' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - SLZX Liner Hanger Packer 9,541' MD 6,650' TVD PACKER - HRDE ZXP Packer 11,665' MD 7,928' TVD SSSV NONE MD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 11903-16826 Treatment descriptions including volumes used and final pressure: Total Well -1 Stage 400,960lbs placed.... See attached schematic for full FRAC details 13. Representative Daily Average Producti0 or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1400 380 Subsequent to operation: 494 569 27 7384 484 14.Attachments(required per 20 MC 25.070,25.071, 925.293) 15. Well Class after work: Daily Report of Well Operations 21 Exploratory ❑ Development ❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ �J�( 16. Well Status after work: Oil El Gas 0 WDSPL E] Printed and Electronic Fracture Stimulation Data tr/ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-064 Authorized Name: Adam Klem Contact Name: Adam Klein Authorized Title: Com letion En ineer ``Contact Email: adam. klem (QCOp.COm Authorized Signature / Date: S/r4 9,//? Contact Phone: (907) 263-4529 VrL ('11111.7 7w/7 o6I(O/y Ht3UMbM" MAY 3 12019 Submit Original Only / V WNS PROD WELLNAME MT6-06 WELLBORE MT6-06 OPhiI'ins /� �' Well Attributes Max Angle 8 MD TD 1" IFieoa me (Wellbore gPVUWI IWe11Wre$Gtue 11nJcl�°Q MB �n%BI ACI Bim^earg A85kE.Ir1C, LO(lK!)I1T Sn1B"iJBJ]inn PRIIn 6 rn -rc n t-rnna MTBre. Sr%A19B5?19 PM1 Last Tag Verlk lxlanaEalavMll printer. p¢pN 1aK01 Entl Oate1 WeREore Last Mntl By f armERxaB LAST TAG 1.T6-06 ijennalt Last Rev Reason Annopflon End Gale WNIWre Laatmet By -._-- ......_._.........._.. __.._...... Rev Reason'. Post Frac Wellwork 3/1312019 [a -O6 ....h Casing Strings Casing Descnption OD lint CONDUCTOR 20 10 on) Top MKBI Set Depth miss) het Dealt TD) ty",p... Grade 1912 36.9 115.0 115.0 94.00 11-40 Top TnmO Welded � cccchm QroR.sastLso FWd petal ars.Casing f OCO o.1a11 /S%8 A--bFlw- Diartl: m.b u Counp Des pain ODpm SURFACE 13318 106-1 ToPtl Set Depth (MB) SN Depth Rnim. WVLen 6... GrvOe 1242 36.9 2.1180 20032 68.00 L-00 Tap Threes TXP DesarlWut 00 (an) 9510"INTERMEDIATE 95M IO gin) TZ lrtl(8) 9N Oepth 6tl{B) get Dep+n IND)... VALen (1... Gmtle 8.84 340 10,3160 ],2449 4000 LA0 Top Threao TXP 1bJ U, ow'ser8 C-1, Deperia n OD (in) T' TIE BACK STRING 7 ID(in) Tolia l SOOeproppa Stt OTI, wcm.. WMIen(I GmUe 6.28 32.2 9,534.0 6,6440 26.00 1 Tap Thread H563 Cmlrp DesellpYon Do (in) 1"SDL LINER 7 ID lint Tap6Y(B) aperpMl DellKBI ser Depin IN01... apmen(I...GraM 620 9,5196 11,833.0 )9826 32.00 LA0 Top Thread Tenons Blue Liner Details NIPPMX2.IM2 TaP 11Ke) Toplf n%Gl topnl con, xominate 6n1 9,519.5 6,632.3 35.93 SDE Seal Bore Extension 6.150 SURFADE; W".its0 9,541.1 6,649] 35.93 PACKER SLZX Liner Hanger Patica 3.7 Gas uFr; a'.5 9.5524 6,658.9 3593 TEALASSY Latching Seal easy (5,76 seals in LSS below) 6,276 arur FlW-selnmrenre; t,am "Ane"). tatamfe 9.555.2 6,661.1 35,93 ETTING HRD-E Liner San, Sleeye SLEEVE 7.735 mruw R,. uss.nrredm; +,amoN.DsOnaxtrmte 9,563.8 6668.1 35.93 DICK H Liner Quick ammo ..BUlet eats 0 CONNECT Tenaris Blue 6.150 11,826.9 ; 872% STABILIZER Reamer 6ce tabilisor wi pine mre, p 6.080 OSS u". B1mT MYS110 Tenons Blue C.On. Desadplon 0011-1 -FO (in-) Top MK8) 9Naphpfisj 9N m"m"no'.. WUIn 6... Top TWOO LINER 490 Late 396 11,664.6 16826.3 $0854 12.60 LA0 TXP Liner Details r7hRoACKSTRues,gi.2 Sssf.D Top fnKal rap rv0 Pl I6IX0) Tap loot rl Irtm Des com Nomhull0 r-1 t 1.664.8 7927.8 m, ul PACKER ut:Z !, 500"SBE (15.94') M521 pin 3.875 11,6912 7937.2 mi ch HNAGER la -l" a7" Flex lock 1-1gr11521 Pag.Pin 3860 Tubing Strings Tuning Oesapoon slrina ma... TUBING 4112 m 6n) 3.96 top (XI(B) 288 get Degn (n. 11,6746 set pepM (ry0)1... 7,931.3 Wt(IMII) 12.60 Onde L-80 Top connecthin TWue PRODUCTION liW a,m RMEDWE; ]9.& 10,31ao� Completion Details ninuW Fue-EYMbe/eM1p; 9.Lp-l'. atadVAaa �9. ToP inert roPmtl Top1nKB) fM01 V) IMm Des Com Norriel to (in) Memo. v.4aex Annular Fluty- san✓abr 28.8 288 000 HANGER FMC 4.112" -Tb of, HanBer H533 3958 nnw.wtemo.lenerena 2,100.2 1,995.0 3321 NIPPLE% L,LANmN,1 X,. ",TSH Blo, 3.813 Id sem ^POlisS Bore Integrity Suspect 10120118^ oneric r, sauce,- 1 2 11,556. 7,886.9 6674 GAUGE SGM,4112',S HLUMBERGER Sold Gauge Mandrel 3.879 11,611.4 ],9082 67.87'RIPPLE -XN NIPPLE,IANDIN ,412'% 3813' XN w13.725"No-Go. TSH Blue 3.725 one. %H: 11,B11A 11,69U 7,9257 6888 LOCATOR Locator No -Go 545"00 ASSY 3,950 LocaioR; 11.a 11,650.3 7,9262 68.91 TEAL Seal Assembly 3.950 a .,VDSY; n W 2 Perforations B Sbis snap Toppallh Stories) Toplrvo) 6 6) ar.o.,D) asset Unaed Lone Date Ianoum 1 Tyq Cam 11,903.0 16,826.3 8,0008 8,005.d ALPC, MT6-O6 lwwlu18 PERFP Frac Summary rSOLUMEel astes-01,833.O L stilt D. pmppsm Designed (to)proPpanrinmra iotlon pet 3(9(2019 400,960.0 SIBtl 91ar1Dale Top Depthguit, .. copu) fink he Fluty 9ysbm VaICWn(Ynit 1 3(912019 FRAC FLUID, 350 Hybor-G Val Slurryryn9 Mandrel Inserts S, m (ND) N TapMa Toilette) IRKa) Wlve --a Po(isize iRhe Run ke Madel oDlln) 9•ry rype Type lin) her.) Run Dab eom 1 4,084.5 3,406.0 Cancer KBG-2 1 GAS LIFT GLV BK -5 0.188 1 ]630 3I12R019 2 8,1017 55813 Camco KBG, 1 GAB LIFT GLV BK -5 0.188 1]920 3/1312019 3 11,4092 7,826.2 Camco KBG, 1 1.11111 10V OK -5 1 .1111 0.0 3/13120,9 Notes: General 8 Safety End cap,::[- Annotation N OFF PERFP, 11,ODaa10,10i .I. Phil -MOBN; I1,65coa q.a83R 1a1.8 LINER; I1FN.btaaYo 3 MT6-06 FRAC STIMULATE DTTMSTAJOBTYP SUMMARYOPS 3/9/19 DRILLING PREFORMED FRACTURE STIMULATION TREATMENT AT 32 BPM SUPPORT- UTILIZING TTS SLIC FRAC DIVERSION SYSTEM, PLACED 400,828# CAPITAL 20/40 WANLI PROPPANT, WELL IS FREEZE PROTECTED. 3/11/19 DRILLING PREFORMED FRACTURE STIMULATION TREATMENT AT 32 BPM SUPPORT- UTILIZING TTS SLIC FRAC DIVERSION SYSTEM, PLACED 400,828# CAPITAL 20/40 WANLI PROPPANT, WELL IS FREEZE PROTECTED. 3/12/19 DRILLING PULLED DV @ 4084' RKB. REPLACED WITH 3/16" GLV (TRO = 1763). SUPPORT- PULLED CAT SV @ 1161 1'RKB. BRUSH & FLUSH TBG TO 11 700'RKB CAPITAL WITH 90 BBL'S LEPD DIESEL. IN PROGRESS. 3/13/19 DRILLING DEPLOY CACHER SUB TO 1161 1'RKB. PULL DV @ 11409' RKB. SUPPORT- REPLACE WITH 1/4" OV. PULLED DV @ 8102' RKB. REPLACE WITH CAPITAL 3/16" GLV (TRO = 1792). PULLED CATCHER SUB @ 11611' RKB. JOB COMPLETE Hydraulic Fracturing Fluid Product Component Information Disclosure Job Start Date: Job End Date: State: County: API Number: Operator Name: Well Name and Number: Latitude: Longitude: Datum: Federal Well: Indian Well: True Vertical Depth: Total Base Water Volume (gal): I Total Base Non Water Volume: 3/9/2019 3/9/2019 Alaska Harrison Bay 50-103-20773-00-00 ConocoPhillips Company/Burlington Resources MT6-e6 70.25601300 Hydraulic Fracturing Fluid Composition: -151.48187200 NAD83 NO NO 8,110 252,737 0 4MM %c Focus l Chemical Disclosure Registry GQOU\DINATER I OU Gas Chemical Maximum Maximum Abstract Ingredient Ingredient Trade Name Supplier Purpose Ingredients Service Concentration Concentration Comments Number in Additive in HF Fluid (CAS #) (% by mass)" (% by mass)" Sea Water Operator Base Fluid Water 7732-18-5 96.00000 79.01013 Density = 8.540 Ingredients Listed Above Listed Above Water 7732-18-5 100.00000 0.08639 Wanli-20/40 Halliburton Additive Listed Below OPTIFLO-III DELAYED RELEASE BREAKER Halliburton Breaker Listed Below Bio-Rez Lo POD Thru Tubing Solutions Additive Listed Below SP BREAKER Halliburton Breaker Listed Below MO -67 Halliburton pH Control Additive Listed Below BE -6 MICROBIOCIDE Halliburton Biocide Listed Below LVF -200 Penreco Additive Listed Below WG -36 GELLING AGENT Halliburton Gelling Agent Listed Below CL -22 LIC Halliburton Crosslinker Listed Below CL -31 CROSSLINKER Halliburton Crosslinker Listed Below LOSURF-300D Halliburton Non-ionic Surfactant Listed Below Items above are Trade Names with the exaspton of Base Water Items below am the individual ingredients. Corundum 1302-74-5 55.00000 8.40911 Mullite 1302-93-8 45.00000 6.88018 Sodium chloride 7647-14-5 4.00000 3.29345 Hydrotreated Distillate, 64742-47-8 light C9-16 100.00000 1.87450 Guargum 9000-30-0 100.00000 0.28664 Borate salts Proprietary 60.00000 0.05995 Potassium formate 590-29-0 60.00000 0.05995 Ethanol 64-17-5 60.00000 0.04009 Oxylated phenolic resin Proprietary 30.00000 0.02673 Heavy aromatic 64742-94-5 petroleum naphtha 30.00000 0.02004 Potassium metaborate 13709-94-9 60.00000 0.01997 Sodium hydroxide 1310-73-2 30.00000 0.01093 Ammonium persulfate 7727-54-0 100.00000 0.00877 Naphthalene 91-20-3 5.00000 0.00334 Poly(oxy-1,2-ethanediyl), 127087-87-0 alpha-(4-nonylphenyl)- omega-hydroxy-, branched 5.00000 0.00334 Crystalline silica, quartz 14808-60-7 30.00000 0.00273 Cured acrylic resin Proprietary 30.00000 0.00263 Potassium hydroxide 1310-58-3 5.00000 0.00166 Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water Information is based on the maximum potential for concentration and thus the total maybe over 100% If you are calculating a percentage of total ingredients do not add the water volume below the green line to the water volume above the green line Note: For Field Development products (products that begin with FDP), MSDS level only information has been proNded. Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Shasta (MSDS) 2-Bromo-2-nitro-1,3- 52-51-7 100.00000 0.00133 propanediol Sodium glyoollate 2836-32-0 1.00000 0.00100 Acrylate polymer Proprietary 1.00000 0.00100 Denise Tuck, Halliburton, 3000 N. Sam Houston Pkwy E., Houston, TX 77032, 281-871-6226 Sodium carboxymethyl 9004-32-4 1.00000 0.00100 cellulose 1,2,4 Trimethylbenzene 95-63-6 1.00000 0.00067 Sodium persulfate 7775-27-1 100.00000 0.00042 Proprietary Blend Proprietary 100.00000 0.00038 Sodium sulfate 7757-82-6 0.10000 0.00000 Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water Information is based on the maximum potential for concentration and thus the total maybe over 100% If you are calculating a percentage of total ingredients do not add the water volume below the green line to the water volume above the green line Note: For Field Development products (products that begin with FDP), MSDS level only information has been proNded. Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Shasta (MSDS) HALLIBURTON Sales Order# 905550570 Conoco Phillips, Alaska Inc. MT6-06 Interval Top Alpine C Formation Harrison Bay County, AK API: 50-103-20773 Prepared for: Adam Klem March 9, 2019 Stimulation Treatment Post Job Report 35# Hybor-G Prepared By: Landon Harrison Chad Burkett Nanook Crew Notice: Although the information contained in this report is based on sound engineering practices, the copyright owner(s) does (do) not accept any responsibility whatsoever, in negligence or otherwise, for any loss or damage arising from the possession or use of the report whether in terms of correctness or otherwise. The application, therefore, by the user of this report or any part thereof, is solely at the user's own risk. HALLIBUR7TON Table of Contents Section Page(s) Executive Summary 3 Actual Design 4 Interval5ummary 5-9 Fluid System-Proppant Summary 10 Interval Detaik 11 Interval I Plots 12 -1] Appendix 18 Chemical Summary 19 Planned Design 20 Water Straps 21 Field Water Analysis 22 Real -Time QC 23 Wellbore Information 24 Event Log 25-26 15 min XL -Treatment 1 27 15 min XL -Treatment 2 28 15 min XL - Treatment 3 29 15 min XL- Treatment 4 30 Lab Testing 31-34 Conoco Phillips, Alaska Inc. - MT6-06 TOC Engineering Executive Summary On March 09, 2019 a stimulation treatment was performed in the Top Alpine C formation on the MT6-06 well in Harrison Bay County, AK. The MT6-06 was a 1 stage Horizontal Sleeve Design. The proposed treatment consisted of: 245,129 gallons of 35# Hybor-G 7,609 gallons of 35# WaterFrac-G 1,300 gallons of Freeze Protect 400,000 pounds of Wanli 20/40 80 pounds of TTS Pods The actual treatment fully completed 5 of 1 stages. 0 stages were skipped, and 0 stages screened out or were otherwise cut short of design. The actual treatment consisted of: 223,661 gallons of 35# Hybor-G 7,979 gallons of 35# WaterFrac-G 1,470 gallons of Freeze Protect 400,960 pounds of Wanli 20/40 80 pounds of TTS Pods A more detailed description of the actual treatment can be found in the attached reports. The following comments were provided to summarize events and changes to the proposed treatment: Did not pump minifrac per customer engineer request. Did not pump the 3.5# sand stage in the first sand ramp per customer engineer's request due to low treating pressure; pumped all 3.5# sand in the 4.0# sand stage. Did not drop rate for second and third TTS pod drops per customer engineer's request. Did not collect fluid samples after the pad stage of the last group per customer engineer's request to going near redzone. Had a couple issues with CL-22UC and CL -31 cutting unintentionally duringiob, blender operator worked to correct issues immediately, did not experience any issues with placing proppant during any event. Halliburton is strongly committed to quality control on location. Before and after each job all chemicals, proppants, and fluid Changed breaker setpoint from the planned 2.00 pot on OptiFlo-Ill and 0.25 ppt on OptiFlo-11 in original design to 1.00 ppt on OptiFlo-111 and no OptiFlo-11 based on operational lab testing performed in Deadhorse lab with customer engineer's approval. Halliburton maintains a continuous quality improvement process and appreciates any comments or suggestions that you may have. Halliburton again thanks you for the opportunity to perform service work on this well. We hope to be your solutions provider for future projects. Thank you, Landon Harrison Technical Professional Halliburton Energy Services Conoco Phillips, Alaska Inc. - MT6-06 Executive Summary Conoco Phillips, Alaska Inc. - MT6.06 Actual Design MT6-06 - Top Alpine C - Group 7 Interval Summary Start Date/Time: 3/9119 12:36 End Date/Time: 3/9/1913:31 Pump Time: 55 min Initial Rate (Breakdown): 29.0 bpm Initial Surface Pressure (Breakdown): 4,526 psi Max Rate: 32.0 bpm Max Surface Pressure: 4,715 psi Average Rate: 31.4 bpm Average Missile Pressure: 3,258 psi Average Surface Pressure: 3,353 psi Average Missile HHP: 2,507 hhp Initial OA Pressure: 450 psi Max OA Pressure: 541 psi Max Proppant Concentration: 4,17 Ppg Average Visc: 39 CP Average Temp: 92 F Average pH: 9.4 ISIP: 1683 psi Initial Fracture Gradient: 0.653 psi/ft Proppant Summary Wanli 20/40 Pumped: 100,970 Its TTS Pods Pumped: 0 Ibis Total Proppant Pumped' : 100,970 lbs Proppant in Formation: 100,970 lbs Fluid Summary (by Fluid description) Sea Water Volume: 0 gal 0 bbls 35# Hybor-G Volume: 53,436 gal 1,272 bbls 35# WaterFrac-G Volume: 7,979 gal 190 bbls Freeze Protect Volume: 1,470 gal 35 bbls Fluid Summary (by stage description) Load Well Volume: 0 gal 0 bbls Pad Volume: 8,894 gal 212 bbls Proppant Laden Fluid Volume: 42,482 gal 1,011 bbls Spacer Volume: 2,060 gal 49 bbls Flush Volume: 7,979 gal 190 bills Minifrac Volume: 0 gal 0 bills Freeze Protect Volume: 1,470 gal 35 bills TTS Pods Volume: 4,280 gal 102 bbls Interval Status: Completed stage. Pumped group to design, all proppant placed per design.I Treater.' Daniel Faur Supervisor: Chad Burkett for proppant are taken from software calculations based on multiple variables. I Customer Eng: Sandeep Pedam I is billed off of weight ticket volumes and may vary slightly from this number. Customer Rep: Paul Bessette Interval Summary Jill - Top Alpine C - Group 2 Interval Summary Start Date/Time: 3/9/19 13:31 End Date/Time: 3/9/19 14:17 Pump Time: 46 min Initial Rate (Breakdown): 31.4 bpm Initial Surface Pressure (Breakdown): 3,281 psi Max Rate: 31.9 bpm Max Surface Pressure: 3,405 psi Average Rate: 31.5 bpm Average Missile Pressure: 2,901 psi Average Surface Pressure: 2,992 psi Average Missile HHP: 2,240 hhp Initial OA Pressure: 525 psi Max OA Pressure: 549 psi Max Proppant Concentration: 4.16 ping Average Visc: 30 cp Average Tamp: 88 F Average pH: 9.6 Proppant Summary Warth 20/40 Pumped: 101,010 lbs TTS Pods Pumped: 20 lbs Total Proppant Pumped' : 101,010 lbs Proppant in Formation: 101,010 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbls 35# Hybor-G Volume: 54,386 gal 1,295 bbls 35# WaterFrac-G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Load Well Volume: 0 gal 0 bbls Pad Volume: 8,759 gal 209 bbls Proppant Laden Fluid Volume: 43,724 gal 1,041 bbls Spacer Volume: 1,494 gal 36 bills Flush Volume: 0 gal 0 bills Minifrac Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls TTS Pods Volume: 409 gal 10 bbls Interval Status: Completed Fressures from diverter was a pre -hit of 3,057 psi, post -hit was 3,281 psi for differential pressure Engineer: Landon Harrison of+224 psi. Start of TTS drop was 1,387 bbl on slurry volume; start of pressure build was 1,463 Treater: Daniel Faur bbl. Pressure build was 105 bbl early compared to 1 wellbore volume. Pumped group to Supervisor: Chad Burkett completion, all proppanl placed per design. „e taken from software calculations based on multiple variables Customer Eng: Sandeep Pedam weight ticket volumes and may vary slightly from this number. Customer Re P' Paul Besserie Interval Summary 6 MT6-06 - Top Alpine C - Group 3 31.7 Interval Summary Start Date/Time: 3/9/19 14:17 End Date/Time: 3/9/19 15:04 Pump Time: 47 min Initial Rate (Breakdown): 31.7 bpm Initial Surface Pressure (Breakdown): 3,404 psi Max Rate: 31.7 bpm Max Surface Pressure: 3,340 psi Average Rate: 31.5 bpm Average Missile Pressure: 2,971 psi Average Surface Pressure: 3,053 psi Average Missile HHP: 2,294 hhp Initial OA Pressure: 535 psi Max OA Pressure: 560 psi Max Proppant Concentration: 4.41 ring Average Visc: 32 CP Average Temp: 92 F Average pH: 9.6 45 bbls Proppant Summary 0 Wal 20/40 Pumped: 100,763 lbs TTS Pods Pumped: 20 lbs Total Proppant Pumped* : 100,763 lbs Proppant in Formation: 100,763 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbls 35# Hybor-G Volume: 57,598 gal 1,371 bbls 35# WaterFrac-G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Load Well Volume: 0 gal 0 bb/s Pad Volume: 9,861 gal 235 bbls Proppant Laden Fluid Volume: 43,716 gal 1,041 bbls Spacer Volume: 1,897 gal 45 bbls Flush Volume: 0 gal 0 bbls Minifrac Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls TTS Pods Volume: 2,124 gal 51 bbls Interval Status: Completed ulama crop rate for second I I b crop per customer engineer. I I b pods were dropped at 2,803 bbl Engineer Landon Harrison on slurry volume; pressure build was 2,891 bbl; pods hit early by 93 bbl. Start of pressure build Treater: Daniel Faur was 3,165 psi; peak pressure was 3,404 psi; pressure differential was +239 psi. Pumped group to Supervisor: Chad Burkett completion, All proppant placed. Values for proppant are taken from software calculations based on multiple variables. Customer Eng: Sandeep Pedam Proppant is billed off of weight ticket volumes and may vary slightly from this number. Customer Rep: Paul Bessette Interval Summary 7 - Tnn Glninp C - Start Daterf ime: 3/9/19 15:04 End Date/Time: 3/9/19 16:08 Pump Time: 64 min Initial Rate (Breakdown): 31.7 bpm Treater: Daniel Faur from 3158 psi to 3468 psi, which is a differential of+310 psi. Stopped collection samples after pad Initial Surface Pressure (Breakdown): 3,468 psi Pumped group to completion, All castles empty; All proppant placed. Max Rate: 31.8 bpm Customer Rep: Paul Bessette Max Surface Pressure: 3,564 psi Average Rate: 31.3 bpm Average Missile Pressure: 3,295 psi Average Surface Pressure: 3,209 psi Average Missile HHP: 2,528 hhp Initial OA Pressure: 558 psi Max OA Pressure: 562 psi Max Proppant Concentration: 4.25 Ppg Average Visc: 35 CP Average Temp: 9.5 F Average pH: 87 ISDP: 2508 psi Final Fracture Gradient: 0.756 psi/ft Proppant Summary Wanli 20/40 Pumped: 98,217 lbs TTS Pods Pumped: 40 lbs Total Proppant Pumped' : 98,217 lbs Proppant in Formation: 98,217 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbls 35# Hybor-G Volume: 58,241 gal 1,387 bbls 35# WaterFrac-G Volume: 7,979 gal 190 bbls Freeze Protect Volume: 1,470 gal 35 bills Fluid Summary (by stage description) Load Well Volume: 0 gal 0 bbls Pad Volume: 8,844 gal 211 bbls Proppant Laden Fluid Volume: 47,650 gal 1,135 bbls Spacer Volume: 0 gal 0 bbls Flush Volume: 7,979 gal 190 bbls Minifrac Volume: 0 gal 0 bbls Freeze Protect Volume: 1,470 gal 35 bbls TTS Pods Volume: 1,747 gal 42 bbls Interval Status: Completed Stan pressure Duilo for olvener Immemately atter shutting down acid pumper at 4,SU4 ON of Slurry tnglneer Landon Harrison volume, started pumping TTS balls at 4,271 bbl on slurry, hit was 148 bbl early. Pressure built Treater: Daniel Faur from 3158 psi to 3468 psi, which is a differential of+310 psi. Stopped collection samples after pad stage per customer engineer's request to keep EE's completely out of the area of the redzone. Supervisor.' Chad Burkett Pumped group to completion, All castles empty; All proppant placed. ✓alues for proppant are taken from software calculations based on multiple variables Customer Eng: Sandeep Pedam I roppant is billed off of weight ticket volumes and may vary slightly from this number Customer Rep: Paul Bessette Interval Summary 8 Mrs -Oft - Top alpine C - Interval 7 29,0 Interval Summary Start Date/Time: 3/9/19 12:36 End Date/Time: 3/9/19 16:08 Pump Time: 212 min Initial Rate (Breakdown): 29,0 bpm Initial Surface Pressure (Breakdown): 4526.0 psi Max Rate: 32.0 bpm Max Surface Pressure: 4,715 psi Average Rate: 31.5 bpm Average Missile Pressure: 3,074 psi Average Surface Pressure: 3,164 psi Average Missile HHP: 2,373 hhp Initial OA Pressure: 448 psi Max OA Pressure: 563 psi Max Proppant Concentration: 4.41 ppg Average Visc: 34 CP Average Temp: 91 F Average pH: 9.5 ISIP: 1683 psi Initial Fracture Gradient: 0.653 psi/ft ISDP: 2508 psi Final Fracture Gradient: 0.756 psi/ft Proppant Summary Wanli 20/40 Pumped: 400,960 lbs TTS Pods Pumped: 80 Ibs Total Proppant Pumped' : 400,960 lbs Proppant in Formation: 400,960 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbls 35# Hybor-G Volume: 223,661 gal 5,325 bbls 35# WaterFra -G Volume: 7,979 gal 190 bills Freeze Protect Volume: 1,470 gal 35 bbls Fluid Summary (by stage description) Load Well Volume: 0 gal 0 bbls Pad Volume: 36,358 gal 866 bbls Proppant Laden Fluid Volume: 177,872 gal 4,228 bbls Spacer Volume: 5,451 gal 130 bbls Flush Volume: 7,979 gal 190 bbls Minifrac Volume: 0 gal 0 bb/s Freeze Protect Volume: 1,470 gal 35 bbls TTS Pods Volume: 4,280 gal 102 bbls Interval Status: Completed aKlppeo mmmac per customer engineer request. sKlppea a.e# sena stage and put an send Into engiri Landon Harrison 4# sand stage. Pumped treatment to design, all proppant placed per design. all castles empty. Treater.' Daniel Faur Supervisor: Chad Burkett 'aloes for proppant are taken from software calculations based on MUstre variables. Customer Eng: Sandeep Pedam I mppant is billed or of weight ticket volumes and may vary slightly from this number Customer Rep: Paul Bessette Interval Summary 9 Customer Conoco Phillips, Alaska Int Formation Tap Alpine Lease W"6 An 50.103 60773 Date March 09, 2019 Well Summary WILLIBURTON Planned Recorded Hinds Flwda Psalms.. Ino -al sea Water 35a Hybor-G as. Washer—G Freeze P.. Tend Fluid Wan620/40 TTS Podx ToblProppant 354 WaterFnW gal bbl gal 1 bbl gal 1 bbl gal 1 bbl I gal bbl IDS lbs IDS 1 83,661 1 5,325 1 7,979 1 190 1 1,470 1 35 1233,110 5,550 4CO3%0 g0 401,010 Planned Recorded aotltiplevaXablea e` PreppaM In billed fsam Weight Ticket volumes Conoco Phillips, Alaska Inc. - MT"6 Fluid System-Prappant Summary Flwda Psappants Sea Water 35N Hyior-G 354 WaterFnW freeze P.. Total Fluid Wang Wile IIS Pod. Tatal Paoppant Bal bbl gal bbl sal bbl gal bbl gal 661 Ibs Ibs Total 0 D 245,129 5,836 7,609 181 L3D0 31 ]fi1,646 6.230 400,CO0 g0 400,1180 0 0 1 223,661 1 5,325 7,979 1 190 1 L470 1 35 1 233,110 1 5,550 I 400,96D I w 4D1.D40 Weight TlcI,m 400,960 1 80 40L04D aotltiplevaXablea e` PreppaM In billed fsam Weight Ticket volumes Conoco Phillips, Alaska Inc. - MT"6 Fluid System-Prappant Summary wR4rc[a• ax xc XALLIRURTM Conoco Phillips, Alaska Inc. -W6R 6 Interval D.Wis wlwl o- vry `IWM mrtare/nmewaw/�x. eu:ym. •In0 µ ayalrt m an a1n,rt alµlrt nwM1 Mesal Neal In0 M.n kol RRp Hmlm wort WI UO Scapa YVvv:x a/s/uv m aaya ya/bav f/yaeu ;f p1 S9fi i1W ]p5 RS W •/z/ascan La/asua evga :/Lu ya/v u:m a}f57. ayn ;SR l.W I— um vm Mnp R ;aN 3.W M. n#9 ayR Yalas ZZLmiximum Conoco Phillips, Alaska Inc. -W6R 6 Interval D.Wis Pressure Test -Treatment) Treating Pressure (psi) Treating Pressure @Pump (psi) 11 Global Kickoul Pressure (psi) P1 Kickout Pressure (psi) lime Customer: CONDOOPHILLPS NORTH SLOPE- EBL14 I ,bb Date: 09-W-2019 Saks Order* 0912345678 Wed Description: Mr606 lMR 50-103-20773 Conoco Phillips, Alaska Inc. - MT&06 Interval 1 Plots Gobal Event Log Intersection TP Intersection TP Q Pressure Test-GLOBALS 11:25:21 127.5 ® Pressure Test -LOCALS 11:25:37 420.0 Q PressureTest-70% 11:27:17 6285 ❑5 PressureTest-Mex 11:29:22 8055 Customer: CONDOOPHILLPS NORTH SLOPE- EBL14 I ,bb Date: 09-W-2019 Saks Order* 0912345678 Wed Description: Mr606 lMR 50-103-20773 Conoco Phillips, Alaska Inc. - MT&06 Interval 1 Plots Pop -Off Test -Treatment 1 11 Global Kickout Pressure (psi) P1 Kickout Pressure (psi) 11:38 11:40 11:42 1144 11:46 WW2019 Time W9I2019 G obal Event Log Intersection TP Intersection TP PressureTest-PRV 113848 6984 Q Bleed -Off to Retest PRV 114053 285.9 ❑8 Pressure-PRVOonfin 11:43:50 7002 customer: CONOCOPHILLIPS NORTH SLOPE- ®l15 Job Date: 09-kbr-2019 Sales Order #: 0912345678 Well Description: MIS 06 INN: 50-103-20773 Conow Phillips, Alaska Inc. - Mr6-06 krtercal 1 Plois 13 Treatment Plot -Treatment 1 Treating Pressure (psi) A Slurry Rate (bpm) B A Slurry Proppant Conic (Ib/gal) — C BH Proppant Conic (Ib/gal) C B C Time wstorner: GUNUUUPHLLPS NDRTH SLOPE- ®l1SI J�Date: 509-2019 0- 0320773 Sales Order M 0912345676 Wei Description: MTS 06 Conoco Phillips, Alaska Inc. - MTe-0e Interval 1 Plots Blender Chemical Plot - Treatment 1 A 2.0 1.8 1.6 1.4 1.2 1.0 0.8 0.6 0.4" o.z- 1 illloll W� yu.11i I!l��ryl.I kill,�L�w�14V1.1 YYIIM MII YIY II I IY P I'AA 01 "uj'Wn,," L*11W UA wasi i■■yi A" 14-101"1 1111 ff� �� A L. Ilk, JII 111.41 IIMWMM'rYAI yM114114L YiW IY/N41'�II I 1 Y. 0.0 iii i I II1 I � p� ■ 11 o.z- 1 0.0 iii i I II1 13:00 13:30 14:00 14:30 15:00 15:30 WW2019 Time &9/2019 Custorrer: WNOQDR-CLIPS NORTH SLOPE -®US .bb Dl 09-kbr-2019 Sales Ortler#: 0912345676 We9 Description: MI6 O6 LAM 50-103-20773 B 4 -3 -2 1 D1 Conoco Phillips, Alaska Inc. - MT6-0e Interval 1 Pll 15 ADP Chemical Plot -Treatment 1 A Losurf-3000 Conc (gal/Mgal) A WG -36 Conc Qb/Mgal) B B 2.0 1.8- 1.6- 1.4- 1.2- 1.01- 0..8- 0..6- 0.4- 0.2- 001 .81.61.41.21.00.80.60.40.200 100 90 80 70 60 50 40 30 20 10 0 13:00 13:30 14:00 14:30 15:00 15:30 WW2019 &9/2019 Time Customer: CONOCORiLPS NORTH SLOPE- ESUS .bb Date: 09 -fuer -2019 Sales Omer #: 0912345678 Wall Description: Mf606 LM 50-103-20773 Conoco Phillips, Alaska Inc. - MT"6 Interval 1 Plots 1s Net Pressure Plot -Treatment 1 — Net Calc'd BH Pres(psi) A —BH Proppant Conc (ts9ial) B A Slope of Net Pressure (psi/min) C Time (min) Qrstoner. OONOCOPFLLIPS NORTH SLOPE- ®l15 I .bh Cate: 09 -Mar -2019 Sales Order #: 0912345678 VM Description: We 06 UM S0.103.20773 Conoco Phillips, Alaska Inc. - MT6-06 Interval 1 Plots 17 HALLIBURTON Sales Order# 905550570 Conoco Phillips, Alaska Inc. MT6-06 Interval I Top Alpine C Formation Harrison Bay County, AK API: 50-103-20773 Preparedfor: Adam Klem March 9, 20/9 Stimulation Treatment Appendix - Chemical Summary - Planned Design - Water Straps - Field Water Analysis - Real -Time QC - Wellbore Information - Event Log - 15 min XL - Treatment 1 - 15 min XL - Treatment 2 - 15 min XL - Treatment 3 - 15 min XL - Treatment 4 - Lab Testing Conoco Phillips, Alaska Inc. - MT6-06 Appendix 18 Customer Conoco Phillips, Alaska Inc. Formation Top Alpine HALLIBURTON E�M1aUeeTO a Lease MT6-06 API 50-103-20773 Data 3/9/2019 Interval Summary - Chemicals Conoco Phillips, Alaska Inc. - MT6-06 Chemical Summary Liquid Additives Ory Additives Interval LOSur(-300D MO -67 CL -22 UC CL -31 LW -200 1 WG -36 BE4i OpOFIo-III 1 OptiFlo-11 SP (gal) (ga0 (gal) (gal) (gal) I (lbs) I (lbs) I (lbs/ I (lbs) I (lbs) Prime Up 1 00 233 90 0 223 0 80 0 7140 0 7517 10 35 0 230 0 0 0 11 Total 233 90 223 60 7140 7517 45 230 0 11 w/o Prime Up 233 90 1 223 80 7140 7517 35 230 0 ZI Conoco Phillips, Alaska Inc. - MT6-06 Chemical Summary Conoco Phillips, Alaska Inc. - MT606 Planned Design 20 Customer: Conoco Phillips, Alaska Inc. Well: MT6-06 Date: 3/9/2019 Formation: Top Alpine C SOM 905550570 Conoco Phillips, Alaska Inc. - MT606 Water Stays General Beginning Strap Ending Strap Tank Type Water Source Inches Gallons Barrels Temperature (*F) Inches Gallons Barrels 1 Wichita CPF3 103 19,370 461 109 13 1,974 47 2 Wichita CPF3 100 18,787 447 108 13 1,974 47 3 Wichita CPF3 105 19,757 470 111 13 1,974 47 4 Atigan CPF3 104 19,564 466 102 13 1,974 47 5 Atigan CPF3 104 19,564 466 105 9 1,260 30 6 Atigan CPF3 104 19,564 466 105 9 1,260 30 7 Atigan CPF3 104 19,564 466 106 9 1,260 30 8 Atigan CPF3 104 19,564 466 106 9 1,260 30 9 Atigan CPF3 94 17,627 420 102 9 1,260 30 10 Wichita CPF3 105 19,757 470 100 9 1,260 30 11 Atigan CPF3 104 19,564 466 107 9 1,260 30 12 Atigan CPF3 104 19,564 466 100 55 9,954 237 13 Atigan CPF3 105 19,757 470 101 121,806 43 14 Atigan CPF3 82 15,305 364 93 S7 10,374 247 15 Wichita CPF3 81 15,112 360 112 59 10794 257 Location Summary Starting Volume Ending Volume Total Used Gallons Barrels Gallons Barrels Gallons Barrels 282,416 6,724 49,644 1,182 232,772 5 542 Pre -Job Barrel Bottoms Zones: Volume Needed for % Intervals (BBL): Number of Tanks Needed: Tank Bottoms (BBL): 1 1,394 3 355 2 3 2,767 4,141 6 9 264 172 4 5,727 13 66 Conoco Phillips, Alaska Inc. - MT606 Water Stays C kkw. Well Name: Waters raa: HALLIBURTON Alwk Dinner Field QC Pr9ob Water Nnalr isanl maticn COn.. PMllips, Made lnc Treatments: MT6 Gale Tested' 6 0 s 1 3/9/2019 Spec? Oravitr TenIY Temperature Dismlmtl lmn Fe's Chimed. d Sulttle U.. MYnes Total linear SDa'I [a° M °' Xartiness Ymmntr Water pH Get pM Pre-Cmss4nk PX Poll{msslink pM Cr -ink Bacteria 'F mpJ1 me/L m L m8/L m8/L WL cP ty/NI BQValue Tank XYprometer DWmI Thermomen, Stnp Teralmn Snip Tiledin Tohl XaMness Til.m. FANN35 Mins ciu Probe Probe Probe Probe Myrometer 1 1.022 68.1 0 35,3CD BOD 1,960 520 2,080 35 7.3 7.8 8.3 9.1 Y BDe 2 1.020 69.0 0 MV. . ;COO 400 2,047 35 7.3 7.5 8.1 93 V 1,246 3 SAM 67.1 0 20,170 800 2,[M 320 2,400 32 7.2 7.3 9.1 9.5 V 2-036 4 1.036 68.3 0 20,170 800 2,M 404 2,440 28 ]R ]A 9.5 9.5 Y y]]7 5 1.OM 34.0 0 14690 800 1,960 640 2,347 3s 7.2 7.6 9.] 9.8 V I11M 6 1.OM 65.4 0 1],320 Bm L9E0 720 2,640 34 ].3 ].3 9.8 9.7 Y 1,130 7 1024 63.6 0 38,750 BW 2.120 440 2.560 35 Z3 7.S1�4 9.8 Y 60B 8 IWIS .7 0 47.840 800 2.040 640 2,680 32 7.2 ]3 9.9 V t'. 9 1026 M.e 0 35,340 BCO 2,470 720 2,720 35 ].3 ]J 9.7 V 5,931 10 L@6 60.0 0 4],840 BCO 2120 600 2,720 32 ]3 7.5 9.7 Y List 11 1.,426 62A 0 35,340 eW 2,400 760 2,nO 35 ]3 ].6 99 Y 864 12 VW6 63.5 0 38720 8q1 2,480 32D 2,8W 31 7.3 ].9 9.9 Y 6,134 13 LOW 62.9 0 35340 BW 1,800 920 21720 33 7.3 )5 98 Y 1,28 14 1-028 60.2 0 4].BNI 800 4WO 647 2,600 32 7.4 ]6 10.0 Y 18,984 15 1.026 M.2 0 42,82D BOD 2,560 20 2AW 35 7.4 ].e9.9 Y 1118Aver 1.025 65.1 0 33,448 BOO 2,0]2 549 2,621 33 ].3 ].5 9.7 3,S5]Maximum 1028 69.0 0 4],840 BW 2,560 920 2AW 35 7.4 ].9 10.0 1$984Minimum 1.022 624 0 1],320 B00 1,BW 240 2,. 2B >2 ].3 9.1 864 Pa OA36 6.6 0 30530 0 760 66O 400 ] O.E 0.6 lJ 0.9 18,120 HALLIBURTON Customer: ConocoPhillips Alaska, Inc. Wellname & #: MT8-06 El Date: March 9, 2019 Interval Stage Visc Linear pH Temp OF XL PH Comments Pad 35 9.6 95 9.8 14 50 9.5 90 9.3 Higher setpoint due to LVT in ADP tub. 1 2# 49 9.6 91 9.3 Higher setpoint due to LVT in ADP tub. 3# 33 9.3 96 9.4 4# 29 9.3 88 9.4 Pad 37 9.6 89 9.5 1# 29 9.5 89 9.6 2 2# 29 9.6 89 9.7 3# 28 9.5 89 9.6 4# 28 9.4 89 9.6 Pad 26 9.4 95 9.9 1# Missed sample due to waiting for CL -31 to line out 3 2# 37 9.6 95 9.4 34 33 9.5 92 9.6 4# 1 30 9.5 92 9.6 Pad 35 9.5 87 9.5 1# Didn't collect sample per customer engineer's request. 4 2# Didn't collect sample per customer engineers request. 3# Didn't collect sample per customer engineer's request. 4# Didn't collect santle per customer engineer's request. Conoco Phillips, Alaska Inc. MT6 06 peal -Time QC xax �° leual 'Ip xoml ••••lel �.. ..rrosowe. " y'mxa�w r� n.../..awl ,wnnl IeM o� Ieen � xxleeA uwuw , wW r�im�N�O �iwl I Iwl� �• mKxw IVnA rw r4ert 4on �Ur, .An WHNvc tY, iOt C ncoo Phillips, Alaska Inc.- MT"6 Wellbore Information 24 Event Lug IOb51prr9V01 Toul Prespere Time CYmmeM (pbg (pi( 09:D8:54(03/09/191 Startglob 0 09:08:54 X03/09/191 Treatment Interval l 0 113531 Pressure Tert-GIABALS 266.42 11:25:32 Pressure Test -LOCALS 266.42 1122:16 Pressure Test -70% 266.42 11:29:22 Pressure Test Mea 266.42 11s8:47 Pressure Test PW 266.42 1140:53 Bleal to Retest PRV 266.42 1143:49 Pro ssureiRV Confirm 266.42 12:34:14 Open Well 26&36 12:36:25 Start Pumping 268.36 12:38:00 Good Crosslink in Van 288.62 12:4053 ISIP 322.32 12:41:29 Shut -In 322.32 12:4162 Load Well 0 12A2:05 Fluid Efficiency Tert 0 12:42:11 Flush o 12-42:12 Shut In for FET Analysis 0 12:42:20 Skipped W rIFmc Stage per Customer Rep 0 12:4282 Pad 0 12:450.3 Break Formation 41.24 12:48:01 Informed Customer we needed to cut ate during proppanl to not overrate our iron 132.46 12A9:34 Stege At Top Perf=6 189.44 12:50:191.00ppg 20/40 Wanli 213.36 12:51:W Lost Rate due to Bwst Pump only achleWng 25 psi 235.60 12:5235 Overrode diuharge pump to achieve more pressure 220.12 12:5691 Stage At Top Perf=7 403.32 13:00:14 2.00ppg 2014D Waidi 519.53 13:06:14 Stage At Top Ped=B 208.89 13:10:35 3.00ppg 20/40 Wann 843.42 13:16:42 Stage At Top Perf=9 1033.43 13:12:31 Shipping 3.50 stage per customer rep's request 1059.3 13:17:513.50ppg 20/40 Wanll 1069.41 13:23:52 Stage At Top Perf=lo 1B9.04 13:26:19 Spaeer 1335.54 1330:14 TTS Balls X20 1311 1338:38 Dropping TTS Pods from Acid Pumper 1386.66 13:28:43 Entering patient - Dropping Preload 1386.85 13:29:13 Ending Reciter- Preload 1382.90 13:3142 Pad 139853 13:31:43 Nest Group 1398+53 13:34:01 Drainer - Law Pressure 1462.53 13:36:00 Stage At Top Pad =11 1525.03 13:36:53 Diverter - Nigh Pressure 155266 13:3236 Stage At Top Red =l2 1575.68 13:38,00 Stage Al Top Pad =13 1588.23 13:38:35 1.00ppg 20/40 Wanli 1606.02 13:44:32 Stage At Top Ped=14 129584 13:48:44 2.00ppg 20/00 Wanll 1924.56 13:54:46 Stage At Top Perf= 15 2114.54 13:58:58 3.00ppg 20/40 Wanli 2246.84 14:05:00 Stage At Top Fed =16 2436.7 14:08:53 4.00ppg 20/40 Wanli 2559.04 14:14:56 Stage Al Top Ped= 27 2249.09 14:150.2 Spacer 2752.22 14:15:39 Not Dropping Rate per Customer Engineer Reclusion 2721.63 14:16:12 TTS Balls X20 2789.00 14:16:30 Dropping TTS Balls 2802.82 14:12:44 Acid Pumper Closed In Follow TTS Ball Drop, Short Next Group 2632.8 14:17:44 Pad 2832.8 14:19:22 Pressure Build 2891.6 14:19,41 Nage At Top Perf=18 2898.88 1431:32 Peak Pressure 2960.35 14:22:11 Ship At Top Perf=19 2979.28 14:23:44 Stage At Top Perf= 20 302729 14:25:091.00ppg 20/40 Wanli 3021.32 14:31:09 Stage Al Top Roof =21 3261.24 14:35:18 2DOppg 20/40 Aesop 3392.34 14:41:19 Stage At Top Perf=22 3581.53 14:45:30 3DOppg 20/40 Wanll 3213.25 14:51:31 Stage At Top Perf=23 3902.22 14:55:26 4.00ppg 20/41) Wardl 4024.98 15:01:28 Stage At Top Ped= 24 4214.82 15:01:32 Spacer 4216.30 1592:58 IIS Balt X40 4261.0 1593:15 Drop TT5 Pods 4220.85 15:00:12 Pad 4303.25 15:04:17 Acid Pumper Offline; Storting Final Group 430375 15:07:29 Stage Al Top Perf=25, Max Pressure Following Drop 4405.91 15:08:56 Stage At Top Pad =26 4451.32 15:20:14 Stage Al Top Ped= 22 4492.98 15:30:561.90ppg 20/40 Warp 4510.6 15:16:55 Stage At Top Ped=28 470,1 15:20:59 2.00ppg 20/40 Wanli 4832.79 15:22:01 Stage At Top Perf=29 5022.71 15:31:06100ppg 20/40 Wanli 5151.35 15:32:02 Stage At Top Ped=30 5340.57 comm wiatip-.,astir 1.-.. Evmtwg Treating Pressure ®Pump (pnl O 0 SD 420 6285 8055 6984 206 2002 389 688 2880 1683 1629 1621 1640 1632 1626 1622 1621 4526 3285 3234 3259 3282 3223 4526 4462 3106 3060 2828 2840 MIS 2695 2684 1828 2063 2097 2178 2714 2704 3052 3225 3201 3228 3221 3169 3071 3106 3016 3003 2839 2834 2733 2728 2744 2795 3079 3015 2943 3165 3188 3404 3366 3354 3307 3212 3159 2813 3026 3047 3076 2918 2888 3205 3277 3166 3158 3466 3491 3461 3470 3357 3371 3301 3295 3156 0 0 151 410 6212 2929 5889 151 6696 386 524 2807 1220 1223 1269 1258 1255 1253 1252 1251 4431 3666 3132 3160 3208 3605 4463 4355 3099 2993 2222 2208 2692 2562 25W 1289 1942 1985 2084 2606 2605 2954 3130 3161 3133 3116 3076 2967 3004 2906 2907 2771 2764 2666 2656 2664 2703 2942 2859 2019 3055 3081 3282 3229 3239 3231 30% 3054 2233 2944 2956 2986 2832 2832 3092 3202 3055 3048 33M 3384 3381 3383 3260 3290 3223 3213 3023 51.11 Rate (lipm( 0 O 0 0 0 0 0 0 0 O 0 14.5 0 0 0 9 0 0 0 0 28.9 35 0 32.1 31.5 30.2 30.2 30.6 31.6 31.2 31.4 31.2 31.6 31.5 31.5 31.5 2.6 2.2 2.2 2.3 15.9 15.9 315 31.5 314 31.4 31.4 31.4 31.5 31.5 315 31.5 31.5 31.5 314 31.4 31.6 31.8 31.8 316 31.6 313 31.2 31.7 31.7 31.5 31.5 316 31.5 31.5 31.5 31.4 31.4 31.4 31.4 31.6 31.9 31.8 318 317 317 31.7 31.7 31.6 31.6 31.5 31.5 314 15:40:39 4.11Oppg 20/0 Wanli 5051.29 3101 3081 31.5 15:46A15hge At Top Perf=31 5641.22 3120 30" 31.5 15:49:39 Flush 523462 3298 3208 31.0 15:55.4() Surge At Top Perf=32 5924.38 3192 2941 19.6 15:52:11 Freeze Proted 5934.39 2209 2652 5.2 16:07:541SIP 6041.02 2508 2420 0 17:31:115uspending3ob 6041.02 0 0 0 12:31:24 Endirq lab 64)41.02 0 0 0 zewnrnAla nears.. toe, Us �w.tw. m.W r.-rmzoz tsmi,.xx n.:a^.mt HALL1MUM7MM Treatment 7 Crosslink Test(s) ALASKA DISTRICT FIELD OC -Break -Ps] _1a -2a -34 15 Minute Farm Morel 35 Crosslinked Fluid Report 0m Fluid System; HyborvG tmo Data: 3/912018 Company: Con. Phillips -Alaska Project No: Well Name: MT6-O6 Treatment: t BHST(eF(: 185 Water Source: CD -5 _ 10m Depth: 8037 Water pH: 7.30 L' a00 Fomution: Top Alpine C Hydration pH: 7.50 8 m0SN Analyst: Y. g6rn Hydration Visc: 33 cp® 65 At ao0 an a mm 0210 osm m10 tom tzm iEco TlnutPJ-)ccIk 14oOIP BYpu Vlw Linear CmsYlnk pH Temp Loiud3000 CL42UC CL41 W47 WB3e 001FbMl np11F.a BP BEB ante cP -F 00 pW pW eW pW "t PW PW pW Pad 35 9.6 9.8 95 1.00 1.00 0.35 0.40 35.00 1.00 0.00 0.00 0.15 10 50 9.5 9.3 90 1.00 1.00 0.35 0.40 35.00 1.00 0.00 0.00 0.15 2A 49 9.6 9.3 91 1.00 1.00 0.35 0.40 35.00 1.00 0.00 0.00 0.15 30 33 9.3 9.4 98 1.00 1.00 am 0.40 35.00 1.00 0.00 0.00 0.15 U 29 9.3 9.4 88 1.00 1.00 0.35 0.40 35.00 1.00 0.00 0.00 0.15 �w.tw. m.W r.-rmzoz tsmi,.xx n.:a^.mt HAL.LIBUFITON Treatment 2 Crosslink Testis) ALASKA DISTRICT FIELD QC -Break -Pad -u -2a -W -ak 15 Minute Farm Model 35 Crosslinked Fluid Report en Fluid System: HyEor-G Data: 3IW2018 foto Company: Conoco Phillips-Alaska Project No: Ino Well Name: MT6-06 Treatment:2 1W6 aHST)nF): 185 Water Source: CPS np Depth: 8037 Water pH: T.30 = Formation: Top Alpine C. Hydration pH: 7.50 6 an Analyst: yn.r fFb7rr Hydration Vise: 33 cP@ 65 °00 m6 0 D1W p$'.30 QiID 0733 1PW 13]0 f5W Tlme (mN:secj FwY le Ytlentl70p�p ayp Vlw LYwr0 CroeNin O Tem, L uRS00 CL.. CL41 W47 MM46 Oo Fb l OoiFlull SP BEd enm cP - -F go .0 BM OW PW PM PN PN PPr Pad 37 9.6 9.5 89 1.00 1.00 0.35 0.40 35.00 1.00 0.00 0.00 0.15 V 29 9.5 9.6 89 1.00 1.00 0.36 0.40 35.00 1.00 0.00 0.00 0.15 28 29 9.6 9.7 89 1.00 1.00 0.35 0.40 35.00 1.00 0.00 0.00 0.15 38 28 9.5 9.6 89 1.00 1.00 0.35 0.40 35.00 1.00 0.00 0.00 0.15 48 28 9.4 9.6 88 1.00 1.00 0.35 0.40 35.00 1.00 0.00 OAO 0.15 .... .111....�-x*6a6 +s..a-n..,.„,6 H^UU1 BU RTON Treatment 3 Crosslink Test(s) ALASKA DISTRICT FIELD QC -break -Pad -1# _24 _3# -a# 15 Minute Farm Model 35 Crosslinke ! Fluid Report Fluid System: Xytmrli Data: 319/2016 l40� Company. Corwco Phillips -Alaska Project No: 1600 Welt Name: M116416 Treatment: 3 +OoO BHSTj'9: 165 Water source: CDS em Depth: 0037 Water pH: 7.30 d Formation: _ Top Alpine C Hydration pH: 7.50 600 Analyst yuv V*. Hydration Vlsc: 33 cpW 65 S' e0o an 0 moo mm mm W30 +om 12. :. T'-#,n:.acl 11.. b axna m0.ro nee Vlsc UnlarW Crasallnkw T -P LaeuRd000 CL3a.c CL41 MOA] M46 001FIa01 OglFW1 SP BE.6 Ums CP T BW 60 BW eq PPr PW PW PW PW Pad 26 9.4 9.9 95 1.00 1.00 0.35 0.40 35.00 1.00 0.00 0.00 0.15 1# 1.00 1.00 0.35 0A0 36.00 1.00 0.00 0.00 0.15 2# 37 9.6 9.4 95 1.00 1.00 0.35 0.40 35.00 COO 0.00 0.00 0.15 3# 33 9.5 9.6 92 1.00 1.00 0.35 0.40 35.00 1.00 0.00 0.00 0.15 4# 30 9.6 9.6 92 1.00 1.00 0.36 0.40 35.00 1.00 0.00 0.00 0.16 .w x.roer-- .... .111....�-x*6a6 +s..a-n..,.„,6 .-. WAs'...... a..n-T.„1.... FIALLI BURTON ALASKA DISTRICT FIELD OC Treatment 4 Crosslink Test(s) _ Brepk -P. -t# -2y _Os 15 Minute Farm Model 35 Crosslinked Fluid Report lau Fluid System: Hyborli Dale: 3/9/2018 100° Company: Cameo Phillips -Alaska Project No: Well Name: MT6-06 Treatment: 4 _ SHST (°F): 185 Water Source: CD -5 _ Epp Depth: 8037 Water pH: 7.30 DIf Formation: Top AlpimC Hydration pH: 7.50 3 Analyst: Y.V*. Hydration Visc: 33 cps 65 mo 0 mpg mm psm pray tom lz. ism 11-e l:..1 nuW1Sbr ene LOrP Supe VU U -r0 Cro fiek pH Temp L Rt3WG CL42UC CL41 ..T WG46 OWOFb l OORW 41 SP BE4 Unb cp T 0M pM BM .0 PP, Pet Ppt ppt pp Pad 35 9.5 9.5 87 1.00 COO 0.35 0.40 35.00 1.00 0.00 0.00 0.15 1# 1.00 1.00 0.35 0.40 35.00 1.00 0.00 0.00 0.15 20 1.00 1.00 0.35 0.40 35.00 1.00 0.00 0.25 0.15 3# 1.00 1.00 0.35 0.40 35.0 1.00 0.00 0.26 0.15 4# 1.00 1 1.00 0.36 0.40 1 35.00 1.0 0.0 0.50 0.15 a xmm r .-. WAs'...... a..n-T.„1.... HALLIBURTON Prudhoe Bay Field Laboratory - Rockies NWA Laboratory Project ID Number: 2066475 Customer: Conoco Well Name & Number: Fluid System: Hybor G Date: February 20, 2019 0 minutes at 511 1/sec 10 minutes the shear rate was decreased to 100 1/sec Seawater Technician(s) Performing Testing: Reviewed & Approved By: inner : Conoco Fluid System: Hybor G Bob Type: B5 Name: 0 Water Source: Seawater Shear Rate (1/sec): 511 / 100 Febmary 20, 2019 BHST (eF): 165 1 n Prnieot TD- 7(166e76 FLUID DESIGN Test No: I 1 23 51 Water Analysis Lot Chemical Units Chemical Concentrations BE -6 Fpt 0.15 0.15 0.15 0.15 LoSmf300D sin 1.00 1.00 1.00 1.00 WG -36 ppt 35.00 35.00 35.00 35.00 MO -67 8pt 0.40 0.40 0.40 0.40 CL -22 PIA 1.00 1.00 1.00 1.00 CL31 Ppt 0.35 0.35 0.35 0.35 Optiflo III ppt 1,50 1.50 1.50 SP Breaker Pitt 1 1 0.25 0.50 'calculated values FU 1 PROPERTIES Test No: 1 2 3 5 r. Gel Hydration (511/s) Water pH 6.81 6.81 6.81 6.81 Min Gel (4) 35.00 35.00 35.00 35.00 1Base Gel Vise (cP) 37.0 37.0 37.0 37.o 2Base Gel pH7.45 7.44 744 7.47 3Base MpBase Gel Temp. CF) 75 75 75 75 4Buffered pH 9.23 9.38 9.32 9.21 5Cmssllnk pH 9.80 9.82 9.84 9.82 10 Final pH 9.23 8.97 9.03 9.20 Test Temp. (OF) 165 165 165 165 Break Time (hCmin) ala 2:19 2:19 1:14 Test Nates: .......^Shear Rate �Viswsay ^ Shear Rate BREAK �Vscoeity TEST CIIARI .^^^^Shear Rafe-Vlseoslty --ShearRate -Viscosity .......... Shear Rate Viscosity --'--. Shea Rate Viscosity - - - Temperature - - - Temperature - - - Temperature - - - Temperature - - - Temperature - - - temperature 1200 180 loon i - 160 Al 140 eon `(tj lzo at i as tato Eco AA itst Vr- 80 g 400 60 40 200 _.._.._..._.....> ......................................................... ................................................................... 20 o - o 0:00 0:28 0:57 1:26 lass 224 2:52 3:21 3:50 Time, h:mm HALLIBURTON Prudhoe Bay Field Laboratory - Rockies NWA Laboratory Project ID Number: 2066872 Customer: Conoco Well Name & Number: MT6-06 Fluid System: Hybor G Date: March 8, 2019 0 minutes at 511 1/sec 10 minutes the shear rate was decreased to 100 1/see SL#1064 Technicians) Performing Testing: Reviewed & Approved By: O1 INFORMATION AND TESTINC CON DITIONS Customer: Conoco Fluid System: Hybor G Bob Type: B5 Well Name: MT6-06 Water Source: Seawater Shear Rate (1/sec): 511/100 Date: March 8, 2019 BHST ("F): 165 Lab Project ID: 2066872 1 1 Test No: 1 2 3 5 Water Analysis Lot# Chemical Units Chemical Concentrations BL-6 ppt 0-15 0.15 0.15 0.15 Total Alkalinity(ppm)180 LOSurf300D Spt 1.00 1,00 1.00 LOU Total Hardness m) 425 WG-36 PIA 35.00 35.00 35.00 35,00 Chloride m ) Water 173M MO-67 gpt 0.40 0.40 0.40 0.40 CL-22 PPI 1.00 1.00 1.00 1.00 Iron m 5 CL31 ppt 0.35 0.35 0.35 0.35 H 7.02 Sulfate m L >1200 Optl0o III ppt 1.00 1.00 1.00 Temperature (°F) 70 SP Breaker ppt 1 1 0.25 0.50 $ cifiic Gravity 1.028 eca7cu/a1edvo1ues Test No: 1 2 3 5 e Gel Hydration (Sl l/s) Water pH 7,02 7.0217,417A2 .02 Mia Viscosity (oP) Temp. .F): Base Gel (ii) 35.00 35.005.00 I 75 Base Gel Vise (cP) 37.0 37.037.0 2 75 Base Gel pH 7.37 7.407.42 3 75 Base Gel Temp. (OF) 75 7575 4 75 Buffered pH 947 9.53.38 5 75 Crosslink pH 9.68 9.70.65 10 75 Final pH 8.98 8.97.95Test Temp. (°F) 165 165165Break Time(hr:min) da 2.54.57 Test Notes: i .......... Shear Rate -Viscosity.......... Shear Rate -Viscosity .......... Shear Rate -V6casity - - Shear Rate - Viseosity ------ Shear pate Vlzc slty -Shear Rate -Viscosity - -- Temperature - -- Temperature - -- Temperature --- Temperatum- -- Temperature ---Temperature 1400 -- - __. 160 1200 160 140 Iwo " 120 ('t aoo �- _ loo L l� o / 600 0 40 S 60 400 ao 200 zo ° 0 0:00 0:28 0:57 1:26 1:55 224 2:52 3:21 3:50 4:19 Time, h:mm THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Adam Klem Completions Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Greater Mooses Tooth Field, Lookout Oil Pool, MT6-06 Permit to Drill Number: 218-093 Sundry Number: 319-064 Dear Mr. Klem: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov 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 yL-� DATED this ) S day of February, 2019. RBDMSI FEB 19 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAQ- gr 2Rn RECEIVED FEB 11 201 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Exploratory El Development Slratigraphic ❑ Service ❑ 218-093 ' 3. Address: 6. API Number: f P. O. Box 100360, Anchorage, Alaska 99510 50-103-20773-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? MT6-06 ' Will planned perforations require a spacing exception? Yes ❑ No ❑� 9. Property Designation (Lease Number): 10. Field/Pool(s): r AA081818, AA092346 .AA081798, AA092342 Greater Mooses Tooth Unit Lookout 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): 17482 8111 Casing Length Size MD TVD Buret Collapse Structural Conductor 152 20 115 115 Surface 2155 13.375 2118 2003 Intermediate 103531 9.6251 10316 7245 Production 118701 71 118331 7983 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 4 1/2" L80 11675 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): ZXP linertop, no SSSV 11,665'MD no SSSV 12. Attachments: Proposal Summary 71 Wellbore schematic Lij 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strafigraphic ❑ Development ❑✓ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/23/2019 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. Contact Adam Klem, 907-263-4529 Email adarn.klelTConocoPhilli s.conn Printed Name Ada tem Title Completions Engineer Signature Phone 907-263-4529 Dale COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No Eirl Subsequent Form Required: /0 _ -el 0 g. AP/PROVED BY j� Approved b Roc\lJ COMMISSIONER THE COMMISSION Date: Form 10403 Revised 11/2015 Approved ap 0-U4w �'���2v1`� V1 -Z z/isji9 f�r/lartj I frAm�he date of 1p I.�� Submit Form and Attachments in Duplicate MT6-06, B1 Location Final Completion Schematic t � t 0 2(r 79 pot H401nSt fated t � ' I Conductor Tubing/ Liner completion. TOC al ieaet 300' MD 1 4J." 12.68 LAO TXP 80 feet, Contended to sufaco S41th Pert Pups I I i) 4-14" Loading Nipple (3.813' X) @ 2,108' MD Te Planned to Dner TOR I TOPAlPlneC 2) 4`.'x 1'GLM@4,D84'MO 0 0 0 11,849'MD t 7,988'TVD I 0 7-26 ppf L-80 TS Blue Liter I to 11,833' MD 17,98T TVD @ 73 deg 3)4G"z 1'GLM@8.101'MD 1 I 4) 4-X'X 1'GLM@11,409'MO I I 13J18" 68 Pot LAO TXPSTCM 5)DonNale Gauge @ 11,556'MD i Surface Casing I @ 21 IT MD 12003' TVD 6) 4'h' Landing Nipple (3.75 XN) I O cetranted to sudaca set at 11,61 T MD @68 deg 7) Liner Top Packer i Hanger@ 11,665 MD y wt Tie Hack sleare 1 I ej 4l' TX eWe Blank Pipe w/ port joins I 4112" 126 ppi LA0 Tenada due I I to 11,678 MD 1 7" 26 PW L-80 I 1 TS Blue Tie Back 1 tk i {^� �J 1 I 9 518" 40 pot LA0 H7d563 (to 1,166 MD) I 0 518" 40 opt LA0 TXP (to 6278' MD) 9 518" 40 opt TN -80 HS UP (to TD) I @ 10,316' MD tT,246 TVD t � t 0 t � ' TOC al ieaet 300' MD 4J." 12.68 LAO TXP atxrve Packer &SOP ' \ S41th Pert Pups MDaboveUnAlper Cop @16.826'MD Te Planned to Dner TOR C) TOPAlPlneC o 0 0 0 0 11,849'MD t 7,988'TVD 7-26 ppf L-80 TS Blue Liter to 11,833' MD 17,98T TVD @ 73 deg 6" Hole, TD at at 17,482'MD J 8,111'TVD October 20111- As Section 1 -Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1). TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Jason E. Lyons Request of ConocoPhillips Alaska, Inc. for ) Hydraulic fracturing for the MT6-06 Well ) under the Provisions ) of 20 AAC 25.280 ) STATE OF ALASKA ) THIRD JUDICIAL DISTRICT ) herein. Jason E. Lyons, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Jason E. Lyons. I am over 19 years old and have personal knowledge of the matters set forth 2. 1 am Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAI") 3. Pursuant to 20 AAC 25.283 (1) CPAI prepared the attached Notice of Operations ("Notice"). 4. On February 5, 2019, CPAI sent a copy of the Notice by certified mail to the last known address of all other owners, landowners, surface owners, and operators of record within a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 51h day of February, 2019. �Q Jason E. Lyons STATE OF ALASKA ) THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 5'h day of February, 2019 by Jason E. Lyons. No ary Public, State of Alaska My Commission Expires: STATE. OIC ALASKA NOTARY PUBLIC REBECCA SWENSEN M .Commission Ez fires Aug. 27, 2020. ConocoPhillips Alaska February 5, 2019 To: Operator and Owners (shown on Exhibit 2) Jason Lyons Staff Landman Alaska Land & BD ConocoPhillips Company 700 G Street, ATO -1478 Anchorage, AK 99501 Office: 907-265-6002 Fax: 918-662-3472 lason.lyons@cop.com VIA CERTIFIED MAIL Re: Notice of Operations pursuant to 20 AAC 25.283 (1) for MT6-06 Well AA -92346 (ASRC), AA -92342 (ASRC) Greater Mouses Tooth Unit, Alaska CPAI Contract No. 204278 Dear Operator and Owners: ConocoPhillips Alaska, Inc. ("CPAI") as Operator and 100% working interest owner of the of the Greater Mouses Tooth Unit ("GMTU"), hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the MT6-06 well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about February 8, 2019. This Notice is being provided pursuant to subsection of 20 AAC 25.283. The Well is currently planned to be drilled as a directional horizontal well on leases AA -92346 (ASRC) and AA -92342 (ASRC) as depicted on Exhibit 1 and has locations as follows: Location FNL FEL Township Range Section Meridian Surface 268' 3189' ION R3E 6 Umiat Top Open Interval 2040' 2576' T11N R2E 36 Umiat Bottomhole 1824' 315' TION R2E 1 Umiat Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section ("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of record of all properties within the Notification Area. Upon your request, CPAI will provide a complete copy of the Application. If you require any additional information, please contact the undersigned. Si erely, on ons Staff Lan an Attachments: Exhibits 1 & 2 AA092346 AA092342 Well Pad Well Trajectory — Frac Interval Q Half Mile Frac Point Radius ® Half Mile Trajectory Radius — Wells within Trajectory Radius Lookout PA CPAI Leases Exhibit 1 N A 0 0.2 0.4 0.6 Miles r AA081798 ConocoPhillips A aska MT6-06 Lease Plat Exhibit 2 List of the names and addresses of all owners, landowners and operators of all properties within the Notification Area. Operator & Owner: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1226 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Misty Alexa, NS Development Manager Landowners: Arctic Slope Regional Corporation 3900 C Sheet, Suite 801 Anchorage, Alaska 99503-5963 Attention: Teresa Imm, Executive VP, Regional and Resource Development United States Department of Interior, BLM 222 West 7th Avenue, #13 Anchorage, AK 99513 Attention: Wayne Svejnoha, Branch Chief Energy and Minerals Surface Owner: Kuukpik Corporation P.O. Box 89187 Nuiqsut, AK 99789-0187 Attention: Joe Nukapigak, President United States Department of Interior, BLM 222 West 7th Avenue, #13 Anchorage, AK 99513 Attention: Wayne Svejnoha, Branch Chief Energy and Minerals Section 2 — Plat 20 AAC 25.283 (a)(2) Plat 1: Wells within .5 miles P A I � 0 e b c AA092346 C y -off �0 q AA081818 E �TS�Sp 1 c n f qB ! 1 i 1 � i (6 MT61 t ! i i 1 AA092342 r i ? i l ! AA081798 j t 1 t `t Well Pad i i Lookout PA i — Well Trajectory •— Frac Internal Q Half Mile Frac Point Radius h Conoco"Phillips O Half Mile Trajectory Radius 1801 Alaska Wens within Trajectory Radius MT6-06 L.._,.� Lookout PA 0 0.2 0A 0.6 Lease Plat ��--1Miles CPAI Leases u 1!24/2019 Table 1: Wells within .5 miles API Well Name Well Type I Status 501032077000 MT6-03 PROD ACTIVE 501032077070 MT6-03PH SVC PROP 7 501032077500 MT6-04 INJ ACTIVE 501032077570 MT6-04PB1 EXPEND PA 501032077100 MT6-05 PROD ACTIVE 501032077160 MT6-05L1 PROD ACTIVE 501032077170 MT6-05P61 EXPEND PA 501032077171 MT6-05PB2 EXPEND PA 501032077370 MT6-06PB1 EXPEND PA 501032077371 MT6-06PB2 EXPEND PA 501032077200 MT6-08 INJ ACTIVE 501032077270 MT6-08PB1 EXPEND PA 501032077900 MT6-09 INJ ACTIVE SECTION 3 — FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. See Conclusion number 6 of the Area Injection Order AIO 40- Greater Moose's Tooth Field, Lookout Oil Pool, which states: "There are no freshwater aquifers in the Affected Area of the LOP." SECTION 4 — PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. SECTION 5 — DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) All casing is cemented in accordance with 20 AAC 25.52(b) and tested in accordance with 20 AAC 25.030 (g) when completed. See Wellbore schematic for casing details. SECTION 6 — ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(a)(6) Casing & Cement Assessments: 13 & 3/8" casing cement pump report on 9/13/18 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 11 ppg LiteCRETE cement lead, followed by 15.8 ppg class G cement displaced with 10ppg mud. Full returns were seen throughout the job. The plug bumped at 900 psi and the floats were checked and they held. 9 & 5/8" casing cement pump report on 9/22/2018 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 12.2ppg cement lead, followed by 15.8 ppg class G cement, displaced with 10.4ppg mud. Full returns were seen throughout the job. The plug bumped at 1100 psi and the floats were checked and they held. The 7" casing cement report on 9/30/2018 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg class G cement. Full returns were seen throughout the job. Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. SECTION 7 — PRESSURE TEST INFORMATION AND PLANS TO PRESSURE -TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 9/15/2018 the 13-3/8" casing was pressure tested to 3,000 psi for 30 mins. On 9/24/2018 the 9-5/8" casing was pressure tested to 3,500 psi for 30 mins. On 10/3/2018 the 7" casing was pressure tested to 3,500 psi for 30 mins. On 10/25/2018 the 4.5' tubing was pressure tested to 3,500 psi for 30 mins. Prior to Frac, the 4.5' tubing will be pressured tested to 4,400 psi and the T' IA will be pressure tested to 3,850 psi. AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 6,000 Annulus pressure during frac 3,500 Annulus PRV setpoint during frac 3,600 7" Annulus pressure test 3,850 4 1/2" Tubing pressure Test 4,370 Nitrogen PRV 6,935 Highest pump trip 6,735 SECTION 8 — PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight Grade API Burst API Collapse 10 & 3/8" 68 L-80 5,020 psi 2,260 psi 9 & 5/8" 40 L-80 5,750 psi 3,090 psi 7" 26 L-80 7,240 psi 5,410 psi 4.5 12.6 L-80 8,430 psi 7,500 psi Table 2: Wellbore pressure ratings Stimulation Surface Rig -Up 91eetl,Taltle \ @ Tab TetN • Minimum pressure rating on all surface treating lines 10,000 psi • Main treating line PRV is set to 95% of max treating pressure • IA parallel PRV set to 3,600 psi • Frac pump trip pressure setting are staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 psi. M haul duaid Pgyoff Ta* �— PwrpTruck Foo Off Tank ary gZ ti Stimulation Tree Saver OPEN POSITION +PMOR TO M4NDREL IN5ERMN! OPE4AlED YKVE OK"TM VALVE SU V QUAD PA RISEN Puce w i CLOSED POSITION • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 '/z tubing and 1.75" down 3 'h tubing. • Max rate with 2.25" mandrel is 60 bpm and with 1.75" mandrel 36 bpm Alpine Wellhead System SECTION 9 - DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPA] has formed the opinion, based on seismic, well, and other subsurface information currently available that: The Alpine C interval is approximately 50' TVD thick at the heel of the lateral and thinning to approximately 25' at the toe. The Alpine C sandstone is very fine grained quartz rich sandstone with varying amounts of glauconite and a fining upward log profile. Top Alpine C is estimated to be at 11,879' MD/ 7,905 TVDSS. The estimated fracture gradient for the Alpine C sandstone is 12.5 ppg. The overlying confining zone consists of greater than 800' TVD of Miluveach, Kalubik and HRZ mudstones. The estimated fracture gradient for the Miluveach is 15-16 ppg and for the Kalubik and the HRZ is 16 ppg. Top HRZ was encountered at 10,288' MD/ 7,135' TVDSS. The underlying confining zone consists of approximately 1800' TVD of Kingak shales. The estimated fracture gradient for the Kingak interval ranges from 15-18 ppg. Fracture gradient increases down section. The top of the Kingak interval ranges from 7,950' TVDSS ( 12,255' MD in the MT6-06PB1) at the heel to 17,402' MD/ 8,016 TVDSS at the toe of the well. SECTION 10 — LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casino & Cement assessments for all wells that transect the confining zone MT6-03: The 7" casing cement pump report on 4/16/2018 shows that the job was pumped with 841bbls losses with 471bbls lost after cement was in openhole leaving 37 bbls cement behind liner. The cement job was pumped with 15.8 ppg Class G cement, displaced with 10.8 LSND. The string was then unstung from the cement retainer. MT6-03PH: MT6-03PH was plugged and abandoned per state regulations on 4/6/2018. MT6-04: T' casing cement pump report on 11/6/2018 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg Class G cement, and displaced with 11.2 ppg LSND. Full returns were seen throughout the job. The plug bumped @ 1100 psi and the floats were checked and they held. MT6-04PB1: This lateral was openhole sidetracked and therefore falls under the casing and cement assessment for MT6-04. MT6-05: T' casing cement pump report on 5/29/2018 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 12.2 ppg Class G for the lead and 15.8 ppg Class G cement for the tail, and displaced with 10.7 ppg LSND. Full returns were seen throughout the job. The string was then unstung from the cement retainer. MT6-05L1: This is the upper lateral on MT6-05 and therefor falls under the casing and cement assessment for MT6-05. MT6-05PB1: MT6-05PB1 was plugged and abandoned per state regulations on 6/12/2018. MT6-06PB1: MT6-05PB1 was plugged and abandoned per state regulations on 10/7/2018. MT6-06PB2: This lateral was openhole sidetracked and therefore falls under the casing and cement assessment for MT6-06. MT6-08: 7" casing cement pump report on 8/16/2018 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg Class G cement, and displaced with 10.8 ppg LSND. Full returns were seen throughout the job. The string was then unstung from the cement retainer. MT6-08PB1: MT6-08PB1 was plugged and abandoned per state regulations on 8/7/2018. MT6-09: The 7" casing cement pump report on 12/7/2018 shows that the job was pumped with 32bbls lost after cement was in openhole leaving 27.5 bbls cement behind liner. The cement job was pumped with 15.8 ppg Class G cement, displaced with 10.8 LSND. The string was then unstung from the cement retainer. MT6-06 Fracture Stimulation Area of Review Top a(Oil Pool Top of OII Pool Top of Cement Top of Cement Top of Cement Reservolr5tatus Zonal Isolation Cement Operations Merhanim"casi WELL NAME STATUS Casing Size (MD) (TVDSS) (MD) (1VDS5) Determined By Summery casing g MT6-03 ACTIVE 7" 9680 ]]B] 8,355' 7023 Log open hole liner for production TOC @8,355&Packer @10,029' 421 sx 15.8 ppg class G e t Pressure tested to 3,300 pressure cement si Plug B3: 341 sx 15.8 ppg Class MT AKIPN PROP N/A 9680 7787 8,172' 6921 Tag PA PA, Cement Plugs G Plug 02: 341 sx 15.8 ppg class G cement Plug #3:356 N/A sx 17 ppg class G cement 11/16/18, 7" casing ACTIVE T' 9181 7881 7,708' 7297 Log Pre -perforated liner for injection TOC @ 7,708' & Packer @ 7,546' 259 sx 15.8 ppg class G Pressure tested to 3,300 MT6-04 cement I 11/I6/I8, 7" casing PA N/A 9181 7881 7,708' 7297 Log OH sidetrack in lateral TOC @7,708'&Packer @],546' 259 ax 15.11 on class G pressure tested to 3,300 MT6-04PB3 cement i Lead: 78 sx 12.2 ppg class G 7/13/18,7" wring MT6-05 ACTIVE 7" 10625 7848 8,933 ],043 Log open hole liner for production 933' &Packer @ TOC @ 8, 933'&' cement Tail:126 sx 15.8 ppg 3 pressure tested to 3,00 class G cement psl Lead: 78 sx 12.2 ppg class G ]/13/18, 7" casing 1,1116-051.1 ACTIVE ]' 10625 7848 8933 7,043 Log open hole liner for productioncement TOC 1118,933' & Packer @ Tail: 126 sx 15.8 ppg pressure tested to 3,300 30,814' class G cement Psi MT6-0SPBl PA NA 10625 7848 10,627' 7848 Tag PA PA Cement Plugs, 123 sx 16.5 cog Class NA Lead: 78 m 12.2 ppg clan MT6-0SPB2 PA N/A 10625 7848 8933 7,043 Log OH sidetrack in lateral TOC @8,933'&Packer @ cement Tai1:126 m 35.8 Ppg N/A 10,814' class G cement Plug B1: 109 ax 15.8 on Class MT6-06PB1 PA N/A 11,775 7,876 11,653' 7834 Tag PA PA, Cement Plugs G Plug g2: 135 sx 16.5 ppg N/A class G cement 10/25/18,7'canng N/A 11,775 7,876 10,047' 6960 Calculated OH sidetrack In lateral TOC @10,04]'&Packer @ 266 sx 15.8 ppg class G pressure tested W 3,500 MT6-06PB2 PA 11,665' cement 9/3/18,7" casing 7812 10,310' 7142 Log Pre -perforated liner for injection TOC @ 10,310' &Packer @ 303 sx 15.8 ppg class G Pressure tested to 3,300 MT6-08 ACTIVE 7" 11956 10,814' cement l MT6-0BPBl PA N/A 11956 7812 10,221' 7094 Tag PA PA, Cement Plugs 235 sx 17 ppg Class G cement N/A 12/20/18, 7" casing ]]89 10,326' 7155 Log Pre-pertorated liner for injection TOC @ 10,326' & Packer @ 287 M 15.8 ppg class G pressure tested to 3,300 MT6-09 ACTIVE ]"11873 11,864' cement Psi SECTION 11 — LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that 2 fault or fracture systems transect the Alpine C formation or enter the confining zone within one half mile radius of the wellbore trajectory for MT6-06. The two faults system were interpreted from seismic data prior to drilling and 1 was confirmed with log data while drilling. The fault was a single fault plane with 5' of throw at 16,495' MD and the second fault is not present in the MT6-06 wellbore. Any faults that are within the half mile radius of the wellbore do not extend up through the confining interval and fracture gradients within the top seal intervals would not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults will not interfere with containment. Based on our knowledge of the principle stress direction in the Alpine C formation, along with the well path, all the fractures will be longitudinal, running parallel to the wellbore. We do not expect any of our hydraulic fractures to intersect faults seen in this wellbore. If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. Vertical Well Depth Depth Displacement Loss Name MD (ft) TVDSS (ft) (bbls/hr) MT6-06 16,495 7990 5' None Plat 2: MT6-06 Fault Analysis 0 0 A b� 3� m w AA092346 �0 AA081818 w� S cif Qom . ............ _....... _. --------------------- .—.._..—.._.._.._.._i1 i1 INR3c -11'v:2t i i i MT6 I I i i I i AA092342 I i z I ! AA081798 I 1 Well Pad I I i - Well Trajectory Lookout PA i � Frac Interval ® Half Mile Frac Point Radius Half Mile Trajectory Radius N ✓ Conoco l'hillips ® Faults within Frac Point Radius 1801 Alaska MT6-06 — Wells within Frac Point Radius Lookout PA 0 0.2 OA 0.6 Frac Plat CPAI Leases Miles 1/24!2019 SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) MT6-06 was completed in 2018 as a producer with 4.5" tubing and a 4.5" liner with perf pups. Due to low production rates, a diversion frac will be performed. After the 1st stage we will drop and array of dissolvable pods to attempt to plug of the perf holes to divert the frac to new formation. Proposed Procedure: Halliburton Pumping Services: 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre -frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 15 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 6,500 bbls are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. MIRU Stinger Tree Saver Equipment and HES Frac Equipment. 6. PT Surface lines to 9,000 psi using a Pressure test fluid. 7. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 8. Pump the 310 bbl breakdown stage (35# Hybor G) according to the attached excel HES pump schedule. Bring pumps up to maximum rate of 30 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 9. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 10. Pump the Frac job by following attached HES schedule @ 30bpm with a maximum expected treating pressure of,7 50afsi. <:— 6 aao p s i • 4 stages, - 400,000 lbs of 20/40 Wan Ii proppant 11. RDMO HES Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 12. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). CUSTOMER mno o Ph"Fps Flees BPI 50-103-x077 8FG(w/9W) Ru Un mssic"cz LFAEE SPLESOROER ill (1 1.1 Xg1us"Ti'u"'^" LONG �153-fhol 36 Threatll[ Interval 9Uge Wines, Descriptionnsoon fluidMPmp�ntOd� age Woppenr Oeutl�Oof Prop Con[ I.) Slurry Puu (bpm) Od90n Clean VONme 1902) Oesll, Clean Vdume (bby ...,Slurry Vlumn No") Dodge 11 Total (W) Slye note ILkrroo." Interval chose (hh..."l lo.Sud FOOD fli a i3 eNhr (.0 C1-22VC 01.0 CL -31 IPM) LVr3W (1M)� W(f. 16 WI) al 1pAN 1 OFDFI411t od'.11 011) SP 0.6 1a snm.Io Shout M.t 0.3 2.5 0.3 o.6 Mln.Wee Rale 34717 1a Ras W. Local .1 sl, s0) a 12 AM¢4 3:42.12 I.J. O.so Ago o.4s 3500 xAo o.xs lz "M 91"nra[ 30 oh. 'so 110 oao so 1PoPe I.J. 0.50 0.90 0.45 slop 0.15 "Oo 0,25 I-3 E35 Walel6et 30 2,W9 101 10t 0,06132 3:36:34 l.w 0.50 0.90 0.45 35.00 0.15 200 0.25 11 Sh.tholl 3:30:31 b5 135 XVboGad 30 15,122 361 363 01203 33031 ICO 050 D.90 OAS 35.00 0.15 200 035 16 #35 Ill Odd Fluid WanIRO/10 3M 30 '42M 2% 300 12.203 0:1002 3:1629 Led 0.50 0.90 ous 3500 0.15 200 0.25 12 935Ill laden Flultl Wirsh 20/40 2.00 30 12AM ]95 ll2 4,BOD 0:10:40 30821 IM 0.50 0.90 045 35.03 0.15 x00 0.25 18 05XYhoG laden Fluid Aeush x0/40 3.00 3D 6333 198 x26 "Shoo 00]31 2.51:32 IOO 0.50 090 OAS 3500 D.15 200 0.25 F9 p35 XVboG latlen Fluid WanIi 20/00 3.50 30 20.29 til 205 x6,000 0:06:$0 3'51306 IW 050 090045 3500 015 200 Oi5 10 1735 Hl Wden Flultl Well 20/03 4.03 30 3,000 21 84 Il.MD 002A9 2.3'.16 1.00 0.50 0.90 OAS 35.00 015 200 025 L%U 535 ft. Spier 30 210 5 5 O:M:10 :x2 1.0.1 0.50 0.90 045 35. 0.15 2o0 025 112 tl35 XVbW TrSPWs Micros 30 soli 1x0 120 20 0:01:013 :12 1.00 050 AM 045 35.W 0.15 203 0.25 143 535 hitless Patl 30 8,240 x00 208 0:06:56 :12 1.. 0.50 090 045 35.00 0.15 ?M 025 pLL N Y14 tl35 Helsel Proppant laden Pull Moll sold) I.0) 30 12,000 305 319 12,0.001 0:1032 :20 1.. 0.50 O. SO 0.45 35.0] 0.15 2.00 025 135 11.0. FroppaM Laden Fluid Wan1120/40 z.0) 30 12.03 295 322 24,g]0 0:1000 :43 1.00 0.50 O.W 045 35.03 0.15 2.. 0.25 `a 1-16 035 Hi Proppant Latlm Fluid WanIi 20/40 3.03 30 11,EN V. 314 34,80) 0:10:28 :59 Soo Miso 13.90 0.45 35.00 0.15 2.00 0.15 2 a ]-13 el XyhoG Proppant Laden Fluid i i20/W 490 30 6,903 184 Wit 22,fiM of :31 LM 050 0.90 0.45 35.. 0.15 300 025 2_ 1-10 .35X0340 Spacer 30 210 5 5 0.O :10102 IIA1. ire 050 090 045 35.00 0.15 Sod 0.25 1-19 R3S MybN FIS Pool TR Pods 30 5,040 no 130 20 0:04 Do'.52 Ido 050 0..W 35.00 o.11 2.00 0.25 ISO ns Ill Pad 30 8,240 sed se. 0:06:56'52 1.03 de. 090 045 3503 015 2.Po 0.25 13] I. weeds Freeport La den Fli Well 2W40 100 30 12,000 305 319 12,803 0:10:329'.56 I.0) 050 OW 0.45 35.00 015 2X 025 ®I 1Sz 535Mss Proppant laden Fluid WanIW40 2.W 30 13,400 295 322 24,800 010:449:19 100 0.50 0.M 0.45 35 U] AIS 2.00 A25 133 035 XybW Proppant laden Flout W.11 20e. 3.03 30 11600 P6 310 34,0..'0 0:10:288:30 10o le. 0.90 045 35W 0.15 303 Less 134 03S Hi Propose. Mden Food Wsellsods, 4.00 30 6.900 aW 190 12,f1A ....8:01 100 050 0.90 045 35.00 0.11 2.03 O.ss 1-21 035.1. Sparer 30 210 5 5 OLO:101:30 1.00 0.50 090 OAS 35.00 PAS 2.00 025 186 .35 Xy0W 225 Pods TR Pods 30 SAW IM 120 do OU4W 1. I.. 0.50 090 045 35.03 0.15 300 O.z1 1-22 135 XNuC Pad 30 13,203 2136 208 M:. 0:52:x8 L03 0.50 0.90 045 3503 0.15 so. 0.25 I2g pas X9[.(5 Proppenl Wtlen Fluid Wan1120. 1.03 30 12,800 305 339 12,800 0:10:32 0.50 0.90 0.4S 35M OIS 200 0.25 1-29 -35 Xy6eG Proppant laden Fluid Wall 2W40 2.03 30 n,4W 395 $22 24.80) 0:1044 0.50 0.00 OAS 35.00 GAS 200 0.25 0.25 IM 035 Xybo6 Proppant teren Fluid WanIi 20/40 3.00 30 11,6W 226 314 34,803 0:10:x0 0.50 OW 0.45 35.2 0.15 I.00 0.25 0.25 L31 035 school, Proppant Led-Fluitl Wellsell 400 30 6900 IA red 21 0:06:29 ffi29301M 050 090 OA5 Mr. 015 2w 0.251.32 tl35 Waterlla[G Flush 30 2.609 18I 181 0:06:02 33 free'. Pmtera Freeze Protest 5 1.300 31 31 O:M:I3 1000.00 to Shaun Sham Iluid"Pe lieu nTou lfeoU Sea Water 400,000 035 hyboG 145129 035 Watertra[6 1s310 FreeuhIXect I." sp f9um1 f9um1 f9pm1 fSuml (des Wm Proppant Ill Designlculd (15,) Wan1130N0 400,000 TTS Pods BO LV28M WG -36 RE6 Olellolll Optlflnll sp Samson Resources - Bridle 0214-10H Planned Design 1050!(-3000 1 MO62 CL -x200 U31 LVr3M our BES if III OPOFIOII SP (Orel (9011 (poll (gal) (gal) PDsJ QRsI phs) (IN) (IhsJ Indcal Design MaLNial Vol2W.3 1 I26A 1 327.5 1 113.2 1 1,300.0 1 9,313.1 1 39.1 sol 651 9.5 LOSul .0.62 aLRUC CL -3l LV28M WG -36 RE6 Olellolll Optlflnll sp f9um1 f9um1 f9pm1 fSuml (des Wm pum pFm PM spm Ma ad=Rale L3 0.6 L.1 0.6 1,203.0 M.t 0.3 2.5 0.3 o.6 Mln.Wee Rale .1 sic Hydraulic Fracturing Fluid Product Component Information Disclosure Pnd(we wN vzvzdla a. him brYa LUMy XemBe BobBLOPE APIeumene� le'.11Orr] NOPTM ,ri ner Name'. ESUS WeP NarN ins NYm 4r: To ll[ rememoe' A51AB xatlnWe: ]OSB re"AutPmlmam, NMf] bm.-T M. PmEumeoni ON mevemeal Uepa"m: B.flt roblwaMvoBml. a .a. Mytlnullc Frec ring Flup Campaltlon' Chemical Maximum Abell MaxNnumingretllent InBre mint Trade Mama Supplier Purpose lngmd'unts Seritu Concentratipnin Adiigve Concenlratlonle Ipgm ienl Mase Co... C." Flet Name land Name Erlmg ph.. Number (CAS 1%by ini NFMuid(%by IEa Sea Wabi wFNd "I'l65 1 3130414 Oen. -0. BEA MILROBIOLIOE We BYbw Awed Bebw R NA CL -Z2 UC XehWMn CrowMNer LiebEBebw IIc1e4 BeLw 0 NP Cho INNER HYNWnon ....r Undonew Lowe Babw, 0 NA LOSUflF3]00 HaliWbn NonbNe SUNWN WSUFF- UahJ Bebw Lille Bebw 0 NA MPs] Napnuwn dlCwNdArdhhew l®btl Below LiaYE Below 0 NA N EEI,E.R0 HaBMnon brute, LEASE ratedBMw Uflait Below 0 NA BREXKEn ornao-a RELEASE Xeldulon anaxer BKE it. IiMEBebw 0 IU BREAKER BP BREAKER L'MM Bebw 0 NA AGENT wBWnen Gelyq /qem LENT ltltlBebw 0 NA W=m plm labourn -1 BBbw 0 NA LL?xIXl Penem Freem Probed Lebtl Bebw glee Bebw o NA Ebbw ire. beromlb used Mnn Later Acme 13,f1ouryIDavere R583A c.00014; g zBnma-zaea.la , ml JTAI-] is oneway. F. W4b .9YO N. CerY.TwSO Myyb ptlymer PnpeYry L. ormt.li 2] IS,H. T E.. R..n Pone T. WBWMm .,M,tS tri BYA Mmoraml ulkb PY!£60 5a! Renu Tucx® Ba1cYeW Pretender, f0, ..n5J5fi 16% Hb dNa Ti .= .1d71. be 1]0b]LS 4.IO114f }pOCO doodeComlvlun ireadrw, ueh 1i4%]8e(IL7 )0.004 cl." 1. D—.Tliex® oundam4nm Papribry )o. a. ooEzla 1T H.bubn Omwe Tug H... 231d11A42a on EBurol 1]d 11]5 6nr 5000.L0 ....... .l..... 8113 X. nm.tic Yabunnidow 64. SH Hydrourvated LeOYbLight W4N748 130.00, ]51E1 BB]0 Bnh I.. f.0o, I -1111e 1. Na Nn 9t -MO Eo Oxxm.TVAgg OgyberMrMcnW �o. O.OM.Ce ]Bq Mvebn Poral i k Wlbabn.m ]rl.dl Y[9 re PeMea-t xon ormir de" ia- mrrpbr.].wm.e=nrdram. I4ma]d]a .. o. poezpi BB N a e fp.Bm Idu I.—loon=le Pobsswn M1 rvuie IS' 1JIOH9 in 63 vew.,..n mem«nb 1Jmse4e ]as Jeaium m.M «YM« BC06J?. n Sodium chirM1hrtle ]aP!-14d 4.005 BBWS lbl. doe zz 4e, Serunn lwXan "t -V-1 7"t -V-1 ne.f. t0 .dn,n nndM ^.we 1 wear mzaaa we.odL g.l p9ou 4eeg • Total Water Vqume aeurett may include lreur water, produce! water, andor mo, ed water ^ Inlwmatlon b baeM on me busion L mglentlI for attendance and Nue me WM may be over 100% Nob: For Field DevMOpmenl Produce,(Womme, NN begin with FOP), MSOB M'rel only dolor in mon him been provided component mmmommi hard dre obtained inm IM WWhere Mmebal S.1i Oeta Sbe. IMSOSL As such, are Dater or of ml mpamtle for imcw2ee information. AM Vumtione 1BgYanp Ne tOAt$M01 NB MS05 MMId M dliSCbd IB Ih$ sup[5.r Me WOWded X. The Occupational SAW and HeMh Admini&IaM1i(C)S old...ulMon g ... to the Cnled. for the dlouldso a of Nle information. Fraud nate that remain Law Welacb'proWielaly', bade w FW. and 'mnfidantiN whermeee inlolmarl and NB cribne fol how this humbeedon is mounted on an Ri b Retract to 21 CFR 1910.1411 and A ode0 GMTU MT6-06 Stage Job Size (lb) Top MD (ft) Top TVD (ft) Propped Half- length (ft) Fracture Height (ft) Avg Fracture Width (in) 1 100,000 16,100 8,040 540 65 0.315 2 100,000 14,655 7,998 540 65 0.315 3 100,000 13,220 7,997 540 65 0.315 4 100,000 12,112 7,995 540 65 0.315 Disclaimer Notice: This model was generated using commercially available modeling software and is based on engineering estimates of reservoir properties. Conoco Phillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results SECTION 13 — POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through PTS until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to alpine disposal facilities until they are clean enough for production.) Loepp Victoria T (DOA) From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Friday, February 15, 2019 7:11 AM To: Loepp, Victoria T (DOA) Cc: Klem, Adam; Hobbs, Greg S Subject: RE: [EXTERNAL]GMT MT6-06(PTD 218-093, Sundry 19-064) Fracture Stimulation Follow Up Flag: Follow up Flag Status: Flagged Victoria, You are correct, MT6-06 was not intended to be fracture stimulated when the well was permitted and drilled. However, once completed, we have been unable to get the well to flow at rates anywhere near where expected. We have performed a number of tests/interventions hoping to find a mechanical cause for the low flow with no success. It now appears that our formation is far tighter than we had originally suspected for the southern row of wells at MT6 (MT6-06, MT6-07, and MT6-04). If we are able to stimulate MT6-06 and we see a significant increase in production then we can confirm there is a better way to develop the southern area of MT6. MT6-07 was deferred shortly before spud for this reason. This is an abbreviated summary of MT6's development over the last few months so if you would like to discuss it further I would be happy to walk over and review with you. I will also send you the requested cement review of MT6-06 Intl in a separate email. Thanks, Andrew (303)378-8881 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Thursday, February 14, 2019 2:26 PM To: Beat, Andrew T <Andrew.T.Beat @conocophillips.com> Cc: Klem, Adam <Adam.Klem @conocophillips.com> Subject: [EXTERNAL]GMT MT6-06(PTD 218-093, Sundry 19-064) Fracture Stimulation Andrew, In reviewing the approved PTD, the 10-401 indicated that this well was not going to be fracture stimulated. As a result, no cement evaluation log of the 7" liner was run, nor was the cement job reviewed. Please explain how this happened. Provide cement job information and TOC determination. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria Loepo<dalaska.gov Loepp, Victoria T (DOA) From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Thursday, February 14, 2019 2:01 PM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]GMT MT6-06(PTD 218-093, Sundry 319-064) Fracture Stimulation My apologies. Both should be 5000psi From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Thursday, February 14, 2019 1:56 PM To: Klem, Adam <Adam.Klem@conocophillips.com> Subject: [EXTERNAL]GMT MT6-06(PTD 218-093, Sundry 319-064) Fracture Stimulation Adam, The maximum treating pressure in Section 7 is 6000 psig, however in Step 10 of Section 12, it is 7500 psig. Please clarify. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp aaalaska.aov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Viclona.Loepp >alaska-aov Loepp, Victoria T (DOA) From: Sent: To: Cc: Subject: Attachments: Follow Up Flag: Flag Status: Victoria, Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Friday, February 15, 2019 7:35 AM Loepp, Victoria T (DOA) Klem, Adam; Hobbs, Greg S RE: [EXTERNAL]GMT MT6-06(PTD 218-093, Sundry 19-064) Fracture Stimulation MT6-06 7in Liner Trt Report.pdf; MT6-06 Intl Cement WV Report.pdf Follow up Flagged The Intermediate 2 liner cement job on MT6-06 was pumped without issue. We had full returns throughout and lift pressures were as expected. In total, 55 bbl of 15.8# Class G cement were pumped with 5 bbl left in the drill pipe. From previous 7" CBL's on MT6, the hole appears to be very close to gauge so if we assume the same for MT6-06, the expected top of cement is around 10,047' MD / 7,048' TVD (1,786' MD / 934' TVD above 7" shoe). Similarly, the conditions and execution of MT6-06's cement job were very similar to the logged wells so I am confident the cement bond is equally strong. I have attached the SLB job log as well as the WellView report for your review. Let me know if you need anything else or would like to discuss this further. Thank you, Andrew Beat Senior Drilling Engineer ConocoPhillips Alaska (303)378-8881 cell (907) 265-6341 office From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Thursday, February 14, 2019 2:26 PM To: Beat, Andrew T <Andrew.T.Beat@co nocophillips.com> Cc: Klem, Adam <Adam.Klem@conocophillips.com> Subject: [EXTERNAL]GMT MT6-06(PTD 218-093, Sundry 19-064) Fracture Stimulation Andrew, In reviewing the approved PTD, the 10-401 indicated that this well was not going to be fracture stimulated. As a result, no cement evaluation log of the 7" liner was run, nor was the cement job reviewed. Please explain how this happened. Provide cement job information and TOC determination. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission Cement Detail Report MT6-O6 String: 7" Liner Cement Job: DRILLING ORIGINAL, 9/10/2018 00:00 Cement Details Description T' Liner Cement Cementing Start Date 9/3012018 00:53 Cememing End Data 9/30!2018 03:40 Wellbore Name MT6-06 Comment Cement Stages Stage >« 1 Description T' Liner Cement Objective Top Depth (ftKB) Cement Liner 10,047.0 Bottom Depth (ftKe) 11,833.0 Full Return? Yes Vol Cement... Top Plug? No Bim Plug? No Q Pump Init (bbl/m... 2 Q Pump Final (bbg... 1 Q Pump Avg (bbl1... 2 P Pump Final (psi) 640.0 P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No I Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ttK6) Drill Out Diameter (in) Comment 55 bbls of 15.8 ppg Cement. CIP = 03:40 Hm. Left 5 bbls cement in OP. Cement Fluids & Additives Fluid Fluid Type G -blend Tail Fluid Description Estimated Top (ftKB) 10,047.0 Eri 8lm (Pole) 11,833.0 Amount (sacks) 266 Class G Volume Pumped (bb!) 55.0 Yield (tPlsack) 1.16 Mix H2O Ratio (gal/ea... 5.07 Free Water (h) Density (ildgall 15.80 Plastic Viscosity (CP) 103.1 Thickening Time (hr) 5.28 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 111 Report Printed: 211512019 Schlumberger Cementing Job Report CemCAT V1.7 Well MT6-06 Client ConomPhiliips Field Alpine SIR No. Engineer Lance Kalivas Job Type 7^ Liner Country United Stales Job Date 09-29-2018 Time Pressure Rate Density WHP Messages 00:32:38 Hate lade good PBM Done Blow Air Down Hard tine Fluid P86 Hard Lim tnw Pr/ Test Tnps 00:48:00 TnP5 Tripped High Pr Reset Total, Vol = 1.37 Ittl Pr Good Stmt bstchig MWR h MudPush Scaled 11.5 Heavy Stmt MP Down MW 01:03:00 End MudPush Stat batching Cement Haset Taal, Vol = 20.02 bbl Cement Scaled 15.9 SWR Tab arr Down Hae 01:18:00 01:33:00 EM Tall Cement Rewe Taal, Vol = 55.04 bbl Fresh water behlM 01:48:00 20 Obis water behind by straps Swap to ng to dl5place l Feast Taal, Vol = 18.70 bbl 02:03:00 02:18:00 l 1 I i &ow ar down herd tine 02:33:00 i 02:48:00 03:03:00 03:18:00 03:33:00 03:40:39 EM displaaenent sting out hh:mm:% em oom moo mm woo Sono om yr .a m sat yea sat Boa rsa ma s om vw zsvo mw sow oumam ^• PSI BM LB/G PSI 09/30/2018 04:50:02 Schlumberger Cementing Service Report Page 10 4 C- amer Cono xWhlihps Job Number Well MT6-06 teelNen(legal) GMT Scblimiter .r Lerstlon PRUDHOE OTHER Jab BtaR Sep/29/2018 Field Alpine Formation Nam./Type D,ylauon deg BH Ab In WNI MD 11020.O It Well TVP 8010.OIt County Sbta/praylnce Alaska SNP psi BMST 181 degF BHCT 138 degF Pme area. Graf." Ib/gal Well Neater A /UWJ Rig Me. Drilled For Oil 8ervioa Wa Land C"MofEller capPyft Sire, in Weight lb/ft Greg. Thread ONghere none Well Cie.. New Well Type Development 11820.0 7.0 26.0 0.0 0.0 0.0 Drilling Fluid Type Max. Penalty ID/gal Flastic Viscosity CP Tubbq/gdD Pipe T/D Dappyft Sb; in WNphq lb/ft Greg. Thread Service Line Cementing Job type 7" Uner D 9517.0 5.0 19.5 D 11769.0 4.0 14.0 Max. Allowed Tub. Prete psi Max. Allowed Arm. Preis pal WH rmnstlen 2" 1502 ParibwtleM/OIMn Hnie Tap, ft Sotean, It ahot/ft Mo. of Snob Tatell Interval Service 1 .eructlan. R ft it ft It It R ft In Tract Down Drill Ape Displacement Parker Type 183.3 bbl Packer paper R Tubing Val. bbl Caging Va. annular VN. 1.9 told bbi Ppanhole VN. bbl Ca;,/Tubing Secured I Hide Vail. a culabd Prior to CammR ❑ Miahp Trade sq... Jab lift Pressure M Siwe Type Spumes, Type Ape Rooted El PIM Reciprocated ❑ Shoe pepth It Tool Type Ha Centrallems Top Pleas ---F- Plupg Stage Teel Type Teed Depth It Cement Head Types StaVd Teal Depth ft Tell Ma. Sire in Job ScbMukg For Sep/2912018 AW.d on Lera0an Sep/29/2018 Viva tootlon SeP/29/2018 COMar Type Tall Ape Depth ft Tsar Degree It Sas. Tebl Va, bbl Dab Time 24 -hr aleck TrtaNp "mr, Assure Ibis PSJ B/M Daus" U/G Volume CM _SyG OI SBL SSL MaaMsa 09/30/2018 00:32:38 124 0.0 5.99 0.0 0.0 Staged Acpuisition 09/30/2018 00:32:51 122 0.0 5.99 0.0 0.0 Rate Chaco; good 09/30/2018 00:33:02 119 0.0 5.99 0.0 0.0 PJSM Done 09/30/2018 00:34:18 119 0.0 5.99 0.0 0.0 09/30/2018 00:35:58 106 D.0 5.99 0.0 0.0 09/30/2018 00:37:38 88 0.0 5.99 0.0 0.0 09/30/2018 00:38:49 79 0.0 5.99 0.0 0.0 Bit. Air Down Hard Uma 09/30/2018 00:39:18 84 0.0 5.99 0.0 0.0 09/30/2018 00:40:58 113 0.0 6.55 0.0 0.0 09/30/2018 00:41:42 111 0.0 6.57 0.0 0.0 Fluld Padr Had U. 09/30/2018 00:42:38 15 2.1 6.72 0.1 0.1 09/30/2018 00:44:18 67 0.0 6.49 1.3 1.3 09/30/2018 00:45:58 44 0.0 6.49 1.3 1.3 09/30/2018 00:46:09 47 0.0 6.49 1.3 1.3 W. PF/ Test TIPS 09/30/2018 1 00:46:34 990 0.2 6.56 1.3 1.3 Trips hipped 09/30/2018 00:46:46 1140 0.0 6.49 1.3 1.3 High PT 09/30/2018 00:47:16 3959 0.0 6.49 1.4 1.4 Reset Total, Vol = 1.37 bbl 09/30/2018 00:47:38 3859 O.D 6.49 1.4 0.0 09/30/2018 00:48:44 3821 0.0 5.92 1.4 0.0 Pt Good 09/30/2018 00:49:18 -23 0.0 5.84 1.4 0.0 09/30/2018 00:50:14 47 0.0 7.41 1.4 0.0 Start betchMg MudAiSh Page 10 4 Molt MT6-06 FleM nlgne lab Stmt Sep/29/2018 curt4m4r ConocoMillim lab Number Bata lima Z r clod[ Treo0B9 lMnaru s PBI Flow Baer B/M BnMity M/0BBL Volume CNT S YBL ex Ma . 09/30/2018 00:52:38 61 0.0 11.29 1.4 0.0 09/30/2018 00:54:04 60 0.0 11.53 1.4 0.0 MudR Scaled 11.5 Heavy 09/30/2018 00:54:18 60 0.0 11.52 1.4 0.0 09/30/2018 00:54:38 145 0.9 11.52 1.4 0.0 Start MP Down Hole 09/30/2018 00:55:58 455 1.9 11.29 3.8 2.5 09/30/2018 00:57:38 417 1.9 11.48 7.0 5.6 09/30/2018 OD:59:18 403 1.9 11.57 10.2 8.8 09/30/2018 01:00:58 400 1.9 11.45 13.4 12.0 09/30/2018 01:02:38 408 1.9 11.39 16.5 15.2 09/30/2018 01:04:18 388 1.9 11.62 19.7 18.4 09/30/2018 01:05:12 145 0.3 11.62 21.4 20.0 End MudRsh 09/30/2018 01:05:58 34 0.0 11.56 21.4 20.0 09/30/2018 01:07:38 39 0.0 9.99 21.4 20.0 09/30/2018 D1:09:18 M 0.0 8.68 21.4 20.0 09/30/2018 01:09:32 42 0.0 8.69 21.4 20.0 Sart batching Cement 09/30/2018 01:10:45 64 0.0 1217 21.4 20.0 Res& TCW, Vol - 20.02 bbl 09/30/2018 01:10:58 72 0.0 13.35 21.4 0.0 09/30/2018 01:12:38 90 0.0 15.89 21.4 0.0 09/30/2018 01:12:51 90 D.0 15.89 21.4 0.0 Cement Scaled 15.9 09/30/2018 01:13:13 248 1.0 15.89 21.4 0.0 Sart Tail CMT Down Hole 09/30/2018 01:14:18 495 1.9 15.61 23.4 2.0 09/30/2018 01:15:58 456 1.9 15.89 26.5 5.1 09/30/2018 01:17:38 385 1.9 15.78 29.7 8.3 09/30/2018 01:19:18 329 1.9 15.74 32.8 11.4 09/30/2018 01:20:58 302 1.9 15.82 36.1 14.7 09/30/2018 01:22:38 245 1.9 15.86 39.3 17.9 09/30/2018 01:24:18 201 1.9 15.802 21 21.1 09/30/2018 01:25:58 182 1.9 15.85 45.6 24.3 09/30/2018 01:27:38 146 2.0 15.92 48.9 27.5 09/30/2018 01:29:18 163 2.0 15.90 52.2 30.8 09/30/2018 01:30:58 150 2.0 15.90 55.4 34.1 09/30/2018 01:32:38 151 2.0 15.88 58.7 37.3 09/30/2018 01:34:18 128 1.9 15.89 62.0 40.6 09/30/2018 01:35:58 123 1.8 15.82 65.1 43.8 09/30/2018 01:37:38 132 1.9 15.93 68.2 46.8 09/30/2018 01:39:18 143 1.8 15.92 71.3 49.9 09/30/2018 01:40:58 136 1.8 15.89 74.3 52.9 09/3D/2038 01:42:05 124 1.9 15.89 76.4 55.0 End Tad [mart 09/30/2018 01:42:07 124 1.9 15.89 76.4 55.0 Peeet Total, Vol = 55.D4 bbl 97 1.8 15.90 77.1 0.6 Fash water behind :42:38 61 1.9 15.90 77.4 0.9 M09/3012018DI:42:28:42:28 :44:18 32 2.0 15.90 80.6:45:58 32 2.0 15.90 83.8 7.4 1:47:38 33 2.0 15.91 87.0 10.6 09/30/2018 01:49:18 34 1.9 15.91 90.3 13.9 09/30/2018 01:50:58 36 2.0 15.91 93.5 17.1 09/30/2018 01:51:49 -33 0.3 15.91 95.1 18.7 20 bbh water behind by staPs 09/30/2018 01:52:32 -33 0.0 15.91 95.1 18.7 Swap torp to displace 09/30/2018 01:52:38 -34 0.0 15.91 - 95.1 18.7 09/30/2018 01:52:42 -35 0.0 15.91 95.1 18.7 Rene TOal, Vol = 18.70 btl 09/3D/2018 01:54:18 -17 0.0 11.41 95.1 0.0 09/30/2018 01:55:58 -20 0.0 11.38 95.1 0.0 09/30/2018 01:57:38 -20 0.0 11.39 95.1 0.0 09/30/2018 01:59:18 -23 0.0 11.18 95.1 0.0 Pa9a 7 aI4 Well W6-06 Fleg alone Sob Start SeW29/2018 Cueo r Conoco Phillips Jab Number Date Tim g 4,r mock Treating Veeawn PSS Flaw Rab B/N Density MJG Valume BSL CN[_STB_VM Nerage SSL 09/30/2018 02:02:38 -20 0.0 11.04 95.1 0.0 09/30/2018 02:04:18 -23 0.0 10.73 95.1 0.0 09/30/2018 02:05:58 -24 0.0 10.05 95.1 0.0 09/30/2018 02:07:38 -31 0.0 8.55 95.1 0.0 09/30/2018 02:09:18 -37 D.0 0.00 95.1 0.0 09/30/2018 02:10:58 -37 0.0 8.34 95.1 0.0 09/30/2018 02:12:38 -42 0.0 8.32 95.1 0.0 09/30/2018 02:14:18 6 0.0 8.30 95.1 0.0 09/30/2018 02:15:58 -37 0.0 5.82 95.1 0.0 09/30/2018 02:17:38 -39 0.0 5.77 95.1 0.0 09/30/2018 02:19:18 31 0.0 8.30 95.1 0.0 09/30/2018 02:20:58 -34 0.0 8.27 95.1 0.0 09/30/2018 02:22:38 -18 0.0 8.30 95.1 0.0 09/30/2018 02:24:18 -35 0.0 8.30 95.1 0.0 09/30/2018 02:25:58 27 0.0 8.31 95.1 O.0 09/30/2018 02:27:38 -37 0.0 8.16 95.1 0.0 09/30/2018 02:28:32 -38 0.0 7.98 95.1 0.0 Slow air down hard line 09/30/2018 02:29:18 -13 0.0 7.90 95.1 0.0 09/30/2018 02:30:58 -17 0.0 8.21 95.1 0.0 09/30/2018 02:32:38 -33 0.0 8.06 95.1 0.0 09/30/2018 02:34:18 -32 0.0 7.65 95.1 0.0 09/30/2018 02:35:58 -32 0.0 0.01 95.1 0.0 09/30/2018 02:37:38 -36 0.0 0.00 95.1 0.0 09/30/2018 02:39:18 -39 0.0 0.00 95.1 0.0 09/30/2018 02:40:58 -38 0.0 0.00 95.1 0.0 09/30/2018 02:42:38 -38 0.0 0.00 95.1 0.0 09/30/2018 02:44:18 -35 0.0 0.00 95.1 0.0 09/30/2018 02:45:58 -35 0.0 0.00 95.1 0.0 09/30/2018 02:47:38 -35 0.0 -0.00 95.1 0.0 09/30/2018 02:49:18 -37 0.0 0.01 95.1 0.0 09/30/2018 02:50:58 -34 0.0 -0.00 95.1 0.0 09/30/2018 02:52:38 -37 D.0 0.00 95.1 0.0 09/30/2018 02:54:18 -37 0.0 0.00 95.1 0.0 09/30/2018 02:55:58 -41 0.0 0.00 95.1 0.0 09/30/2018 02:57:38 -38 0.0 0.00 95.1 0.0 09/30/2018 02:59:18 -0O O.D 0.00 95.1 0.0 09/30/2018 03:00:58 -36 0.0 0.00 95.1 0.0 09/30/2018 03:02:38 -38 0.0 0.00 95.1 0.0 09/30/2018 03:04:18 -37 0.0 0.01 95.1 0.0 09/30/2018 03:05:58 -38 0.0 0.00 95.1 0.0 09/30/2018 03:07:38 -39 0.0 0.01 95.1 0.0 09/30/2018 03:09:18 -39 0.0 0.00 95.1 0.0 09/30/2018 03:10:56 -40 0.0 0.01 95.1 0.0 09/30/2018 03:12:38 -38 0.0 0.00 95.1 0.0 09/30/2018 03:14:18 -41 0.0 0.00 95.1 0.0 09/30/2018 03:15:58 -39 0.0 0.00 95.1 0.0 09/30/2018 03:17:38 -38 0.0 0.00 95.1 0.0 09/30/2018 03:19:18 -37 0.0 0.00 95.1 0.0 09/30/2018 03:20:58 -39 0.0 0.00 95.1 0.0 09/30/2018 03:22:38 -39 0.0 0.00 95.1 0.0 09/30/2018 03:24:18 -35 0.0 O.OD 95.1 0.0 09/3D/2018 03:25:58 -40 0.0 0.00 95.1 0.0 09/30/2018 03:2]:38 -38 0.0 0.00 95.1 0.0 09/30/2018 03:29:18 -37 0.0 0.00 95.1 0.0 Rage 3 ar4 Well MT6-06 RMp Alpine lobemR Sep/29/2018 Slurry Customer CpnoCOPhi11ip5 lob NumBw Dam Time 24M Jottlr TrwtM9 pmewre PSI TOW Slurry Row Rim B/M Mud perMRT LB/G volume BBL cNT STG_VOL Meseapa BBL 09/30/2018 03:32:38 1.9 -39 0.0 0.00 95.1 0.0 09/30/2018 03:34:18 0.0 -39 0.0 0.00 95.1 0.0 09/30/2018 03:35:58 BMeb4own Ruld -41 0.0 0.00 95.1 0.0 09/30/2018 03:37:38 Tw -38 Vplume 0.0 0.01 95.1 0.0 09/30/2018 03:39:18 255 -39 0.0 0.01 95.1 1 0.0 Post Sob Summary Pepe 4 et4 AVereSe Pump Roma. bbl/min Velum a pbap 3n3eAN, bW Slurry N2 Mu4 Mvi rn Rem TOW Slurry Mud S"mr N2 1.9 2.2 55.0 0.0 20.0 Tmetlng PmWm 8ummry, pM BMeb4own Ruld mzimum Fl .1 Awnpa Bump Mug m BnaY4own Tw Vplume p4mit, 4035 -41 255 bbl Ib/gal AVS. N2 Pement D"Sne4 Slurry Volum ols,m.nt Mls Weew Temp pmen[C12Wem mSurteal ❑ Volume bd weahep ".pertc ❑ TP R % 55.0 bbl 183.0 bd ]9 de9F cuammer w AuMOrle Rep .WH. SRAlumhwper Supervbor Clnmlatlm Lott ❑ 3O1bcomplam4 ❑2 Rob Reinhardt i n:e Kalivaa Pepe 4 et4 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permitto Drill 2180930 Well Name/No. GMTU MT6-06 V$10 Operator CONOCOPHILLIPS ALASKA, INC MD 17482 TVD 8111 REQUIRED INFORMATION PB2o Completion Date 10/21/2018 Completion Status 1 -OIL Current Status 1 -OIL Mud Log No ✓ Samples No DATA INFORMATION List of Logs Obtained: GR/RES/DEN/NEU , C Well Log Information: Log/ Electr API No. 50-103-20773-00-00 UIC No Directional Survey Yes v (from Master Well Data/Logs) Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name -Data Scale Media No Start Stop _ P CH Received Comments ED C 29959 Digital 115 17482 11/5/2018 Electronic Data Set, Filename: MT6-06 Drilling Mechanics Depth Data.las ED C 29959 Digital Data 60 17482 11/5/2018 Electronic Data Set, Filename: MT6-06 LTK Memory Drilling Data.las ED C 29959 Digital Data 11/5/2018 Electronic File: MT6-06 Drilling Mechanics Depth Log.ogm ED C 29959 Digital Data 11/5/2018 Electronic File: MT6-06 LTK 21VID Memory Log.cgm ED C 29959 Digital Data 11/5/2018 Electronic File: MT6-06 LTK 5MD Memory Log.cgm ED C 29959 Digital Data 11/5/2018 Electronic File: MT6-06 LTK 5TVD Memory Log.cgm ED C 29959 Digital Data 11/5/2018 Electronic File: MT6-06 Drilling Mechanics Time Log Run6.cgm ED C 29959 Digital Data 11/5/2018 Electronic File: MT6-06 LTK Memory Drilling Data.dls ED C 29959 Digital Data 11/5/2018 Electronic File: MT6-06 Drilling Mechanics Depth Log.PDF ED C 29959 Digital Data 11/5/2018 Electronic File: MT6-06 LTK 2MD Memory Log.pdf ED C 29959 Digital Data 11/5/2018 Electronic File: MT6-06 LTK 51VID Memory Log.pdf ED C 29959 Digital Data 11/5/2018 Electronic File: MT6-06 LTK 5TVD Memory Log.pdf ED C 29959 Digital Data 11/5/2018 Electronic File: MT6-06 Drilling Mechanics Time Log Run6.PDF AOGCC Page 1 of 6 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2180930 Well Name/No. GMTU MT6.06 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20773-00-00 MD 17482 TVD 8111 Completion Date 10/21/2018 Completion Status 1 -OIL Current Status 1-0I1. UIC No ED C 29959 Digital Data 11/5/2018 Electronic File: MT6-06 EOW-NAD27.pdf ED C 29959 Digital Data 11/5/2018 Electronic File: MT6-06 EOW-NAD27.txt ED C 29959 Digital Data 11/5/2018 Electronic File: MT6-06 EOW-NAD83.pdf ED C 29959 Digital Data 11/5/2018 Electronic File: MT6-06 EOW-NAD83.txt ED C 29959 Digital Data 11/5/2018 Electronic File: MT6-06_FinalSurvey.pdf ED C 29959 Digital Data 11/5/2018 Electronic File: MT6-06_FinalSurvey.bd Log C 29959 Log Header Scans 0 0 2180930 GMTU MT6-06 LOG HEADERS Log C 29960 Log Header Scans 0 0 2180930 GMTU MT6-06 PB1 LOG HEADERS ED C 29960 Digital Data 42 12688 11/5/2018 Electronic Data Set, Filename: MT6-06PB1 Drilling Mechanics Depth Data.las ED C 29960 Digital Data 0 12688 11/5/2018 Electronic Data Set, Filename: MT6-06PB1 LTK Memory Drilling Data.las ED C 29960 Digital Data 11/5/2018 Electronic File: MT6-06PB1 Drilling Mechanics Depth Log.cgm ED C 29960 Digital Data 11/5/2018 Electronic File: MT6-06P131 LTK 2MD Memory Log.cgm ED C 29960 Digital Data 11/5/2018 Electronic File: MT6-06PB1 LTK 51VID Memory Log.cgm ED C 29960 Digital Data 11/5/2018 Electronic File: MT6-06PB1 LTK 5TVD Memory Log.cgm ED C 29960 Digital Data 11/5/2018 Electronic File: MT6-06PB1 Drilling Mechanics Time Log Runl.cgm ED C 29960 Digital Data 11/5/2018 Electronic File: MT6-0613131 Drilling Mechanics Time Log Run2.cgm ED C 29960 Digital Data 11/5/2018 Electronic File: MT6-06PB1 Drilling Mechanics Time Log Run3.cgm ED C 29960 Digital Data 11/5/2018 Electronic File: MT6-06PB1 Drilling Mechanics Time Log Run4.cgm ED C 29960 Digital Data 11/5/2018 Electronic File: MT6-06PB1 LTK Memory Drilling Data.dls ED C 29960 Digital Data 11/5/2018 Electronic File: MT6-06PB1 Drilling Mechanics Time Data Run1.ASC ED C 29960 Digital Data 11/5/2018 Electronic File: MT6-06PB1 Drilling Mechanics Time Data Run2.ASC AOGCC Page 2 of 6 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill MD 17482 2180930 Well Name/No. GMTU MT6-06 TVD 8111 Completion Date 10/21/2018 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20773-00-00 Completion Status 1-011- Current Status 1 -OIL UIC No 29960 Digital Data 11/5/2018 Electronic File: MT6-06PB1 Drilling Mechanics Time Data Run3.ASC FED 29960 Digital Data 11/5/2018 Electronic File: MT6-06PB7 Drilling Mechanics Time Data Run4.ASC 29960 Digital Data 11/5/2018 Electronic File: MT6-06PB1 Drilling Mechanics Depth Log.pdf ED C 29960 Digital Data 11/5/2018 Electronic File: MT6-06P131 LTK 2MD Memory Log.pdf ED C 29960 Digital Data 11/5/2018 Electronic File: MT6-06PB1 LTK 51VID Memory Log.pdf ED C 29960 Digital Data 11/5/2018 Electronic File: MT6-06PB1 LTK 5TVD Memory Log.pdf ED C 29960 Digital Data 11/5/2018 Electronic File: MT6-06PB1 Drilling Mechanics Time Log Runl.pdf ED C 29960 Digital Data 11/5/2018 Electronic File: MT6-06PB1 Drilling Mechanics Time Log Run2.pdf ED C 29960 Digital Data 11/5/2018 Electronic File: MT6-06PB1 Drilling Mechanics Time Log Run3.pdf ED C 29960 Digital Data 11/5/2018 Electronic File: MT6-06PB1 Drilling Mechanics Time Log Run4.pdf ED C 29960 Digital Data 11/5/2018 Electronic File: MT6-06 P131 EOW-NAD27.txt ED C 29960 Digital Data 11/5/2018 Electronic File: MT6-06 FBI EOW-NA083.pdf ED C 29960 Digital Data 11/5/2018 Electronic File: MT6-06 P131 EOW-NAD83.txt ED C 29960 Digital Data 11/5/2018 Electronic File: MT6-06PB1 EOW-NAD27.pdf ED C 29960 Digital Data 11/5/2018 Electronic File: MT6-06PB1_FinalSurvey.pdf ED C 29960 Digital Data 11/5/2018 Electronic File: MT6-06Pl31_FinalSurvey.txt ED C 29961 Digital Data 115 16803 11/5/2018 Electronic Data Set, Filename: MT6-06PB2 Drilling Mechanics Depth Data.las ED C 29961 Digital Data 60 16802 11/5/2018 Electronic Data Set, Filename: MT6-06PB2 LTK Memory Drilling Data.las ED C 29961 Digital Data 11/5/2018 Electronic File: MT6-06PB1 Drilling Mechanics Depth Log.cgm ED C 29961 Digital Data 11/5/2018 Electronic File: MT6-06PB2 LTK 21VID Memory Log.cgm AOGCC Page 3 of 6 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2180930 Well Name/No. GMTU MT6-06 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103.20773-00-00 MD 17482 TVD 8111 Completion Date 10/21/2018 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 29961 Digital Data 11/5/2018 Electronic File: MT6-06PB2 LTK 5MD Memory Log.cgm ED C 29961 Digital Data 11/5/2018 Electronic File: MT6-06PB2 LTK 5TVD Memory Log.cgm ED C 29961 Digital Data 11/5/2018 Electronic File: MT6-06PB2 Drilling Mechanics Time Log Run5.cgm ED C 29961 Digital Data 11/5/2018 Electronic File: MT6-06PB2 LTK Memory Drilling Data.dls ED C 29961 Digital Data 11/5/2018 Electronic File: MT6-06PB2 Drilling Mechanics Depth Log.PDF ED C 29961 Digital Data 11/5/2018 Electronic File: MT6-06BP2 LTK 51VID Memory Log.PDF ED C 29961 Digital Data 11/5/2018 Electronic File: MT6-06BP2 LTK 5TVD Memory Log.pdf ED C 29961 Digital Data 11/5/2018 Electronic File: MT6-06PB2 LTK 21VID Memory Log.pdf ED C 29961 Digital Data 11/5/2018 Electronic File: MT6-06PB2 Drilling Mechanics Time Log Run5.pdf ED C 29961 Digital Data 11/5/2018 Electronic File: MT6-06PB2 EOW-NAD27.pdf ED C 29961 Digital Data 11/5/2018 Electronic File: MT6-06PB2 EOW-NAD27.t# ED C 29961 Digital Data 11/5/2018 Electronic File: MT6-06PB2 EOW-NAD83.pdf ED C 29961 Digital Data 11/5/2018 Electronic File: MT6-06P82 EOW-NAD83.tM ED C 29961 Digital Data 11/5/2018 Electronic File: MT6-06PB2_FinalSurvey.pdf ED C 29961 Digital Data 11/5/2018 Electronic File: MT6-06PB2_FinalSurvey.bd Log C 29961 Log Header Scans 0 0 2180930 GMTU MT6-06 PB2 LOG HEADERS ED C 30077 Digital Data 12/7/2018 Electronic File: MT6-06 EOW-NAD27.pdf ED C 30077 Digital Data 12/7/2018 Electronic File: MT6-06 EOW-NAD27.txt ED C 30077 Digital Data 12/7/2018 Electronic File: MT6-06 EOW-NAD83.pdf ED C 30077 Digital Data 12/7/2018 Electronic File: MT6-06 EOW-NAD83.bd Log C 30077 Log Header Scans 0 0 2180930 GMTU MT6-06 LOG HEADERS Log C 30078 Log Header Scans 0 0 2180930 GMTU MT6-06 PB1 LOG HEADERS ED C 30078 Digital Data 12/7/2018 Electronic File: MT6-061381 EOW-NAD27.pdf AOGCC Page 4 of 6 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2180930 Well Name/No. GMTU MT6-06 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20773-00.00 MD 17482 TVD 8111 Completion Date 10/21/2018 Completion Status 1-0I1- Current Status 1-0I1- UIC No ED C 30078 Digital Data 12/7/2018 Electronic File: MT6-06PB1 EOW-NAD27.t# ED C 30078 Digital Data 12/7/2018 Electronic File: MT6-06PB1 EOW-NAD83.pdf ED C 30078 Digital Data 12/7/2018 Electronic File: MT6-06PB1 EOW-NAD83.txt ED C 30079 Digital Data 12/7/2018 Electronic File: MT6-06PB2 EOW-NAD27.pdf ED C 30079 Digital Data 12/7/2018 Electronic File: MT6-061282 EOW-NAD27.txt ED C 30079 Digital Data 12/7/2018 Electronic File: MT6-06PB2 EOW-NAD83.pdf ED C 30079 Digital Data 12/7/2018 Electronic File: MT6-06PB2 EOW-NAD83.t# Log C 30079 Log Header Scans 0 0 2180930 GMTU MT6-06 PB2 LOG HEADERS ED C 30326 Digital Data 14490 9401 2/5/2019 Electronic Data Set, Filename: MT6- 06_MFC40_24NO V 18_Centered.las ED C 30326 Digital Data 14490 9401 2/5/2019 Electronic Data Set, Filename: MT6- 06_MFC40_24NOV18_Uncentered.las ED C 30326 Digital Data 2/5/2019 Electronic File: MT6- 06_MFC40_24NO V 18_Report.pdf ED C 30326 Digital Data 2/5/2019 Electronic File: MT6- 06_MFC40_24NOV18_CENTERED.cmi ED C 30326 Digital Data 2/5/2019 Electronic File: MT6- 06_MFC40_24NOV18_CENTERED.wvd ED C 30326 Digital Data 2/5/2019 Electronic File: MT6- 06_MFC40_24NOV18_CENTERED.wvf ED C 30326 Digital Data 2/5/2019 Electronic File: MT6- 06_MFC40_24NOV18_CENTERED.wvp ED C 30326 Digital Data 2/5/2019 Electronic File: MT6- 06_MFC40_24NOV18_UNCENTERED.cmi ED C 30326 Digital Data 2/5/2019 Electronic File: MT6- 06_MFC40_24NOV18_UNCENTERED.wvd ED C 30326 Digital Data 2/5/2019 Electronic File: MT6- 06_MFC40_24NOV18_UNCENTERED.wvf ED C 30326 Digital Data 2/5/2019 Electronic File: MT6- 06_MFC40_24NOV18_UNCENTERED.wp ED C 30326 Digital Data 2/5/2019 Electronic File: MT6-06_MFC40_24NOV18.pdf ED C 30326 Digital Data 2/5/2019 Electronic File: MT6- 06_MFC40_24NO V 18_img.tiff Log C 30326 Log Header Scans 0 0 2180930 GMTU MT6-06 LOG HEADERS AOGCC Page 5 of 6 Monday, Febrwry 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2180930 Well Name/No. GMTV MT6-06 Operator CONOCOPHILLIPS ALASKA, INC. MD 17482 TVD 8111 Completion Date 10/21/2018 Completion Status 1 -OIL Current Status 1 -OIL Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report ��V Production Test InformatioY/ NA Geologic Markers/Tops Y COMPLIANCE HISTORY Completion Date: 10/21/2018 Release Date: 8/16/2018 Description Comments: Compliance Reviewed By: Directional / Inclination Data D Mechanical Integrity Test Information Y / NA Daily Operations Summary O Date Comments API No. 50-103-20773-00-00 UIC No Mud Logs, Image Files, Digital Data Y 1( Core Chips YA Composite Logs, Image, Data Files 0 Core Photographs Y / Cuttings Samples Y / I� Laboratory Analyses Y / Date: AOGCC Page 6 of 6 Monday, February 25, 2019 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Adam Klem Completions Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Greater Mooses Tooth Field, Lookout Oil Pool, MT6-06 Permit to Drill Number: 218-093 Sundry Number: 319-064 Dear Mr. Klem: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Ww .aogcc.alaska.gov 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 fiu-ther 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, -44' Daniel T. Seamount, Jr. Commissioner yL� DATED this 1-57 day of February, 2019. ����2 RIMMS.,L FEB 19 2019 SCANNED !.""R 0 F 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 11 2013 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑� . Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Exploratory ❑ Development Q Stratigraphic Service El 218-093 ' 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20773-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? MT6-06 r Will planned perforations require a spacing exception? Yes ❑ No ❑Q 9. Property Designation (Lease Number): 10. Field/Pool(s): AA081818, AA092346:AA081798, AA092342 Greater Mooses Tooth Unit Lookout 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): 17482 8111 Casing Length Size MD TVD Burst Collapse Structural Conductor 152 20 115 115 Surface 2155 13.375 2118 2003 Intermediate 10353 9.625 10316 7245 1 1 Production 11870 7 118331 7983 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 4 1/2" L80 11675 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): ZXP linertop, no SSSV 11,665'MD no SSSV 12. Attachments: Proposal Summary Wellbore schematic EF 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hic g p ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/23/2019 OIL ❑Q 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 poor written approval. Contact Adam Klem, 907-263-4529 Email adarnAlern(WonocoPhillios.corn Printed Name Ada tem Title Completions Engineer Signature Phone 907-263-4529 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes E] No [qO Subsequent Form Required: -�jOg lLI) APPROVED BY Approved b SOMMISSIONER THE COMMISSION Date: rrn nn4n . I LD I J LUTa Submit Form and Form 10403 Revised 11/2015 Approved applicatlo i V I f h f mhe date Of a r�` fOV�I��V\ Attachments in Duplicate MT6-06, B1 Location Final Completion Schematic 20" 79 ppt H40 Insulated Conductor 80 feet, cernerked to surface In I 13-V8- 69 PpfL$O T7(PtBTCM I Surface Casing @ 2118' MD 12003' TVD Q ceitio ted to sttdacs - I 4-112" 116 pill LA0 Tamils Blue to 11,678 MO Tubing! Lina Corrgtkbon: 1) 4-14^ Landing Nipple (3813' X) @ 2,108' MO 2) 4-Y' x 1' GLM @ 4,084' MO 3) 4%' x 1` GCM @ 8,101' MD 4) 4-'/.' X V GLM @ 11,409' MD 5} Oomaiaole Gauge @ 11,%6' MD 6) 4-M.'Landing Nipple (3,75XN) set at 11,61T MO @68 deg 7) Liner Top Packers Hanger@ 11,665 MD w1 Tie Back sleeve 8) 4 VV UP Bus Blank Plpawl peRpints I 7"25 poll LA0 I TS Blue Tie Hack n i fl 0 n i n 9518" 46 ppt LM NYd563(to 1,169 MD) n 9518" 40 PM LA0 TXP(to 6,278'MD) n 9518"40 pptTN-80 HS TXP Ito TD) @ 10,316 MD 17,245 TVD I 1 1 � 5 0 i Y E TOC at least 380'MD1. 0 above Packer 8 500' 4-'l," 12.69 LA0 TXP MD above Alpine C With Ped Puns Planned to liner Top. @ 18,828 MD Top ApraeC 11,849'MDl 7,gM'TVD ` 7"26 ppf L-80 TS Bare Liner t0 11,833 MD 17,983' TVD @ 73 deg 0 6" note, TD at at 17,482'MDJ8,111'TVD October2018-AX Section 1 - Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1). TO THE. __ASKA OIL AND GAS CONSERVATION COIVt_..3SION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Jason E. Lyons Request of ConocoPhillips Alaska, Inc. for ) Hydraulic fracturing for the MT6-06 Well ) under the Provisions ) of 20 AAC 25.280 ) STATE OF ALASKA ) THIRD JUDICIAL DISTRICT ) herein. Jason E. Lyons, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Jason E. Lyons. I am over 19 years old and have personal knowledge of the matters set forth 2. 1 am Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAP') 3. Pursuant to 20 AAC 25.283 (1) CPAI prepared the attached Notice of Operations ("Notice"). 4. On February 5, 2019, CPAI sent a copy of the Notice by certified mail to the last known address of all other owners, landowners, surface owners, and operators of record within a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 51h day of February, 2019. Jason E. Lyons STATE OF ALASKA ) THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 51h day of February, 2019 by Jason E. Lyons. Noiary Public, State of Alaska My Commission Expires: STATE OF ALASKA NOTARY PUBLIC, REBECCA SWENSEN My Commission Ek lms Aug. Con ocoPhillips Alaska February 5, 2019 To: Operator and Owners (shown on Exhibit 2) Jason Lyons Staff Landman Alaska Land & BD ConocoPhillips Company 700 G Street, ATO -1478 Anchorage, AK 99501 Office: 907-265-6002 Fax: 918-662-3472 jason.lyons@cop.com VIA CERTIFIED MAIL Re: Notice of Operations pursuant to 20 AAC 25.283 (1) for MT6-06 Well AA -92346 (ASRC), AA -92342 (ASRC) Greater Mooses Tooth Unit, Alaska CPAI Contract No. 204278 Dear Operator and Owners: ConocoPhillips Alaska, Inc. ("CPA]") as Operator and 100% working interest owner of the of the Greater Mooses Tooth Unit C GMTU"), hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the MT6-06 well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about February 8, 2019. This Notice is being provided pursuant to subsection of 20 AAC 25.283. The Well is currently planned to be drilled as a directional horizontal well on leases AA -92346 (ASRC) and AA -92342 (ASRC) as depicted on Exhibit I and has locations as follows: Location FNL FEL Township Range Section Meridian Surface 268' 3189' ION R3E 6 Umiat Top Open Interval 2040' 2576' T11N R2E 36 Umiat Bottomhole 1824' 315' TION R2E 1 Umiat Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section ("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of record of all properties within the Notification Area. Upon your request, CPAI will provide a complete copy of the Application. If you require any additional information, please contact the undersigned. Si erely, son ons Staff Lan an Attachments: Exhibits I & 2 AA092346 AA092342 Well Pad Well Trajectory Frac Interval Q Half Mile Frac Point Radius Half Mile Trajectory Radius — Welts within Trajectory Radius L..__.� Lookout PA CPAI Leases Exhibit 1 N A 0 0.2 0.4 0.6 r Miles AA081798 Y ConocoPhillips Alaska MT6-06 Lease Plat 1/24Y Exhibit 2 List of the names and addresses of all owners, landowners and operators of all properties within the Notification Area. Operator & Owner: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1226 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Misty Alexa, NS Development Manager Landowners: Arctic Slope Regional Corporation 3900 C Street, Suite 801 Anchorage, Alaska 99503-5963 Attention: Teresa Imm, Executive VP, Regional and Resource Development United States Department of Interior, BLM 222 West 7th Avenue, #13 Anchorage, AK 99513 Attention: Wayne Svejnoha, Branch Chief Energy and Minerals Surface Owner: Kuukpik Corporation P.O. Box 89187 Nuiqsut, AK 99789-0187 Attention: Joe Nukapigak, President United States Department of Interior, BLM 222 West 7th Avenue, #13 Anchorage, AK 99513 Attention: Wayne Svejnoha, Branch Chief Energy and Minerals Section 2 — Plat 20 AAC 25.283 (a)(2) Plat 1: Wells within .5 miles a AA092346 3s y &°m oR0 b@i AA081818 s t � I 1 i f � 1 r ! t •_y"(,.±_ ,ate. j 'yJF-3 MT6? i I i r i AA092342 i ? ; AA081798 r i i t ;,- Well Pad i lookout PA I Well Trajectory *— Frac Interval ® Half Mile frac Point Radius}' h GonocoPhillips Half Mile Trajectory Radius 11801 Alaska Wells within Trajectory Radius MT6-06 lookout PA 0 0.2 04 0.6 Lease Plat CPAs leases Miles 7/2472019 Table 1: Wells within .5 miles API I Well Name I Well Type I Status 501032077000 MT6-03 PROD ACTIVE 501032077070 MT6-03PH SVC PROP 7 501032077500 MT6-04 IN1 ACTIVE 501032077570 MT6-04PB1 EXPEND PA 501032077100 MT6-05 PROD ACTIVE 501032077160 MT6-051-1 PROD ACTIVE 501032077170 MT6-05PB1 EXPEND PA 501032077171 MT6-05PB2 EXPEND PA 501032077370 MT6-06PB1 EXPEND PA 501032077371 MT6-06PB2 EXPEND PA 501032077200 MT6-08 IN1 ACTIVE 501032077270 MT6-08PB1 EXPEND PA 501032077900 MT6-09 INJ ACTIVE SECTION 3 — FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. See Conclusion number 6 of the Area Injection Order AIO 40- Greater Moose's Tooth Field, Lookout Oil Pool, which states: "There are no freshwater aquifers in the Affected Area of the LOP." SECTION 4 — PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. SECTION 5 — DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) All casing is cemented in accordance with 20 AAC 25.52(b) and tested in accordance with 20 AAC 25.030 (g) when completed. See Wellbore schematic for casing details. SECTION 6 — ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(a)(6) Casing & Cement Assessments: 13 & 3/8" casing cement pump report on 9/13/18 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 11 ppg LiteCRETE cement lead, followed by 15.8 ppg class G cement displaced with 10ppg mud. Full returns were seen throughout the job. The plug bumped at 900 psi and the floats were checked and they held. 9 & 5/8" casing cement pump report on 9/22/2018 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 12.2ppg cement lead, followed by 15.8 ppg class G cement, displaced with 10.4ppg mud. Full returns were seen throughout the job. The plug bumped at 1100 psi and the floats were checked and they held. The 7" casing cement report on 9/30/2018 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg class G cement. Full returns were seen throughout the job. summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. SECTION 7 — PRESSURE TEST INFORMATION AND PLANS TO PRESSURE -TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 9/15/2018 the 13-3/8" casing was pressure tested to 3,000 psi for 30 mins. On 9/24/2018 the 9-5/8" casing was pressure tested to 3,500 psi for 30 mins. On 10/3/2018 the 7" casing was pressure tested to 3,500 psi for 30 mins. On 10/25/2018 the 4.5" tubing was pressure tested to 3,500 psi for 30 mins. Prior to Frac, the 4.5" tubing will be pressured tested to 4,400 psi and the 7" IA will be pressure tested to 3,850 psi. AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 6,000 Annulus pressure during frac 3,500 Annulus PRV setpoint during frac 3,600 7" Annulus pressure test 3,850 4 1/2" Tubing pressure Test 4,370 Nitrogen PRV 6,935 Highest pump trip 6,735 SECTION 8 — PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight Grade API Burst API Collapse 10 & 3/8" 68 L-80 5,020 psi 2,260 psi 9 & 5/8" 40 L-80 5,750 psi 3,090 psi 7" 26 L-80 7,240 psi 5,410 psi 4.5' 12.6 L-80 8,430 psi 7,500 psi Table 2: Wellbore pressure ratings 81G ITatpe Tale Tar& Stimulation Surface Rig -Up r y Hauldumd 9 POP,ONTmk i> �ca r� L 0 Frac Pune Frac Pune IN • Minimum pressure rating on all surface treating lines 10,000 psi • Main treating line PRV is set to 95% of max treating pressure • IA parallel PRV set to 3,600 psi • Frac pump trip pressure setting are staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 psi. 1 Pune raKk Frac Pune Frac Ping, ¢mcU VM ct Stimulation Tree Saver OPEN POSITION [PRIOR TO WANDKI. MERDbN) CLOSED POSITION iMANDREL INSERTED) stinger ASSEMBLY TN T PtAGF !N tU81NG Y • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 '/2 tubing and 1.75" down 3 % tubing. • Max rate with 2.25" mandrel is 60 bpm and with 1.75" mandrel 36 bpm VENT riLLVE OVEN a Alpine Wellhead System SECTION 9 — DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPA] has formed the opinion, based on seismic, well, and other subsurface information currently available that: The Alpine C interval is approximately 50' TVD thick at the heel of the lateral and thinning to approximately 25' at the toe. The Alpine C sandstone is very fine grained quartz rich sandstone with varying amounts of g]auconite and a fining upward log profile. Top Alpine C is estimated to be at 11,879' MD/ 7,905 TVDSS. The estimated fracture gradient for the Alpine C sandstone is 12.5 ppg. The overlying confining zone consists of greater than 800' TVD of Miluveach, Kalubik and HRZ mudstones. The estimated fracture gradient for the Miluveach is 15-16 ppg and for the Kalubik and the HRZ is 16 ppg. Top HRZ was encountered at 10,288' MD/ 7,135' TVDSS. The underlying confining zone consists of approximately 1800' TVD of Kingak shales. The estimated fracture gradient for the Kingak interval ranges from 15-18 ppg. Fracture gradient increases down section. The top of the Kingak interval ranges from 7,950' TVDSS ( 12,255' MD in the MT6-06PB1) at the heel to 17,402' MD/ 8,016 TVDSS at the toe of the well. SECTION 10 — LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing & Cement assessments for all wells that transect the confining zone: MT6-03: The 7 casing cement pump report on 4/16/2018 shows that the job was pumped with 84bbls losses with 47bbls lost after cement was in openhole leaving 37 bbis cement behind liner. The cement job was pumped with 15.8 ppg Class G cement, displaced with 10.8 LSND. The string was then unstung from the cement retainer. MT6-03PH: MT6-03PH was plugged and abandoned per state regulations on 4/6/2018. MT6-04: 7 casing cement pump report on 11/6/2018 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg Class G cement, and displaced with 11.2 ppg LSND. Full returns were seen throughout the job. The plug bumped @ 1100 psi and the floats were checked and they held. MT6-04PB1: This lateral was openhole sidetracked and therefore falls under the casing and cement assessment for MT6-04. MT6-05: 7" casing cement pump report on 5/29/2018 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 12.2 ppg Class G for the lead and 15.8 ppg Class G cement for the tail, and displaced with 10.7 ppg LSND. Full returns were seen throughout the job. The string was then unstung from the cement retainer. MT6-05L1: This is the upper lateral on MT6-05 and therefor falls under the casing and cement assessment for MT6-05. MT6-05PB1: MT6-05PB1 was plugged and abandoned per state regulations on 6/12/2018. MT6-06PB1: MT6-05PB1 was plugged and abandoned per state regulations on 10/7/2018. MT6-06PB2: This lateral was openhole sidetracked and therefore falls under the casing and cement assessment for MT6-06. MT6-08: 7" casing cement pump report on 8/16/2018 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg Class G cement, and displaced with 10.8 ppg LSND. Full returns were seen throughout the job. The string was then unstung from the cement retainer. MT6-08PB1: MT6-08PB1 was plugged and abandoned per state regulations on 8/7/2018. MT6-09: The 7' casing cement pump report on 12/7/2018 shows that the job was pumped with 32bbls lost after cement was in openhole leaving 27.5 bbls cement behind liner. The cement job was pumped with 15.8 ppg Class G cement, displaced with 10.8 LSND. The string was then unstung from the cement retainer. MT6-06 Fracture Stimulation Area of Review WELLNAME STATUS CmIng5lee To of Oil Pool P To of 011 Pool p To of Cement p To of Cement p To of Cement p Cement Operations (MD) (TVDSS) (MD) (TVDSS) Determined By ReserwlrShtus Zonal isolation Summary Mechanical iota Integrity 5/8/181 ]" casing W6.03P 3 ACTIVE ]" %80 8] 8,355' 7023 Log open hale liner for production TOC @ 8,355&Packer@10,029' 421 sx 15.8 ppg class G pressure tested to 3,300 cement sl Plug #1: 341 ax 15.8 ppg Class MT6-03PH PROP N/A 9680 ]78] 8,172' 6921 Tag PA PA, Cement Plugs GPlug #2: 341 sx 15.8 ppg N/A class G cement Plug 113: 356 sx 17 on class G cement 14T6-0 ACTIVE ]" 9181 ]881 7,]08' ]29] Log Pre -perforated injection TOC@7,708'&Packer@],546' 259sx 15.8 ppg class G 11/16/18,7"casing4 pressure tested to 3,300 cement si 11/16/18, T' casing MT604PB1 PA N/A 9181 7861 ],]OB' ]29] Log ON sidetrack in lateral TOC @],]OB'&Packer @7,546' 259 sx 15.8 ppg class G pressure tested to 3,300 cement Pei MT6-05 ACTIVE 7" 10625 ]848 8,933 ],043 Log open hole liner for ,933' TOC @ 8,933' & Packer Lead: ]8 sx 12.2 ppg class G ]/13/38, T' casing Production cement Tall:126 sx 15.8 on pressure tested to 3,300 class G cement psi MT6-0Sl1 ACTIVE ]" 10625 ]Bq8 8933 7,043 Log open hole llnerforpreduaion TOC @ 8,933' &Packer @ Lead: 78 sx 12.2 ppg class G ]/13/18, 7" casing 10,814' cement Tail:126 sx 15.8 ppg pressure tested W 3,300 class G cement sl MT6-0SPBI PA NA 10625 7848 1062]' ]848 Ta PA PA, Cement Plus 123 sx 16.5 pipg Class NA MT6-0SPB2 PA N/A 10625 7848 8933 7,043 Log ON sidetrackTOC@8,933'&Packer@ sidetrack In lateral Lead: 78 sx 1 c lessG cementTail 2.2 ppg 26 sx 15.8 N/A 10,814' ppg class G cement Plug #1:109 sx 15.8 ppg Class M16-06PB1 PA N/A 11,775 7,876 11,651' 7834 Tag PA PA, Cement Plugs GPlug #2:135 ax 16.5 ppg N/A class G cement MT6-06P82 PA N/A 11,775 ],8]6 10,047' 6960 Calculated ON sidetrack in lateral TOC @ 10,047 & Packer @ TOC 266 sx 15.8 ppg class G 10/25/18, ]" casing cement pressure tested to 3,500 si M36-08 ACTIVE 7" 11956 7812 10,310' 7142 Lo g pre- perforated liner for infection TOC @10,310'&Packer @ 301sx15.8ppg class G 9/3/18,]"casing 10,814' cement pressure tested M 3,300 P.1 MT6-08PB1 PA N/A 11956 7812 10,221' 7094 Tag PA PA, Cement Plugs 235 sx 17 ppg Class G cement N/A MT6-09 ACEIVE 7" 11873 ]789 10,326' 7155 Log Pre -perforated liner for infection TOC @ 10,326' & Packer @ 28] sx 15.8 ppg class G 12/20/18, T' casing 11,664' cement pressure tested to 3,300 SECTION 11 — LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that 2 fault or fracture systems transect the Alpine C formation or enter the confining zone within one half mile radius of the wellbore trajectory for MT6-06. The two faults system were interpreted from seismic data prior to drilling and 1 was confirmed with log data while drilling. The fault was a single fault plane with 5' of throw at 16,495' MD and the second fault is not present in the MT6-06 wellbore. Any faults that are within the half mile radius of the wellbore do not extend up through the confining interval and fracture gradients within the top seal intervals would not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults will not interfere with containment. Based on our knowledge of the principle stress direction in the Alpine C formation, along with the well path, all the fractures will be longitudinal, running parallel to the wellbore. We do not expect any of our hydraulic fractures to intersect faults seen in this wellbore. If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. Vertical Well Depth Depth Loss Name MD (ft) TVDSS (ft) Displacement (bbls/hr) MT6-06 16,495 7990 5' None Plat 2: MT6-06 Fault Analvsis o° 0 $n 4 a m $b Uri w AA092346 �Q0^ AA081818 --------------- LIP g by i °sae g s f bm i { t 1 f I i i MT6 i t w i { AA092342 I ! { AA081798 p Well Pad i i — Well Trajectory i Lookout PA i Frac Interval ® Half Mile Frac Point Radius Q Half Mile Trajectory Radius N COCIOCOPIIlllpS ® Faults within Frac Point Radius 1801 Alaska — Wells within Frac Point Radius MT6-06 ._.. Lookout PA 0 0.2 0.4 0.6 Frac Plat CPAI Leases Miles 1/24/2019 SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) MT6-06 was completed in 2018 as a producer with 4.5" tubing and a 4.5" liner with perf pups. Due to low production rates, a diversion frac will be performed. After the 1:t stage we will drop and array of dissolvable pods to attempt to plug of the perf holes to divert the frac to new formation. Proposed Procedure: Halliburton Pumping Services: 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre -frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 15 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 6,500 bbls are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. MIRU Stinger Tree Saver Equipment and HES Frac Equipment. 6. PT Surface lines to 9,000 psi using a Pressure test fluid. 7. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 8. Pump the 310 bbl breakdown stage (35# Hybor G) according to the attached excel HES pump schedule. Bring pumps up to maximum rate of 30 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 9. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 10. Pump the Frac job by following attached HES schedule @ 30bpm with a maximum expected treating pressure of si. F— ro v0OPs i • 4 stages, — 400,000 lbs of 20/40 Wanli proppant 11. RDMO HES Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 12. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). CUSTOMER CMoMindt"NaaM RN 54010,x,,3 BFp(m/9W/ F.I. .1 ralu3s63x "A $RLESOROER RXSTIY/ Igt xALL®uHT +^^^ Lpl4 151418]436 Teetered! tmerval $lobe Number no Fluid Cehut-in sM1ua-In Slope OShut-iion sbm-In Proppant Om[NpNon prop .ve:) (ppel $lurry Nae (banal OeYOn Clean Volume IWII re 1,, M:4gn Clpn VWum IbM9a De[Ign Sfulry Volume Ibbp Oex;gal 'al flbal $lade Tme Ibb:mmnal Interval Tme IMI:mm:Ml 147:17 LOsur63W0 IapUM tand"AedlbTPa _ . CL -33 UC [L-3] fwrl AlWII !Wr) LV7-SIXI H IBorIM wAn (00[3 886 anus W) Ory.MtlHluar DpIiFM-01 Oanxntrl 'pi'll IWU $p (Mat ppm I1 L3 1-3 iA 135 Wb. X35 boa X35 Wi1¢rira[G Shut -In IoM wm Mlnlfra[ nuaM1 Stalin 0.6 1.1 3a 30 30 AM 13.0$0 ],609 1z 31p 181 12 310 Igl 1 2.5 1 03 Ox)M24 M10:. O:MA2 347:17 3A6:54 3:36:34 3:30:31 tM I.W 1C0 Mso list 050 p.M MOO 0.90 a.4s OAS 045 ism 35. 3500 pas 015 p.15 m0 2.00 2.pp o.zs 0.25 015 `a q[ ' E $ ^[[gl ' LS 1-6 1-7 Id lA 120 ]-]S tit t -t3 t-10 1-15 1-16 1-17 1-18 1-]9 1-30 131 133 ,23 34 L35 126 1-2] ]30 ]E9 130 1-34 p35 WbW tl35 H56W p35 XMi p35 HYhW 035 NybOG tl35 XVbW 0735 XVbW p;S WboG p35 M. IS Wbati p35N bW #35 NYhG .3S.A. p35 HYboG a3S XybpG X35N boo .35 xybW X35 boG .35 Whve 835 XYER3 p35 XyhG 035 HMMM p35 XybuG p35 XyN 435 HyboG p35 xyboG 0733 HVboG Walel Fla[6 11ut11 pat, Proppant laden Fluid Proppant laden Fluid %op.na laden Fluid p ,114440 Fluid pro nl Ladee Fluid Spa[er RSpWs pad Pmppanl laden Flud Proppant LadM Flultl Proppant laded Filed proppanaladen Fluid Spa[tt ITS Pods pad An". laden Huid Proppantladen Fluw0/40 Proppand Spacer, Fluid/40 Spacer30 Tn POda proppanl laden Fluitlg�W�. Pad30 pro n[LadM Fluld/40 h0ppalO Wen Flultl/40 Im mWen Fluid/40 poppana laden Huitl/40 HuaM130 Pdata5 1 SM1ulln Wandu 10040 Wan1120/40 Wan1130/40 WinIi 30/40 004011$0/40 MMds WanIl W. Wan1130/40 Wanli$Od. Wan1130/40 TIS Pods Wank 20/a0 /40 ift 200 I,W 3.00 350 4400 ]D2 2.6] 3.00 4.[0 l.. I. 340 4fp l.M 2.40 3. 1. 30 30 M 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 15.177 ]3,20> U4. &333 7,429 I= El0 s. 6740 13,800 ]2,gpp iLdM) 6.900 210 5,040 8,140 12. 1$,400 1I6. fi.9. 210 I.. 0.240 12.6. 114. 11,6040 6,9040 7,609 1,30a 361 2% 295 L90 t" 21 5 I20 2. 305 $95 2.. 1. 5 110 200 305 395 I. 164 5 I ) 208 305 ]96 276 160 181 3] 361 300 An R6 205 sa 5 320 IMA 5. 32$ 3fa 194 S 120 300 319 323 314 19a S 120 U. Its 32] 31a 394 tat".,aP.aly,F-7 31 12j00 24400 25,0040 26,000 13,003 20 12,ftO 21,800 3q,0pp 21,6. $0 12,BM S4,. 34,840 3].600 40 UB40 $4,b0 34,80) 22,U1 Mt2:03 Q1M07 0:10:44 0:0]:31 (:06:50 Mal. OW:10 O:W:W 006:56 0:10:32 0:20:44 0:1040 D06:29 0.00:10 b.M'.. 1' 11 0.10'.32 0.1044 0:1028 0:06:$9 0:40:30 0... M(ek. 0:10:3] 0:]0:44 0:1048 O:Ofi:ll 3:30:31 3:18:29 3.:31 2:5]:3] 2:5MOS 2:13:1fi 2:40]] 1:40:17 2:36:17 2:.:20 2:18:43 307:59 15]31 S:St. L51152 1:46:53 1:39:56 129:19 ]:18:34 ]ABA] 101:38 1.1:28 0:5]:38 0:50:33 0:39:55 4049;10 O:M:1] ].0] 1.00 ].W IW LOO LCM LOS 1.00 1. I.. L. 1.. ]W 100 1.. LOO LOO IM 100 IM ].M IM IM LM 1.. 1.. M. 050 0.50 0.50 0.50 0.50 0.50 0.50 050 050 M. 050 050 OS. ISO 0.50 0.50 0.50 050 0.50 050 0.50 050 0.50 050 0.50 0.90 090 0.50 090 090 090 ¢90 0.90 0.. 0.90 0.90 0.90 090 ISS) MAS 0.90 0.90 090 0.9D 0. 050 OM OM O.M 0.. 0.40 0.45 OAS 045 045 0.45 OAS CAS 095 OAS 045 0.45 0.45 045 0.45 0.45 045 OAS p.45 0.45 0.45 OAS 045 045 045 0.15 045 ypp,M 35.03 35.01 35.00 35.00 35.00 35.LL IS.. 35.00 35.00 35.00 3SOp 35.00 3500 Is. 35. 35. 3500 350n 3500 3540 35.. I, On 35.. 3540 35.40 35.. 0.15 O.ls 0.15 p.IS 015 40.15 0.15 0.15 Its 015 0.15 0.15 015 0.15 0.15 0.15 0.t5 MIS 0.15 0.15 0.15 0.15 0.15 p.15 0.15 0.15 2. I. 1.00 200 S.CM 2.00 2.00 $.W Im IM 2.01 2.00 3.[0 2.00 2.. 3.. $.. 3.00 $.. $.00 i. I. I. 2,40 $M 3.40 021 035 0.$5 0.25 035 0.25 0.25 O.IS MIS 035 0$5 035 035 0.35 025 025 035 025 MIS 0.25 035 p$5 035 035 035 O9S 0$5 p35 Flultl Type I Oe3ign T01alf9al Sea warn 9.L Y35HVdW 245,129 035 weed1ra[G 15,218 Freeze Nutt,, 4340 3P fppm) fppml l9pml fWml 19pm1 Proppant Type a08n TWa1 flbs) Wamil SO/90 9.L T's Pod, Ip 846 OpOFlpall OptHF-ll 3P Samson Resources - Bridle 0214-10H Planned Design Wsul' MOb] Cl -23 UC 1 CL-3LLOT-200 846 OpOFlpall OptHF-ll 3P fppm) fppml l9pml fWml 19pm1 pNn ppm Pom AWn ppm Max 4dd;Nre R.tel 1.3 0.6 1.1 0.6 13..01 0),I 1 0.$ 1 2.5 1 03 p.fi Min Additive Rin! Mydmohn, Fracturing usia FroSUM Component Information Disclosure Fmcdre orts ENMJ1e 9md: Mata CwNU WnNon as Apl Numbee: 6%OLOT1] MOWN SWFE 0'.. Name ESU WW seem -a NYmber Mesa LxplNae: .lets umenew )0.]e Lon90.atpmhathem HAO]] adla ow, was poral-thini ON Tor.., 0e'.M1 mvo1' elft Tobl WaQtYp&me ]W,]E6 Nyaraide iracNrly Had CampNExl: Cbemiml Malimum Assured Maximum Ingredient Ingmdleot Trade Name Storks, P.,... Ingmdiente Service Concenbm0onin AdI Commostrafipn In (n9rtdlent Mess Commenn Company Finl Nome Last Nm ae Synod Ph.. Numbe1(CA$ p6 by masay RF Must 1% by Ise M moi Sea Wadr Ban FYtl Wamr }131010 pens = OSiO MICMOMMCAD -haWMn Baow Issmtl Babw CmeNv4x rya C1-4 1, HesdMnn ea Bebw 0 NA CL -3911 ..., CWNer I.. Babw maebw B CLNNFA ro 0 NA LOSUM%&KO WFbunon Nemwc sl-rea Llsbo aw's p No MC -0] HasbuMn Owned! Pb]Me LL9M Oabw My. 0 NA OoTFL. RELEASE W4Wnon Shea.., Uvea Bebx Lord Babw 0 µq BREAKER opnFLO.W RF� sE IYEhvbn Wee A., Liod Sebe Ueda 9.bx o Fy[ BRFAI(ER SP MREAHER Hasdmm, a—., IL. Baow Used BWw 0 NA WGJB GELLING ,aawns, Gig/gg4 Lhma SeW LW]Sebw N3ENT0 NA WadCie.. HaYW,Nn MLLAe IMOBebw INH BMs p Llwo pane- Fnem promo 1pbd aebw IbM Below I,,mm.. LnmaP lwYJ ptox 1.Z41mmatlybmro yp8 .o0%at p i9mmu3Nbs1 dal 4bl-) 100.0n, b. orrp OeMa TUII, MMmpoM1mx pmpbmry 1.006 0.001019 q Sam MUMi]COM, E Hw2 i% Haddad upY® HpNabn Came Tors, Kidvbnm ]Btd)16216 71oY1.$Bld]t- p Amm+mm ,W,eb 7vb60 1J0.006 cmw4lii SB] Bons yb I'mpdhry LO.On\ 0.06nse, lora Naidabn 0.,i.tuft NYLU Tierramnao S81471.4iddi ConrNn 130210.. .IDila4 Snc,ca Yw sow, greame, 14.7 M o0s 16] CUMwT preen orrery e] )0.009 O.no56le IT] Owin.T.de Ha®ubn ergs TIaF HaEdnbnm IDtd)t8$R ENaml64 511)5 war m- pM]OO 1J0.00Y O. 14Iegi MiIi Mml.nmplma sa]axa-s eaoOeeW o.Jni O.oza119 sm QwMh. "d U742474 iJ0.004 0.»sl Ei p%B M.dlei.7w.e 1BX0'J Ne Mubm 9110. 0.00]599 SB OpLlea aerolcraan Repmdry 50.00{ 0.%9561 )SE Ansa Tvt® IhMumn OeMe Twl Mabubam 211-arl. as I paAoy-1 xewrealM.apmla ,e"Amemantnsm."w" 19o9]a]a ..-1 d.Om69R p iamad Fe.--Nnnale SAAJ Es. n.04Jsle dew pahww, nytlrcMa 1]105&] on9 o.Oszlae W ppmenun m.hmmm d.e2ao9a ]as spew -more .m mopes .o%ma n spmum mere. 1612E 1. )cdsaa sealum bm I]Iwaz r, soeium n tltle 1c.0% z.. s 108 soaum ,Worm msZ]-1 e..5±Se m speNn worm nna2a ow 1 w.mr nu -135 len.mc oaosJn moo •roW NM., vaume..,.n...lman wards,0maumd.1. an., hags.. wader Information is based On Me matlmum polendeuor col:cemmSon and mw meloid may be tsar lrloA Nxa: Fee Fieb Oavelopmenl PmWN(produetr Am Men yeah FOP), Maus wa onlyiMmmaaon has been goMWtl, All compemM✓dxmaXon nand w9e o.b. from IM.paler. Weaned Sell OM She., IMSCBI. M such, we Opms, If nor reepcommeW Imecomd media, inmm ate information. AM pureaons regard, Me Whown of Ne MSOS.Hula M dincbd In Ne wpolow Me WbAded if Tor Occupaaonel Sdery and Heats Amonstledone (OSHA) repllmon. pavan IM came fw this dadwun d Nb i fw..mn Mem. imle Met Federal Law pMecb "propnesg- "fress menet, aM'coMkaNel buanm MWM MM and Me ordains he now Mie iblo,malon is rM on an MSOS a subhol b29 CFR 1910,12WO and A endan G MTU MT6-06 Stage Job Size (lb) Top MD (ft) Top TVD (ft) Propped Half- length (ft) Fracture Height (ft) Avg Fracture Width (in) 1 100,000 16,100 8,040 540 65 0.315 2 100,000 14,655 7,998 540 65 0.315 3 100,000 13,220 7,997 540 65 0.315 4 100,000 12,112 7,995 540 65 0.315 Disclaimer Notice: This model was generated using commercially available modeling software and is based on engineering estimates of reservoir properties. Conoco Phillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results SECTION 13 — POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through PTS until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to alpine disposal facilities until they are clean enough for production.) Loepp Victoria T (DOA) From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Friday, February 15, 2019 7:11 AM To: Loepp, Victoria T (DOA) Cc: Klem, Adam; Hobbs, Greg S Subject: RE: [EXTERNAL]GMT MT6-06(PTD 218-093, Sundry 19-064) Fracture Stimulation Follow Up Flag: Follow up Flag Status: Flagged Victoria, You are correct, MT6-06 was not intended to be fracture stimulated when the well was permitted and drilled. However, once completed, we have been unable to get the well to flow at rates anywhere near where expected. We have performed a number of tests/interventions hoping to find a mechanical cause for the low flow with no success. It now appears that our formation is far tighter than we had originally suspected for the southern row of wells at MT6 (MT6-06, MT6-07, and MT6-04). If we are able to stimulate MT6-06 and we see a significant increase in production then we can confirm there is a better way to develop the southern area of MT6. MT6-07 was deferred shortly before spud for this reason. This is an abbreviated summary of MT6's development over the last few months so if you would like to discuss it further I would be happy to walk over and review with you. I will also send you the requested cement review of MT6-06 Intl in a separate email. Thanks, Andrew (303)378-8881 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Thursday, February 14, 2019 2:26 PM To: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Cc: Klem, Adam <Adam.Klem@conocophillips.com> Subject: [EXTERNAL]GMT MT6-06(PTD 218-093, Sundry 19-064) Fracture Stimulation Andrew, In reviewing the approved PTD, the 10-401 indicated that this well was not going to be fracture stimulated. As a result, no cement evaluation log of the 7" liner was run, nor was the cement job reviewed. Please explain how this happened. Provide cement job information and TOC determination. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoePPCn?alaska.gov Loepp, Victoria T (DOA) From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Thursday, February 14, 2019 2:01 PM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]GMT MT6-06(PTD 218-093, Sundry 319-064) Fracture Stimulation My apologies. Both should be 6000psi From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Thursday, February 14, 2019 1:56 PM To: Klem, Adam <Adam. Klem @conocophillips.com> Subject: [EXTERNAL]GMT MT6-06(PTD 218-093, Sundry 319-064) Fracture Stimulation Adam, The maximum treating pressure in Section 7 is 6000 psig, however in Step 10 of Section 12, it is 7500 psig. Please clarify. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeooCa alaska.00v 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 oryiClonaloe_pp adaska.gov Loepp, Victoria T (DOA) From: Sent: To: Cc: Subject: Attachments: Follow Up Flag: Flag Status: Victoria, Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Friday, February 15, 2019 7:35 AM Loepp, Victoria T (DOA) Klem, Adam; Hobbs, Greg S RE: [EXTERNAL]GMT MT6-06(PTD 218-093, Sundry 19-064) Fracture Stimulation MT6-06 7in Liner Trt Report.pdf; MT6-06 Intl Cement WV Report.pdf Follow up Flagged The Intermediate 2 liner cement job on M76-06 was pumped without issue. We had full returns throughout and lift pressures were as expected. In total, 55 bbl of 15.8# Class G cement were pumped with 5 bbl left in the drill pipe. From previous 7" CBL's on MT6, the hole appears to be very close to gauge so if we assume the same for MT6-06, the expected top of cement is around 10,047' MD / 7,048' TVD (1,786' MD / 934' TVD above 7" shoe). Similarly, the conditions and execution of MT6-06's cement job were very similar to the logged wells so I am confident the cement bond is equally strong. I have attached the SLB job log as well as the WellView report for your review. Let me know if you need anything else or would like to discuss this further. Thank you, Andrew Beat Senior Drilling Engineer ConocoPhillips Alaska (303) 378-8881 cell (907) 265-6341 office From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Thursday, February 14, 2019 2:26 PM To: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Cc: Klem, Adam <Adam.Klem @conocophillips.com> Subject: [EXTERNAL]GMT MT6-06(PTD 218-093, Sundry 19-064) Fracture Stimulation Andrew, In reviewing the approved PTD, the 10-401 indicated that this well was not going to be fracture stimulated. As a result, no cement evaluation log of the 7" liner was run, nor was the cement job reviewed. Please explain how this happened. Provide cement job information and TOC determination. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 4-�� Cement Detail Report MT6-06 String: 7" Liner Cement Job: DRILLING ORIGINAL, 9/10/2018 00:00 Cement Details Description T' Liner Cement Cementing Start DaleCementing 9/30/2018 00:53 End Date 9/30/2018 03:40 Wellbore Name MT6-06 Comment Cement Stages Stage # 1 Description T' Liner Cement Objective I Cement Liner Top Depth (ftKB) 10,047.0 Bottom Depth (ftKB) 11,833.0 Full Retum? Yes Vol Camant... I Top Plug? No Bbn Plug? No O Pump [nit (bbl/m... 2 O Pump Final (blalf 1 O Pump Avg (bbl/... 2 P Pump Final (psi) 640.0 P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No I Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) DHII Out Diameter (In) Comment 55 bbls of 15.8 ppg Cement. CIP = 03:40 Hm. Left 5 bbis cement in OP. Cement Fluids 8 Additives Fluid Fluid Type G -blend Tail Fluid Description Estimated Top (ftKB) 10,047.0 Est Btm (f1K8) 11,833.0 Amount (sacks) 268 Class G Volume Pumped (bbl) 55.0 Yield (ftlsack) 1.16 Mia H2O Ratio (gal/ea... 5.0 Free Water 1 Density (Iblgal) 15.80 Plastic Viscosity (cp) 103.1 Thickening Time (hr) 5.28 CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Page 111 Report Printed: 21161201 9 Schlumberger Cementing Jo' Report CemCAT V1.7 Well MT6-06 Rate Client ConocoPhillips Field Alpine SIR No. Engineer lance Kalivas Job Type 7" Liner Country United States WSM Dore Dom Job Date 09-29-2018 Time Pressure Rate — Density WHP Messages 00:32:38 Bategood WSM Dore Dom Blow Air Down Hard Une Fluid Rad, Hard Ure W. Pr/ Test Tdps 00:48:00 Tdps TdpPed High Pr Beset Total, Vol. 1.37 bbl Pr cow Start %b ping Mu h MudR sh stalled 11.5 Heave Start MP Dom Hole 01:03:00 End Mudiush Start batchhsg Cement Reset Trial, Vol - 20.02 bbl Cement scaled 15.9 start Tal CMr Dorn Hole 01:18:00 01:33:00 End Tall Cement Reset Total, Vol - 55.04 bbl Fresh water behind 01:48:00 20 bbls water behind by steps Swap to dg to displace i Reset Total, Vol s 18.70 bbl 02:03:00 02:18:00 1 1 i aow air down hard line 02:33:00 t 02:4&:00 03:03:00 03:18:00 03:33:00 03:40.39 End displacement sting out hh:mm:ss zsa so soo zsa ma zsa om zzso zsm nso sm PSI Sim l9/G PSI 09/30/2018 04:50:02 Schlumberger Cementing Serv..;e Report Add W4 Customer Cal000RnIllps Job Number Well MT6-06 loradon(I.,H) GMT Schlumberger Loratlon PRUDHOE OTHER )ob Stan Sep/29/2018 Field Alpine Fwaiii Name/Type pwla". deg Saw. In WAS ND 11820.0 R wdlwa 8010.0 It County Sbb/Provinca Alaska SHP psi III 181 degF SHCT 138 dei Iwo Pram. Genu bnl Ib/gal WON Maher APIINWX Rig name and" For Oil Service In. Land eaadr5/Wer Dep11yR Slee, In Weghl, lb/ft Grad. Thread WAi.is Zane Well clava New Well Type Development 11820.0 ].0 26.0 0.0 0.0 0.0 Drilling Auld Type Mex. Danelty Ib/gal Pbvtic vi...q CP Tubing/pall Pipe T/D Capm,R SIM In Weight lb/ft Sues. lbesd servlet Lt. Cementing Joe Type 7" finer D 9517.0 5.0 19.5 0 11769.0 4.0 14.0 Moe. Allowed Tub. Prw psl H.. lluowed Ann. P.en psl xm emnactlOn 2" 1502 Iwbanme/open xoh Tp R iuiwd , R ali N. W Shote Tobi Interval Serried LMtruwon. ft ft It It It Dlameler in ft ft T.t D.- Drill AN MepbcNHM Packer Typo 183.3 bbi PbWMr gepb N Tubing Vol. bb) Qu0ng Vol. Annabr V,1. 1.9 bbl bbl Openho a Vol. bbl CeNng/Tubing SecurW I Hole Vol. amulabd prior b Cement Cabinp Taub Squeeze Job uft P.. psi Noe Two Sq" In va Apo Notated ❑ NVe Reapbratad Shw MPm It Taal TTP, Na. Cenballzan Top Muga Gelber Plug. Stege TOW Type Taal Dwm ft Cement Heed Type Stege Tool Capm ft Tail Plea Sib. In Job Scheduled For Sep/29/2018 AW'1v,d m LacMlm Sep/29/2018 lees W. Sep/29/2018 Calbrrype TNI Npa Dept R puller ppm ft Sqz Total VW. bbl Cato Time 241, cbek Tieeamg Aqw lib Rab m B/M W.Mv W/o Valid. C _STQVDL SSL m Negag, 09/30/2018 00:32:38 124 0.0 5.99 0.0 0.0 Started A¢tuisitun 09/30/2018 00:32:51 122 0.0 5.99 0.0 0.0 Rate Ojeda goad 09/30/2018 00:33:02 119 0.0 5.99 0.0 0.0 NSM Dare 09/30/2018 00:34:18 119 0.0 5.99 0.0 0.0 09/30/2018 00:35:58 106 0.0 5.99 0.0 0.0 09/30/2018 00:37:38 88 0.0 5.99 0.0 0.0 09/30/2018 00:38:49 79 0.0 5.99 0.0 0.0 STOW Air Down hard! Une 09/30/2018 00:39:18 S4 0.0 5.99 0.0 0.0 09/30/2018 00:40:58 113 0.0 6.55 0.0 0.0 09/30/2018 00:41:42 111 0.0 6.57 0.0 0.0 Fluid Pork Had lire 09/30/2018 00:42:38 IS 2.1 6.72 0.1 0.1 09/30/2018 00:44:18 67 0.0 6.49 1.3 1.3 09/30/2018 00:45:58 4W1 0.0 6.49 1.3 1.3 09/30/2018 1 00:46:09 47 0.0 6.49 1.3 1.3 1pw PT/ Tat Trips 09/30/2018 00:46:34 990 0.2 6.56 1.3 1.3 Trips Tdpped 09/30/2018 00:46:46 1140 0.0 6.49 1.3 1.3 High PT 09/30/2018 00:47:16 3959 0.0 6.49 1.4 1.4 Reset TOW, Vol = 1.37 bbl 09/30/2018 00:47:38 3859 0.0 6.49 1.4 0.0 09/30/2018 00:48:44 3821 0.0 5.92 1.4 0.0 PT Good 09/30/2018 00:49:18 -23 0.0 5.84 1.4 0.0 09/30/2018 00:50:14 47 0.0 7.41 1.4 0.0 Staft bslxhing MudPush Add W4 wall W6-06 q.l Alpine 3Pbstae Sep/29/2018 cusewner ConaroP:1'I", 1P0 number Dab nm 244N tlbce TrNtln9 PRPewa P93 lo Pw PJta 6/001 Da-" M/G Valua m deal, p-gnQVOL Bal Nersa9e 09/30/2018 00:52:38 61 0.0 11.29 1.4 0.0 09/30/2018 00:54:04 60 0.0 11.53 1.4 0.0 Mud Push SOW 11.5 Heavy 09/30/2018 00:54:18 60 0.0 11.52 1.4 0.0 09/30/2018 00:54:38 145 0.9 11.52 1.4 0.0 Start MP Gown Hole 09/30/2018 00:55:58 455 1.9 11.29 3.6 2.5 09/3D/2018 00:57:38 417 1.9 11.48 7.0 5.6 09/3D/2018 OD:59:18 403 1.9 11.57 10.2 8.8 09/30/2018 01:00:58 400 1.9 11.45 13.4 12.0 09/30/2018 01:02:38 408 1.9 11.39 16.5 15.2 09/30/2018 01:04:18 388 1.9 11.62 19.7 18.4 09/30/2018 01:05:12 145 0.3 11.62 21.4 20.0 End MWPLrh 09/30/2018 01:05:58 34 0.0 11.56 21.4 20.0 09/30/2018 01:07:38 39 0.0 9.99 21.4 20.0 09/30/2018 01:09:18 M 0.0 8.68 21.4 20.0 09/30/2018 01:09:32 42 0.0 8.69 21.4 20.0 Start battlibp Cement 09/30/2018 01:10:45 64 0.0 12.27 21.4 20.0 Peeat TCW, Vol - 20.02 bbl 09/30/2018 01:10:58 72 0.0 13.35 21.4 0.0 09/3D/2018 01:12:38 90 0.0 15.89 21.4 0.0 09/30/2018 01:12:51 90 0.0 15.89 21.4 0.0 Cement Scaled 15.9 09/30/2018 01:13:13 248 1.0 15.89 21.4 0.0 Start Tal CW Down Hole 09/30/2018 01:14:18 495 1.9 15.61 23.4 2.0 09/30/2018 01:15:58 456 1.9 15.89 26.5 5.1 09/30/2018 01:17:38 385 1.9 15.78 29.7 8.3 09/30/2018 01:19:18 329 1.9 15.74 32.8 11.4 09/30/2018 01:20:58 302 1.9 15.82 1 36.1 14.7 09/30/2038 01:22:38 245 1.9R15.92 39.3 17.9 09/30/2018 01:24:18 201 1.9 42.5 21.1 09/30/2018 01:25:58 182 1.9 45.6 24.3 09/30/2018 01:27:38 146 2.0 48.9 27.5 09/30/2018 01:29:18 163 2.0 52.2 30.8 09/30/2018 03:30:58 150 2.D 55.4 34.1 09/3D/2018 01:32:38 151 2.0 58.7 37.3 09/30/2018 01:34:18 128 1.9 62.0 40.6 09/30/2018 01:35:58 123 1.8 65.1 43.8 09/30/2018 01:37:38 132 1.9 15.93 68.2 46.8 09/30/2018 01:39:18 143 1.8 15.92 71.3 49.9 09/30/2018 01:40:58 136 1.8 15.89 74.3 52.9 09/30/2018 01:42:05124 1.9 15.89 76.4 55.0 End Toa Cement 09/30/2018 D1:42:07 124 1.9 15.89 76.4 55.0 Reset TCW, Vol 55.04 bbl 09/30/2018 01:42:28 97 1.8 15.90 77.1 0.6 Fnsh water behind 09/30/2018 01:42:38 61 1.9 15.90 77.4 0.9 09/30/2018 01:44:18 32 2.0 15.90 80.6 4.1 09/30/2038 01:45:56 32 2.0 15.90 83.8 7.4 09/30/201801:47:38 33 2.0 15.91 87.0 10.6 01:49:18 34 1.9 15.91 90.3 13.9 29/30/2018 9/30/2018 01:50:58 36 2.0 15.91 93.5 17.1 09/30/2018 01:51:49 -33 0.3 15.91 95.3 18.7 20 We water behind by straps 09/30/2018 01:52:32 -33 O.D 15.91 95.1 18.7 Swap to N to displace 09/3D/2018 01:52:38 -34 0.0 15.91 95.1 18.7 09/30/2018015242 -95 0.0 15.91 95.1 18.7 R Tpta, Vol = 18.70 bbl 09/30/2018 01:54:18 -17 0.0 11.41 95.1 0.0 09/30/2018 01:55:58 -20 0.0 11.38 95.1 0.0 09/30/2018 01:57:38 -20 0.0 31.39 95.1 0.0 09/30/2018 01:59:18 -23 0.0 11.18 1 95.1 0.0 Pape 204 Well MT6-O6 F1e14 Alpine lob ffiK SeW29/2D36 Custmmae 1 COn=Phillips lab Number Date line, 'l4iM Noel, h g A.9au. PSL ROW MFe S/M Density l0/G Volute. BLL CM SfG_VOL Message NL 09/30/2018 02:02:38 -20 0.0 11.04 95.1 0.0 09/30/2018 02:04:18 -23 0.0 10.73 95.1 0.0 09/30/2018 02:05:58 -24 0.0 10.06 95.1 0.0 09/30/2018 02:07:38 -31 0.0 8.55 95.1 0.0 09/30/2018 02:09:18 -37 0.0 0.00 95.1 0.0 09/30/2018 02:10:58 -37 0.0 8.34 95.1 0.0 09/30/2018 02:12:38 -42 0.0 8.32 95.1 0.0 09/30/2018 02:14:18 6 0.0 8.30 95.1 0.0 09/30/2018 02:15:58 -37 0.0 5.82 95.1 0.0 09/30/2018 02:17:38 -39 0.0 5.77 95.1 0.0 09/30/2018 02:19:18 31 0.0 8.30 95.1 0.0 09/30/2018 02:20:58 -34 0.0 8.27 95.1 0.0 09/30/2018 02:22:38 -38 0.0 8.30 95.1 0.0 09/30/2018 02:24:18 -35 0.0 8.30 95.1 0.0 09/30/2018 02:25:58 27 0.0 8.31 95.1 0.0 09/30/2018 02:27:36 -37 0.0 8.16 95.1 0.0 09/30/2018 02:28:32 -38 0.0 7.98 95.1 0.0 M. ar Down hMd line 09/30/2018 02:29:18 -13 0.0 7.90 95.1 0.0 09/30/2018 02:30:56 -17 0.0 8.21 95.1 0.0 09/30/2018 02:32:38 -33 D.0 8.06 95.1 0.0 09/30/2018 02:34:18 -32 0.0 7.65 95.1 0.0 09/30/2018 02:35:58 -32 0.0 0.01 95.1 0.0 09/30/2018 02:37:38 -36 0.0 0.00 95.1 0.0 09/30/2018 02:39:18 -39 0.0 0.OD 95.1 0.0 09/30/2018 02:40:58 -38 0.0 0.00 95.1 0.0 09/30/2018 02:42:38 -38 0.0 0.00 95.1 0.0 09/30/2018 02:44:18 -35 0.0 0.00 95.1 0.0 09/30/2018 02:45:58 -35 0.0 0.00 95.1 0.0 09/30/2018 02:47:38 -35 0.0 -0.00 95.1 0.0 09/30/2018 02:49:18 -37 O.D 0.01 95.1 0.0 09/30/2018 02:50:58 -34 0.0 -0.00 95.1 0.0 09/30/2018 02:52:38 -37 0.0 0.00 95.1 0.0 09/30/2018 D2:54:18 -37 0.0 0.00 95.1 0.0 09/30/2018 02:55:58 -41 0.0 0.00 95.1 0.0 09/30/2018 02:57:38 -38 0.0 0.00 95.1 0.0 09/30/2018 02:59:18 -40 0.0 0.00 95.1 0.0 09/30/2018 03:00:58 -36 0.0 0.00 95.1 0.0 09/30/2018 03:02:38 -38 0.0 0.00 95.1 0.0 09/30/2018 03:04:18 -37 0.0 0.01 95.1 0.0 09/30/2018 03:05:58 -38 0.0 0.00 95.1 0.0 09/30/2018 03:07:38 -39 0.0 0.01 95.1 0.0 09/30/2018 03:09:18 -39 0.0 0.00 95.1 0.0 09/30/2018 03:10:58 -40 0.0 0.01 95.1 0.0 09/30/2018 03:12:38 -38 0.0 0.00 95.1 0.0 09/30/2018 03:14:18 -41 0.0 0.00 95.1 0.0 09/30/2018 03:15:58 -39 0.0 0.00 95.1 0.0 09/30/2018 03:17:36 -38 0.0 0.00 95.1 0.0 09/30/2018 03:19:18 -37 0.0 0.00 95.1 0.0 09/30/2018 03:20:58 -39 0.0 0.00 95.1 0.0 09/30/2018 03:22:38 -39 0.0 0.00 95.1 0.0 09/30/2018 03:24:18 -35 0.0 0.00 95.1 0.0 09/30/2018 03:25:58 -40 0.0 0.00 95.1 0.0 09/30/2016 03:2]:38 -38 0.0 0.00 95.1 0.0 09/30/2018 03:29:18 -37 0.0 0.00 95.1 0.0 PaOe 3 of 4 WWI W6-06Alpine Fleld lab stat Sep/29/2018 CUWomar COno mlllip5 ]ob xpmber babe nme 24-M tlptlt Traeling N6aWre P4 NPVr Bata S/N OanaBy W/O Volume BBL CMT STp_VOL M.a. BBL 09/30/2018 03:32:38 -39 0.0 0.00 95.1 0.0 09/30/2018 03:34:18 -39 0.0 0.00 95.1 0.0 09/30/2018 03:35:58 -41 0.0 0.00 95.1 0.0 09/30/2018 03:37:38 -38 0.0 0.01 95.1 0.0 09/30/2018 03:39:18 -39 0.0 0.01 95.1 0.0 Post Sob Summary Pape 4 W 4 Average pump RWaa, bel/min Vali. W WxM N1aWad, bN Shirty 1.9 N3 NW MaNmum Rete 2.2 T�1Blurry 55.0 Mod 3.0 Spacer 20.0 N3 Treaxbg I,xWW. Summary, pW BreagdPVm Nuld MaWmpm 4015 Mpal 41 AVarepe 255 eumPNWW Brealydawo Typa vol... bbl Bemity Ib/gal An. N2 percentDealpnad % Slurry V Wume 55.0 bd Oltplac<meat 183.0 bd Mia WWN r Temp 79 &gF Cement Gradated b Surlami VW.. bbl Wombed nap perp rP R Cus[amer or Augorleed BepreaeWWNVa Fob Reinhardt BWilumberyer Supervxar lance Kaliyae Cbculexoa Lest E3 3ob CNnplebad %❑ _ Pape 4 W 4 PT -D a/8 -b43 Loepp, Victoria T (DOA) From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Friday, February 15, 2019 7:35 AM To: Loepp, Victoria T (DOA) Cc: Klem, Adam; Hobbs, Greg S Subject: RE: [EXTERNAL]GMT MT6-06(PTD 218-093, Sundry 19-064) Fracture Stimulation Attachments: MT6-06 7in Liner Trt Report.pdf; MT6-06 Intl Cement WV Report.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, The Intermediate 2 liner cement job on MT6-06 was pumped without issue. We had full returns throughout and lift pressures were as expected. In total, 55 bbl of 15.8# Class G cement were pumped with 5 bbl left in the drill pipe. From previous 7" CBL's on MT6, the hole appears to be very close to gauge so if we assume the same for MT6-06, the expected top of cement is around 10,047' MD / 7,048' TVD (1,786' MD / 934' TVD above 7" shoe). Similarly, the conditions and execution of MT6-06's cement job were very similar to the logged wells so I am confident the cement bond is equally strong. I have attached the SLB job log as well as the WellView report for your review. Let me know if you need anything else or would like to discuss this further. Thank you, Andrew Beat Senior Drilling Engineer ConocoPhillips Alaska (303) 378-8881 cell (907) 265-6341 office From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Thursday, February 14, 2019 2:26 PM To: Beat, Andrew T <Andrew.T.Beat @conocophillips.com> Cc: Klem, Adam <Adam.Klem @conocophill ips.com> Subject: [EXTERNAL]GMT MT6-06(PTD 218-093, Sundry 19-064) Fracture Stimulation Andrew, In reviewing the approved PTD, the 10-401 indicated that this well was not going to be fracture stimulated. As a result, no cement evaluation log of the 7" liner was run, nor was the cement job reviewed. Please explain how this happened. Provide cement job information and TOC determination. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission Schlumberger Cementing Job h.eport CemCAT V1.7 Well h1T6-06 Rate Client ConocoPhillips Field Alpine I SIR No. Engineer Lance Kalivas Sob Type T' Liner Country United States RJSMate Done Dore Sob Date 09-29-2018 Time Pressure Rate Density -WHP Messages 00:32:38 I 1 Rate good!JIII RJSMate Done Dore Blow Air Down H floe JIII Fluid � Had Lire W. Rr/ Test Trips 00:98:00 THps Tripped High Pr Reset Total, Vol = 1.37 bbl Pr Good Start bsttlting MudN h Mudl sh Staled 11.5 Heald 01:03:00 Start MP Down Hole End MudRYsh '., Start batching cernazt Rest Total, Vol = 20.02 btl Cement Soled 15.9 Start Tall CMT vo m Hole 01:18:00 01:33:0 1 '.. EM Tall Cement Reset Total, Vol n 55.09 btl Fresh water trttlnd 01:98:00 - 20lotb water beldrvJ by soaps swap to rig to displace I Reset Total, Val - 18.70 btl 02:03:00 i 02:18:00 I 1 - I BYsw air down hard Yre 02:33:00 i D2:48:00 03:D3:00 03:18:OD 03:33:00 03:40:39 EW displacement sting out hh:mm:ss zwo zoso '°°° '°°° xa sn sa sa mn rsa zsa ma z zzm zsw mo ••_•^• — - P51 — B/M —___ lB/G pal 09/30/2018 04:50:02 Schlumberger Cementing Service Report CN.mmar Conxafhllllps lob Rumba _. W.6 MT6-06 I4otlon (M9.D OMT Scnlumb.Wr Mc.tlon PRUDHOE OTHER lob Sbrt Sep/29/2018 FlN. Alpine I.rI1NYw N.m./TTp. 0.yMtl.n deg 6n Ilse In WWI ND 11820.0R W.HTVD 8010.0 It T ty 6M0./RrovbNa AMske YV pd 61161 181 degF eMR 138 degF poli FYw. BMtl.11t 10/gal wa 111N API/DWI Wp N.. DHpN Pw 011 /.M[. VM lend p0di D.RIgR Nw,M Wtl61M, W/R YINI. 11114.0 ORFhore zone Wap zMw New web Typ. De°dwnbnl 11820.0 7.0 26.0 0.0 Drilling Fluid Type IML DIIII" 11,10N fta VR..." heN9/Gi MRI T/D D.RM,R Me.In W0161w, •/R 9rNN 111rW 1oe Une Celnenwq 7•Liner D 951].0 5.0 19.5 D 11769.0 {.0 11.0 Mac AW.N. Tub. Old h.M MM.A6aw.0Am.Rrw pN WM fiWWNNn 2.1502 R4IMnR�./dyN1NW T.pR 6wIIt NNI/R Nw N66.b TNN z.bllV.l Nrvb lroD.NW R R R R R DliI In R R 11..t O.wn DRO Mpe DI19MM.1..3 R.tllw TyM 183.3 bU R.tlw D.Rl9 R TIM*YN. DDl C.NW VN. AAMN 1 a 1.9 Ubl b01 D.NIbW VN. ODI d.M/TUNe1JlIe.r4e ❑ iMeM VN. CIn}WNwW MT4w.N ❑ C..MT OIIr.m1N M prom pa R.. TRN 64u..MTYM pe.. Re1.M1 ❑ I NN R.dae.olM ❑ 6 D.9& R Tw7V" Mil',, VW.N. I TN NW. 6N.w My. OU"TMTyne T.N DOM It O.IIwnt ll..e Trp. StW T.N DWIh R j T.ORIR.6D, In Jeb SQ.INN I.r SW29/2018 AMvtl en l.MlNn SeW29/2018 WwI.MWI $tp/29/2018 DeliaIv" R T4p.r ii ft i :114"D.Ro seL TNN vel eN Dob. mil.TNOW4 2441. N..k 11111D,,, I11" w.rl Ift RII R/M �D �YO1 6a 061 09/30/2018 00:32:38 124 0.0 5.99 0.0 0.0 Slated AMARIon 09/30/2016 00:32:51 122 0.0 5.99 0.0 0.0 Re11 OwOa 9wd 09/30/2018 00:33:02 119 0.0 5.99 0.0 0.0 ISM Done 09/30/2016 00:34:18 119 0.0 5J9 0.0 0.0 09/30/2018 00:35:50 106 0.0 5.99 0.0 0.0 09/30/2018 00:37:38 BB 0.0 5.9f 0.0 0.0 09/30/2018 00:36:49 79 0.0 5.99 0.0 0.0 plow Air Down MM lbw 09/30/2016 00:39:18 84 0.0 5.99 0.0 0.0 09/30/2018 00:10:56 113 0,0 6.$ 0.0 0.0 09/30/2018 00:41:42 211 0,0 6.57 0.0 0.0 1 pick FMrd I" 09/30/2018 00:42:38 IS 2.1 6.72 0.1 0.1 09/30/2018 OD:44:18 67 0.0 6.49 1.3 1.3 09/30/2018 1 00:45:58 M 0.0 6.49 1.3 1.3 09/30/2010 00:46:09 47 0.0 6.49 1.3 1.3 lew pry Tim THpe 09/30/2018 00:46:34 990 0.2 6.56 1.3 1.3 111"THpped 09/30/2018 00:46:46 1140 0.0 6.49 1.3 1.3 High IT 09/30/2018 00:47:16 3959 0.0 6.49 1.4 1.4 9asa[TOM, VD . 1.37 oN 09/30/2018 00:47:38 3859 0.0 6.49 1.4 0.0 09/30/2018 00:48:44 3621 0.0 5.92 10.0 K Good 09/30/2018 00:49:18 -23 0.0 5.64 1.4 0.0 09/30/2018 00:50:14 47 0.0 7A1 1.4 0.0 SMR twttlYrp Mudpusll W.B W"6 Fidd Alpine lob B O Sep/29/2018 Cu.mm.r Cmm Mlllim lob NumNr Dab lime 24 -IV dxk Tr"u" P.. .fl FbM Re4 B/M BerWW V/O Vdume BBL ONlffC VOL BBL M 9. 09/30/2018 00:52:38 61 0.0 11.29 1.4 0.0 09/30/2018 00:54:04 60 0.0 11.53 1.4 0.0 MudPWh SODW 11.5 HawVy 09/30/2018 00:54:18 60 0.0 11.52 1.4 0.0 09/30/2018 00:54:38 145 0.9 11.52 1.4 0.0 Stag MP Down Hole 09/30/2018 00:55:58 455 1.9 11.29 3.8 2.5 09/30/2018 OD:57:38 417 1.9 11.48 7.0 5.6 09/30/2018 00:59:18 403 1.9 11.57 10.2 8.8 09/30/2018 01:00:58 400 1.9 11.45 13.4 12.0 09/30/2018 01:02:36 408 1.9 11.39 16.5 15.2 09/30/2018 01:04:18 388 1.9 11.62 19.7 18.4 09/30/2018 01:05:12 145 0.3 11.62 21.4 20.0 Eno MWFulh 09/30/2018 01:05:58 34 0.0 11.56 21.4 20.0 09/30/2018 01:07:38 39 0.0 9.99 21.4 20.0 09/30/2018 01:09:18 49 0.0 8.68 21.4 20.0 09/30/2018 01:09:32 42 0.0 8.69 21.4 20.0 Start ba"ft Cement 09/30/2018 01:10:45 64 0.0 12.27 21.4 20.0 PF Total, Vol = 20.02 bd 09/30/2018 01:10:58 72 0.0 13.35 21.4 0.0 09/30/2018 01:12:38 90 0.0 15.89 21.4 0.0 D9/3D/2018 01:12:51 90 0.0 15.89 21.4 0.0 CanaK Sa 15.9 09/30/2018 01:13:13 248 1.0 15.89 21.4 0.0 Start Tel CW Down Hole 09/30/2018 01:14:18 495 1.9 15.61 23.4 2.0 09/30/2018 01:15:58 456 1.9 15.89 26.5 5.1 09/30/2018 01:17:38 385 1.9 15.78 29.7 8.3 09/30/2018 01:19:18 329 1.9 15.74 32.8 11.4 09/30/2018 01:20:58 302 1.9 15.82 36.1 14.7 09/30/2018 01:22:38 245 1.9 15.86 39.3 17.9 09/30/2018 01:24:18 201 1.9 15.80 42.5 21.1 09/30/2018 01:25:58 182 1.9 15.85 45.6 24.3 09/30/2018 01:27:38 146 2.0 15.92 48.9 27.5 09/30/2018 01:29:18 163 2.0 15.90 52.2 30.8 09/3D/2018 01:30:58 150 2.0 15.90 55.4 34.1 09/30/2018 01:32:38 151 2.0 15.88 58.7 37.3 09/30/2018 01:34:18 128 1.9 15.89 62.0 40.6 09/30/2018 01:35:58 123 1.8 15.82 65.3 43.8 09/30/2018 01:37:38 132 1.9 15.93 68.2 46.8 09/30/2018 01:39:18 143 1.8 15.92 71.3 49.9 09/30/2018 01:40:58 136 1.8 15.89 74.3 52.9 09/30/2018 01:42:05 124 1.9 15.89 76.4 55.0 6 TN cF 09/30/2018 01:42:07 124 1.9 15.89 76.4 55.0 9F5et T&M, Vol = 55.04 bbl 09/30/2018 01:42:28 97 1.8 15.90 77.1 0.6 Fresh water nd 09/30/2018 01:42:38 61 1.9 15.90 77.4 0.9 09/30/2018 01:44:18 32 2.0 15.90 80.6 4.1 09/30/2018 01:45:58 32 2.0 15.90 83.8 7.4 09/30/2018 01:47:38 33 2.0 15.91 87.0 10.6 09/30/2018 01:49:18 34 1.9 15.91 90.3 13.9 09/30/2018 01:50:58 36 2.0 15.91 93.5 17.1 09/30/2018 01:51:49 -33 0.3 15.91 95.1 18.7 20 bb6 water behird by straps 09/30/2018 01:52:32 -33 0.0 15.91 95.1 18.7 Swap Wrig to disdaoe 09/30/2018 01:52:38 -34 0.0 15.91 95.1 18.7 09/30/2018 01:52:42 -35 0.0 15.91 95.1 18.7 Nests Td , Vol = 18.70 bd 09/30/2018 01:54:18 -17 0.0 11.41 95.1 D.0 09/30/2018 01:55:58 -20 0.0 11.38 95.1 0.0 09/30/2018 01:57:38 -20 0.0 11.39 95.1 0.0 09/30/2018 01:59:18 -23 0.0 11.18 95.1 0.0 Fag.2d4 Wtll W6-06 FlN4 Alpine ].b 8btl Sep/29/2036 cutl.mer Cp .ftllipe 106 Number Dab Time 24a.r aoa. Tr w P....en m FlmO idb 8/w Denow LB/G vo.. xL IM-STC_W)L Me0p9e DDL 09/30/2018 02:02:38 -20 0.0 11.04 95.1 0.0 09/30/2018 02:04:18 -23 0.0 10.73 95.1 0.0 09/30/2018 02:05:56 -24 0.0 10.06 95.1 0.0 09/30/2018 02:07:38 -31 0.0 8.55 95.1 0.0 09/30/2018 02:09:18 -37 0.0 0.00 95.1 0.0 09/30/2018 02:10:58 -37 0.0 8.34 95.1 0.0 09/30/2018 02:12:36 -42 0.0 8.32 95.1 0.0 09/30/2018 02:14:18 6 0.0 8.30 95.1 0.0 09/30/2018 02:15:58 -37 0.0 5.82 95.1 0.0 09/30/2018 02:17:38 -39 0.0 5.77 95.1 0.0 09/30/2018 02:19:18 31 0.0 8.30 95.1 0.0 09/30/2018 02:20:58 -34 0.0 8.27 95.1 0.0 09/30/2018 02:22:38 -18 0.0 8.30 95.1 0.0 09/30/2018 02:24:18 -35 0.0 8.30 95.1 0.0 09/30/2018 02:25:58 27 0.0 8.31 95.1 0.0 09/30/2018 02:27:38 -37 0.0 8.16 95.1 0.0 09/30/2018 02:28:32 -38 0.0 7.98 95.1 0.0 Blow Mr Sown heN Ilse 09/30/2018 02:29:18 -13 0.0 7.90 95.1 0.0 09/30/2018 02:30:58 -17 0.0 8.21 95.1 0.0 09/30/2018 02:32:38 -33 0.0 8.06 95.1 0.0 09/30/2018 02:34:18 -32 0.0 7.65 95.1 0.0 09/30/2018 02:35:58 -32 0.0 0.01 95.1 0.0 09/30/2018 02:37:38 -36 0.0 0.00 95.1 0.0 09/30/2018 02:39:18 -39 0.0 0.00 95.1 0.0 09/30/2018 02:40:58 -38 0.0 0.00 95.1 0.0 09/30/2018 02:42:38 -38 0.0 0.00 95.1 0.0 09/30/2018 02:44:18 -35 0.0 0.00 95.1 0.0 09/30/2018 02:45:58 -35 0.0 0.00 95.1 0.0 09/30/2018 1 02:47:38 -35 0.0 -0.00 95.1 0.0 09/30/2018 02:49:18 -37 0.0 0.01 95.1 0.0 09/30/2018 02:50:58 -34 0.0 -0.00 95.1 0.0 09/30/2018 02:52:38 -37 0.0 0.00 95.1 0.0 09/30/2018 02:54:18 -37 0.0 0.00 95.1 0.0 09/30/2018 02:55:58 41 0.0 0.00 95.1 0.0 09/30/2018 02:57:38 -38 0.0 0.00 95.1 0.0 09/30/2018 02:59:18 40 0.0 0.00 95.1 0.0 09/30/2018 03:00:58 -36 0.0 0.00 95.1 0.0 09/30/2018 03:02:38 -38 0.0 0.00 95.1 0.0 09/30/2018 03:04:18 -37 0.0 0.01 95.1 0.0 09/30/2018 03:05:58 -38 0.0 0.00 95.1 0.0 09/30/2018 03:07:38 -39 0.0 0.01 95.1 0.0 09/30/2018 03:09:18 -39 0.0 0.00 95.1 0.0 09/30/2018 03:10:58 -40 0.0 0.01 95.1 0.0 09/30/2018 03:12:38 -38 0.0 0.00 95.1 0.0 09/30/2018 03:14:18 41 0.0 0.00 95.1 0.0 09/30/2018 03:15:58 -39 0.0 0.00 95.1 0.0 09/30/2018 03:17:38 -38 0.0 0.00 95.1 D.0 09/30/2018 03:19:18 -37 0.0 0.00 95.1 0.0 09/30/2018 03:20:58 -39 0.0 0.00 95.1 0.0 09/30/2018 03:22:38 -39 0.0 0.00 95.1 0.0 09/30/2018 03:24:18 -35 0.0 0.00 95.1 0.0 09/30/2018 03:25:58 -40 0.0 0.00 95.1 0.0 09/30/2018 03:27:38 -38 0.0 0.00 95.1 0.0 09/30/2018 03:29:18 -37 0.0 0.00 95.1 0.0 V.9.104 well MT6-06 FIDE Alpine lob SLR Sep/29/2018 Cuswmer Conacomillips lob Number Dew In. T r tloeY TmaWq Prmrm PSS Flaw cave S/M D.." lW/p Vowma BeL CMT.¢rG_VJL M MmWpe 09/30/2018 03:32:38 -39 0.0 0.00 95.1 0.0 SmeMdaun Fluor 09/30/2018 03:30:16 -39 0.0 0.00 95.1 0.0 TV" 09/30/2018 03:35:58 41 0.0 0.00 95.1 0.0 OMgn" Slurry VOYme 55.0 bbl 09/30/2018 03:37:38 -38 0.0 0.01 95.1 0.0 N 09/30/2018 03:39:18 -39 0.0 1 0.01 1 95.1 1 0.0 O Post Job Summary •carpe Pump Mies, bM/min Vabmle 4 %Md lidect.4 bbl SlurryN3 1.9 NUE Mecimum RM! 2.2 Tavel Slurry S. MW 0.0 Spaces 20.0 N2 T "Pleepw S..Ml pN SmeMdaun Fluor Meelmum 0015 %nen 41 poempe 255 pump %upw M Iukue TV" Valium bbl penNw Ib/gal •n. NZ percent % OMgn" Slurry VOYme 55.0 bbl blsp x .M 183.0 bbl MY Wates Temp 79 Ee9F C ttlranMp w suneul ❑ VOYme bbl Wy ed Tprp Pp Te N Customer pr SUWorlsW ppresonwtNe Rob RelnhanR SWlumberyw Superebar lance Kalivas tlrwYUp LM lob Completed O Cement Detail Report W MT6-O6 String: 7" Liner Cement Job: DRILLING ORIGINAL, 9/10/2018 00:00 Cement Details Description CementingStart Date Cementing End Date Wellborn Name 1 7" Liner Cement 9/30/2018 00:53 9/30/2018 03:40 MT6-06 Comment Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) T' Liner Cement Cement Liner 10,047.0 11,833.0 O Pump Init Ibbl/m_. O Pump Final (bbll.. O Pump Avg (bbll - P Pump Final (Pail P Plug Bump (pal) Recip7 Stroke (ft) Rotated. Pipe RPM (rpm) 2 1 2 640.0 No Depth Plug Driilea Out To (ftKB) DNII OW Dlametar (In) DP Cement Fluids 8 Additives Fluid Fluid Type Fluid Description G-blend Tail ..:_ ..... 11 p,......, � 1 . _ _ Yield (h'/sack) Mia H2O Ratio (gallsa . Free Water (%) Denslry (Iblgal) Ptastic Vlacwity (cP) Thickening Time (hQ • CmprSv 7 (pal) 1 16 5 07 15 80 103.1 5.24 Additives Additive '-�^ Type Page 1I1 Report Printed: 2/152019 WELL LOG TRANSMITTAL #905290720 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED FEB 0 5 2019 RE: Multi Finger Caliper: MT6-06 A®GCC Run Date: 11/24/2018 21 809 , 30320 January 9, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 MT6-06 Digital Data, Digital Log Image file, 3D viewers, and Interpretation Report 1 CD Rom 50-103-20773-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: Oz&l q Signed: A V BA ER BAT a GE company Date: December 6, 2018 Abby Bell AOGCC 333 West 71" Ave, Suite 100 Anchorage, Alaska 99501 218093 30077 Letter of Transmittal Michael Soper Baker Hughes, a GE Company 795 East 94`" Avenue Anchorage, Alaska 99515 Pleased find enclosed the directional survey data for the following well(s): MT6-06PB1 MT6-06PB2 MT6-06 REcEIV ED DEC p 12418 ADc,CC (3) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Applications Engineer Michael.Soper@BakerHughes.com ConocoPhillips ConocoPhill ips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-06 50-103-20773-00 Baker Hughes INTEQ Definitive Survey Report 02 November, 2018 BAKER JUGHES a GEmmpany 218093 30077 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc.-WNS Local Coordinate Reference: Project: Western North Slope TVD Reference: Site: GMT1 Lookout Pad MD Reference: Well: MT6-06 North Reference: Wellbore: MT6-06 Survey Calculation Method: Design: B1-Wp02 Database: Project Western North Slope, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 — Well MT6-06 Well Position +N/ -S 0.00 usft Northing: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore MT6-06 Magnetics Model Name Sample Date BGGM2018 8/9/2018 Design MT6-06 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) (usft) 0.00 , S Well MT6-06 ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) True Minimum Curvature EDT 14 Alaska Production ) 3 Mean Sea Level Using geodetic scale factor 5,945,536-92usft 317,041.19usft 0.00usft Declination (°) 1645 Latitude: Longitude: Ground Level: Dip Angle (°) 80.70 Tie On Depth: 15,799.83 +N/ -S +E/ -W Direction (usft) (usft) (I 0.00 0.00 234.01 70° 15'22.892 N 151' 28' 43.472 W 1 37.20usR Field Strength (nT) a 57, 397 11=018 3:47:55AM Page 2 COMPASS 5000.14 Build 85D I �. ConocoPhillips BA ER HSo ConocoPhillips map Definitive Vertical MD Inc Survey Repo TVDSS Company: Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MT6-06 Project: Western North Slope TVD Reference: ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) V) Site: GMT1 Lookout Pad MD Reference: ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) Northing Well: MT6-06 Section North Reference: True Wellbore: MT6-06 Survey Calculation Method: Minimum Curvature (ft) Design: B1-wp02 Ift) Database: EDT 14 Alaska Production 0.00 Survey Program �T Date 0.00 0.00 5,995,536.92 From To 0.00 UNDEFINED Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 115.00 1,021.00 Gyrodate GyroSS 16" (MT6-06PB1) GYD-CT-DMS Gyrodata cont.drillpipe m/s 9/10/2018 9/10/2018 1,106.74 2,063.83 BHGE MWD+SAG+IFR+MSA16"(MT6-0 MWD+IFR-AK-CAZ-SC MWD+IFRAK CAZ SCC 9/11/2018 9/12/2018 2,160.89 10,285.85 BHGE MWD+SAG+IFR+MSA 121/4"(M MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/15/2018 9/17/2018 10,371.52 11,785.07 BHGE MWD+SAG+IFR+MSA 6x83/4" (M MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/26/2018 9/28/2018 11,842.00 15,799.83 BHGE MWD+IFR+MSA6"(MT6-OBPB2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/10/2018 10/12/2018 15,829.00 17,419.01 BHGE MWD+IFR+MSA6"(MT6-O6) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/13/2018 10/14/2018 Survey 11/2,2018 3:47:55AM Page 3 COMPASS 5000.14 Build 85D map Map Vertical MD Inc AA TVD TVDSS +N/6 +EAW (usft) V) V) (usft) (usft) (usft) (usft) Northing Fasting ('1UU.) Section Survey Tool Name Annotation (ft) (ft) Ift) 36.94 0.00 0.00 3634 -52.20 0.00 0.00 5,995,536.92 317,041.19 0.00 0.00 UNDEFINED 115.00 0.51 167.22 115.00 25.86 -0.34 0.08 5,945,536.58 317,041.26 0.65 0.14 GYD-CT-DMS(1) 205.00 0.76 167.84 204.99 115.85 -1.31 0.29 5,945,535.60 317,041.45 0.28 0.54 GYD-CT-DMS(1) 300.00 0.66 206.24 299.99 210.85 -2.42 0.18 5,945,534.50 317,041.32 0.50 1.27 GYD-CT-DMS(1) 361.00 0.70 247.51 350.98 271.84 -2.88 -0.32 5,995,534.05 317,040.81 0.79 1.95 GYD-CT-DMS(1) 455.00 1.60 298.97 454.96 36582 -2.46 -2.00 5,945,53451 317,039.14 1.37 3.06 GYD-CT-DMS(1) 550.00 379 309.86 549.85 460.71 0.19 5.57 5,945,53725 317,03563 2.36 4.39 GYD-CT-DMS(1) 645.00 6.03 311.84 644.50 555.36 5.54 -1169 5,945,54274 317,02964 2.36 6.21 GYD-CT-DMS(1) 738.00 8.81 311.77 736.71 647.57 13.54 -20.65 5,945,55096 317,020.88 2.99 8.75 GYD-CT-DMS(1) 832.00 11.03 312.24 829.30 740.16 24.38 -3267 5,945,562.09 317,009.12 2.36 12.11 GYD-CT-DMS(1) 926.00 12.93 312.92 921.25 832.11 37.59 47.03 5,945,575.64 316,995.09 2.03 15.97 GYD-CT-DMS(1) 1,021.00 15.01 313.60 1,01343 924.29 53.31 -63.73 5,945,591.76 316,978.78 2.20 20.24 GYD-CT-DMS(1) 1,106.74 17.20 314.12 1,095.80 1,006.65 69.80 -80.87 5,945,608.66 316,962.05 2.56 24.42 MWD+IFR-AK-CAZ-SC(2) 1,149.72 18.70 316.17 1,136.69 1,047.55 79.19 -90.21 5,945,61828 316,952.94 3.79 26A6 MWD+IFR-AK-CA7-SC(2) 1,244.34 20.79 31664 1,225.74 1,136.60 102.35 -11224 5,945,641.96 316,931.48 2.22 30.68 MWD+1FR-AK-CAZ-SC(2) 1,337.61 22.41 317.98 1,312.46 1,223.32 127.59 -135.51 5,945,667,76 316,908.83 1.82 34.68 MWD+IFR-AK-CAZSC(2) 1,432.48 23.36 318.88 1,399.86 1,310.72 155.20 -159.98 5,945,695.95 316,885.04 1.07 3826 MWD+1FR-AK-CAZ-SC(2) 1,526.98 24.13 315.69 1,486.37 1,397.23 183.13 -185.80 5,945,724.50 316,859.91 1.58 4273 MWD+IFR-AK-CAZ-SC(2) 11/2,2018 3:47:55AM Page 3 COMPASS 5000.14 Build 85D 101. ConocoPPhillips ConocoPhillips Definitive Survey Report BA, ((ER UGHES Company: Project: Site: Well: Wellbons: Design: ConocoPhillips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-06 MTe-06 B1-wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MT6-06 ACTUAL MTB -06 @ 89.14usft (Actual Doyonl9) ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) True Minimum Curvature EDT 14 Alaska Production i I Survey Map Map Vertical MD Inc AN ND NDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) lust) (usft) (usft) (°/100') Survey Too]Name Annotation (ft) (ft) (ft) 1,621.89 25.74 314.42 1,57243 1,483.29 21144 -214.07 5,945,753.49 316,832.33 1.79 48.98 MWD+11FR-AK-CAZSC(2) 1,716.26 27.14 314.61 1,656.92 1,557.78 240.90 -244.03 5,945,78366 316,803.10 1.49 55.91 MWD+IFR-AK-CAZSC(2) 1,809.69 29.23 314.55 1,739.27 1,650.13 271.88 -275.46 5,945,815.39 316,772.43 2.24 63.14 MWD+IFR-AK-CAZSC(2) j 1,903.56 30.26 314.04 1,820]7 1,73163 304.40 -308.79 5,945,848.71 316,739.90 1.13 71.00 MWD+IFR-AK-CAZSC(2) 1,997.77 31.40 315.37 1,90167 1,812.53 338.37 -343.10 5,945,883.50 316,706.43 1.41 78.80 MWD+IFR-AK-CAZ-SC(2) 2,063.83 32.48 315.15 1,957.73 1,868.59 363.19 -367.70 5,945,908.91 316.682.44 1.64 84.12 MWD+IFR-AK-CAZSC(2) fI 2,118.58 33.38 315.18 2,003.68 1,914.54 384.30 -388,68 5,945,930.52 316,661.98 1.64 88.69 MWD+IFR-AK-CAZSC (3) 13-3/8" x 16" 2,160,89 34.07 31520 2,038.87 1,949.73 400.96 405.24 5,945,947.58 316,645.84 1.64 92.30 MWD+IFR-AK-CAZSC(3) ) 2,183.49 34.36 315.10 2,057.56 1,968.42 409.97 414.20 5,945,956.81 316,637.10 1.31 94.26 MWD+1FR-AK-CAZ-SC(3) 2,277.93 36.43 316.27 2,134.54 2,045.40 44911 -052.40 5,945,996.86 316,599.86 2.31 102.16 MWD+IFR-AK-CAZ-SC(3) 2,371.41 38.75 316.97 2,20861 2,119.47 490.56 491.56 5,946,039.25 316,561.73 2.52 109.49 MWD+IFR-AK-CAZ-SC(3) 2,465.52 40.55 317.72 2,281.07 2,191.93 534.73 532.24 5,946,084.39 316,522.13 1.98 116.46 MWD+IFR-AK-CAZ-SC (3) 2,559.45 42.05 318.30 2,351.63 2,262.49 580.81 -573.71 5,946,131.46 316,481.80 1.65 122.94 MWD+IFR-AK-CAZ-SC (3) 2,654.14 44.08 318.95 2,420.81 2,331.67 629.33 -61644 5,946,181.00 316,440.26 2.19 129.00 MWD+IFR-AK-CAZ-SC(3) 2,74839 45.85 318.24 2,487.49 2,398.35 679.28 .660.49 5,946,232.00 316,397.44 1.95 135.30 1AWD+IFR-AK-CAZ-SC(3) I 2,842.58 45.83 318.00 2,553.11 2,463.97 729.59 -70560 5,946,283.39 316,353.57 0.18 142.23 MWD+IFR-AK-CAZ-SC(3) 2,935.53 45.83 318.11 2,618.57 2,529.43 779.71 -75064 5,946,334.59 316,309.76 0.08 149.23 MWD+IFR-AK-CAZ-SC(3) 9 3,031.20 45.85 318.43 2,684.53 2,595.39 830.40 -795.85 5,946,386.35 316,265.80 024 156.03 MWD+IFR-AK-CAZ-SC(3) 3,12470 45.88 318.41 2,749.64 2,660.50 880.59 440.38 5,946,437.61 316,222.50 0.04 162.57 MWD+IFR-AK-CAZ-SC(3) 3 3,219.39 45.88 317.92 2,815.56 2,726.42 93124 -885.72 5,946,48934 316,17840 0.37 169.49 MWD+IFR-AK-CAZ-SC(3) 3,313.34 45.89 318.03 2,880.96 2,791.82 981.35 -930.88 5,946,540.53 316,134.48 0.08 176.59 MWD+IFR-AK-CAZ-SC(3) 3,407.16 45.86 318.19 2,946.28 2,857.14 1,031.48 -975.85 5,946,59174 316,090.75 0.13 183.51 MWD+IFR-AK-CAZSC (3) 3,501.46 45.86 318.44 3,011.95 2,922.81 1,082.02 -1,020.85 5,946,693.35 316,046.99 0.19 190.23 MWD+IFR-AK-CAZSC (3) 3,595.88 45.84 318.14 3,077.71 2,988.57 1,132.59 -1,065.93 5,946,69500 316,003.15 0.23 196.99 MWD+IFR-AK-CAZSC(3) 3 3,690.61 46.07 318.53 3,143.57 3,059.43 1,183.46 -1,111.19 5.946 746.95 315,959.14 0.38 203.73 MWD+1FR-AK-CAZSC (3) 3,784.20 46.91 318.75 3,208.01 3,11867 1,234.41 -1,156.04 5,946,798.97 $15,915.54 0.91 21008 MWD+IFR-AK-CAZSC(3) 3,878.79 48.08 320.20 3,271.92 3,182.78 1,287.42 -1,201.35 5,946,853.06 315,871.55 1.68 215.59 MWD+IFR-AK-CAZSC(3) 3,973.00 48.97 321.36 3,334.31 3,245.17 1,342.10 -1,245.97 5,946,908.81 315,828.26 1.32 219.57 MWD+IFR-AK-CAZSC(3) i 4,068.00 50.72 322.20 3,395.57 3,306.43 1,393.15 -1,290.89 5,946,966.92 315,784.75 1.96 222.39 MWD+IFR-AK-CAZSC(3) 3 4,162.51 51.80 324.09 3,454.72 3,365.58 1,458.13 -1,335.09 5,947,026.96 315,742.00 1.93 22350 MWD+IFR-AK-CAZ-SC (3) 4,257.50 52.83 32878 3,512.79 3,42365 1520.03 -1,377.72 5,947,089.87 315,700.88 2.49 22162 MWD+IFR-AK-CAZ-SC(3) 1122018 3:47:55AM Page 4 COMPASS 5000.14 Build 85D Survey ConocoPhillips Bq(ER ConocoPhilli s Definitive Survey Report HE5 Company: ConowPhillips(Alaske) Inc. -WNS Local Co-ordinate Reference: Well MT6-06 Project: Western North Slope ND Reference: ACTUAL MTB -06 @ 89.14usft (Actual Doyonl9) Site: GMT7 Lookout Pad MD Reference: ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) Well: MT&06 North Reference: True Wellbore: MT6-06 Survey Calculation Method: Minimum Curvature Design: B1-wp02 Database: EDT 14 Alaska Production Survey 11/2/2018 3:47:55AM Page 5 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi ND NDSS -N/-S -E/-W DLS (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (°1100') Section Survey Tool Name Annotation (ft) (ft) (ft) 4,352.09 5404 32849 3,569.15 3,480.01 1,584.20 -1418.38 5,947,155.01 315,661.80 1.94 216.81 MWD+IFR-AK-CAZ-SC(3) 4,44723 55.31 329.74 3,624.16 3,535.02 1650.82 -1,458.22 5,947,22257 315,623.59 1.71 209.90 MWD+IFR-AK-CAZ-SC(3) 4,541.54 56.80 332.26 3,676.82 3,587.68 1,719.24 -1,496.13 5,947,29189 315,587.36 2.72 200.37 MWD+IFR-AK-CAZ-SC(3) 4,635.37 57.50 33469 3,727.73 3,638.59 1,789.77 -1,531.32 5,947,363.24 315,553.89 2.30 187.41 MWD+IFR-AK-CAZ-SC (3) 4,728.10 57.45 337.51 3,777.59 3,688.45 1,861.24 -1,562.99 5,947,435.46 315,523.97 2.56 17104 MWD+IFR-AK-CA7-SC (3) 4,822.50 57.54 338.55 3,828.32 3,739.18 1,935.07 -1,592.77 5,947,509.98 315,495.99 0.93 151.76 MWD+1FR-AK-CAZ-SC (3) 4,916.98 57.89 338.11 3,878.79 3,7139.65 2,009.29 -1,622.27 5,947,584.90 315,468.31 0.54 132.01 MWD+1FR-AK-CAZ-SC (3) 5,011.33 57,91 338.10 3,928.92 3,83918 .2,083.45 -1,652.07 5,947,659.76 315,440.31 0.02 112.55 MWD+IFR-AK-CAZ-SC (3) 5,102.99 57.86 337.95 3,977.65 3,888.51 2,155.45 -1,681.13 5,947,732.43 315,413.02 0.15 93.75 MWD+IFR-AK-CAZ-SC (3) 5,196.00 STT 337.17 4,027.13 3,937.99 2,228.24 -1,711.19 5,947,805.93 315,384.74 0.71 75.31 MWD+IFR-AK-CAZ-SC(3) 5,291,12 58.00 336.35 4,077.64 3,988.50 2,302.30 -1,742.99 5,947,880.74 315,359.74 0.75 57.52 MWD+IFR-AK-CAZ-SC(3) 5,389.57 57.89 33664 4,129.89 4,040.75 2,378.82 -1,776.27 5,947,953.04 315,323.33 0.27 39.49 MWD+IFR-AK-CAZSC(3) 5,485.75 57.88 336.16 4,181.02 4,091.88 2,453.47 -1,808.68 5,948,033.45 315,292.55 0.42 22.01 MWD+IFR-AK-CAZSC(3) 5,579.78 57.83 33529 4,231.05 4,141.91 2,526.04 -1,841.62 5,948,106.79 315,261.59 0.79 5.85 MWD+IFR-AK-CAZSC(3) 5,675.14 57.85 334.31 4,281.81 4,192.67 2,599.09 -1,875.99 5,948,18065 315,229.00 0.87 -9.25 MWD+IFR-AK-CAZSC(3) 5,766.46 57.84 334.17 4,331.48 4,242.34 2,670.24 -1,910.32 5,948,25261 315,196.41 0.13 -2328 MWD+IFR-AK-CAZSC(3) 5,863.69 57.87 333.52 4,382.14 4,293.00 2,742.62 -1,945.87 5,948,325.82 315,162.64 0.58 -37.05 MWD+IFR-AK-CAZSC(3) 5,957.26 57.89 333.65 4,431.90 4,342.76 2,813.59 -1,981.12 5,948,397.63 315,129.12 0.12 -50.23 MWD+IFR-AK-CAZSC(3) 6,052.55 57.85 334.38 4,482.58 4,39344 2,886.13 -2,01648 5,948,471.00 315,095.54 0.65 -64.24 MWD+IFR-AK-CAZSC(3) 6,146.20 57.77 335.63 4,532.47 4,443.33 2,957.96 -2,049.96 5,948,54361 315,063.81 1.13 -79.35 MWD+IFR-AK-CAZSC(3) 6,240.93 57.85 336.41 4,582.93 4,493.79 3,031.21 -2,082.54 5,948,617.63 315,033.02 0.70 -9603 MWD+1FR-AK-CAZSC(3) 6,334.86 57.82 337.09 4,632.94 4,543.80 3,104.26 -2,113.93 5,948,691.42 315,003.41 0.61 -113.56 MWD+IFR-AK-CAZSC(3) 6,429.32 57.88 336.32 4,683.20 4,594.06 3,177.72 -2,145.56 5,948,76562 314,973.58 0.69 -131.13 MWD+IFR-AK-CAZSC(3) 6,523.30 57.86 335.21 4,733.19 4,64405 3,250.29 -2,17823 5,948,838.96 314,942.69 1.00 -147.34 MWD+IFR-AK-CAZSC(3) 6,617.60 57.82 33523 4,783.38 4,694.24 3,322.77 -2,211.69 5,948,91222 314,911.00 0.05 -162.85 MWD+IFR-AK-CAZSC(3) 6,711.36 57.86 335.64 4,833.29 4,744.15 3,39496 -2,244.68 5,948,985.19 314,879.77 0.37 -178.57 MWD+1FR-AK-CAZSC(3) 6,806.08 57.79 334.20 4,883.73 4,794.59 3,467.57 -2,278.67 5,949,05860 314,847.56 1.29 -193.74 MWD+IFR-AK-CAZSC(3) 6,901.02 57.82 334.62 4,934.31 4,845.17 3,54003 -2,313.37 5,949,131.88 314,814.63 0.38 -208.24 MWD+IFR-AK-CAZSC(3) 6,992.85 57.86 334.25 4,983.19 4,89405 3,610.16 -2,346.92 5,949,20280 314,782.80 0.34 -222.30 MWD+IFR-AK-CAZSC(3) 7,087.15 5785 334.38 5,033.37 4,944.23 3,682.11 -2,381.52 5,949,275.56 314749.95 0.12 -236.58 MWD+IFR-AK-CAZ-SC(3) 7,180.14 57.66 333.66 5,082.98 4,993.64 3752.81 -2,415.97 5,949,34708 314,717.23 0.69 -25025 MWD+IFR-AK-CAZ-SC (3) 11/2/2018 3:47:55AM Page 5 COMPASS 5000.14 Build 85D ConocoP1llllps Company: ConocoPhillips(Alaska) Inc. -WNS Project: Western North Slope Site: GMT1 Lookout Pad Well: MT6-06 Wellbore: MT6-06 Design: B1-wp02 µ v ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MT6-06 ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) True Minimum Curvature EDT 14 Alaska Production SAT 0 Survey �-�- Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +El -W Northing Easting DLS Section cticti (usft) V) (1) (usft) (usft) (usft) (usft) (°1100') Survey Tool Name Annotation (ft) (ft) 7,274.18 57.64 33370 5,133.30 5,044.16 3,824.02 -2,451.20 5,949,419.12 314,68375 0.04 -263.59 MWD+IFR-AK-CAZSC(3) 7,368.69 57.68 33404 5,183.83 5,094.69 3,895.67 -2,486.35 5,949,491.60 314,650.35 0.31 -277.25 MWD+IFR-AK-CAZSC(3) ' 7,463.29 5763 334.71 5,234.47 5,145.33 3,967.77 -2,520.93 5,949,564.51 314,617.54 0.60 -29163 MWD+IFR-AK-CAZSC(3) 7,556.76 57.63 33604 5,284.52 5,195.38 4,039.54 -2,553.82 5,949,637.04 314,586.40 1.20 -307.18 MWD+1FR-AK-CAZSC(3) 7,651.69 57.70 33644 5,335.29 5,246.15 4,112.95 -2,586.14 5,949,711.21 314,555.87 0.36 -324.17 MWD+IFR-AK-CAZ-SC(3) 7,745.90 5769 336.06 5,385.64 5,296.50 4,185.83 2,618.21 5,949,789.85 314,525.59 0.34 -341.05 MWD+IFR-AK-CAZ-SC(3) 7,840.35 5766 335.70 5,436.14 5.347.00 4,258.68 -2,650.83 5,949,858.46 314,494.75 0.32 -357.46 MWD+IFR-AK-CAZ-SC(3) 7933.78 57.67 335.72 5,486.12 5,396.98 4,330.63 -2,683.30 5,949,931.18 314,464.04 0.02 -373.46 MWD+IFR-AK-CAZ-SC(3) 8,02798 5541 334.12 5,538.05 5,448.91 4,401.81 -2,716.59 5,950,003.14 314,432.48 2.79 -388.35 MWD+IFR-AK-CAZ-SC(3) + 8,12275 51.95 330.23 5,594.19 5,505.05 4,469.33 -2,752.17 5,950,071.50 314,398.56 4.93 -399.24 MWD+IFR-AK-CAZ-SC(3) 8,216.45 51.90 326.83 5,651.99 5,562.85 4,532.23 -2,790.66 5,950,135.31 314,361.61 2.86 405.05 MWD+IFR-AK-CAZ-SC (3) a 8,311.41 50.31 323.82 5,711.62 5,622.48 4,593.00 -2,832.68 5,950,197.09 314,321.08 2.98 -003.76 MWD+IFR-AK-CAZ-SC (3) 8,403.52 48.25 322.41 5,7]1]0 5,682.56 4,64684 -2,874.57 5,950,253.93 314,280.56 2.52 105.68 MWD+IFR-AK-CAZ-SC(3) 8,49640 46.08 320.67 5,836.21 5,747.07 4,703.33 -2,917.82 5,950,30944 314,23865 2.65 402.69 MWD+IFR-AK-CAZ-SC(3) 8,592.77 43.92 317.91 5,902.94 5,813.80 4,753.92 -2,961.31 5,950,361.07 314,196.40 3.08 -397.23 MWD+IFR-AK-CAZSC(3) 8,685.17 42.19 313.75 5,970.47 5,881.33 4,799.17 3,005.22 5,950,407.37 314,153.61 3.60 -388.29 MWD+IFR-AK-CAZSC(3) 8,779.40 40.80 309.43 6,041.06 5,95192 4,840.61 3,051.87 5,950,449.93 314,107.99 3.38 -374.90 MWD+IFR-AK-CAZSC(3) 8,873.97 39.03 304.15 6,113.62 6,02448 4,876.97 -3,100.39 5,950,48745 314,060.36 4.04 -357.00 MWD+IFR-AK-CAZSC(3) 8,968.83 37.86 299.42 6,187.93 6,098.79 4,908.04 -3,150.48 5,950,519.73 314,011.05 3.34 334.73 MWD+IFR-AK-CAZSC(3) 9,063.42 37.07 294.47 6,263.02 6,173.88 4,934.11 3,201.72 5,950,547.04 313,960.46 3.29 308.58 MWD+IFR-AK-CAZSC(3) 9,157.47 35.91 287.83 6,33666 6,249.52 4,954.31 -3,25380 5,950,568.49 313,908.89 4.37 -278.31 MWD+IFR-AK-CAZSC(3) 9,252.10 35.58 279.91 6,415.51 6,326.37 4,967.55 3,307.37 5,950,583.03 313,855.65 4.90 -242.75 MWD+IFR-AK-CAZSC(3) 9,345.12 35.96 274.19 6,491.00 6,401.86 4,974.21 -3,361.28 5,950,590.99 313,801.93 3.62 -203.09 MWD+IFR-AK-CAZ-SC(3) 9,43997 35.94 26947 6,567.80 6,478.66 4,975.98 3,416.90 5,950,594.12 313,746.37 2.92 -159.08 MWD+IFR-AK-CAZ-SC(3) 9,533.07 35.93 264.10 6,643.20 6,554.06 4,972.92 41,47140 5,950,592.39 313,691.81 3.38 -113.17 MWD+IFR-AK-CAZ-SC (3) 9,62760 35.94 259.29 6,719.76 6,630.62 4,964.91 -3,526.26 5,950,58571 313,636.78 2.99 5Ioil MWD+IFR-AK-CAZ-SG(3) 9,722.00 37.03 253.02 6,795.68 6,706.54 4,951.46 3,58069 5,950,573.58 313,58295 4.11 -12.13 MWD+IFR-AK-CAZ-SC(3) 9,815.57 38.18 24693 6,869.84 6,78070 4,931.89 -3,634.26 5,950,555.32 313,52602 4.16 42.71 MWD+IFR-AK-CAZSC(3) 9,909.91 38.92 241.21 6,943.64 6,854.50 4,906.19 -3,687.08 5,950,530.91 313,474.60 3.86 100.55 MWD+1FR-AK-CAZSC(3) 1o005.11 40.18 237.08 7,017.06 6,927.92 4,875.09 -3,739.08 5,950,501.09 313,421.86 306 160.90 MWD+1FR-0.K-CAZSC(3) '.. 10,09983 4191 231.38 7,088.52 6,999.38 4,838.72 -3,789.47 5.950,46596 313,370.61 4.35 223.04 MWD+IFR-AK-CAZ-SC(3) 11112018 3:47:55AM Page 6 COMPASS 5000.14 Build 85D ✓ ConocoPhillips Company: ConocoPhillips(Alaska) Inc. -WNS Projects Western North Slope Site: GMT1 Lookout Pad Well: MT6-06 Wellbore: MT6-06 Design: B1-wp02 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MT6-06 ACTUAL MT6-06 @ 89.14usft (Actual Doyon19) ACTUAL MT6-06 @ 89.14usft (Actual Doyon19) True Minimum Curvature EDT 14 Alaska Production BAgKHFs A Survey Map Map Vertical MD Inc Azi ND NDSS +N/-5 +E/ -W Northing Easting DLS Section (usft) (`) (°) (usft) (usft) (usft) (usft) (°/100') Survey Tool Name Annotation (ft) (ft) (ft) 10,193.87 43.50 227.39 7,157.63 7,068.49 4,797.19 -3,837.84 5,950.425.62 313,321.24 3.34 286.58 MWD+IFR-AK-CAZSC(3) 10,285.85 44.90 224.52 7,223.58 7,134,44 4,752.61 -3,883.90 5,950,382.17 313,274.11 2.65 350.06 MWD+IFR-AK-CAZSC(3) 10,316.00 44.94 223.94 7244.93 7,155.79 4,737.35 5,89875 5,950,367.28 313,258.89 1.37 371.04 10WD+IFR-AK-CAZ-SC (4) 9-516'x 12-1/4" 10,37152 45.02 222.87 7,284.20 7,195.06 4,708.84 5,925.72 5,95,339.43 313,231.25 1.37 409.61 MWD+IFR-AK-CAZ-SC(4) 10,464.34 4695 219.86 7,348.70 7,259.56 4,658.74 8969.80 5,950290.42 313,185.96 3.12 474.72 MWD+IFR-AK-CAZ-SC(4) 10,560.20 50.65 215.94 7,411.85 7,322.71 4,601.81 4.014.03 5,950,234.59 313,140.37 493 543.95 MWD+IFR-AK-CAZ-SC(4) I 10,655.11 53.73 212.45 7,470.04 7,380.90 4,539.79 4,056.11 5,950,173.61 313,096.79 4.35 614.45 MWD+IFR-AK-CA7-SC (4) 1 10,750.61 56.29 209.17 7,524.80 7,435.66 4,47260 -0,096.14 5,950,107.41 313,055.14 3.89 685.33 MWD+IFR-AK-CAZSC(4) 10,844.73 58.92 206.94 7,575.23 7,486.09 4,40246 4,133.49 5,950,03821 313,016.10 3.44 757.76 MWD+IFR-AK-CAZ-SC(4) 10,938.99 61.56 205.80 7,622.01 7,532.87 4,329.15 4169.83 5,949,965.81 312,978.00 2.99 830.23 MWD+IFR-AK-CAZSC (4) 11,032.00 63.74 203.81 7,664.75 7,575.61 4,254.17 4,20447 5,949,891.69 312,941.55 3.02 902.33 MWD+1FR-AK-CAZSC(4) 11,125.52 64.76 202.54 7,705.38 7,61624 4,176.73 4,23761 5,949,815.09 312,906.54 1.64 974.64 MWD+IFR-AK-CAZSC(4) 11,219.37 64.74 201.73 7,74541 7,656.27 4,096.11 4,269.59 5,949,73].2] 312,872.66 0.78 1,046.72 MWD+IFR-AK-CAZSC(4) 11,312.00 64.69 201.24 7,784.97 7,695.83 4,020.17 4,300.27 5,949,660.11 312,840.10 0.48 1,117.34 MWD+IFR-AK-CAZSC(4) t i 11,406.62 65.03 200.35 7,825.17 7,736.03 3,940.09 4,330.68 5,949,580.80 312,807.76 0.92 1,18900 MWD+IFR-AK-CAZSC(4) 11,501.01 65.63 195.83 7,864.59 7,77545 3,858.59 4,357.30 5,949,499.96 312,779.17 4.40 1,258.43 MWD+IFR-AK-CAZ3C(4) y 11,599.48 67.51 19074 7,901.77 7,812.63 3,775.15 4,376.97 5,949,417.04 312,757.46 5.39 1,323.37 MWD+IFR-AK-CAZSC(4) i 11,689.55 69.54 186.51 7,936.59 7,847.45 3,687.71 4.390.21 5,949,329.95 312,742.12 4.66 1,385.47 MWD+IFR-AK-CAZ-SC(4) j 11,785.07 71.87 183.88 7,968.15 ],8]9.01 3,597.94 4,398.36 5,949,240.41 312,731.80 3.56 1,444.81 MWD+IFR-AK-CAZ-SC (4) € 11,842.00 711 181.91 7,985.17 7,896.03 3,543.68 4.401.10 5,949,186.24 312,727.74 421 1,47891 MWD+IFR-AK-CAZ-SC(5) 11,875.58 75.96 184.73 7,934.05 7,904.91 3,511.36 4.402.98 5,949,153.9] 312,725.08 11.20 1,499.42 MWD+IFR-AK-CAZ-SC(5) 11,894.46 76.12 184.95 7,998.60 7,909.46 3,493.10 4,404.52 5,949,135.76 312,723.09 1.41 1,511.40 MWD+IFR-AK-CAZSC(5) 11,989.42 81.54 184.14 8,01699 ],92].85 3,40027 4,411.90 5,949,043.44 312,713:46 5.77 1,571.91 MWD+IFR-AK-CAZSC(5) g 12,085.58 85.77 181.07 8,027.62 7,93848 3,304.83 4,41623 5,948,947.84 312,706.81 5.42 1,631.50 MWD+IFR-AK-CAZSC(5) i 12,180.38 90.10 177.57 8,031.04 7,991.90 3,210.14 4,415.10 5,948,853.15 312,705.64 5.87 1,686.23 MWD+IFR-AK-CAZSC (5) 12,275.70 90.45 174.55 8,030.58 7,941.44 3,11505 4,408.55 5,948,757.94 312709.88 3.19 1,736.80 MWD+IFR-AK-CAZSC(5) 12,371.47 90.45 170.28 8,029.83 7,940.69 3,020.15 4,395.91 5,948,662.76 312,720.21 446 1,M2 34 MWD+IFR-AK-CAZSC(5) I 12,466.57 89.98 166.51 6,029.47 7,940.33 2,927.01 4.376.79 5,948,569.19 312,737.06 3.99 1,621.59 MWD+IFR-AK-CAZ-SC(5) {) 12,562.02 8942 162.69 8,029.97 7,940.83 2,835.00 4,351.44 5,948,476.61 312,760.16 4.04 1,855.15 MWD+IFR-AK-CAZSC(5) 12,65746 89.46 158.90 8.030.90 ],941.76 2,744.90 4.320.06 5,948,38537 312,789.35 3.97 1.882.70 MW0+IFR-AK-CAZ-SC(5) 12,752.67 89.56 155.17 8631.72 1942.58 2,657.25 4,282.92 5,948,29725 312,824.35 3.92 1,904.14 MWD+IFR-AK-CAZ-SC(5) II 111212018 3:47:55AM Page 7 COMPASS 5000.14 Build 85D Survey ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConomPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MT6-06 Project: Western North Slope TVD Reference: ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) Site: GMT1 Lookout Pad MD Reference: ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) Well: MT6-06 North Reference: True wellbore: MT6-06 Survey Calculation Method: Minimum Curvature Design: B1-wp02 Database: EDT 14 Alaska Production Survey Annotation BAER 1 UGHE6 111WO18 3:47:55411,1 Page 8 COMPASS 50170.14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +El -W DLS (usft) (-) (-) (usft) (usft) (usft) (usft) Northing Easting (-1108) Section Survey Tool Name (ftl (ft) (ft) 12,849.22 88.96 153.17 8,032.96 7.94382 2,570.36 4,240.85 5,948,209.37 312,864.28 2.16 1,921.17 MWD+IFR-AK-CAZ-SC(5) 12,943.01 89.03 151.44 8,034.61 7,94547 2,487.33 -0,197.27 5,948,125.31 312,905.83 1.85 1,934.69 MWD+IFR-AK-CAZ-SC(5) 13,037.74 90.98 151.54 8,034.60 7,945.46 2,404.09 4,15206 5,948,041.00 312,949.01 2.06 1,947.02 MWD+IFR-AK-CAZ-SC(5) 13,135.01 90.59 150.46 8,033.27 7,944.13 2,319.03 4.104.91 5,947,954.82 312,994.08 1.18 1,958.85 MWD+IFR-AK-CAZ-SC(5) 13,228.20 90.01 150.56 8,03238 7,943.64 2,237.91 4,059.03 5,947,872.62 313,037.97 0.63 1,969.39 MWD+IFR-AK-CAZSC(5) 13,322.93 89.98 153,19 8,032.79 7,943.65 2,154.38 4,014.38 5,947,788.03 313,080.57 2.78 1,982.35 MWD+IFR-AK-CAZSC(5) 13,418.47 8998 151.70 8,032.82 7,943.68 2,069.68 3,970.19 5,947,702.29 313,122.69 1.56 1,996.36 MWD+IFR-AK-CAZSC(5) 13,514.88 89.49 15240 8,033.27 7,944.13 1,984.51 3,925.00 5,947,616.06 313,165.80 0.89 2,009.83 MWD+IFR-AK-CAZSC(5) 13,609.06 89.09 151.68 8,034.44 7,945.30 1,901.33 y880.85 5,947,531.84 313,207.91 0.87 2,022.98 MWD+IFR-AK-CAZSC(5) 13,704.52 88.60 15166 8,036.36 7,947.22 1,817.32 -3,835.56 5,947,44676 313,251.15 0.51 2,035.70 MWD+IFR-AK-CAZSC(5) 13,799.86 88.01 151.14 8,039.18 7,950.04 1,733.65 -3,789.94 5,947,362.01 313,294.72 0.82 2,047.95 MWD+IFR-AK-CAZSC(5) 13,895.24 87.89 150.70 8,042.59 7,95345 1,650.35 3,74361 5,947,277.61 313,339.00 0.48 2,059.41 MWD+IFR-AK-CAZSC(5) 13,991.14 88.67 150.75 8,04547 7,955:33 1,566]4 -3,696.74 5,947,192.89 313,383.83 0.82 2,070.62 MWD+IFR-AK-CAZSC(5) 14,086.04 91.01 152.50 8,045.74 7,956.60 1,483.25 -3,651.64 5,947,108.33 313,426.88 3.08 2,083.19 MWD+IFR-AK-CAZSC(5) 14,181.68 91.95 153.08 8,04327 7,954.13 1,398.22 -3,607.92 5,947,022.28 313,468.52 1.15 2,097.77 MWD+IFR-AK-CAZSC(5) 14,276.65 92.44 153.16 8,039.63 7,950.49 1,313.58 3,565.02 5,946,93662 313,509.35 0.52 2,112.79 MWD+IFR-AK-CAZSC(5) 14,372.44 91.60 152.02 8,036.25 7,947.11 1,228.59 3,520.95 5,946,85060 313,551.34 1.48 2,127.07 MWD+IFR-AK-CAZSC(5) 14,467.67 91.27 152.72 8,033.87 7,944.73 1,144.25 -3,476.80 5,946,76521 313,593.43 0.81 2,140.91 MWD+IFR-AK-CAZSC(5) 14,552.83 89.73 153.65 8,033.04 7,943.90 1,059.33 3,433.87 5,946,679.28 313,634.27 1.89 2,156.07 MWD+IFR-AK-CAZSC(5) 14,658.59 89.68 152.57 8,033.53 7,944.39 973.93 3,390.57 5,946,59265 313,675.49 1.13 2,171.21 MWD+IFR-AK-CAZ-SC(5) 14,752.95 89.18 152.80 8,034.47 7,945.33 890.09 3,347.27 5,946,50800 313,716.74 0.58 2,185.44 MWD+IFR-AK-CAZ-SC(5) 14,84863 88.69 152.63 8,036.25 7,947.11 805.07 3,303.41 5,946,421.94 313,758.51 0.54 2,199.91 MWD+IFR-AK-CAZ-SC(5) 14,943.86 87.92 151.97 8,039.06 7,949.92 720.80 3,259.17 5,946,335.62 313,800.70 1.06 2,213.63 MWD+IFR-AK-CAZ-SC (5) 15,039.99 87.42 150.30 8,042.97 7,953.83 63668 3,212.80 5,946,25141 313,845.00 1.81 2,225.54 MWD+IFR-AK-CAZ-SC(5) 15,133.74 88.02 150.37 8,046.70 7,957.56 555.28 3,166.44 5,946,168.92 313,889.37 064 2,235.85 MWD+IFR-AK-CAZ-SC(5) 15,230.24 87.96 152.43 8,05009 7,960.95 47061 3,120.28 5,946,083.16 313,933.46 2.13 2,248.25 MWD+1FR-AK-CAZSC(5) 15,32371 87.90 154.42 8,05346 7,964.32 387.08 3,078.49 5,945,99863 313,973.20 2.13 2,263.52 MWD+IFR-AK-CAZSC(5) 15,419.41 8296 154.34 8,056.92 7,967.78 300.84 3,037.14 5,945,91143 314,012.45 0.10 2,280.73 MWD+1FR-AK-CAZSC(5) 15,515.14 8894 155.08 8,059.51 7,970.37 214.32 -2,996.26 5,94$82394 314,051.21 128 2,298.50 MWD+IFR-AK-CAZSC(5) 15,610.18 88.50 154.62 8,061.63 7.97249 128.31 -2,955.87 5,945,736.98 314,08949 0.67 2.316.36 MWD+IFR-AK-CAZ-SC(5) 15,70509 8848 154.15 8,064.13 7974.99 4276 -2,914.86 5,945,65047 314,12841 0.50 2.33344 MWD+IFR-AK-CAZ-SC(5) Annotation BAER 1 UGHE6 111WO18 3:47:55411,1 Page 8 COMPASS 50170.14 Build 85D ConocoPhillips BA(ER ConocoPhillips Definitive Survey Report r�u�REs Company: ConowPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MT6-06 Project: Western North Slope TVD Reference: ACTUAL MT6-06 @ 89.14usft (Actual Doyon19) Site: GMT1 Lookout Pad MD Reference: ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) Well: MT6-06 North Reference: True Wellbore: MT6-06 Survey Calculation Method: Minimum Curvature Design: B7-wp02 Database: EDT 14 Alaska Production Survey 1 MD Inc Azi TVD NOSS +N/S +EI -W Map Map DLS vertical lush) V) V) (usft) Waft) (usft) (usft) Northing Easting (°/100' Section Survey Tool Name Annotation 15,799.83 88.96 153.35 8,066.65 7,977.51 -02.78 -2,8]29] 5,945,564.54 314,168.22 0.84 2,349.46 MWD+IFR-AK-DAL.-SD (5) 15,829.00 88.93 153.19 8,067.31 7,978.17 -68.22 -2,859.85 5,945,538.19 314,180.70 1.64 2,354.15 MWD+IFR-AK-CAZSC(6) MT6-06 KOP f 15,895.18 88.10 153.55 8,06902 7,979.88 -127.36 -2,830.20 5,945,478.35 314,208.91 1.37 2,364.90 MWD+IFR-AK-CAZSC(6) yp 15,98912 88.36 156.40 8,071.94 7,982.80 -212.98 -2,790.23 5,945,391.79 314,24578 303 2,382.87 MWD+IFR-AK-CAZSC(6) I 16,086.15 88.33 156.29 8,074.73 7,985.59 -301.27 -2,751.56 5,945,302.59 314,283.30 0.12 2,403.46 MWD+IFR-AK-CAZSC(6) ' 16,180.98 89.43 156.65 8,076.58 7,987.44 -388.20 -2,713.71 5,945,214.78 314,319.03 1.22 2,423.91 MWD+IFR-AK-CAZ-SC(6) 1627588 89.96 156.30 6077.08 7,987.99 -075.21 -2,675.63 5,945,126.88 314,354]8 0.67 2,444.39 MWD+IFR-AK-CAZ-SC(6) 3 16,371.09 89.15 154.99 8,077.82 7,988.68 561.94 -2,636.57 5,945,039.22 314,391.92 1.62 2,453.58 MWD+IFR-AK-CAZSC(6) 16.466.56 89.25 153.88 8,079.16 7,990.02 -648.05 -2,595.37 5,944,952.14 314,431.01 1.17 2,480.85 MWD+IFR- AK-CAZSC (6) 1 16,561.50 STM 152.95 8,081.50 7,992.36 -732.92 -2,552.90 5,94,85627 314,471.40 1.71 2,496.35 MWD+IFR-AK-CAZSC(6) 16,657.22 88,76 154.01 6064.27 7,995.13 -818.53 -2,510.18 5,94,779.65 314,512.03 1.41 2,512.09 MWD+IFR-AK-CAZSC(6) i 16,752.92 89.96 154.51 8,085.34 7,996.20 -904.73 -2,468.62 5,944,69247 314,551.48 1.36 2,529.11 MWD+IFR-AK-CAZ-SC(6) i 16,846.71 89.95 153.63 8,085.42 7,996.28 -989.08 -2,427.81 5,944,607.16 314,590.43 0.94 2,545.49 MWD+IFR-AK-CAZ-SC (6) i 16,942.10 89.95 153.37 8,085.60 7,996.36 -1,074.45 -2,385.05 5,944,520.79 314,630.90 0.27 2,561.21 MWD+IFR-AK-CAZSC(6) • 17,037.61 87.54 152.14 8,087.59 7,998.45 -1,159.33 -2,341.34 5,944,434.87 314,672.53 2.83 2,575.72 MWD+IFR-AK-CAZSC(6) 17,132.92 87.46 152.67 8,091.75 8,00261 -1,243.72 -2,297.23 5,94,349.44 314,714.57 0.56 2,589.62 MWD+IFR-AK-CAZSC(6) 17,228.31 86.38 153.15 8,096.87 8,007.73 -1,328.52 -2,253.85 5,944,263.62 314,755.88 1.24 2,604.35 MWD+IFR-AK-CAZ-SC(6) I 17,32366 87.93 152.91 8,101.61 8,012.47 -1,413.39 -2,210.66 5,944,17773 314,796.99 1.64 2,619.27 MWD+IFR-AK-CAZSC(6) 17,419.01 86.14 155.43 8,106.54 8,017.40 -1499.09 -2,169.18 5,944,09105 31036.38 324 2,636.06 MWD+IFR-AK-CAZ-SC(6) '!! 17,48200 66.14 15543 8,110.78 8.021.64 -1,556.25 -2,143.05 5,944,033.28 314,881.11 0.00 2648.50 PROJECTED to TD 4-1/2^x6" 1122018 3:4755AM Page 9 COMPASS 5000.14 Build 850 BA SER HUGHES a GE company Date: December 6, 2018 Abby Bell AOGCC 333 West 7" Ave, Suite 100 Anchorage, Alaska 99501 218093 30078 Letter of Transmittal Michael Soper Baker Hughes, a GE Company 795 East 94th Avenue Anchorage, Alaska 99515 lease find enclosed the directional survey data for the following well(s): MT6-06PB1 MT6-06PB2 MT6-06 F�E�E�vE� pEC 0 � 2018 p�®GCC (3) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Applications Engineer Michael.SoperCci)BakerHughes com ConocoPhillips ConocoPhillips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-06PB1 50-103-20773-70 Baker Hughes INTEQ Definitive Survey Report 02 November, 2018 BATER UGHES a GE company 21 8093 30078 ConocoPhillips Company: ConocoPhillips(Alaska) Inc.-WNS 8/9/2018 Project: Western North Slope Site: GMT1 Lookout Pad Well: MT6-06 Phase: ACTUAL Wellbore: MT6-06PB1 Design: B1-wp02 Project Western North Slope, North Slope Alaska, United States Map System: US State Plane 1927 (Enact solution) System Datum Geo Datum: NAD 1927 (NADCON CONUS) Mean Sea Level Map Zone: Alaska Zone 04 Using geodetic scale factor Well MT6-06 5,945,536.92usft Well Position +NI -S 0.00 usft Northing: Longitude: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Wellbore MT6-06PB1 Field Strength Magnetics Model Name Sample Date (nT) . 11/2/2018 3:44:44AM Page 2 COMPASS 5000.14 Build 850 Depth from (ND) (usft) 0.00 ConocoPhillips Elevation: BGGM2018 8/9/2018 Design MT6 06 PB1 Audit Notes: Well MT6-06 Version: 1 0 Phase: ACTUAL Vertical Section: ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) . 11/2/2018 3:44:44AM Page 2 COMPASS 5000.14 Build 850 Depth from (ND) (usft) 0.00 ConocoPhillips Elevation: B A ER 42 f�UGHES Definitive Survey Report Local Co-ordinate Reference: Well MT6-06 TVD Reference: ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) MD Reference: ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production Mean Sea Level Using geodetic scale factor 5,945,536.92usft Latitude: 70° 15'22S92 N 317,041.19usft Longitude: 151° 28'43,472 W 0.00usft Ground Level: 37.20 usft Declination Dip Angle Field Strength (°) (`) (nT) 16.45 80.70 57,397 Tie On Depth: 36.94 -NI-S (usft) 0.00 +El -W Direction (usft) 3 0.00 188.27 E ✓ ConocoPhillips BAd([R a ConocoPhilli . M In Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: ConocoPhillips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-06 MT6-06PB1 B1-wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MTG-06 ACTUAL MT6-06 @ 89.14usfi (Actual Doyonl9) ACTUAL MT6-06 @ 89.14usfi (Actual Doyonl9) True Minimum Curvature EDT 14 Alaska Production �^ Survey Program Date From To Survey Survey (usft) (usR) Survey (Wellbore) Tool Name Description Start Date End Date 115.00 1,021.00 Gyrodata Gyro$$ 16" (MT6-06PB1) GYD-CT-DMS Gyrodata cont.drillpipe Ms 9/10/2018 9/102018 1,106.74 2,063.83 BHGE MWD+SAG+IFR+MSA16"(MT6-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/11/2018 9/12/2018 2,160.89 10,285.85 BHGE MWD+SAG+IFR+MSA 121/4"(M MWD+IFR-AK-CAZ-SC MWD -IFR AK CAZ SCC 9/15/2018 9/17/2018 10.371.52 11,679.62 BHGE MWD+SAG+IFR+MSA 6x83/4" (M MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/26/2018 9/26/2018 11,894.64 12,651.21 BHGE MWD+SAG+IFR+MSA 6"(MT6-0 MWD-IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/5/2018 10/6/2018 Survey Map Map Vertical MD Inc TVD TVDSS +N/ -S +El -W Northing D Easting LS Section ("art) 1°I ) 1 (°) fusel ( (ustt) (ushl loan) (°ltoo') Survey Tool Name Annotation (ft) (ti) (R) 3694 0.00 0.00 36.94 -52.20 0.00 0.00 5,W,53692 317,041.19 0.00 0.00 UNDEFINED 115.00 0.51 167.22 115.00 25.66 4).34 0.08 5,945,536.58 317,04126 0.65 032 GYD-CT-DMS(1) 205.00 0.76 167.84 204.99 115. B5 -1.31 0.29 5,94553560 317,041.45 028 1.26 GYD-CT-DMS(1) 30000 0.66 206.24 299.99 210.85 -2.42 0.18 5,945,534.50 317,041.32 0.50 2.37 GYD-CT-DMS(1) 361.00 0.70 247.51 360.98 271.84 -2.88 -0.32 5,945,53405 317,040.81 079 2.89 GYD-CT-OMS(1) 455.00 160 298.97 454.96 365.82 -2.46 -2.00 5,945,534.51 317,039.14 1.37 2.72 GYD-CT-DMS(1) 550.00 3.79 309.88 549.85 46071 0.19 5.57 5,945,53725 317,035.63 2.36 061 GYD-CT-DMS(1) 64500 6.03 311.84 6*150 555.36 5.54 -11.69 5,945,542.74 317,029.64 2.36 -3.80 GYD-CT-OMS(1) 738.00 8.81 311.77 73671 647.57 13.54 -20.65 5,945,55096 317,020.88 2.99 -1043 GYD-CT-DMS(1) 832.00 1103 312.24 829.30 740.16 24.38 -32.67 5,945,56209 317,009.12 2.36 -1943 GYD-CT-DMS(1) 926.00 12.93 312.92 921.25 832.11 37.59 47.03 5,945,57564 316,995.09 2.03 30.43 GYD-CT-DMS(1) 1,021.00 15.01 313.60 1,013.43 924.29 53.31 43373 5,94559176 316,97878 2.20 43.59 GYD-CT-DMS(1) 1,106.74 17.20 314.12 1,095.80 1,00666 69.83 -80.87 5,945,608.66 316,962.05 2.56 5744 MWD+1FR-AK-CAZSC(2) 1,149.72 18.70 316.17 1,13669 1,047.55 79.19 -90.21 5,945,618.28 316,952.94 3.79 b5.39 MWD+1FR-AK-CAZSC(2) 1,244.34 20.79 316.64 1,22574 113660 102.35 -112.24 5,945,641.96 316,931.48 2.22 55.14 MWD+1FR-AK-CAZSC(2) 1,337.61 22.41 317.98 1,312.46 1,223.32 127.59 -135.51 5,945,667.76 316,908.63 1.82 -106.77 MWD+1FR-AK-CAZSC (2) 1,432.48 23.36 318.88 1,399.86 1,310.72 155.20 -159.98 5,945,695.95 316,885.04 1.07 -130.57 MWD+IFR-AK-CAZSC(2) 1,526.98 24.13 315.69 1,466.37 1,397.23 183.13 -185.80 5,945,724.50 316,859.91 1.58 -154.50 MWD+1FR-AK-CAZSC(2) 1.62189 2574 31442 1,572.43 1483.29 21144 -214.07 5,945,75349 316,63233 179 -178.45 MWD+1FR-AK-CAZ-SC(2) 1122016 3:44:44AM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips BAER ConocoPhilh t�UGNES In Definitive Survey Report Company: Conocc Phillips(Alaska) Inc.-WNS Project: Western North Slope Site: GMT1 Lookout Pad Well: MT6-06 Wellbore: MT6-06PB1 ' Design: B1-wp02 Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MT6-06 ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) True Minimum Curvature EDT 14 Alaska Production 1122018 3:44:44AM Page 4 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc TVD TVDSS +N/ -S +E7 -W DLS (usft) (°) (1 (°) ) (usft) (usft) (usft) (usft) Northing Easting (°7100') Section Sums Tool Name Annotation Y (ft) (ft) (ft) 1,716.26 27.14 314.61 1,656.92 1,56778 240.90 -244.03 5,945,783.66 316,803.10 1.49 -203.29 MWD+1FR-AK-CAZ-SC(2) 1,809.69 29.23 314.56 1,739.27 1,650.13 271.88 -275.46 5,945,815.39 316,772.43 2.24 -229.43 MWD+IFR-AK-CAZSC (2) 1,903.56 30.26 314.04 1,820.77 1,731.63 304.40 508.79 5,945,848.71 316,739.90 1.13 -256.82 MWD+IFR-AK-CAZ-SC(2) 1,997.77 3140 315.37 1,901.67 1,812.53 338.37 -34310 5,945,883.50 316,706.43 1.41 -285.50 MWD+1FR-AK-CAZ-SC(2) 2,063.83 32.48 315.15 1,957.73 1,868.59 363.19 567.70 5,945,908.91 316,682.44 1.64 -306.53 MWD+IFR-AK-CAZ-SC(2) 2,118.58 33.38 315.18 2,003.68 1,914.54 384.30 588.68 5,945,930.52 316,661.98 1 64 -324.39 MWD+IFR-AK-CAZSC (3) 13-3/8" x 16" 2,160.89 34.07 315.20 2,038.87 1,949.73 400.96 405.24 5,945,947.58 316,645.89 1.64 -338.50 MWD+IFR-AK-CAZ-SC(3) 2,183.49 34.36 315.10 2,057.56 1,968.42 409.97 414.20 5,945,956.81 316,637.10 1.31 -346.13 MWD+IFR-AK-CAZSC(3) 2,277.93 36.43 31627 2,134,54 2,045.40 449.11 452.40 5,945,996.86 316,599.85 2.31 -379.37 MWD+IFR-AK-CAZ-SC(3) 2,371.41 38.75 316.97 2,208.61 2,119.47 490.56 491.56 5,946,039.25 316,561.73 2.52 414.76 MWD+IFR-AK-CAZSC(3) 2,465.52 40.55 317.72 2,281.07 2,191.93 534.73 -532.24 5,946,084.39 316,522.13 1.98 452.61 MWD+IFR-AK-CAZSC(3) 2,559.45 42.05 318.30 2,351.63 2,262.49 580.81 573.71 5,946,131.46 316,481.80 1.65 192.25 MWD+1FR-AK-CAZSC(3) 2,654.14 44.08 31895 2,420.81 2,331.67 629.33 516.44 5,946,181.00 316,440.26 2.19 -534.12 MWD+IFR-AK-CAZSC(3) 2,748.39 45.85 31824 2,487.49 2,39835 679.28 560.49 5,946,232.00 316,397.44 1.95 -577.21 MWD+IFR-AK-CAZSC(3) 2,842.58 45.83 318.00 2,553.11 2,463.97 729.59 -705.60 5,946,283.39 316,353.57 0.18 520.51 MWD+1FR-AK-CAZSC(3) 2.936.53 45.83 318.11 2,618.57 2,529.43 779.71 -750.64 5,946,334.59 316,309]6 0.08 -66363 MWD+IFR-AK-CAZSC(3) 3,031.20 45.85 318.43 2,684.53 2,595.39 830.40 -795.85 5,946,386.35 316,265.80 0.24 -707.29 MWD+IFR-AK-CAZSC(3) 3,124.70 45.88 318.41 2,749.64 2,660.50 880.59 -840.38 5,946,437.61 316,222.50 0.04 -750.56 MWD+IFR-AK-CAZSC(3) 3,219.39 45.88 317.92 2,815.56 2,726.42 931.24 -885.72 5,946,489.34 316,178.40 0.37 -794.16 MWD+IFR-AK-CAZSC(3) 3,313.34 45.89 318.03 2,880.96 2,791.82 981.35 -930.88 5,946,540.53 316,134.48 0.08 -837.25 MWD+IFR-AK-CAZSC(3) 3,407.16 45.86 318.19 2,946.28 2,857.14 1,031.48 -975.85 5,946,591.74 316,090.75 0.13 580.39 MWD+IFR-AK-CAZSC(3) 3,50146 45.86 318.44 3,011.95 2,922.81 1,082.02 -1,020.85 5,995,643.35 316,046.99 0.19 -923.93 MWD+IFR-AK-CAZSC(3) 3,595.88 45.84 318.14 3,077.71 2,98857 1,132.59 -1,065.93 5,946595.00 316,003.15 0.23 -96250 MWD+IFR-AK-CAZSC(3) 3,690.61 46.07 318.53 3,143.57 3,054.43 1,183.46 -1,111.19 5,946,746.95 315,959.14 0.38 -1,011.32 MWD+IFR-AK-CAZSC(3) 3,780.20 46.91 318.75 3,208.01 3,118.87 1,234.41 -1,156.04 5,946,798.97 315,915.54 0.91 -1,055.29 MWD+IFR-AK-CAZSC(3) 3,878.79 48.08 320.20 3,271.92 3,182.78 1,287.42 -1,201.35 5,946,853.06 315,871.55 1.68 -1,101.23 MWD+IFR-AK-CAZSC(3) 3,973.00 48.97 321.36 3,334.31 3,245.17 1,342.10 -1,245.97 5,946,908.81 315,828.26 1.32 -1,148.93 MWD+IFR-AK-CAZSC(3) 4,068.00 50.72 322.20 3,395.57 3,306.43 1,399.15 -1,290.89 5,946,966.92 315)84]5 1.96 -1,19892 MWD+IFR-AK-CAZ-SC(3) 4,162.51 51.80 324.09 3,454.72 3,365.58 1,458.13 -1,335.09 5,947,026.96 315,742.00 1.93 -1,250.93 MWD+IFR-AK-CAZSC(3) 4,257.50 52.83 326.78 3,512.79 3,42365 1,520.03 -1,377.72 5,947,089.87 315,700.88 249 -1,306D6 MWD+IFR-AK-CAZ-SC(3) 4.352.09 54.04 328.49 3,569.15 3480.01 1,584.20 -1,41838 5947,15501 315,661.80 1.94 -1,36371 MWD+IFR-AK-CAZ-SC(3) 1122018 3:44:44AM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConomPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MT6-06 Project: Western North Slope TVD Reference: ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) Site: GMT1 Lookout Pad MD Reference: ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) Well: MT6-06 North Reference: True Wellbore: MT6-06PB7 Survey Calculation Method: Minimum Curvature Design: R1-wp02 Database: EDT 14 Alaska Production Survey Annotation BA � 11/2/2018 3:44:44AM Page 5 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (°1100') Survey Tool Name (ft) (ft) (ft) 4,447.23 55.31 329.74 3,624.16 3,535.02 1,650.82 -1,458.22 5,947,222.57 315,623.59 1.71 -1423.91 MWD+IFR-AK-CAZ-SC(3) 4,541.54 MAO 332.26 3,676.82 3,587.68 1,719.24 -1,496.13 5,947,291.89 315,587.36 2.72 -1,486.17 MWD+IFR-AK-CA7-SC(3) 4,635.37 57.50 334.69 3,727.73 3,638.59 1,789.77 -1,531.32 5,947,36324 315,553.89 2.30 -1,550.89 MWD+IFR-AK-CAZSC(3) 4,728.10 57.45 337,51 3,777.59 3,688.45 1,86124 -1,562.99 5,947,435.45 315,523.97 2.56 -1,617:08 MWD+IFR-AK-CAZSC(3) 4,822.50 57.54 338.55 3,828.32 3,739.18 1,935.07 -1,592.77 5,947, We 98 315,495.99 0.93 -1,685.84 MWD+IFR-AK-CAZSC(3) 4,91698 57.89 338.11 3,878.79 3,789.65 2,009.29 -1,622.27 5,947,584.90 315,468.31 0.54 -1755.06 MWD+1FR-AK-CAZSC(3) 5,011.33 57.91 338.10 3,928.92 3,839.78 2,083.45 -1,652.07 5,947,65976 315,440.31 0.02 -1,824.16 MWD+IFR-AK-CAZSC(3) 5,102.99 57.86 337.95 3,977.65 3,888.51 2,155.45 -1,681.13 5,947,732.43 315,413.02 0.15 -1,891.22 MWD+IFR-AK-CAZSC(3) 5,196.00 57.86 337.17 4,027.13 3,93299 2,228.24 -1,711.19 5,947,805.93 315,384.74 0.71 -1,958.94 MWD+1FR-AK-CAZSC(3) 5,291.12 58.00 336.35 4,07764 3,988.50 2,302.30 -1,742.99 5,947,880.74 315,354.74 0.75 -2,02265 MWD+IFR-AK-CAZSC(3) 5,389.57 57.89 335.64 4,129.89 4,04075 2,378.82 -1,776.27 5.947,958.04 315,323.33 0.27 -2,038.59 MWD+IFR-AK-CAZSC(3) 5,485]5 57,88 33616 4,181.02 4,091.88 2,453.47 -1,808.88 5,948,03345 315,292.55 0.42 -2,167.77 MWD+IFR-AK-CAZSC(3) 5,579.78 57,83 335.29 4,231.05 4,141.91 2,526.04 -1,84162 5,948,10679 315,261.59 0.79 -2,234.88 MWD+IFR-AK-CAZSC(3) 5,675.14 57.85 334.31 4,281.81 4,19267 2,599.09 -1,875.99 5.948,180.65 315,229.00 0.87 -2,302.22 MWD+IFR-AK-CAZ-SC(3) 5,768.46 57.84 334.17 4,33148 4,242.34 2,670.24 -1,910.32 5,948,252.61 315,196.41 0.13 -2,367.70 MWD+IFR-AK-CAZ-SC(3) 5,863.69 57.87 333.52 4,382.14 4,293.00 2,742.62 -1,945.87 5,946325.82 315,162.64 0.58 -2,434.21 MWD+IFR-AK-CAZSC(3) 5,957.26 57.89 333.65 4,431.90 4,342.76 2,813.59 -1,981.12 5,948,397.63 315,129.12 0.12 -2,499.37 MWD+IFR-AK-CAZSC(3) 6,052.55 57.85 334.38 4,482.58 4,39344 2,886.13 -2,016.48 5,948,47100 315,095.54 0.65 -2,566.07 MWD+IFR-AK-CAZSC(3) 6,146.20 57.77 335.63 4,532.47 4,443.33 2,957,96 -2,049.96 5,948,543.61 315,063.81 1.13 -2,632.34 MWD+IFR-AK-CAZSC(3) 6,240.93 57.85 336.41 4,582.93 4,49379 3,031.21 -2,082.54 5,948,617.63 315,033.02 0.70 -2,700.14 MWD+IFR-AK-CAZSC(3) 6,334.86 57.82 337.09 4,632.94 4,543.80 3,104.26 -2,113.93 5,948,69142 315,003.41 0.61 -2,76792 MWD+IFR-AK-CAZSC(3) 6,429.32 57.88 336.32 4,683.20 4,594.06 3,17772 -2,145.56 5,948,765.62 314,973.58 0.69 -2,836.06 MWD+1FR-AK-CAZ-SC(3) 6,523.30 57.86 335.21 4,733.19 4,64405 3,250.29 -2,178.23 5,948,838.96 314,942.69 1.00 -2,903.18 MWD+IFR-AK-CAZSC(3) 6,617.60 57.82 335.23 4,783.38 4,694.24 3,322.77 -2,211.69 5,948,912.22 314,911.00 0.05 -2,970.09 MWD+IFR-AK-CAZ-$C(3) 6,711.36 57.86 33564 4,833.29 4,744.15 3,394.96 -2,244.68 5,948,985.19 314,87977 0.37 -3,036.78 MWD+IFR-AK-CAZ-SC(3) 6,806.08 57.79 334.20 4,883.73 4,794.59 3,467.57 -2,27867 5,949,058.60 314,84255 1.29 -3,103.75 MWD+IFR-AK-CAZ-SC(3) 6,901.02 57.82 334.62 4,934.31 4,845.17 3,540.03 -2,313.37 5,949,13108 314,814.63 0.38 -3,170.47 MWD+IFR-AK-CAZ-SC(3) 6,992.85 57.86 334.25 4,983.19 4,894.05 3,610.16 -2,346.92 5,949,202.80 314,782.80 0.34 -3,235.04 MWD+IFR-AK-CAZ-SC (3) 7,087.15 57.85 334.38 5,033.37 4,944.23 3,682.11 -2,381.52 5,949,27556 314,749.95 0.12 -3,301.27 MWD+IFR-AK-CAZ-SC(3) 7,180.14 57.66 333.66 5,082.98 4,993.84 3,752.81 -2,41597 5,949,347.08 314,717.23 069 -3,366.28 MWD+IFR-AK-CAZ-SC(3) 7,274.18 57.64 33370 5,133.30 5,044.16 3,82402 -2.45120 5,949,419.12 314,683.75 0.04 -3,431.68 MW0+1FR-AK-CAZ-SC(3) Annotation BA � 11/2/2018 3:44:44AM Page 5 COMPASS 5000.14 Build 85D ConocoPhillips BA ER lEsusConocoPhilli s Definitive Survey Report Company: ConccoPhillips(Alaska) Inc.-WNS Project: Western North Slope Site: GMT1 Lookout Pad Well: MT6-06 Wellbore: MT6-06PB1 Design: B1-wp02 Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MT6-06 ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) True Minimum Curvature EDT 14 Alaska Production 11/2/2018 3: 44:44AM Page 6 COMPASS 5000.14 Build 850 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W DLS (usft) (') V) (usft) (usft) (usft) (usft) Northing Easting ("1100') Section Survey Tool Name Annotation (ft) (S) (ft) 7,368.69 5768 334.04 5,183.03 5,094.69 3,895.67 -2,486.35 5,949,49160 314,650.35 0.31 -3,497.53 MWD+IFR-AK-CAZ-SC (3) 7,463.29 5763 334.71 5,234.47 5,145.33 3,967]] -2,52093 5,949,564.51 314,617.54 0.60 -3,553.91 MWD+IFR-AK-CAZ-SC(3) 7,556.76 57.63 336.04 5,284.52 5,19638 4,039.54 -2,553.82 5,949,637.04 314,586.40 1.20 -3,630.19 MWD+IFR-AK-CAZSC(3) 7,651.69 57.70 336.44 5,335.29 5,246.15 4,112.95 -2,586.14 5,949,711.21 314,555.87 0.36 3,698.19 MWD+1FR-AK-CAZSC(3) 7,745.90 57.69 33606 5,385.64 5,296.50 4,165.83 -2,618.21 5,949,784.85 314,525.59 0.34 -3,765.71 MWD+IFR-AK-CAZSC(3) 7,840.35 57.66 335.70 5,436.14 5,347.00 4,258.68 -2,650.83 5,949,85846 314,494.75 0.32 -3,833.10 MWD+IFR-AK-CAZSC(3) 7,933.78 57.67 335.72 5,486.12 5,396.98 4,33063 -2,683.30 5,949,931.18 314,464.04 0.02 -3,899.64 MWD+IFR-AK-CAZSC(3) 8,027.98 55.41 334.12 5,538.05 5,448.91 4,401.81 -2,716.59 5,950,003.14 314,432.48 2.79 -3,965.28 MWD+IFR-AK-CAZ-SC(3) 8,122.75 51.95 330.23 5,594.19 5,505.05 4,469.33 -2,752.17 5,950,07150 314,398.56 4.93 4.026.99 MWD+IFR-AK-CAZ-SC(3) 8,21645 51.90 326.83 5,651.99 5,562.85 4,532.23 -2,790.66 5,950,135.31 314,361.61 2.86 4083.69 MWD+IFR-AK-CAZ-SC(3) 8,311.41 50.31 323.82 5,711.62 5,622.48 4,593.00 -2,832.68 5,950,197.09 314,321.08 2.98 4,137.80 MWD+IFR-AK-CAZ-SC (3) 8,403.52 48.25 32241 5,771.70 5,682.56 4,648.84 -2,874.57 5,950,253.93 314,250.56 2.52 4187.03 MWD+IFR-AK-CAZ-SC(3) 8,498.40 46.08 32067 5,836.21 5,747.07 4,703.33 -2,917.82 5,950,309.44 314,236.65 2.65 4,234.73 MWD+IFR-AK-CAZSC(3) 8,592.77 43.92 317.91 5,902.94 5,813.80 4,753.92 -2,961.31 5,950,361.07 314,196.40 3.08 4,278.54 MWD+IFR-AK-CAZSC(3) 8,685.17 42.19 313.75 5,970.47 5,881.33 4,799.17 3,005.22 5,950,407.37 314,153.61 3.60 4,317.00 MWD+IFR-AK-CAZSC(3) 8,779.40 40.80 309.43 6,041.06 5,951.92 4,840.61 3,051.87 5,950,449.93 314,107.99 3.38 4,351.30 MWD+IFR-AK-CAZSC(3) 8,873.97 39.03 304.15 6,11362 6,024.48 4,876.97 -3,100.39 5,950,487.45 314,060.36 4.04 >,380.30 MWD+IFR-AK-CAZSC(3) 8,968.83 37.86 299.42 6,187.93 6,098.79 4,908.04 3,150.48 5,950,519.73 314,011.05 3.34 4403.84 MWD+IFR-AK-CAZSC(3) 9,063.42 37.07 294.47 6,263.02 6,173.88 4,934.11 3,201.72 5,950,54704 313,96046 329 4,422.28 MWD+IFR-AK-CAZSC(3) 9,15747 35.91 287.83 6,338.66 6,249.52 4,954.31 3,253.80 5,950,56849 313,908.89 4.37 4,434.77 MWD+IFR-AK-CAZ-SC(3) 9,252.10 35.58 279.91 6,415.51 6,326.37 4,967.55 3,307.37 5,950,583.03 313,855.66 4.90 4,440.17 MWD+IFR-AK-CAZ-SC (3) 9,345.12 35.96 274.19 6,491.00 6,401.68 4,974.21 3,36128 5,950,590.99 313,801.93 3.62 4,439.00 MWD+IFR-AK-CAZ-SC (3) 9,439.97 35.94 269.47 6,567.80 6,478.66 4,975.98 3,416.90 5,950,594.12 313,746.37 2.92 4,432.76 MWD+IFR-AK-CAZ-SC(3) 9,533.07 35.93 264.10 6,643.20 6,554.06 4,97292 3,471.40 5,950,592.39 313,691.81 3.38 -0,421.89 MWD+IFR-AK-CAZ-SC(3) 9,627.60 35.94 25929 6,719.76 6,630.62 4,964.91 3,526.26 5,950,585.71 313,636.78 2.99 440608 MWDHFR-AK-CAZSC(3) 9,722.00 37.03 25302 6,79568 6,706.54 4,951.46 3,580.69 5,950,573.58 313,582.05 4.11 4,384.93 MWD+IFR-AK-CAZSC(3) 9,815.57 38.18 246.93 6,869.84 6,780.70 4,931.89 -3,634.26 5,950,555.32 313,528.02 4.16 4,357.86 MWD+IFR-AK-CAZ-SC(3) 9,909.91 38.92 241.21 6,943.64 6,854.50 4,906.19 -3,687.08 5,950,53091 313,474.60 3.86 4,324.83 MWD+IFR-AK-CAZSC(3) 10,005.11 40.18 23708 7,017.06 6,927.92 4,875.09 -3,739.08 5,950,501.09 313,421.86 3.06 4,286.57 MWD+IFR-AK-CAZSC(3) 10,09983 41.91 23138 7,088.52 6999.38 4,838.72 -3,789.47 5,950,465.96 313,370.61 435 -4,243.33 MWD+IFR-AK-CAZSC(3) 10,193.87 4350 227.39 7,157.63 706649 4,797.19 -3837.84 5950,42562 313,321.24 334 -4,19528 MWD+IFR-AK-CAZ-SC(3) 11/2/2018 3: 44:44AM Page 6 COMPASS 5000.14 Build 850 ConocoPhilli s p ConocoPhillips Definitive Survey Report BA ER ,.�., Company: ConocoPhillips(Alaska) Inc -WNS Local Co-ordinate Reference: Well MT6-06 Project: Western North Slope TVD Reference: ACTUAL MT6-06 @ 89.14usft (Actual Doyon19) »..®_„ ---------- .., Site: GMT1 Lookout Pad MD Reference: ACTUAL MT6-06 @ 89.14usft (Actual Doyon19) N Well: MT6-06 North Reference: True Map Wellbore: MT6-06PB1 Survey Calculation Method: Minimum Curvature Design: B1-wp02 Database: EDT 14 Alaska Production (usft) Survey »..®_„ ---------- .., MD Inc Azi N TVDSS +N/ -S +E/ -W Map Map DLS VerticalD (usft) (1) V) (usft) (usft) (usft) (usft) Northing Easting (° (°/100') Section Survey Survey Tool Name Annotation Iftl 181 10,285.85 4490 22452 7,22358 7,134.44 4,752.61 -3,883.90 5,950,382.17 313,274.11 2.65 4,144.53 MWD+IFR-AK-CAZSC(3) 10,316.00 44.94 223.94 7,244.93 7,155.79 4,737.35 5,898.75 5,950,367.28 313,258.89 1.37 4,127.30 MWD+IFR-AK-CAZSC(4) 9-5/8"x12-1/4" 10,371.52 45.02 222.87 7,284.20 7,195.06 4,708.84 -3,925.72 5,950,339.43 313,231.25 1.37 4.095.21 MWD+IFR-AK-CAZSC(4) 10,464.34 46.95 219.86 7,348.70 7,259.56 4,658.74 5,96980 5,950,290.42 313,185.96 3.12 4,039.29 MWD+IFR-AK-CAZ-SC(4) i 10,55020 5065 215.94 7,41185 7,322.71 4,601.81 4.014.03 5,950,23459 313,140.37 4.93 -3,976.59 MWD+IFR-AK-CA7-SC(4) {) 10,655.11 53.73 212.45 7,470.04 7,380.90 4,539.79 -0,056.11 5,950,173.61 313,096.79 4.35 -3,909.16 MWD+IFR-AK-CAZ-SC (4) SE 10,750.61 56.29 209.17 7,524.80 7,435.66 4,472.60 -0,096.14 5,950,107.41 313,055.14 3.89 -3,836.90 MWD+IFR-AK-CAZSC(4) 10,844.73 5892 206.94 7,575.23 7,48689 4,402.46 4,133.49 5,950,038.21 313,016.10 3.44 5,762.13 MWD+IFR-AK-CAZSC(4) 10,93899 61.56 205.80 7,622.01 7,532.87 4,329.15 4,169.83 5,949,965.81 312,978.00 2.99 5,684.36 MWD+IFR.AK-CAZSC(4) 11,032.00 63.74 203.81 7.664,75 7,575.61 4,254.17 4,204.47 5,949,891.69 312,941.55 3.02 -3,605.17 MWD+IFR-AK-CAZ-SC(4) 11,125.52 64.76 202.54 7,705.38 7,616.24 4,176.73 4.237.61 5,949,815.09 312,906.54 1.64 -3,523.77 MWD+IFR-AK-CAZ.SC(4) 11219.37 64.74 20173 7,745.41 7,656.27 4,098.11 4,269.59 5,949,737.27 312,872.66 0.78 -3,441.36 MWD+IFR-AK-CAZ-SC(4) 11,312.00 64.69 201.24 7,784.97 7,695.83 4,020.17 4,300.27 5,949,660.11 312,840.10 0.48 -3,359.82 MWD+IFR-AK-CAZSC(4) 11,40662 65.03 200.35 7,825.17 7,736.03 3,94089 4,330.68 5,949,58080 312,807.76 0.92 5,276.21 MWD+IFR-AK-CAZ-SC(4) 11,501.01 65.63 195.83 7,864.59 7,775.45 3,858.59 -0,357.30 5,949,499.96 312,779.17 440 -3,191.72 MWD+IFR-AK-CAZ-SC(4) 11,594.48 67.51 190.74 7,901.77 7,812.63 3,775.15 4.376.97 5,949,417,04 312,757.48 5.39 -3,106.32 MWD+IFR-AK-CAZSC(4) 11,669.55 69.54 186.51 7,936.59 7,847.45 3,687.71 4,390.21 5,949,329.95 312,742.12 4.66 -3,017.88 MWD+IFR-AK-CAZSC(4) I 11,785.07 71.87 183.88 7,968.15 7,879.01 3,597.94 4,398.36 5,949,240.41 312,731.80 3.56 -2,927.87 MWD+IFR-AK-CAZSC(4) 11,879.62 74.35 180.62 7,995.63 7,906.49 3,507.56 4,401.89 5,949,150.14 312,726.07 4.21 -2,837.92 MWD+IFR-AK-CAZSC(4) 11,894.64 74.79 180.60 7,999.63 7,910.49 3,493.08 4,402.04 5,949,135.67 312,725.56 2.93 -2,823.57 MWD+IFR-AK-CA7-SC(5) 11,991.52 79.91 179.35 8,020.84 7,931.70 3,398.58 4.401.99 5,949,041.21 312,723.32 5.43 -2,730.07 I( MWD+IFR-AK-CAZ-SC (5) 12,086.64 84.75 177.97 8,033.53 7,944.39 3,304.37 4,399.78 5,948,946.98 312,723.24 5.29 -2,637.15 MWD+IFR-AK-CAZ-SC(5) 12,181.55 88.00 175.98 8,039.53 7,950.39 3,209.80 4,394.78 5,948,852.32 312,725.94 4.01 -2,544.29 MWD+1FR-AK-CAZSC(5) 12,276.51 89.07 173.08 8,041.96 7,952.82 3,115.32 -0,385.73 5,948,757.65 312,732.69 3.25 -2,45209 MWD+IFR-AK-CAZSC(5) 12,371.59 89.40 169.92 8,043.23 7,954.09 3,021.30 4,371.68 5,946,663.33 312,744.45 3.34 -2,361.07 MWD+IFR.AK-CAZSC(5) 12,467.18 87.92 165.14 8,045.46 7,956.32 2,928.02 4,351.06 5,948,56958 312,762.81 5.23 -2,271.73 MWD+IFR-AK-CAZ-SC(5) 12,561.50 87.00 162.21 8,049.64 7,960.50 2,837.60 4,324.57 5,948,478.55 312,787.08 3.25 -2,186.05 MWD+IFR-AK-CAZ-SC (5) 12,651.21 85.95 158.71 8,055.16 7,966.02 2,753.23 4,294.63 5,948,393.48 312,814.97 4.07 -2,106.87 MWD+IFR-AK-CAZ-SC(5) S 12,687.21 85.95 158.71 8,057.70 7,968.56 2,719.77 -0,281.59 5,948,359.72 312,827.19 0.00 -2,075.64 PROJECTED to TO ) 11/2/2018 3:44:44AM Page 7 COMPASS 5000.14 Build 85D EA SER UGHES aGEcompany 1191 21 8093 30079 Letter of Transmittal Date: — - -- --------- December 6, 2018 Abby Bell AOGCC 333 West 7" Ave, Suite 100 Anchorage, Alaska 99501 Michael Soper Baker Hughes, a GE Company 795 East 94`^ Avenue Anchorage, Alaska 99515 lease find enclosed the directional survey data for the following well(s): MT6-06PB1 MT6-06PB2 MT6-06 �E(';evEO ID p ? 7V ®GCC (3) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Applications Engineer Michael.Soper@BakerHuehes.com ConocoPhillips ConocoPhillips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-06PB2 50-103-20773-71 Baker Hughes I NTEQ Definitive Survey Report 02 November, 2018 BA <ER I�UGHES a GE company 21 8093 30079 ✓ Conoco Phillips ConocoPhillips Definitive Survey Report 'I Company: ConomPhllllps(Alaska) Inc. -NMS Local Co-ordinate Reference: '.. Project: Western North Slope TVD Reference: '. Site: GMT1 Lookout Pad MD Reference: Well: MT6-06 North Reference: Wellbore: MT6-06PB2 Survey Calculation Method: Design: B1-wp02 Database: Project Western North Slope, North Slope Alaska, United States 8/9/2018 Map System: US State Plane 1927 (Exact solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Phase: ACTUAL Well MT6-06 Depth From Well Position -NI-S 0.00 usft Northing: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore MT6-06PB2 Magnetics Model Name Sample Date (TVD) (usft) 0.00 Well MT6-06 ACTUAL MTB -06 @ 89.14usft (Actual Doyonl9) ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using geodetic scale factor 5,945,536.92usft 317,041.1 gusft 0.00 usft Declination (°1 16.45 Toe On Depth: 11,785.07 +N/ -S (usft) 0.00 +El -W (usft) 0.00 Latitude: Longitude: Ground Level: BA ER UGNES 70' 15'22.892 N 151' 28'43.472 W i i 37.20 usft Dip Angle Field Strength (I (nT) 80.70 57,397 I Direction 188.27 11/2/2018 3:46:36AM Page 2 COMPASS 5000,14 Builtl850 BGGM2018 8/9/2018 Design MT6-06PB2 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) (usft) 0.00 Well MT6-06 ACTUAL MTB -06 @ 89.14usft (Actual Doyonl9) ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using geodetic scale factor 5,945,536.92usft 317,041.1 gusft 0.00 usft Declination (°1 16.45 Toe On Depth: 11,785.07 +N/ -S (usft) 0.00 +El -W (usft) 0.00 Latitude: Longitude: Ground Level: BA ER UGNES 70' 15'22.892 N 151' 28'43.472 W i i 37.20 usft Dip Angle Field Strength (I (nT) 80.70 57,397 I Direction 188.27 11/2/2018 3:46:36AM Page 2 COMPASS 5000,14 Builtl850 ConocoPhillips Company: ConowPhillips(Alaska) Inc.-WNS Project: Western North Slope Site: GMT1 Lookout Pad Well: MT6-06 Wellbore: MT6-06PB2 Design: B1-wp02 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MT6-06 ACTUAL MT6-06 @ 89.14usft (Actual Doyon19) ACTUAL MT6-06 @ 89.14usft (Actual Doyon19) True Minimum Curvature EDT 14 Alaska Production BA�WlffS Survey Program Date From To Vertical Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description SWR Date End Date 115.00 1,021.00 Gyrodata GyroSS 16" (MT6-06PB1) GYD-CT-DMS Gyrodata cont.drillpipe m/s 9/10/2018 9/10/2018 1,106.74 2,063.83 BHGE MWD+SAG+IFR+MSA16"(MT6-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/11/2018 9/12/2018 2,160.89 10,285.85 BHGE MWD+SAG+IFR+MSA 121/4"(M MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/15/2018 9/17/2016 10,371.52 11,785.07 BHGE MWD+SAG+IFR+MSA WNW' (M MWD-IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 9/26/2018 9/28/2018 11,842.00 16,752.22 BHGE MWD+IFR+MSA6"(MT6-06PB2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/10/2018 10/12/2018 Survey IT 11/2/2018 3:46:36AM Page 3 COMPASS 5000.14 Build 850 Map Map Vertical MD Inc Azi TVD NDSS +N/S +E1 -W Northing Easting OLS Section (uaft) (°) (°) (usft) (usft) (usft) (usft) ('M00•) Survey Tool Name (ft) (ft) (ft) 36.94 0.00 0.00 36.94 -52.20 0.00 0.00 5,945,53692 317,041.19 0.00 0.00 UNDEFINED 115.00 0.51 167.22 115.00 25.86 -0.34 0.08 5,945,536.58 317,041.26 0.65 0.32 GYD-CT-DMS(1) 20500 0.76 167.84 204.99 115.85 -1.31 0.29 5,945,535.60 317,041.45 0.28 1.26 GYD-CT-DMS(1) 300.00 0,66 205.24 299.99 210.85 -2.42 0.18 5,945534.50 317,041.32 0.50 2.37 GYD-CT-DMS(1) 361.00 0.70 247.51 360.98 271.84 -288 -0.32 5,945,534.05 317,040.81 0.79 2.89 GYD-CT-DMS(1) 455.00 1.60 29897 454.96 365.82 -2.46 -2.00 5,945,534.51 317,039.14 1.37 2.72 GYD-CT-DMS(1) 550.00 379 309.88 54985 460.71 0.19 -5.57 5,945,537.25 317,035.63 2.36 0.61 GYD-CT-DMS(1) 645.00 6.03 311.84 644.50 555.36 5.54 -11.69 5,945,542.74 317,029.64 2.36 -3.80 GYD-CT-DMS(1) 738.00 8.81 311.77 736.71 647.57 13.54 -20.65 5,945,550.95 317,020.88 2.99 -10.43 GYD-CT-DMS(1) 832.00 11.03 312.24 829.30 740.16 24.38 -32.67 5,945562.09 317,009.12 2.36 -1943 GYD-CT-DMS(1) 926.0 12.93 312.92 921.25 832.11 3759 47.03 5,945,575.64 316,995.09 2.03 -30.43 GYD-CT-DMS(1) 1,021.00 1501 313.60 1,013.43 924.29 53.31 53.73 5,945591.76 316,978.78 2.20 43.59 GYD-CT-DMS(1) 1,106.74 17.20 314A2 1,095.80 1,006.66 69.80 50.87 5,945608.66 316,962.05 2.56 -57.44 MWD+IFR-AK-CAZSC(2) 1,149.72 18.70 316.17 1,136.69 1,047.55 79.19 -90.21 5,945,618.28 316,952.94 3.79 55.39 MWD-IFR-AK-CAZ-SC (2) 1,244.34 20.79 316.64 122574 1,136.60 102.35 -112.24 5,945,64196 316,93148 222 55.14 MWD+IFR-AK-CAZ-SC(2) 1,337.61 22.41 317.98 1,31246 1,223.32 127.59 -135.51 5,945,667.76 316,908.83 1.82 -106.77 MWD+IFR-AK-CAZSC(2) 1,432.48 23.36 318.88 1,399.86 1,310.72 155.20 -159.98 5,945,695.95 316,885.04 1.07 AK57 MWD+IFR-AK-CAZSC(2) 1,526.98 24.13 315.69 1.486.37 1,397.23 183.13 -185.80 5,945,724.50 316,859.91 1.58 -154.50 MWD+IFR-AK-CAZ-SC(2) 1,621.89 25.74 314.42 1,572.43 1,483.29 21144 -21407 5,945,753.49 316,832.33 179 -178.45 MWD+1FR-AK-CAZ-SC(2) IT 11/2/2018 3:46:36AM Page 3 COMPASS 5000.14 Build 850 ConocoPhillips�� Conoco Phillips Definitive Survey Report Company: Con=Phillips(Alaska) Inc. -NMS Project: Western North Slope Site: GMT1 Lookout Pad Well: MT6-06 Wellbore: MT6.06P82 Design: B1-wp02 Survey Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MT6-06 ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) True Minimum Curvature ,EDT 14 Alaska Production 11/2/2018 3:46:36AM Page 4 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi ND NOSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (1) V) (usft) (usft) (usft) (usft) ('1100') Survey Too[Name Annotation (ft) (ft) (ft) 1716.26 27.14 31461 1,656.92 1,56778 240.90 -244.03 5,945 783.66 316,803.10 1.49 -20329 MWD+1FR-AK-CAZSC(2) 1,809.69 29.23 314.56 1739.27 1,650.13 271.88 -275.46 5,995,815.39 316,772.43 2.24 -229.43 MWD+IFR-AK-CAZSC(2) 1,903.55 3026 314.04 1,820.77 1,731.63 304.40 -308.79 5,945,848.71 316,739.90 1.13 -256.82 MWD+IFR-AK-CAZ-SC(2) 1,99277 31.40 315.37 1,901.67 1,812.53 338.37 343.10 5,945,883.50 316,706.43 1.41 -285.50 MWD+IFR-AK-CAZ-SC (2) 2,053.83 32.48 315.15 1,957.73 1,868.59 363.19 -36770 5,945,90891 316,682.44 1.64 -306.53 MWD+IFR-AK-CAZ-SC(2) 2,118.58 33.38 315.18 2,003.68 1,914.54 384.30 -388.68 5,945,93052 316,661.98 1.64 -324.39 MWD+IFR-AK-CA7-SC (3) 13-3/8" x 16" 2,160.89 34.07 315.20 2,038.87 194913 400.96 -005.24 5.945,94758 316,645.84 164 338.50 MWD+IFR-AK-CAZSC(3) 2,183.49 34.36 315.10 2,057.56 1,968.42 409.97 414.20 5,945,956.81 316,637.10 1.31 -346.13 MWD+IFR-AK-CAZSC(3) 2,277.93 36.43 31627 2,134.54 2,045.40 449.11 452.40 5,945,996.86 316,593.86 2.31 379.37 MWD+IFR-AK-CAZSC(3) 2,371.41 38.75 316.7 2,208.61 2,11947 490.56 491.56 5,946,039.25 316,561]3 2.52 414.76 MWD+11FR-AK-CAZ-SC(3) 2,465.52 40.55 317.72 2,281.07 2,191.93 534.73 -532.24 5,946,084.39 316,522.13 1.98 452.61 MWD+IFR-AK-CAZ-SC (3) 2,55945 42.05 318.30 2,351.63 2,262.49 580.81 -57371 5,946,131.46 316,481.80 1.65 492.25 MWD+1FR-AK-CAZ-SC(3) 2,654.14 44.08 318.95 2,42061 2,331.67 629.33 -616.44 5,946,181.00 316,440.26 2.19 534.12 MWD+IFR-AK-CA2SC(3) 2,748.39 45.85 318.24 2,48749 2,39835 679.28 -660.49 5,946,232.00 316,397.44 1.95 577.21 MWD+IFR-AK-CAZ-SC(3) 2,842.58 45.83 318.00 2,553.11 2,463.97 729.59 -705.60 5,946,283.39 316,353.57 0.18 520.51 MWD+IFR-AK-CAZSC(3) 2,936.53 45.83 318.11 2,618.57 2,529.43 779.71 -750.64 5,946,334.59 316,309.76 0.08 -663.63 MWD+IFR-AK-CAZSC(3) 3,031.20 45.85 318.43 2,684.53 2,595.39 830.40 -795.85 5,946,386.35 316,265.80 0.24 -707.29 MWD+IFR-AK-CAZ-SC(3) 3,124.70 45.88 318.41 2,749.64 2,660.W 88059 -840.38 5,946,437.61 316,222.50 0.04 -750.56 MWD+IFR-AK-CAZ-SC(3) 3,219.39 45.88 317.92 2,815.56 2,726.42 931.24 -88572 5,946,489.34 316,178.40 0.37 -794.16 MW0+1FR-AK-CAZ-SC(3) 3,313.34 45.89 318.03 2,880.96 2,791.82 981.35 -93088 5,948,540.53 316,134.48 0.08 -837.25 MWD+iFR-AK-CAZ-SC(3) 3,407.16 45.86 318.19 2,94628 2,85714 1,03148 -975.85 5,946,591.74 316,090.75 0.13 -880.39 MWD+IFR-AK-CA7-SC(3) 3,501.46 45.86 318.44 3,011.95 2,922.81 1,082.02 -1,020.85 5,946,643.35 316,046.99 0.19 -923.93 MWD+IFR-AK-CAZSC(3) 3,595.88 45.84 31814 3,07771 2,988.57 1,132.59 -1,065.93 5,946,695.00 316,003.15 0.23 -%7.50 MWD+IFR-AK-CAZSC(3) 3,690.61 46.07 318.53 3,143.57 3,054.43 1,183.46 -1,111.19 5,945746.95 315,959.14 0.38 -1,011.32 MWD+IFR-AK-CAZSC(3) 3,78420 46.91 318.75 3,208.01 3,118.87 1,234.41 -1,155.04 5,946,798.97 315,915.54 0.91 -1,055.29 MWD+IFR-AK-CAZ-SC(3) 3,878.79 48.08 320.20 3,271.92 3,182.78 1,28742 -1,201.35 5,946,853.06 315,871.55 1.68 -1,101.23 MWD+IFR-AK-CAZ-SC(3) 3,973.00 48.97 321.36 3,334.31 3,245.17 1,342.10 -1,245.97 5,946,908.81 315,828.26 132 -1,148.93 MWD+IFR-AK-CAZSC(3) 4,068.00 5072 322.20 3,395.57 3,306.43 1,399.15 -1,290.89 5,946,966.92 315,784.75 1.96 -1,198.92 MWD+1FR-AK-CAZSC(3) 4,162.51 51.80 324.09 3,454.72 3,365.58 1.458.13 -1,335.09 5,947,026.96 315,742.00 1.93 -1,250.93 MWD+IFR-AK-CAZSC(3) 4,257.50 52.83 326.78 3,512.79 3,42385 1520.03 -1,377.72 5,947,089.87 315,700.88 2.49 -1,306.06 MWD+IFR-AK-CAZ-SC(3) 4,352.09 54.04 328.49 3.569.15 3,480.01 1584.20 -1,418.38 5,947,155.01 315,661.80 1.94 -1,363.71 MWD+IFR-AK-CAZ-SC(3) 11/2/2018 3:46:36AM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips BAUGRES 0 ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc.-WNS Local Co-ordinate Reference:Well MT6-06 Project: Western North Slope ND Reference: ACTUAL MT6-06 @ 89.14usfl (Actual Doyonl9) Site: GMT1 Lookout Pad MD Reference: ACTUAL MT6-06 @ 89.14usft (Actual Doyon19) Well: MT6-06 North Reference: True Wellbore: MT6-06PB2 Survey Calculation Method: Minimum Curvature Design: B1-wp02 Database: EDT 14 Alaska Production Survey (°) (°) (usft) 11/22018 3:46:36AM Page 5 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi ND NDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (°1100') Survey Tool Name Annotation (ft) (ft) (ft) 4,49723 55.31 329.74 3,624.16 3,535.02 1,65082 -1,458.22 5,947,222.57 315,62359 1.71 -1,423.91 MWD+IFR-AK-CAZ-SC(3) 4,541.54 56.80 332.26 3,676.82 3,587.68 1,719.24 -1,496.13 5,947,291.89 315,587.36 2.72 -1,486.17 MWD+IFR-AK-CAZ-SC (3) 4,635.37 57.50 334.69 3,727.73 3,638.59 1,789.77 -1,531.32 5,947,363.24 315,55389 2.30 -1,550.89 MWD+IFR-AK-CAZ-SC(3) 4,728.10 57.45 337.51 3,777.59 3,688.45 1,861.24 -1,562.99 5,947,43546 315,523.97 2.56 -1,617.06 MWD+IFR-AK-CAZSC(3) 4,822.50 57.54 338.55 3,828.32 3,739.18 1,935.07 -1,592.77 5,947,509.98 315,495.99 0.93 -1,655.84 MWD+IFR-AK-CAZ-SC(3) 4,916.98 57.89 338.11 3,878.79 3,789.65 2,009.29 -1,62227 5,947,584.90 315,468.31 0.54 -1,755.06 MWD+IFR-AK-CAZSC(3) 5,011.33 57.91 338.10 3,928.92 3,839.78 2,083.45 -1,652.07 5,947,659.76 315,440.31 0.02 -1,824.16 MWD+IFR-AK-CAZSC(3) 5,102.99 57.86 337.95 3,977.65 3,888.51 2,155.45 -1,681.13 5,907732.43 315,413.02 0.15 -1,891.22 MWD+IFR-AK-CAZSC(3) 5,196.00 57.86 337.17 4,027.13 3,937.99 2,228.24 -1,711.19 5,947,805.93 315,384.74 0.71 -1,958.94 MWD+IFR-AK-CAZSC(3) 5,291.12 58.00 336.35 4,077.64 3,988.50 2,302.30 -1,742.99 5,947,880.74 315,354.74 0.75 -2,027.65 MWD+IFR-AK-CAZSC(3) 5,389.57 57.89 336.64 4,129.89 4,040.75 2,378.82 -1,776.27 5,947,958.04 315,323.33 027 -2,098.59 MWD+IFR-AK-CAZSC(3) 5,485.75 57.88 336.16 4,181.02 4,091.88 2,453.47 -1,808.88 5,948,033.45 315,292.55 0.42 -2,167.77 MWD+IFR-AK-CAZSC(3) 5,579.78 57.83 33529 4,231.05 4,141.91 2,526.04 -1,841.62 5,948,106,79 315,261.59 0.79 -2,234.88 MWD+IFR-AK-CAZSC(3) 5,675.14 57.85 334.31 4,281.81 4,19267 2,599.09 -1,875.99 5,948,180.65 315,229.00 0.87 -2,302.22 MWD+IFR-AK-CAZSC(3) 5,768.46 57.84 334.17 4,331.48 4,242.34 2,670.24 -1,910.32 5,948,252.61 315,196.41 0.13 -2,367.70 MWD+IFR-AK-CAZSC(3) 5,863.69 57.87 333.52 4,382.14 4,293.00 2,742.62 -1,945.87 5,948,325.82 315,162.64 0.58 -2,434.21 MWD+IFR-AK-CAZ-SC(3) 5,957.26 57.89 333.65 4,431.90 4,342.76 2,813.59 -1,981.12 5,948,397,63 315,129.12 0.12 -2,499.37 MWD+IFR-AK-CAZ-SC(3) 6,052.55 57.85 334.38 4,482.58 4,393.44 2,885.13 -2,016.48 5,948,471.00 315,095.54 065 -2,566.07 MWD+IFR-AK-CAZ-SC(3) 6,146.20 5777 335.63 4,532.47 4,443.33 2,957.96 -2,049.96 5,948,54361 315,063.81 1.13 -2,632.34 MWD+IFR-AK-CAZ-SC(3) 6,240.93 57.85 336.41 4,582.93 4,493.79 3,031.21 -2,082.54 5,948,61763 315,033.02 0.70 -2,700.14 MWD+IFR-AK-CAZ-SC(3) 6,334.86 57.82 337.09 4,632.94 4,543.80 3,104.26 -2,113.93 5,948,69142 315,003.41 061 -2,767.92 MWD+IFR-AK-CA7-SC(3) 6,429.32 57.88 336.32 4,683.20 4,594.06 3,177.72 -2,14556 5,948,765.62 314,973.58 0.69 -2,836.06 MWD+IFR-AK-CAZ-SC(3) 6,523.30 57.86 335.21 4,733.19 4,644.05 3,250.29 -2,178.23 5.M,838.96 314,94269 1.00 -2,903.18 MWD+IFR-AK-CAZ-SC(3) 6,617.60 5782 335.23 4,783.38 4,694.24 3,322.77 -2,21169 5,946,912.22 314,911.00 0.05 -2,970.09 MWDNFR-AK-CAZ-SC(3) 6,711.36 5786 335.64 4,833.29 4,744.15 3,394.96 -2,24468 5,948,985.19 314,879.77 0.37 -3,036.78 MWD+IFR-AK-CAZSC(3) 6,806.08 57.79 334.20 4,883.73 4,79459 3,467.57 -227867 5,94905860 314,847.56 1.29 -3,103.75 MWD+IFR-AK-CAZ-SC(3) 6,90102 5782 33462 4,934.31 4,845.17 3,540.03 -2,313.37 5,949,131.88 314,814.63 0.38 -3,170.47 MWD+IFR-AK-CA7-SC(3) 6,992.85 57.86 33425 4,983.19 4,894.05 3,610.16 -2,346.92 5,949,202.80 314,782.80 0.34 -3,235.04 MWD+IFR-AK-CAZ-SC (3) 7,087.15 57.85 334.38 5,033.37 4,944.23 3,682.11 -2,381.52 5,949,275.56 314,749.95 0.12 5,301.27 MWD+IFR-AK-CAZ-SC(3) 7,180.14 5766 33366 5,08298 4,99384 3,75281 -2,41597 5,949,34708 314,71723 069 -3,366.28 MVM+IFR-AK-CAZ-SC(3) 7,274.18 57.64 333.70 5,133.30 5,044.16 3,824.02 -2,451.20 5,949,419.12 314,683.75 0.04 -3,43168 MWD+IFR-AK-CAZ-SC(3) 11/22018 3:46:36AM Page 5 COMPASS 5000.14 Build 85D ConocoPhillips SA ER ConocoPhilli s p Definitive Survey Report rucNs Company: ConowPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: ^Well MTB-06--"�""-_,.._�___._.__ Project: Western North Slope TVD Reference: ACTUAL MT6-06 @ 89.14usft (Actual Doyon19) Site: GMT1 Lookout Pad MD Reference: ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) Well: MT&06 North Reference: True Wellbore: MT6-06PB2 Survey Calculation Method: Minimum Curvature Design: B1-wp02 Database: EDT 14 Alaska Production Survey ° Map Map Vertical MD Inc Azi TVD TVDSS +N4S +El-W Northing Easting DLS Section (usft) (1) (1) (usft) (usft) (usft) (usft) (°/100') Survey Tool Name Annotation (ft) (ft) (ft) 7,368.64 57.68 334.04 5,183.83 5,094.69 3,895.67 -2,486.35 5,949,491.60 314,650.35 0.31 -3,497.53 MWD+IFR-AK-CAZ-SC(3) 7,463.29 57.63 33471 5,234.47 5,145.33 3,967.77 -2,520.93 5,949,564.51 314,617.54 0.60 -3,563.91 MWD+IFR-AK-CAZ-SC (3) 7,556.76 57.63 336.04 5,284.52 5,195.38 4,039.54 -2,553.82 5,949,637,04 314,586.40 1.20 -3,630.19 MWD+IFR-AK-CAZ-SC (3) 7,651.69 57.70 336.44 5,335.29 5,246.15 4,112.95 -2,586.14 5,949,711.21 314,555.87 0.36 -3,698.19 MWD+IFR-AK-CAZ-SC(3) 7,74590 5]69 336.06 5,385.64 5,296.50 4,185.83 -2,618.21 5,949,78485 314,525.59 0.34 -3,765.71 MWD+IFR-AK-CAZ-SC(3) 7,840.35 57.66 335.70 5,436.14 5,347.00 4,258.68 -2,650.83 5,949,858.46 314,494.75 0.32 -3,833.10 MW0+IFR-AK-CAZ-SC(3) 7,933.78 57.67 335.72 5,486.12 5,396.98 4,33063 -2,683.30 5,949.931.18 314,464.04 0.02 -3,899.64 MWD+IFR-AK-CAZ-SC(3) 8,027.98 55.41 334.12 5,538.05 5,448.91 4,401.81 -2,716.59 5,950,003.14 314,43248 2.79 -3,965.28 MWD+IFR-AK-CAZ-SC(3) 8,122.75 51.95 330.23 5,594.19 5,505.05 4,469.33 -2,752.17 5,950,071.50 314,398.56 4.93 4,026.99 MWD+IFR-AK-CAZSC(3) 8,216.45 51.90 326.83 5,651.99 5,562.85 4,532.23 -2,790.66 5,950,135.31 314,36161 2.86 4,083.69 MWD+IFR-AK-CAZSC(3) 8,311.41 50.31 323.82 5,711.62 5,622.48 4,593.00 -2,83268 5,950,197.09 314,321.08 2.98 A137.80 MWD+IFR-AK-CAZSC(3) 8,403.52 48.25 322.41 5,771.70 5,682.56 4,648.84 -2,874.57 5,950,253.93 314,280.56 2.52 4.187.03 MWD+IFR-AK-CAZSC(3) 8,498.40 46.08 $20.67 5,83621 5,74]07 4,703.33 -2,917.82 5,950,309.44 314,238.65 2.65 4,234.73 MWD+IFR-AK-CAZSC(3) 8,592.77 43.92 317.91 5,90294 5,813.80 4,753.92 -2,961.31 5,950,361.07 314,196.40 3.08 4,278.54 MWD+IFR-AK-CAZSC(3) 8,685.17 42.19 313.75 5,970.47 5,881.33 4,799.17 -3,005.22 5,950,407.37 314,153.61 3.60 4,317.00 MWD+1FR-AK-CAZSC(3) 8,779.40 40.80 309.43 6,041.06 5,951.92 4,840.61 -3,051.87 5,950,449.93 314,107.99 3.38 4,351.30 MWD+IFR-AK-CAZSC(3) 8,873.97 39.03 304.15 6,11362 6,02448 4,876.97 -3,100.39 5,950,487.45 314,060.36 4.04 4,380.30 MWD+IFR-AK-CAZSC(3) 8,968.83 37.86 29942 6,187.93 6,098.79 4,908.04 5,150.48 5,950,519.73 314,011.05 3.34 -0,403.84 MWD+IFR-AK-CAZSC(3) 9,063.42 37.07 294.47 6,263.02 6,173.88 4,934.11 5,201.72 5,950,547.04 313,960.46 3.29 -0,422.28 MWD+IFR-AK-CAZ-SC(3) 9,157.47 35.91 287.83 6,338.66 6,249.52 4,954.31 5,253.60 5,950,568.49 313,908.89 4.37 4,434.77 MWD+IFR-AK-CAZSC(3) 9,252.10 35.58 279.91 6,415.51 6,326.37 4,967.55 5,307.37 5,950,583.03 313,855.66 4.90 4,440.17 MWD+IFR-AK-CAZ-SC(3) 9,345.12 35.96 274.19 6,491.00 6,401.86 4,974.21 5,361.28 5,950,590.99 313,801,93 3.62 4,439.00 MWD+IFR-AK-CAZ-SC (3) 9,43997 35.94 26947 6,567,80 6,478.66 4,975.98 5,416.90 5,95.594.12 313,746.37 2.92 4432.76 MWD+IFR-AK-CAZ-SC(3) 9,533.07 35.93 264.10 6,643.20 6,554.06 4,972.92 5,471.40 5,950,59239 313,691.81 3.38 4,421.89 MWD+IFR-AK-CAZ-SC(3) 9,627.60 35.94 259.29 6,719.76 6,630.62 4,964.91 3,526.26 5,95.58571 313,636.78 2.99 4.406.08 MWD+FR-AK-CAZ-SC(3) 9,722.00 3703 253.02 6,795.68 6,706.54 4,95146 3,58069 5,950,57358 313,582.05 4.11 4,384.93 MWD+IFR-AK-CAZSC(3) 9,815.57 38.18 246.93 6,869.84 6,780.70 4,931.89 3,634.26 5,950,555.32 313,528.02 4.16 4.WT86 MWD+IFR-AK-CAZSC(3) 9,909.91 38.92 241.21 6,943.64 6,854.50 4,906.19 5,687.08 5,950,530.91 313,474.60 3.86 4.324.83 MWD+IFR-AK-CAZSC(3) 10,005.11 40.18 237.08 7,017.06 6,927.92 4,875.09 5,739.08 5,950,501.09 313,421.86 3.06 4286.57 MWD+IFR-AK-CAZSC(3) 10,09983 41.91 231.38 ],088.52 6,999.38 4,838.72 -3,78947 5,950 465 96 313,370.61 4.35 -4,243.33 MWD+IFR-AK-CAZSC(3) 10,19387 43.50 227.39 7,157.63 7,068.49 4,797.19 -3,837.84 5,950,425.62 313,32124 334 4,195.28 MWD+IFR-AKW-SC(3) 11?J2018 3:46:36AM Page 6 COMPASS 5000.14 Build 850 ConocoPhillips SAHE (ER 0 UGS ConocoPhillips Definitive Survey Report Company: ConomPhillips(Alaska) Inc. -WNS Project: Western North Slope Site: GMTI Lookout Pad Well: MT6-06 Wellbore: MT6-06PB2 Design: B1-wp02 Survey Local Co-ordinate Reference: Well MT6-06 TVD Reference: ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) MD Reference: ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production Annotation 9-5/9'x 12-1/4" MT6-06PB2 KOP 71/2/2018 3:46:36AM Page 7 COMPASS 5000.14 Build 850 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W DLS (usR) (°) (°) (usft) (usR) (usft) (Daft) Northing Seating ( °r100' ) Section Survey Tool Name (ft) (ft) fftl 10,285.85 44.90 224.52 7,223.58 7,134.44 4,752.61 -3,883.90 5,950,382.17 313,274.11 2.65 4,144.53 MWD+IFR-AK-CAZ-SC(3) 10,31600 44.94 223.94 7,244.93 7,155.79 4,737.35 -3,898.75 5,950,367.28 313,256.89 1.37 4127.30 MWD+IFR-AK-CAZ-SC(4) 10,371.52 45.02 222.87 7,284.20 7,195.06 4,708.84 3,925.72 5,950,339.43 313,231.25 1.37 -0,095.21 MWD+IFR-AK-CAZ-SC(4) 10,464.34 46.95 21986 7,348.70 7,259.56 4,658.74 -3,969.80 5,950,290.42 313,185.96 3.12 4,039.29 MWD+IFR-AK-CAZ-SC(4) 10,560.20 50.65 215.94 7,411.85 7,32271 4,601.81 4,014.03 5,950,234.59 313,140.37 4.93 3,976.59 MWD+IFR-AK-CAZSC(4) 10,655.11 53.73 212.45 7,470.04 7,380.90 4,539,79 4.056.11 5,950,173.61 313,096]9 4.35 -3,909.16 MWD+IFR-AK-CAZSC(4) 10,750.61 56.29 209.17 7,524.80 7,435.66 4,472.60 4,096.14 5,950,107.41 313,055.14 3.89 3,836.90 MWD+IFR-AK-CAZSC(4) 10,84473 58.92 206.94 7,575.23 7,486.09 4,402.46 4,13349 5,950,038.21 313,016.10 3.44 3,762.13 MWD+IFR-AK-CAZ-$C(4) 10,938.99 61.56 205.80 7,622.01 7,532.87 4,329.15 4A69.83 5,949,965.81 312,978.00 2.99 -3,684.36 MWD+IFR-AK-CAZSC(4) 11,032.00 63.74 203.81 7,664.75 7,575.61 4,254.17 4,204.47 5,949,891.69 312,941.55 3.02 3,605.17 MWD+IFR-AK-CAZSC(4) 11,125.52 64.76 202.54 7,705.38 7,616.24 4,176.73 4,23761 5,949,815.09 312,906.54 1.64 3,523]7 MWD+1FR-AK-CAZSC(4) 11,219.37 64.74 201.73 7,745.41 7,656.27 4,098.11 4,269.59 5,949,737.27 312,872.66 0.78 3,441.36 MWD+IFR-AK-CAZSC(4) 11,312.00 64.69 201.24 7,784.97 7,695.83 4,020.17 4,300.27 5,949,660.11 312,840.10 0.48 3,359.82 MWD+IFR-AK-CAZSC(4) 11,406.62 65.03 200.35 7,825.17 7,736.03 3,940.09 4,33068 5,949,580.80 312,807.76 0.92 -3,276.21 MWD+IFR-AK-CAZSC(4) 11,501.01 65.63 195.83 7,864.59 7,77545 3,858.59 4,357.30 5,949,499.96 312,779.17 4.40 3,191.72 MWD+IFR-AK-CAZSC(4) 11,594.48 67.51 190.74 7,901.77 7,812.63 3,775.15 4,376.97 5,949,417.04 312,757.48 5.39 3,106.32 MWD+IFR-AK-CAZ-SC(4) 11,689.55 69.54 186.51 7,936.59 7,84745 3,687.71 4.390.21 5,949,32995 312,742.12 4.66 -3,017.88 MWD+IFR-AK-CAZSC(4) 11,785.07 71.87 183.88 7,968.15 7,879.01 3,59]94 4,398.36 5,949,24041 312,731.80 3.56 -2,927,87 MM+IFR-AK-CAZ-SC(4) 11,84290 73.36 181.91 7,985.17 7,896.03 3,543.68 4,401.10 5,949,18624 312,727.74 4.21 -2,873.79 MWD+IFR-AK-CAZ-SC(5) 11,875.58 75.96 184.73 7,934.05 7,904.91 3,511.36 4,402.98 5,949,153.97 312,725.08 1120 -2,841.53 MWD+IFR-AK-CAZ-SC(5) 11,894.46 76.12 184.95 7,998.60 7,909.46 3,493.10 4,404.52 5,949,13576 312,723.09 141 -2,823.24 MWD+IFR-AK-CAZ-SC(5) 1198942 81.54 184.14 8,01699 7,927.85 3,40027 4,411.90 5,949,043.14 312,713.46 5.77 -2,730.31 MWD+IFR-AK-CAZ-SC(5) 12,085.58 95.77 181.07 8,027.62 7,938.48 3,304.83 4,416.23 5,948,94]84 312,706.81 5.42 -2,635.24 MWD+IFR-AK-CAZ-SC(5) 12,180.38 90.10 177.57 8,031.04 7,941.90 3,210.14 4,415.10 5,948,853.15 312,70564 5.87 -2,541.70 MWD+IFR-AK-CAZ-SC(5) 12,275.70 90.45 174.55 8,030.58 7,94144 3,115.05 4,408.55 5,948,757.94 312,709.88 3.19 -2448.54 MWD+IFR-AK-CAZ-SC(5) 12,37147 90.45 170.28 8,029.83 7,94069 3,020.15 4,39591 5,94$66276 312,72021 4.46 -2,356.44 MWD+IFR-AK-CAZ-SC(5) 12,466.57 89.98 166.51 8,02947 7,940.33 2,927.01 4,376.79 5,948,569.19 312,737,06 3.99 -2,267.02 MWD+IFR-AK-CAZSC(5) 12,56292 89.42 162.69 8,029.97 7,940.83 2,835.00 4,351.44 5,948,47661 312,760.16 4.04 -2,179.62 MWD+IFR-AKCAZSC(5) 12,657.46 89,46 158.90 8,030.90 7,94176 2,744.90 4.32006 5,948,38577 312,789.35 3.97 -2,034.96 MWD+IFR-AK-CAZSC(5) 12,752.67 89.56 155.17 8,031.72 7,942.58 2,65]25 4,282.92 5,948,297.25 312,824.35 3.92 -2,013.57 MWD+IFR-AKCAZ-SC(5) 12.849.22 88.96 153.17 8,032.96 7,943.82 2,570.36 -4,240.85 5,948,209.37 312,864.28 2.16 -193363 MWD+IFR-AK-CAZ-SC(5) Annotation 9-5/9'x 12-1/4" MT6-06PB2 KOP 71/2/2018 3:46:36AM Page 7 COMPASS 5000.14 Build 850 Survey ConocoPhillips BA ER ConocoPhillips Definitive Survey Report Iu�NEs Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MT6-06 .......... . Project: Western North Slope ND Reference: ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) TVD Site: GMT1 Lookout Pad MD Reference: ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) Map Well: MT6-06 North Reference: True v Wellbore: MT6-06PB2 Survey Calculation Method: Minimum Curvature (usft) Design: B7-wp02 Database: EDT 14 Alaska Production Northing Survey MD Inc Azi TVD NDSS +N/ -S +E/ -W Map Map DLS Vertical v (usft) (°) V) (usft) (usft) (usft) (usft) Northing Ea(ft ng (°/100') Section Survey Tool Name ADOOtali0n S 12,943.01 89.03 151.44 8,034.61 7,945.47 2,487.33 4,197.27 5,948,125.31 312,905.83 1.85 -1,857.74 MWD+IFR-AK-CAZ-SC (5) 3 13,03274 90.98 151.54 8,034.60 7,945.46 2,404.09 4,152.06 5,948,041.00 312,949.01 2.06 -1,781.87 MWD+IFR-AK-CAZ-SC (5) i 13,135.01 90.59 150.46 8,033.27 7,944.13 2,319.03 4,104.91 5,947,954.82 312,994.08 1.18 -1,70447 MWD+IFR-AK-CAZSC(5) 13,228.20 90.01 150.56 8,032.78 7,943.64 2,237.91 4,059.03 5,947,872.62 313,037.97 0.63 -1,630.80 MWD+1FR-AK-CAZSC(5) 13,322.93 89.98 153.19 8,032.79 7,94365 2,154.38 4,014.38 5,947,788.03 313,080.57 2.78 -1,554.55 MWD+IFR-AK-CAZSC(5) _ 13,418,47 89.98 151.70 8,032.82 7,943.68 2,06968 -3,970.19 5,947,702.29 313,12269 1.56 -1,477.09 MWD+IFR-AK-CAZSC(5) j 13,514.88 89.49 152.40 8,033.27 7,944.13 1,984.51 41,925.00 5,947,616.06 313,165.80 0.89 -1,399.31 MWD+1FR-AK-CAZ-SC(5) Ii 13,609.06 89.09 151.68 8,034.49 7,945.30 1,901.33 5,880.85 5,947,53184 313,207.91 0.87 -1,323.35 MWD+IFR-AK-CAZ-SC (5) 13,704.52 8860 151.66 8,036.35 7,947.22 1,817.32 5,835.56 5,947,446.76 313,251.15 0.51 -1,246.73 MWD+1FR-AK-CAZ-SC(5) 13,799.86 88.01 151.14 8,039.18 7,950.04 1,733.85 5,769.94 5,947,362.01 313,299.72 0.82 4,170.49 i MWD+1FR-AK-CAZ-SC(5) I 13,895.24 87.89 150.70 8,042.59 7,953.45 1,650.35 -3,743.61 5,947,277.61 313,339.00 0.48 -1,094.72 MWD+IFR-AK-CAZ-SC(5) Y 13,991.14 88.67 150.75 Bp45.47 7,956.33 1,566.74 5,696.74 5,W.192 89 313,383.83 0.82 -1,01871 MWD+IFR-AK-CA2SC(5) i 14,086.04 91.01 152.50 8,045.74 7,956.60 1,483.25 -3,651.64 5,947,108.33 313,426.88 3.08 -942.58 MWD+IFR-AK-CAZSC(5) 14,181.68 91.95 153.08 8,043.27 7,954.13 1,393.22 -3,607.92 5,947,022.28 313,468.52 1.15 -864.73 MM+IFR-AK-CAZSC(5) 14,276.65 92.44 153.16 8,03963 7,950.49 1,313.58 -3,565.02 5,946,936.62 313,509.35 0.52 -787.13 MWD+IFR-AK-CAZSC(5) 14,372.44 91.60 152.02 8,036.25 7,947.11 1,228.59 5,520.95 5,946,850.60 313,551.34 148 -709.37 MWD+IFR-AK-CAZSC(5) 14,46267 91.27 152.72 8,033.87 7,944.73 1,144.25 5,476.80 5,946,765.21 313,593.43 0.81 532.26 MWD+IFR-AK-CAZ-SC(5) 14,562.83 89.73 153.65 8,033.04 7,943.90 1,059.33 5,433.87 5,946,679.28 313,634.27 1.89 -554.39 MWD+IFR-AK-CAZ-SC (5) 14,658.59 8968 152.57 8,033.53 7,944.39 973.93 5,390.57 5,946,592.85 313,675.49 1.13 476.11 MWD+IFR-AK-CAZSC(5) 14,752.95 89.18 152.80 8,034.47 7,945.33 890.09 5,347.27 5,W,50860 313,]16.]4 0.58 -399.37 MWD+IFR-AK-CAZSC(5) 14,848.63 88.69 152.63 8,036.25 7,947.11 805.07 -3,303.41 5,946,421.94 313,758.51 0.64 -321.54 MWD+IFR-AK-CAZSC(5) t 14,943.86 87.92 151.97 8,039.06 7,949.92 720.80 -3,259.17 5,946,336.62 313,800.70 1.05 -244.51 MWD+IFR-AK-CAZSC(5) i1 15,039.99 87.42 150.30 8,042.97 7,953.83 636.68 -3,212.80 5,946,251.41 313,845.00 1.81 -167.94 MWD+IFR-AK-CAZSC(5) 15,133.74 88.02 150.37 8,046.70 2957.56 555.28 5,166.44 5,946,168.92 313,889.37 0.64 -9405 MWD+IFR-AK-CAZSC(5) i j 15,230.24 87.96 152.43 8,050.09 7,960.95 47061 5,120.28 5,946,083.16 313,933.46 2.13 -1691 MWD+IFR-AK-CAZ-SC(5) E` 15,323.71 87.90 154.42 8,053.46 7,964.32 387.08 5,078.49 5,945,998.63 313,973.20 2.13 59.75 MWD+1FR-AK-CAZ-SC(5) 1 15,419.41 87.96 154.34 8,056.92 7,967.78 300.84 -3,037.14 5,945,911.43 314,01245 0.10 139.14 MWD+IFR-AK-CAZSC(5) 15,515.14 8894 155.08 8,059.51 7,970.37 214.32 -2,996.26 5,945,823.94 314,051.21 1.28 218.88 MWD+IFR-AK-CA7-SC(5) 15,610.18 88.50 154.62 8,061.63 7,972.49 128.31 -2,955.87 5,945,73698 314,089.49 067 298.19 MWD+IFR-AK-CA7-SC(5) 15,705.09 88.48 154.15 8,064.13 2974.99 4276 -2,914.86 5,945,650.47 314,128.41 0.50 376.95 MWD+IFR-AK-CAZ-SC(5) 15,79983 88.48 153.35 8,066.65 ]977.51 -42.18 -2.872.97 5,945,564.54 314,16822 0.84 454.98 MWD+IFR-AK-CAZ-SC (5) 11/22018 3:46.'36AM Page 8 COMPASS 5000.14 Build 85D 1122018 3:46:36AM Page 9 COMPASS 5000.14 Build 850 ConocoPhillips ❑A<ER M ConocoPhillips GHES UDefinitive Survey Report Company: ConowPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MT6-06 Project: Western North Slope TVD Reference: ACTUAL MT6-06 @ 89.14usft (Actual Doyon19) Site: GMT1 Lookout Pad MD Reference: ACTUAL MT6-06 @ 89.14usft (Actual Doyonl9) Well: MT6-06 North Reference: True Wellbore: MT6-06PB2 Survey Calculation Method: Minimum Curvature Design: B1-wp02 Database: EDT 14 Alaska Production Survey MD Inc Azi TVD NDSS +N/ -S -S +E/ -W Map DLS Vertical 3 (usft) (°) (°) (usft) (usft) (usft) Northing (usft) Easting (°/100-) Section Survey Tool Name S Annoteti0n (ft) (ft) (ft) 15,894.95 89.96 15283 8,067.94 7,978.80 -126.99 -2,82993 5,945,478.72 314,209.19 165 532.72 MWD+1FR-AK-CAZSC(5) 15,990.03 90.88 152.29 8,067.24 7,978.10 -211.37 -2,786.11 5,945,393.30 314,250.94 1.12 609.92 MWD+IFR-AK-CAZ.SC(5) I 16,085.99 9168 152.17 8.65 .10 7,975.96 -296.25 .2,741 41 5,945,307.36 314,293.56 0.84 687.49 MWD+IFR-AK-CAZ-SC(5) 16,181.05 91.95 153.59 8,062.09 7,972.95 -380.82 -2,698.10 5,945,221.78 314,334.80 1.52 764.95 MWD+IFR-AK-CAZ-SC (5) j 16,275.75 91.98 153.56 8,058.84 7,969.70 -065.57 -2,655.98 5,945,136.03 314,374.85 0.04 842.76 MWD+IFR-AK-CAZSC(5) 16,370.71 92.01 153.22 6,055.54 7,966.40 -550.42 -2,613.48 5,945,050.17 314,415.28 0.36 92061 MWD+IFR-AK-CAZSC(5) 16,466.28 92.04 153.92 8,052.16 7,963.02 -635.95 -2,570.96 5.94,963 65 314,455.70 0.73 999.14 MWD+1FR-AK-CAZ-SC(5) 16,561.90 88.52 153.38 8,051.69 7,962.55 -721.62 -2,528.53 5,94,87698 314,496.04 3.72 1,077.81 MWD+IFR-AK-CAZ-SC(5) 16,655.50 86.91 153.55 8.55.46 7,966.32 -806.18 .2,486.30 5,94,791.42 314,536.20 1.71 1,155.42 MWD+IFR-AK-CAZ-SC (5) 16,752.22 85.61 153.31 8,061.71 7,972.57 591.61 -2,443.58 5,944,704.98 314,576.83 1.38 1,233.82 MWD+IFR-AK-CAZ-SC(5) 16,802.00 85.61 153.31 8,055.52 7,976.38 -935.96 -2,421.29 5,944,660.11 314,598.04 0.00 1,274.50 PROJECTED to TD t t 1122018 3:46:36AM Page 9 COMPASS 5000.14 Build 850 RECEIVED STATE OF ALASKA I NOV 2 6 2018 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AN Ia. Well Status: Oil ❑Z Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ ib. Well Class: 20AAC 25.105 20MC 25.110 E] WINJ ❑ WAG[- ❑ No. of Completions: 2. Operator Name: 6. Date Comp., Susp., or ConocoPhillips Alaska, Inc. Abend.: 10/2!/2018 3. Address: 7. Date Spudded: Development El Exploratory ElGINJ Service ❑ Stratigraphic Test ❑ 14. Permit to Drill Number / Sundry: 218-093 4 15. API Number: P.O. Box 100360 Anchorage, AK 99510.0360 9/11/2018 50.103.20773.00.00150-103-20773-70.001 50.103.20773.71.00 4a. Location of Well (Governmental Section): Surface: 266' FNL, 3096' FEL, Sec 6. T10N, R3E, UM Top of Productive Interval: 2041' FNL, 2577' FEL, Sec 36, T11 N, R2E, UM Total Depth: 1825' FNL, 315' FEL, Sec 1, TION, R2E, UM11833/7982 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 317041 y- 5945536 + Zone- 4 TPI: x- 312724 y- 5949151 Zone- 4 Total Depth: x- 314661 y- 5944033 Zone- 4 8. Date TD Reached: 10/14/2018 16. Well Name and Number: MT6-06/MT6.06PB1/MT6-06PB2 9. Ref Elevations: KB:89 - 17. GL: 37 - BF: Greater Field / Pool(s): Mooses Tooth Unit/LookoutPberW 10. Plug Back Depth MD/TVD: 18, 11. Total Depth MD/TVD: 19. 17482/8111 - Property Designation: AA081818 AA081798, AA092342, DNR Approval Number Ogqtt�r����$rf 932553, 340760, 340763, 932533B-�i 12. SSSV Depth MD/TVD: 20. N/A Thickness of Permafrost MD/iVD: 1205/1189 5. Directional or Inclination Survey: Yes ❑Q (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: 21. N/A (ft MSL) Re-drill/Lateral Top Window MD/TVD: N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res/Den/Neu , mwlh'-F+meg -61-14' 23. CASING, LINER AND CEMENTING RECORD CASING FT WT. PEREH-4037 DEPTH MD SETTING DEPTH TVD BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20 94 115 37 115 42 10 yds 13.375 68 2118 37 2003 16 1020 sx 11.0ppg LiteCrete 9.625 40 10316 34 7245 12.25 95 sx 12.2ppg Class G, 7 26 JI 32 8.75 266 SX 15.8 Class G 16826 7928 8085 6 Uncemented Perf Pup Liner 24. Open to production or injection? Yes f No ❑ 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): Perforated Liner@ SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 41/2 11675 1166517967 11904-16826 MD and 6001-8085 TVD.... 10/16/2016 COMPLETION 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑e Per 20 AAC 25.283 (i)(2) attach electronic and printed information I DATE f1/ 21 �I 0 VERIFIED DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 10/2712018 GAS LIFT Date of Test: 11/1/2018 Hours Tested: 12hrs Production for Test Period Oil -Bbl: 123 Gas -MCF: 113 Water -Bbl: 0 Choke Size: 54 Gas -Oil Ratio: 915 Flow Tubin4g Press. 353 Casing Press: 2 Calculated 24 -Hour Rate Oil -Bbl: 24 Gas -MCF: 2 Water -Bbl: 0 Oil Gravitv - API (corr): 42 10-407 Revised orzui r V' / L 1-1611'7 CONTINUED ON PAGE � , RB®Wi J 0/ NU,y 2 7 2618 Submit O�RIIGII/NIAL only' fy'� lit tl 14 28. CORE DATA Conventional Core(s): Yes ❑ No 21 Sidewall Cores: Yes ❑ No ❑Q If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology, and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071, 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 11879 7995 information, including reports, per 20 AAC 25.071. Formation @ TPI -Alpine C C30 2217 2085 C10 2697 2451 K-3 4001 3353 K-2 4448 3625 ALBIAN 96 5457 4166 HRZ 10268 7225 KALUBIK 10397 7302 LCU 10659 7472 TD 17482 8111 MT6-06PB1 12687 8058 MT6-06PB2 16802 8065 Formation at total de the I Alpine 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, paleontolouical report. oroduction or well test results, ner 20 AAC 25,070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: G.L. Alvord Contact Name: Andrew Beat Authorized Title: Alaska Drilling Manager Contact Email: Andrew.T.Beat co .com Authorized / I' Contact Phone: 265-6341 Signature: r-r-(.t`, Date: 1114l/ ZO(c7 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 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 512017 Submit ORIGINAL Only MT6-06, 131 Location Final Completion Schematic TOC at least 300' MD above Packer & 500' MD above Alpine C. Planned to Liner Top. 20" 79 ppf H-40 Insulated Conductor 80 feet, cemented to surface ❑0 13-3/8" 68 ppf L-80 TXPIBTCM Surface Casing @ 2118' MD / 2003' TVD Ocemented to surface z 4-1/2" 12.6 ppf L-80 Tenaris Blue to 11,675' MD u 7" 26 ppf L-80 TS Blue Tie Back Tubing / Liner Completion 1) 4-11." Landing Nipple (3.813" X) @ 2,108' MD 2) 4-%" x 1" GLM @ 4,084' MD 3) 4-%]" x V GLM @ 8,101' MD 4) 4-%" x 1" GLM @ 11,409' MD 5) Downhole Gauge @ 11,556' MD 6) 4-%" Landing Nipple (3.75" XN) set at 11,611' MD @68 deg 7) Liner Top Packer / Hanger @ 11,665' MD w/ Tie Back sleeve 8) 4 Yz" TXP Blue Blank Pipe w/ perf joints 9 5/8" 40 ppf L-80 Hyd563 (to 1,166' MD) 9 518" 40 ppf L-80 TXP (to 6,278' MD) 9 518" 40 ppf TN -80 HS TXP (to TD) @ 10,316 MD / 7,245' TVD Top Alpine C 11,849' MD / 7,988' TVD 4-'/.' 12.6# L-80 TXP With Perf Pups @ 16,826' MD 0 0 0 0 0 0 0 0 0 0 E 7" 26 ppf L-80 TS Blue Liner to 11,833' MD / 7,983' TVD @ 73 deg 6" Hole, TD at at 17,482' MD / 8,111' TVD October 2018- AK WN$ PROD WELLNAME MT6-06 WELLBORE MT6-06 ConocoPhillips Naska, Tri. ... nnegma z:+ a a a Px Last Rev Reason Vati9dwra![P.T Annoralbn I EM Us. ..,non. (erthea, Rev Reason: Install GLVD, Pull RHC 8 BHP 10252018 MT6-O6 liaw" He,,.. ir Casing Strings Cher CescJption OD lint ID lint TeplXNal Set DeptM1IXNp) Set Depth IND)-. Wt/Lan 11 Gree Top Thread CONDUCTOR 20 19.12 36.9 1150 115.0 9400 H-0 Welded ............................................... _............. Caslnp Cncnplion ODlinl IDlinl TOp 1X0181 Set DepO (11018) Sel Oeptn IND1-. "iIL.. Gable TOPTNreaE SURFACE 13318 1242 38.9 2,118.0 2,0032 6800 LA0 T%P CUinguesnlpapn OD (in) to (in) Top MIXED Par Depth VUEe) last Delta IND)... WasD (L.. Gaatle Top TXreaO -: 998" Intermediate 9518 8,84 34.0 10.316.0 7,2449 4000 LA0 TXP Cab NMCemem,3G1Nxe COeardue ;35 al lsP .':r, Annear due zea casing purlPtbn OO gn) Siring ] TTng No Reopens)see Gone In) 2,295XDIM1 (XNe) 6,644.0 MID).... M.. (I... LBO 628 22 8,644.0 26.00 LBO ill6330 Top Ttlrea4 tapping osuriplbn ODlin) DEED Be10ePIM1 IXNB) Se1proM (0101... WIM1en (I... Grade set0sp TOPi TOPintakeBl 1,aW D,1M1ltC1B AmJm pud-oi.aa: ze e- W. U ]"$DL Ulcer ] 6 8 95196BI 628 9,5196 ],982.8 32.00 L-80 Terris Blue Liner Details cerven1A1B sur.... CeLLg Cement 3]1 NNB D TOP InNe) Top(TVD)VOkilb) Twiner(') IlBow cnm (m) 9519fi 6,632.3 35.93 Seal Bow Seal Bore Extension b 15 Extension ,541.1 6,649.7 35.93 Packer SLZX Liner Hanger Packer 3.27 ,552.4 5,658.9 3593 Seal Assembly Latching Seal assy(5J' seals In LSS below) 6.2]6 NgAs-X; 3.IM3 91555.2 5.551.1 3593 Sexing Sleeve HRD-E Liner Setlirlg Sleeve 7735 aUREACE %6211do 9,563.8 5,558.1 35.93 Quick Connect HP Liner Quick Conness,skeliallin Seals ]" M 6.150 Terns Blue Mamm 4084.5 Mrer flw-aelPr winning 9,5694 ]. 35.93asing PUP]" 26# LAD Liner Tanana Blue Liner Intermediate 3276 Miva FlW-s.IMalmrenw: UM.ou.4w.DlaalrMe 11)898 ], ] asin T'32#L- g BO Liner Tenads BWe Casing joim 6276 Intermediate 11,626.9 7,980. ] Stabilizer Reamer we Mbilizerw/ pine ras, Mamm: arm] MVS110 Tanana Blue CasingOe¢rlptbn Oe lint ID (int Top IXNB) SNOePIX IXKBI .0tak D1....1en IL.. Gra4e D.P Thread Liner 412 396 111664A 116,8263 8.085.4 12.60 LA0 TXP Liner Details xominal ID T'Taeack sefmigl az.xe.554B rap luxe) Top (rvD)IXlcal Top r) Item ee: Com f3 11,6912 >,93]2 ba 69.5 0 Hanger 4-112"x]"Flex Lock Tri H521 Pinx Pin 3860 Tubing Strings TUEIip Oeecripllon Slnnp Ma... ID lin) Top IXNB) Se[Depth(X.. Set OeptX jNm l... Wt11N%) Grade Tap Gonnxiion �mm.emh costa cermet:_ ealla ars Tubing - Production 4112 3.96 288 11,6]4.6 ],931.3 1260 L-80 Tblue Completion Details ata°Irmrmxbu.3A6 m moo Mnuler Hca -lisih htredre: 1' OR (TVD) Top l- TopMKB) IXNB) fl Ihm Des cam xominal ID lint 28.8 28.8 000 Hanger FMC 4-12" Tubing Hanger H563 .956 T9 shah b30: "'Doe" Lin. Co.. maza.Ne- MmhN: 1+40az 2,108.2 1,9950 3321 Nipple -X DING.4 ', .3.81TSH Blue 'Polish Bore Integrity Suspect 1=011 8" 3.813 Mnmar Fiv]-sMnmeraere: mean en.o:laterzme MwIe FIUN-eameMrredre: 11,556.2 7886.9 6674 75 Sensor age /Pump SGk1,4112',SCHLUMBERGER Solid Gauge Mandrel 3.879 u Hw.o-n em.o: rofvmle 11,811.4 7,9082 6787 Nipple -X01 NIPPIE,IANDING,412",3R5"Na-Go,XN, TSH Blue 3,725 4aupel Pumpsnm:tl.Yb.z 11,658.8 ],925] 6888 No -GO Locator LCcamr No -GO 575'00 3.950 xippe-xe; 1101.4 11,660.3 7,926.2 6891 Seal Assembly Seal Assembly 3.950 See ppmw: 11 caz.otue Perforations B Slots Ni 11 �.8 shw pens asst...it ; tt eM.g rpp (XKel elm MNa) IXTV I To(pl eltX)Dl IXIca) unkedioiw wM (eSOTor 1 Trce cam 11,903.0 16,626.3 8,0006 8.0854 10.512018 PERFP Mandrel Inserts SI an an Top INOI T"Inks) me) Make Model Oe lin) Sm Valve IaEch Por184e Tyye Typ (in) TROflun (psi) Ron Deb Co.- r tot Up, estaan eta 4,0845 3.4060 Camco KBG2 1 GAS LIFT GLV BK5 0.188 1763.0 101292018 2 8,1013 5,581.3 Camm K0G-2 i GAS LIFT GLV BK5 DIM 1792.0 101242018 3 11009.2 7,8262 Cannon KBG-2 1 GAS LIFT OV BK -5 0250 00 192412018 Notes: General & Safety End Dash A..a NOTE'. PERFP. 11.9010wraa3 Mrvle Fair - MCBM: 119M.6 IT.4B2R wrod r. Iver, 11.M4.6IA. 3 Operations Summary (with Timelog Depths) MT6-06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Time End Time Our (hr) Phew Op Cafe AchWy Code Time P -T -X Operaton start Depm (M(13) EM Depth mKB) 9/5/2018 9/6/2018 3.00 DEMOB MOVE RURD P Move pits & motors complex & pipe 0.0 0.0 21:00 00:00 shed away from sub. Skid rig floor. Raise support feet. 9/10/2018 9/10/2018 12.00 MIRU MOVE RURD P Cont. w/trough & grating in pits. R/U 0.0 0.0 00:00 12:00 flow line & MPD return lines. Finish rigging up top drive & function test good. Paint inspected handling equipment. Work on new riser & N/U flow line. R/U cement lines in cellar. Wrap up Tubo inspections. 9/10/2018 9/10/2018 4.50 MIRU MOVE RURD P Cont. w/trough & grating in pits. NOV 0.0 0.0 12:00 16:30 commission soft speed. Dummy run landing jt. Bring BHA tools & equipment to rig floor. Clean pits. Work on rig acceptance check list. Accept rig @ 16:30 Hrs 9/10/2018 9/10/2016 3.00 MIRU MOVE RURD P Test gas alarms. Finish assembling 0.0 0.0 16:30 19:30 hand tools. Install victaulic clamp f/pit equalizer. Install rubber wrap on kelly hose. Calibrate block height. Clean pits. Install valves on conductor outlets. Finalize pre -spud check list. 9/10/2018 9/10/2018 3.25 MIRU MOVE BHAH P M/U 16" mud motor BHA as per Baker 0.0 115.0 19:30 22:45 reps to 115'. MWD offset 8.6°. SIMOPS - Take on spud mud. 9/10/2018 9/10/2018 0.75 MIRU MOVE PRTS P Fill riser w/32 bbls spud mud & check 115.0 115.0 22:45 23:30 for leaks. (good) Pressure lest surface lines to 4000 psi (good) 9/10/2018 9/11/2018 0.50 MIRU MOVE RURD P Pre -spud meeting & finalize pre -spud 115.0 115.0 23:30 00:00 check list. 9/11/2018 9/11/2018 0.50 MIRU MOVE RURD P Pre -spud meeting & finalize pre -spud 115.0 115.0 00:00 00:30 1 1 check list. 9/11/2018 9/11/2018 0.25 MIRU MOVE REAM P W&R down to base of conductor @ 115.0 115.0 00:30 00:45 115'w/450 gpm, 800 psi, 40 rpm, 3 k trq. No fill. 9/11/2018 9/11/2018 7.25 SURFAC DRILL DDRL P Drill ahead from 115' to 555' MD 1554' 115.0 555.0 00:45 08:00 TVD, ADT 3.7 Hrs, ECD 11.0 ppg, 550 gpm, 1000 psi, PU wt 90 k, SO wt 89 k, Rot Wt 90 k, 40 rpm, On/Off trq 2/1 k ft/lbs 9/11/2018 9/11/2018 0.50 SURFAC DRILL SVRG P Service rig while C/O butterfly valve in 555.0 555.0 08:00 08:30 1 1 centrifugal room. 9/11/2018 9/11/2018 3.50 SURFAC DRILL DDRL P Drill ahead from 555'to 837' MD / 823' 555.0 837.0 08:30 12:00 TVD, ADT 2.0 Hrs, ECD 11.06 ppg, 550 gpm, 1,190 psi, PUW/SOW/ROW = 95k/93k/95k, 40 rpm, On/Off trq 2.5/1.5 k fUlbs 9/11/2018 9/11/2018 9.25 SURFAC DRILL DDRL P Drill ahead from 837'to 1,403'/ 1,372' 837.0 1,403.0 12:00 21:15 TVD, ADT 5.8 Hrs. ROT = 3.9 Hrs. ROT 1.9 Hrs. ECD 10.6 ppg, 775 gpm, 1,750 psi, PUW/SOW/ROW = 98k/94k/95k, 50 rpm, On/Off trq 4.5/2.0 kf/lbs Reduce ROP - 30-15 fph due to bit balling after the permafrost depth - 1,300'. CBU x2 and pumped 3 Walnut NP Medium sweeps (8.0, 16.5 and 16.5 ppb) with 1.75% extra Drilzone 9/11/2018 9/11/2018 0.75 SURFAC DRILL RGRP T Suction line leak in centrifugal room 1,403.0 1,403.0 21:15 22:00 (MP #2). Circulate at 450 gpm, 600 psi, 10 rpm, 1.5 Tq while troubleshooting valve and installing new gasket. -Pictures in Well Folder - Page 1/31 ReportPrinted: 1012512018 Operations Summary (with Timelog Depths) MT6-O6 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Siert Time End Time Out (hr) Phase Op Code AMdy Code Time P -T -X Operation Start Depth MIKE) End Depth (MB) 9/11/2018 9/12/2018 2.00 SURFAC DRILL DDRL P Continue drilling ahead from 1,403'to 1,403.0 1,593.0 22:00 00:00 1,593'/ 1,546' TVD, ADT 7.2 Hrs, ECD 10.7 ppg, 775 gpm, 1,750 psi, PUW/SOW/ROW = 98k/94k/95k, 50 rpm, On/Off trq 4.5/2.0 kfVlbs 9/12/2018 9/12/2018 5.50 SURFAC DRILL DDRL P Drill ahead f/1,593'to TD of 2,129' 1,593.0 2,129.0 00:00 05:30 MD / 2,012' TVD, ADT 4.3 Hrs, ECD 10.8 ppg, 850 gpm, 2380 psi, PU wt 122 It, SO wt 115 it, Rot Wt 118 k, 60 rpm, ONOff trq 5.5/2.5 k ft/lbs 9/12/2018 9/12/2018 2.75 SURFAC CASING CIRC P Circ hole clean for 5 B/U, 850 gpm, 2,129.0 1,968.0 05:30 08:15 2170 - 2090 psi, 60 rpm, 2.5 k trq. Pumping 30 bbl nut plug drill zone sweeps to aid in hole cleaning. Racked back 1 stand per 2 B/U f/2,129'to 1,968' 9/12/2018 9/12/2018 2.25 SURFAC CASING RGRP T Top drive repair. Shot pin assembly 1,968.0 1,968.0 0815 10:30 seals failed. Remove assy & rebuild in rig shop & re -install. Add fresh hydraulic fluid to top drive. SIMOPS - replace #1 mud pump drive chain gasket. 9/12/2018 9/12/2018 0.75 SURFAC CASING CIRC P Pump nut plug sweep & circ 1 B/U w/ 1,968.0 1,874.0 10:30 11:15 850 gpm, 2090 psi, 80 rpm, 2.5 k trq. Rack back 1 stand from 1,968'to 1,874' 9/12/2018 9/12/2018 0.25 SURFAC CASING OWFF P F/C (slight drop/static) 1,874.0 1,874.0 11:15 11:30 9/12/2018 9/12/2018 2.75 SURFAC CASING TRIP P POOH from 1,874'to 368' 1,874.0 368.0 11:30 14:15 9/12/2018 9/12/2018 3.00 SURFAC CASING BHAH P Flow check (static). L/D BHA as per 368.0 0.0 14:15 17:15 Baker reps from 368'. Calculated fill = 15.18 bbls. Actual fill = 25 bbls 9/12/2018 9/12/2018 1.00 SURFAC CASING SHAH P Clean & clear floor of BHA tools & 0.0 0.0 17:15 1815 equipment 9/12/2018 9/12/2018 1.75 SURFAC CASING RURD P R/U to run casing. R/U Volant, power 0.0 0.0 18:15 20:00 tongs, bale extensions, casing slips & elevators. 9/12/2018 9/12/2018 0.50 SURFAC CASING RURD P PU landing joint and torque up to 3k 0.0 0.0 20:00 20:30 9/12/2018 9/12/2018 1.50 SURFAC CASING PUTB P PJSM - Run Csg. MU shoe track shoe 0.0 80.0 20:30 22:00 joint #1 and joint #2 with mg tongs to 34k (not made up to diamond - 2" thread gap). Attempt to torque up with volant CRT to diamond (unsuccessful). 9/12/2018 9/13/2018 2.00 SURFAC CASING PUTB T Break out top drive from volant CRT. 80.0 80.0 22:00 00:00 Steam collar and break out joint #2 from collar successfully. Inspect threads on jt #2 and collar- both significantly galled. Mobilize equipment from CD2,. Discuss plan forward options w/Town Engineer. Decision to lay down jt #2 and attempt to replace collar on shoe jt while waiting on equipment from CD2. P/U and R/U strap tongs to break out collar. 9/13/2018 9/13/2018 2.50 SURFAC CASING PUTB T Cont. to break collar on shoe jt. Galled 80.0 80.0 00:00 02:30 I threads. C/O jts #1 & #2. 9/13/2018 9/13/2018 1.00 SURFAC CASING PUTB P Cont to M/U 13-3/8" shoe track to 80.0 200.0 02:30 03:30 1 1 1 I 200'. Check floats (good) Page 2131 Report Printed: 10/25/2018 Operations Summary (with Timelog Depths) MT6-06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log StartTime End Time Dur (hr) Phase op toes Activity ivily Code -RR Tlme PJA Operation Depth (ftKB) End Depth (IKB) 9/13/2018 9/13/2018 2.50 SURFAC CASING GRP T Top drive repair. Shot pin assembly 200.0 200.0 03:30 06:00 seals failed. Remove assy & rebuild in rig shop & re-install. Add fresh hydraulic fluid to top drive. 9/13/2018 9/13/2018 3.00 SURFAC CASING PUTB P RIH 13-3/8" 68# L-80 BTC casing 200.0 1,130.0 06:00 09:00 f/200'to 1,130'. Started taking wt 9/13/2018 9/13/2018 1.50 SURFAC CASING CIRC P7 Circ & cond mud at base of perm frost 1,130.0 1,178.0 09:00 10:30 f/1,130' to 1,178'w/2.5 - 8 bpm, 260 psi. Heaviest mud observed 10.5 ping 9/13/2018 9/13/2018 3.25 SURFAC CASING PUTB P RIH 13-3/8" 68# L-80 BTC/TXP casing 1,178.0 2,079.0 10:30 1345 f/1,178' to 2,079' 9/13/2018 9/13/2018 0.75 SURFAC CASING HOSO P M/U hanger & landing it. Wash down 2,079.0 2,118.0 13:45 1430 w/1 bpm & casing on hanger @ 2,118' PU wt 190 k, SO wt 125k 9/13/2018 9/13/2018 2.00 SURFAC CEMENT CIRC P Circ& cond for cement job. Stage 2,118.0 2,118.0 14:30 1630 pumps to 8 bpm, 150 psi. Reciprocate pipe. SIMOPS - UD via beaver slide power tongs, casing slips & elevators, bale extensions. 9/13/2018 9/13/2018 0.50 SURFAC CEMENT RURD f5 Shut down pumps & B/D top drive. 2,118.0 2,118.0 16:30 17:00 Shut in IBOP. RID cement lines. 9/13/2018 9/13/2018 0.75 SURFAC CEMENT CIRC P Break circ thru cement lines w/6 bpm 2,118.0 2,118.0 17:00 17:45 260 psi. PJSM on cementing 9/13/2018 9/13/2018 3.50 SURFAC CEMENT -dM-NIT P Dowell pump .9 bbis H2O & PT to 2,118.0 2,118.0 17:45 21:15 3500si p (good). Dowell pump 100.1 bbls 10.3 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 361.7 bbls 11.0 ppg 1.92 ft3/sx yield LIteCRETE lead cement and 69.9 bbls 15.8 ppg 1.16 ft3/sx yield tail cement @ 3 - 5 bpm. Drop top plug. Dowell pump 20.1 bbls H2O. Rig displace with 284.7 bbls 12,839 stks 10 ppg DrillPlex with 8 bpm 1740 psi. Reduce pumps to 3 bpm / 400 psi. last 10 bbls. Bump plug, pressure 500 psi over to 900 psi for 5 min. Check floats. F/C good. CIP @ 21:07 Hrs. Calculate 99 bbls good cement to surface. Full returns during cement job. 9/13/2018 9/14/2018 2.75 SURFAC CEMENT RURD P Rig down cement hose, volant CRT, 0.0 0.0 21:15 00:00 back off landing it and drain riser. Lay down landing it, remove bushings and clean drip pan. MU stack washer and flush stack with black water. Lay down stack washer and blow down top drive 9/14/2018 9/14/2018 4.00 SURFAC WHDBOP NUND P N/D riser & N/D starting head. 0.0 0.0 00:00 0400 SIMOPS - Clean pollution pan. RID flow line drains, bleeder lines & pull mouse hole. 9/14/2018 9/14/2018 1.00 SURFAC P N/U well head &test void U1000 psi 0.0 0.0 04:00 0500 f/10 min good. CPAI witness test and verification of alignment. 9/14/2018 9/14/2018 1.00 SURFAC P N/U BOPE 0.0 0.0 05:00 0600 9/14/2018 9/14/2018 2.50 SURFAC IWHDBOPMPDA P N/U MPD equipment, MPD clamp, 0.0 0.0 06:00 08:30 orbit valve, flow box. Drain lines. Hole fill & bleeder lines. 9/14/2018 9/14/2018 1.50 SURFAC P N/U kill line & N/U accumulator lines 0.0 0.0 08:30 10:00 from post annual inspection. 9/14/2018 9/14/2018 1.00 SURFAC P N/U MPD lines, Katch Kan, & 1502 0.0 0.0 10:00 11:00 lines. Page 3131 Report Printed: 10/25/2018 Operations Summary (with Timelog Depths) MT6-06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation rt Depth S�(flKB) End Depth (NKS) 9/14/2018 9/14/2018 1.50 SURFAC WHDBOP NUND P Tighten BOPE ram doors. Clean & 0.0 0.0 11:00 12:30 clear mezz of tools & equipment. Charge accumulator & check for leaks. Set 5" lest jt & function rams (good). UD test jt & function blinds (good) 9/14/2018 9/14/2018 1.50 SURFAC WHDBOP MPDA P Set MPD test cap. Test MPD system. 0.0 0.0 12:30 14:00 Fluid leaking from to-trq. C/O to-trq. Test MPD system to 250 psi for 5 min & 1200 psi for 10 min on chart (good). Remove MPD test plug & install trip nipple. 9/14/2018 9/14/2018 2.00 SURFAC WHDBOP RURD P Install 5" test joint. R/U BOPE test 0.0 0.0 14:00 16:00 equipment. Fill trip nipple & lines w/1-120. Fill choke/kill lines. Perform shell test. 2500 psi on annular & 5000 psi on upper pipe rams (3.5" x 6" - good) 9/14/2018 9/14/2018 1.50 SURFAC WHDBOP WAIT T Stand by for Austin McLeod (AOGCC). 0.0 0.0 16:00 17:30 SIMOPS: Loading 9-5/8" mg and HWDP in pipe shed. 9/1412018 9/14/2018 5.00 SURFAC WHDBOP BOPE P Test BOPE w/5 test joint. Annular for 0.0 0.0 17:30 22:30 5 min / 2500 psi 2500 psi 10 min, Remaining test 250 psi for 5 min / 5000 psi for 10 min. 4" Demco, Choke valves 1 - 14; IBOP's, Choke needle valve, Upper/lower 3-1/2" X 6" VBR's & blind rams, 5" Dart/FOSV, HCR / Man choke/kill, Accumulator test, Initial 2,950 psi, final 1,450 psi, 1st 200 psi recharge = 30 sec's, full recharge = 161 seconds. Nitrogen Bottles x4 =2150 psi. Gas alarms and PVT alarms tested. Draw down on chokes 1/1100 psi. AOGCC Austin McLeod witness test, BLM Mutasim Elganzoory waived witness. 9/14/2018 9/14/2018 0.50 SURFAC WHDBOP RURD P Blow down and rig down test 0.0 0.0 22:30 23:00 equipment. 9/14/2018 9/14/2018 0.50 SURFAC WHDBOP RURD P Pull test plug and set 12-3/8" ID wear 0.0 0.0 23:00 23:30 bushing. 9/14/2018 9/15/2018 0.50 SURFAC CEMENT BHAH P Mobilize BHA and equipment to the rig 0.0 0.0 23:30 00:00 floor 9115/2018 9/15/2018 0.50 SURFAC CEMENT RURD P R/U Baker BPA 0.0 0.0 00:00 00:30 9/15/2018 9/15/2018 2.00 SURFAC CEMENT BHAH P M/U 12-1/4" BHA#2 as per Baker reps 0.0 622.0 00:30 02:30 to 622' 9/15/2018 9/15/2018 0.75 SURFAC CEMENT TRIP P RIH f/622'to 1,940' 622.0 1,940.0 02:30 03:15 9/15/2018 9/15/2018 0.25 SURFAC CEMENT WED P Shallow hole lest MWD 800 gpm, 1,940.0 1,940.0 03:15 03:30 2210 psi, 30 rpm, 4.5 k trq, PU wt 120 k, SO wt 110 k, ROT wt 115 k 9/15/2018 9/15/2018 1.00 SURFAC CEMENT SLPC P PJSM. Slip & cut drill line. SIMOPS - 1,940.0 1,940.0 03:30 04:30 circ B/U w/3 bpm, 80 psi 9/15/2018 9/15/2018 0.50 SURFAC CEMENT SVRG P Service rig & adjust drum brakes. 1,940.0 1,940.0 04:30 05:00 9/15/2018 9/15/2018 1.00 SURFAC CEMENT PRTS P R/U testing equip. Test casing to 3000 1,940.0 1,940.0 05:00 06:00 psi & chart for 30 min (good). RID testing equip. 9/15/2018 9/15/2018 0.50 SURFAC CEMENT COCF P Wash down f/1,940'to 2,017'w/600 1,940.0 2,017.0 06:00 06:30 gpm, 1290 psi & tag T.O.C. 2,017' 9/15/2018 9/15/2018 3.50 SURFAC TEMENT P Drill cement, float collar, shoe track, & 2,017.0 2,129.0 06:30 10:00 rat hole f/2,017' to 2,129'w/600 gpm, 1290 psi Page 4131 ReportPrlrrted: 10125/2018 AM Operations Summary (with Timelog Depths) MT6-06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log StartTme End Time Our(hr) Phase Op Code Acbvlly Code Time P -T -X Opmaton Stan Depth (ftKB) End Depth(XKB) 9/15/2018 9/15/2018 0.50 SURFAC CEMENT DDRL P Drill 20' new formation f/2,129'to 2,129.0 2,149.0 10:00 10:30 2,149' MD / 2,029' TVD, ADT .3 Hrs, ECD 10.11 ppg, 825 gpm, 2130 psi, PU wt 125 k, SO wt 115 k, ROT wt 120 k, 100 rpm, Trq On/Off 5.5/2.5 k ft/lbs. 9/15/2018 9/15/2018 0.75 SURFAC CEMENT DISP P Displace to new 9.4 ppg LSND w/825 2,149.0 2,034.0 10:30 11:15 - 650 gpm, 2130 - 980 psi, 60 rpm, 5.5 k Inc. BROOH f/2,149' to 2,034' 9/15/2018 9/15/2018 0.25 SURFAC CEMENT OWFF P F/C (static) 2,034.0 2,034.0 11:15 1130 9/15/2018 9/15/2018 0.50 SURFAC CEMENT FIT P R/U testing equipment. FIT to 18.0 2,034.0 2,034.0 11:30 1200 ppg (900 psi w/9A ppg LSND). R/D testing equipment. 9/15/2018 9/15/2018 0.25 INTRMI DRILL REAM P RIH f/2,034'to 2,127'. W&Rf/2, 127to 2,034.0 2,149.0 12:00 1215 2,149' w/900 gpm 1600 psi, 80 rpm, 3 k trq 9/15/2018 9/16/2018 11.75 INTRMI DRILL DDRL P Drill ahead f/ 2,149' to 3,070' MD / 2,149.0 3,070.0 12:15 00:00 2,712' TVD, ADT 9.7 Hrs, ECD 9.97 ppg, 850 gpm, 1,840 psi, PU wt 132k, SO wt 120k, ROT wt 125k, 100 rpm, Trq On/Off 4.5/3 kf /lbs. Pumping 10 ppb nut plug drill zone sweeps to aid in bit balling. **Control drill at 110 fph for mud conditioning from 2,500'to 3,070- 9/1612018 9/16/2018 12.00 INTRMI DRILL DDRL P Drill ahead f/3,070'to 4,486' MD / 3,070.0 4,486.0 00:00 12:00 3,646' TVD, ADT 9.6 Hrs, ECD 10.25 ppg, 850 gpm, 2,220 psi, PU wt 145k, SO wt 135k, ROT wt 137k, 160 rpm, Trq On/Off 7/4 kfUlbs. Pumping 10 ppb nut plug drill zone weighted sweeps to aid in bit balling. 9/16/2018 9/17/2018 12.00 INTRMI DRILL DDRL P Drill ahead (/4,486' MD to 5,500' MD/ 4,486.0 5,500.0 12:00 00:00 4,188' TVD, ADT 9.2 Hrs, ECD 10.42 ppg, 900 gpm, 2,530 psi, PU wt 150k, SO wt 135k, ROT wt 140k, 160 rpm, Trq On/Off 9/5 kf /lbs. "5" DP Std #51 was drilled then backreamed to MU 10-5/8" OD Ghost Reamer (7.12') below top jt on std #50. Placing reamer –5,300' behind bit' 9/17/2018 9/17/2018 12.00 INTRMI DRILL DDRL P Drill ahead f/5,500' to 7,020' MD / 5,500.0 02 7,0.0 00:00 12:00 4,998' TVD, ADT 9.8 Hrs, ECD 10.55 ppg, 900 gpm, 2,560 psi, PU wt 180k, SO wt 145k, ROT wt 155k, 180 rpm, Trq On/Off 13/7.5 kf /lbs. Adding whole mud dilutions to control mud wt. Pumping weighted nut plug sweeps to aid in hole cleaning. 9/17/2018 9/18/2018 12.00 INTRMI DRILL DDRL P Drill ahead f/7,020'to 8,200' MD / 7,020.0 8,200.0 12:00 00:00 5,641' TVD, ADT 9.3 Hrs, ECD 10.76 ppg, 900 gpm, 2,700 psi, PU wt 190k, SO wt 148k, ROT wt 160k, 180 rpm, Trq On/Off 14/7 kft/lbs. Adding whole mud dilutions to control mud wt. Pumping weighted nut plug sweeps to aid in hole cleaning. Page 5/31 Report Printed: 10/25/2018 Operations Summary (with Timelog Depths) MT6-06 Rig: DOYON 19 Job: DRILLING ORIGINAL Ttme Log Start Time End Time Dur (hr) Phew Op Code Activity Code Time P -T -X Operation Start Depth (MB) EW Depth(8KB) 9/18/2018 9/18/2018 12.00INTRMI DRILL DDRL P Drill ahead f/8,200' MD to 9,425' MD / 8,200.0 9,425.0 00:00 12:00 6,556' TVD, ADT 9.8 Hrs, ECD 10.89 ppg, 900 gpm, 2,900 psi, PU wt 247k, SO wt 173k, ROT wt 195k, 180 rpm, Trq On/Off 17.5/12k ft/lbs. Adding whole mud dilutions to control mud wt. Pumping weighted nut plug sweeps to aid in hole cleaning. 9/18/2018 9/18/2018 8.25 INTRMI DRILL DDRL P Drill ahead f/9,425' MD to 10,326' 9,425.0 10,326.0 12:00 20:15 MD / 7,525' TVD, ADT 7 Hrs, ECD 10.8 ppg, 900 gpm, 3,060 psi, PU wt 260k, SO wt 1851k, ROT wt 197k, 180 rpm, Trq On/Off 18/9k ft/lbs. Adding whole mud dilutions to control mud wt. Pumping weighted nut plug sweeps to aid in hole cleaning. 9/18/2018 9/18/2018 0.25 INTRMI CASING OWFF P Monitor well. Slight drop in fluid level. 10,326.0 10,326.0 20:15 20:30 9/18/2018 9/18/2018 2.00 INTRMI CASING CIRC P Circulate and weight up mud system 10,326.0 10,326.0 20:30 22:30 to 10.4 ppg. 900 gpm, 3230 psi, 140 rpm, Trq=10k. Reciprocate from 10,326' MD to 10,232' MD. Sim- ops/Make up and stand back 15 stands 4" 14# ddllpipe. 9/18/2018 9/19/2018 1.50 INTRMI CASING CIRC P Continue to circulate and condition 10,326.0 10,064.0 22:30 00:00 mud system standing back one stand every 1/2 hour from 10,326' MD to 10,064' MD 9/19/2018 9/19/2018 12.00 INTRMI CASING BKRM P BROOH from 10,064' MD to 7,180' 10,064.0 7,180.0 00:00 12:00 MD. 900 gpm, 3160 psi ICP -2820 psi FCP, 140 rpm, 11-7.5k tq, PU wt 180k, SO wt 157k, ROT wt 1301kPerform 550 bbl mud dilution while BROOK 9119/2018 9/19/2018 8.00 INTRMI CASING BKRM P BROOH from 7,180' MD to 5431' MD. 7,180.0 5,431.0 12:00 20:00 900 gpm, 2640 psi, 140 rpm, 7k tq,. 9/19/2018 9/19/2018 1.00 INTRMI CASING CIRC P CBU x2. Rotate and reciprocate from 5,431.0 5,361.0 20:00 21:00 5431' MD to 5361' MD. 140 rpm, 900 gpm, 2640 psi. 9/19/2018 9/19/2018 0.25 INTRMI CASING PMPO P Pump OOH from 5361' MD to 5336' 5,361.0 5,336.0 21:00 21:15 MD. 900 g[m, 2640 psi, PU wt 175/185k. Attempt to POOH on elevators from 5336' MD to 5316' MD. 30-40k overpull observed. RIH to 5336' MD. 9/19/2018 9/19/2018 0.50 INTRMI CASING PMPO P Pump OOH from 5336' MD to 5295' 5,336.0 5,336.0 21:15 21:45 MD. 900 gpm, 2550 psi, PU wt. 175- 195k SO wt 130k. Lay down ghost reamer. Ream from 5295' MD to 5336' MD. 400 gpm, 800 psi, 100 rpm, 71k tq. 9/19/2018 9/20/2018 2.25 INTRMI CASING BKRM P BROOH from 5336' MD to 4760' MD. 5,336.0 4,760.0 21:45 00:00 900 gpm, 2550 psi, 140 rpm, 6k tq,.10.88 ECD. 9/20/2018 9/20/2018 12.00 INTRMI CASING BKRM P BROOH from 4760' MD to 2848' MD. 4,760.0 2,848.0 00:00 12:00 900 gpm, 2480-2150 psi, 140 rpm, 5- 3k tq PU wt, 130k SO wt 120k Rot wt 125 at 2848' MD..At 3330' MD observed ECD spike to 11.86 ppg and gradual increase in cuttings. Pump 35 bbl 12.4 ppg weighted sweep. No increase in cuttings on sweep return. Pump another 35 bbl weighted sweep at 2985' MD with no increase in cuttings on sweep return. Perform 275 bbl mud dilution at 2894' MD while continuing to BROOH. Page 6/31 Report Printed: 10/25/2018 S, Operations Summary (with Timelog Depths) MT6-06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur(hn Phase Op Code Activity Code Time P -T -X Operation Stan Depth (kKB) End Depth (MIKE) 9/20/2018 9/20/2018 8.00 INTRMI CASING BKRM P BROOH from 2848' MD to 2466' MD. 2,848.0 2,466.0 12:00 20:00 900 gpm, 2260 psi, 120 rpm, 2-4k tq PU wt,130k SO wt 120k Rot wt 125 at 2848' MD -At 2742' MD pump 35 bbl 12.4 ppg weighted sweep. No increase in cuttings on sweep return. Pump another 35 bbl weighted sweep at 2540' MD with no increase in cuttings on sweep return. 9/20/2018 9/20/2018 0.75 INTRMI CASING PMPO P Pump OOH from 2466' MD to 2406' 2,466.0 2,406.0 20:00 2045 MD. 5 bpm, Observe packing off and overpull of 25-50k. PU wt 125k SO wt 100k. Attempt to pull with no pump and oberving overpull of 25-50k. 9/20/2018 9/20/2018 1.75 INTRMI CASING BKRM P BROOH from 2406' MD to 2116' MD. 2,406.0 2,116.0 20:45 22:30 900 gpm, 2340 psi, 120 rpm, 3k tq 9/20/2018 9/21/2018 1.50 INTRMI CASING CIRC P Circulate casing clean. 900 gpm, 2300 2,116.0 2,116.0 22:30 00:00 psi, 140 rpm, 2k tq. Reciprocate from 2116' MD to 2034' MD. PU wt 125k SO wt 100k. Pump 60 bbl 12.4 ppg weighted sweep. 200% increase in cuttings load at sweep return. Pump 40 bbl weighted sweep. 100% increase in cuttings load at sweep return. Pump another 40 bbl weighted sweep. 25% increase in cuttings load at sweep return. 9/21/2018 9/21/2018 0.75 INTRMI CASING OWFF P Rack back one stand of DP Monitor 2,116.0 2,034.0 00:00 00:45 well. Slight drop in fluid level. Blow down TD. 9/21/2018 9/21/2018 0.50 INTRMI CASING TRIP P Attempt to POOH on elevators from 2,034.0 1,936.0 00:45 01:15 2034' MD to 1900' MD. Observe 25k overpull.and swabbing. RIH to 1936' MD 9/21/2018 9/21/2018 2.00 INTRMI CASING BKRM P BROOH from 1938' MD to 1372' MD. 111936.0 1,372.0 01:15 0315 800-900 gpm, 1760-2280 psi. 120 rpm, 2.5k tq. Well bore unloaded at 1800' MD. Pump 35 bbl 11.5 ppg weighted sweep. 20% cutting increase on sweep return. 9/21/2018 9/21/2018 1.50 INTRMI CASING PMPO P Attempt to POOH. Swabbing. Pump 1,372.0 615.0 03:15 0445 OOH from 1372' MD to 615' MD. 500 gpm, 700 psi. 9/21/2018 9/21/2018 0.25 INTRMI CASING OWFF P Monitor well. Static. Function rams. 615.0 615.0 04:45 0500 9/21/2018 9/21/2018 1.25 INTRMI CASING PMPO P Attempt to POOH. Swabbing. Pump 615.0 1910 05:00 06:15 OOH from, 615' MD to 193' MD. 500 gpm, 650 psi. 9/21/2018 9/21/2018 2.251NTRM1 CASING BHAH P Blow down TD. Lay down BHA as per 193.0 0.0 06:15 08:30 Baker DD. Calc disp=98.54 bbls Act disp=356.5 bbls for trip. 9/21/2018 9/21/2018 0.50 INTRMI CASING WWWH P Make up stack washing tool. Flush 0.0 0.0 08:30 09:00 stack. 15 bpm, 250 psi, 20 rpm, 1.5k tq. 9/21/2018 9/21/2018 0.50 INTRMI CASING SHAH P Blow down mud line. Clean and clear 0.0 0.0 09:00 09:30 rig floor. 9/21/2018 9/21/2018 0.50 INTRMI CASING BOPE P Drain BOPE. Pull wear ring and set 0.0 0.0 09:30 10:00 test plug. 9/21/2018 9/21/2018 1.50 INTRMI CASING BOPE P PJSM-Change out upper pipe rams to 0.0 0.0 10:00 11:30 9 5/8". Sim -ops/ Mobilize CRT, bail extensions and elevators to rig floor and rig up. Page 7131 Report Printed: 10/25/2018 Operations Summary (with Timelog Depths) MT6-06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Tme End Time Cur (h0 Phase Op Code Activit' Coda Time P -T -x Operation start Depth (%(B) End Depth(WEI) 9/21/2018 9/21/2018 1.00 INTRMI CASING BOPE P Set test plug. Rig up test equipment. 0.0 0.0 11:30 1230 Test annular preventer to 250/2500 psi and upper pipe rams to 250/3500 psi. Low pressure tests were for 5 minutes each and high pressure tests were for 10 minutes each. 9/21/2018 9/21/2018 0.50 INTRMI CASING RURD P Pull test plug, set thinwall wear ring. 0.0 0.0 12:30 13:00 9/21/2018 9/21/2018 0.50 INTRMI CASING RURD P Rig up to run 9 5/5" casing. 0.0 0.0 13:00 13:30 9/21/2018 9/21/2018 6.50 INTRMI CASING PUTB P PJSM-Make up shoe track. Thread 0.0 2,565.0 13:30 20:00 lock to pin of #5. Pump through shoe track and check floats. Good. Continue to pick up and RIH with 9 5/8" 40# TXP-HS casing to 2565' MD as per detail.Observe loss of SO weight. PU wt 150k SO wt120k. 9/21/2018 9/21/2018 0.50 INTRMI CASING CIRC P Break circulation. Wash down from 2,565.0 2,585.0 20:00 20:30 2565' MD to 2577' MD. Stage up to 4.5 bpm 300 psi while working pipe. Attempt to wash past 2577' MD multiple times. Turn pipe 90° right and wash down to 2585' MD. 9/21/2018 9/21/2018 3.00 INTRMI CASING PUTB P Continue to pick up and RIH with 9 2,585.0 4,038.0 20:30 2330 5/8" 40# TXP-HS casing from 2585' MD to 4038' MD as per detail. 9/21/2018 9/22/2018 0.50 INTRMI CASING CIRC P CBU. Stage pump up to 6 bpm. 160 4,038.0 4,038.0 23:30 0000 psi. Reciprocate from 4038' MD to 3997' MD. PU wt 175k SO wt 150k. Heaviest mud weight out 10.7 ppg. 9/22/2018 9/22/2018 0.50 INTRMI CASING CIRC P CBU. 160 psi. Reciprocate from 4038' 4,038.0 4,038.0 00:00 0030 MD to 3997' MD. PU wt 175k SO wt 150k. Heaviest mud weight out 10.7 pp9 9/22/2018 9/22/2018 4.75 INTRM1 CASING PUTB P Continue to pick up and RIH with 9 4,038.0 6,507.0 00:30 0515 5/8" 40# TXP-HS casing from 4038' MD to 6507' MD as per detail. PU wt 240k SO wt 185k 9/22/2018 9/22/2018 2.00 INTRMI CASING CIRC P CBU 1 1/2x. 270 psi. Reciprocate 6,507.0 6,057.0 05:15 07:15 from 6507' MD to 6467' MD. PU wt 240k SO wt 195k. Heaviest mud weight out 10.6+ ppg. 9/22/2018 9/22/2018 7.75 INTRMI CASING PUTB P Continue to pick up and RIH with 9 6,057.0 10,278.0 07:15 1500 5/8" 40# TXP-HS TN80, TXP L80 and HYD 563 L80 casing from 6507' MD to 10278' MD as per detail. 254 jts in hole plus X -O and pup jt. SO wt 225k 9/22/2018 9/22/2018 0.75 INTRMI CASING HOSO P Make up hanger and landing joint, 10,278.0 10,316.0 15:00 1545 wash down @ 1.5 bpm, 340 psi. Land hanger and stay landed. (Note, very tight tolerances through stack and thin wall wear ring, Reciprocation would be very risky) Final SOW=225k. 9/22/2018 9/22/2018 4.25 INTRMI CEMENT CIRC P Circulate and condition mud for 10,316.0 10,316.0 15:45 20:00 cementing. Stage pump up from 1.5 bpm 340 psi to 8 bpm 400 psi. Heaviest mud weight out 10.8 ppg. 9/22/2018 9/22/2018 0.50 INTRMI CEMENT RURD P Shut down, OWFF static. Blow down 10,316.0 10,316.0 20:00 20:30 top drive, remove mud saver valve from Volant CRT. Rig up cement hose and 1502 equipment to cement line. Page 8131 Report Printed: 10/25/2018 Operations Summary (with Timelog Depths) MT6-06 %0 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Time End Time Dur (h) Phase Op Code Activity Code Time P -T -x Operelion Stan Depth (9KB) End Depth(ftKB) 9/22/2018 9/22/2018 1.50 INTRMI CEMENT CMNT P SLB flood lines with 5 bbl water. 10,316.0 10,316.0 20:30 22:00 Pressure test to 4000 psi, good. SLB pumped 60 bbl 11.5 ppg mud push. Shut down and drop bottom plug. Mix and pump 39.4 bbl 12.2 ppg lead cement @ 3.7-4.7 bpm. Mix and pump 53 bbls 15.8 ppg tail cement @ 2.5- 4.2 bpm. Shut down and drop NR top plug and HE top plug. Kick out with 20 bbl water. 9/22/2018 9/23/2018 2.00 INTRMI CEMENT CMNT P Rig displace cement with 10.4 ppg 10,316.0 10,316.0 22:00 0000 LSND @ 8 bpm, ICP=430 psi, FCP @ 8 bpm=880 psi. Slowed pump to 3 bpm, 600 psi @ 7230 stks away. Bump plugs at 7491 stks. Pressure up to 1100 psi and hold for 5 mins. Bleed off and check floats. Good. CIP at 23:34 hrs 9/23/2018 9/23/2018 0.50 INTRMI CEMENT OWFF P Monitor well. Static. Sim-ops/Rig down 10,316.0 10,316.0 00:00 00:30 CRT 9/23/2018 9/23/2018 0.50 INTRMI CEMENT RURD P Lay down landing joint. Drain BOPE. 10,316.0 0.0 00:30 01:00 9/23/2018 9/23/2018 2.00 INTRMI CEMENT WWSP P Pull thin wall wear ring. Set 9-5/8" 0.0 0.0 01:00 03:00 packoff and test to 5000 psi for 10 minutes, CPAI witnessed - good. 9/23/2018 9/23/2018 2.50 INTRM1 CEMENT NUND P PJSM-Lay down mousehole Lay down 0.0 0.0 03:00 05:30 trip nipple, rig down flow box, turnbuckles, mud bucket lines, bleeder and hole fill line. Break choke connection. Rig down MPD package. Break BOPE/wellhead connection. 9/23/2018 9/23/2018 3.50 INTRMI CEMENT NUND P Nipple up 7" casing spool and BOPE. 0.0 0.0 05:30 09:00 Reposition grease flanges on wellhead as per FMC. 9/23/2018 9/23/2018 1.00 INTRMI CEMENT RURD P PJSM-Change out upper pipe rams to 0.0 0.0 09:00 10:00 4 1/2" x 7" VBR's 9/23/2018 9/23/2018 3.50 INTRMI CEMENT NUND P Continue to rig up flow line, flow box, 0.0 0.0 10:00 13:30 mud bucket lines, trip nipple, service lines and MPD lines. Secure drip pan. Install mouse hole. Rig up test equipment. Sim-ops/Rig up circ lines for annular LOT. Perform flush and freeze protect.. Pump 10.5 bbls water for LOT. Flush annulus with 300 bbls water follwed by 85 bbls diesel for freeze protect. 9/23/2018 9/23/2018 1.00 INTRMI WHDBOP RURD P Set test plug. Rig up to test BOPE, fill 0.0 0.0 13:30 14:30 stack, choke,. kill lines and choke manifold with water. Purge air from system. Page 9/31 Report Printed: 10/25/2018 Operations Summary (with Timelog Depths) MT6-06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Stan Depth (rtKB) End Dept (fiKB) 9/23/2018 9/23/2018 5.50 INTRM7 WHDBOP BOPE P Perform BOPE test. with 4", 5" and 7" 0.0 0.0 14:30 20:00 test joints. 250 psi low/3500 psi high.Test #1 w/ 5" TJ -Upper 4 1/2" x 7" VBR, Kill line demco, CV's 1,12,13,14 for 5 min low/10 min high. Test #2- Kill HCR, CV's 9,11,manual IBOP for 5 min low/5 min high. Test #3-5" dart, CV's 5,8,10. 5 min low/5 min high.Test #4-5" FOSV, CV's 4,67. 5 min low/5 min high. Test #5 -CV 2 5 min law/5 min high. Test #6 -Choke HCR. 5 min low/5 min high. Test #7 -Choke and kill manual valves. 5 min low/5 min high. Test #8- Lower 3 1/2" x 6" VBR's. 5 min low/5 min high. Following tests with 4:" test joint and 5 min low/10 min high except annular. Test #9 -Annular 250 low/2500 high.. Test #10 -Lower 3 1/2" x 6" VBR.250 low/3500 high Following tests with 7" test jt. Test #11 - Annular. 250 low/2500 high. Test #12 - Upper 4 1/2" x 7" VBR. 250 low/3500 high. Test #13 -Blind rams 5 min low/5 min high. 250 low/3500 high.Test #14 - Manual choke drawdown to 1100 psi. Test #15- Hydraulic choke drawdown to 1100 pis. Accumulator test -System pressure=2950 psi, After closure=1450 psi. 200 psi attained=34 sec. Full system recovery=169 sec. Four N2 bottles at 2125 psi. Gas alarms and PVT system tested. Test waived by AOGCC rep Jeff Jones and BUM rep Mutasim Elganzoory. 9/23/2018 9/23/2018 1.00 INTRM7 WHDBOP KURD P Pull test plug, set wear ring, blow 0.0 0.0 20:00 1 21:00 down and rig down test equipment. 9/23/2018 9/23/2018 0.50 INTRMI CEMENT BHAH P Mobilize clean out BHA to rig Floor. 0.0 0.0 21:00 21:30 9/23/2018 9/23/2018 1.00 INTRMI TTEMENT CEMENTBHAH P PJSM-Make up 8 3/4" motor cleanout 0.0 400.0 21:30 2230 BHA#3 9/23/2018 9/24/2018 1.50 INTRMI CEMENT TRIP P RIP with clean out BHA#3 from 400' 400.0 2,481.0 22:30 0000 MD to 2481' MD. PU wt 112k SO wt 100k g/24/2018 9/24/2018 4.00 INTRMI CEMENT TRIP P RIH with clean out BHA#3 from 2481' 2,481.0 10,003.0 00:00 04:00 MD to 10003' MD. PU wt 260k SO wt 155k. Fill pipe every 20 stds. 9/24/2018 9/24/2018 1.50 INTRM1 CEMENT PRTS P Rig up for casing test. Test casing to 10,003.0 10,003.0 04:00 05:30 3500 psi for 30 minutes charted, good. 9/24/2018 9/24/2018 1.00 INTRMI CEMENT PC P Slip and cut 45' drilling line. 10,003.0 10,003.0 05:30 06:30 018 9/24/2018 0.50 INTRM1 CEMENT SVRG P Service top drive, block and draworks. 10,003.0 10,003.0 06:30 06:30 07:00 9/24/2018 9/24/2018 1.00 TNT RMI CEMENT COCF P Wash down w/o rotation @ 400 gpm, 10,003.0 10,185.0 07:00 08:00 1100 psi tag plugs on depth @ 10,185' MD. 9/24/2018 9/24/2018 4.50 INTRMI CEMENT DREG P Drill plugs, Float collar, shoe track, 10,185.0 10,326.0 08:00 12:30 shoe and rathole from 10,185' MD to 10,326' MD, 420-600 gpm, 1150-2060 psi, 40-80 rpm, 17-22k Tq. PU wt=260k SO wt=150k Rot wt=192k. Tag up on shoe on depth @ 10,313' MD. Page 10/31 Report Printed: 10/2512018 AIM, Operations Summary (with Timelog Depths) MT6-06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Sart Time End Time Dur (hr) Phase Op Cotle Activity Cotle Time P -T-% Operation Start Depth (ftKB) End Depth htK8) 9/24/2018 9/24/20181.50 INTRM1 CEMENT DDRL P Drill 20' new formation from 10,326' 10,326.0 10,346.0 12:30 14:00 MD to 10,346' MD, 7,266' MD. 500 gpm, 1470 psi, 60 rpm, 10k tq. SIMOPS- Condition mud with product and weight up to 10.8 ppg on the fly. 9/24/2018 9/24/2018 0.50 INTRMI CEMENT BKRM P BROOH from 10346' MD to 10286' 10,346.0 10,286.0 14:00 14:30 MD. 500 gpm, 1470 psi, 60 rpm. 9/24/2018 9/24/2018 0.50 INTRMI CEMENT FIT P R/U test equipment, perform FIT to 10,286.0 10,286.0 14:30 15:00 14.0 ppg EMW. 3.2 bbl pumpetl, 1210 psi. Bleed off, blow down and rig down. 9/24/2018 9/24/2018 0.50 INTRM2 DRILL REAM P Obtain SPR's, wash and ream down 10,286.0 10,346.0 15:00 15:30 from 10,286' MD to 10,346' MD @ 500 gpm, 1450 psi, 60 rpm, 10k tq, 0-4k WOB. 9/24/2018 9/24/2018 2.25 INTRM2 DRILL DDRL P Drill from 10,346' MD to 10,400' MD, 10,346.0 10,400.0 15:30 17:45 7,303' TVD. ADT=1.9 hrs. 550 gpm, 1850 psi, 60 rpm, 10k tq, 20-25k WOB, P/U=250k, S/0=150k, ROT=190k, Tq off=8k. 9/24/2018 9/24/2018 1.75 INTRM2 CSGDRL BKRM P BROOH from 10400' MD to 10312' 10,400.0 10,286.0 17:45 1930 MD. Reamdown from 1 0312'MD to 10400' MD. 600 gpm, 1750 psi, 60 rpm, 9-10k tq. Pump out from 10400' MD to 10286' MD. 600 gpm, 1700 psi, . PU wt=225k. CBU while pumping out. 9/24/2018 9/24/2018 0.50 INTRM2 CSGDRL OWFF P Monitor well. Static. 10,286.0 10,286.0 19:30 2000 9/24/2018 9/25/2018 4.00 INTRM2 CSGDRL TRIP P Drop 2 1/2" hollow drift. POOH on 10,286.0 4,370.0 20:00 0000 elevators from 10286' MD to 4370' MD following trip schedule. Pump dryjob at 9814' MD. PU wt=145k SO wt=132k Calc disp=43 bbls Act disp=43 bbls 9125/2018 9/25/2018 1.50 INTRM2 CSGDRL TR -IPP- POOH on elevators from 4370' MD to 4,370.0 490.0 00:00 01:30 490' MD following trip schedule. 9/25/2018 9/25/2018 0.25 INTRM2 CSGDRL OWFF P Monitor well. Static. 490.0 490.0 01:30 01:45 9/25/2018 9/25/2018 1.50 INTRM2 CSGDRL BHAH P PJSM-POOH and lay down BHA as 490.0 0.0 01:45 0315 per Baker DD. 9/2512018 9/25/2018 0.50 INTRM2 CSGDRL BHAH P Clean and clear rig floor 0.0 0.0 03:15 03:45 9/25/2018 9/25/2018 1.00 INTRM2 CSGDRL BHAH P Mobilize BHA components to rig floor. 0.0 0.0 03:45 0445 9/25/2018 9/25/2018 3.75 INTRM2 CSGDRL BHAH P Make up stop sub, back up steering 0.0 0.0 04:45 0830 head to backup D505T bit. Lay down same to shed. Make up primary lower BHA#4 (AutoTrak steering head, OnTrak, SDN, CoPilot, GaugePro) per DD/MWD and stand back in derrick. 9/25/2018 9125/2018 1.00 INTRM2 CSGDRL KURD P Mobilize SDL tools to rig floor. 0.0 0.0 08:30 09:30 9/25/2018 9/25/2018 1.50 INTRM2 CSGDRL SEQP P Break long and short kick stands to 0.0 0.0 09:30 11:00 250 psi for 5 mins and 3500 psi for 10 mins each. Store in ready positions. 9/25/2018 9/25/2018 2.00 INTRM2 CSGDRL RURD P Rig up casing running equipment. 0.0 0.0 11:00 13:00 1 1 1 1 1 1 Perform dump test on tongs. Page 11/31 ReportPrinted: 10/25/2018 Operations Summary (with Timelog Depths) MTS -06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log 8Time End Time Dur( Phase Op Code Gotle Activity Code Time P -T -X Operation Depth (ftKB) End Dept(ftKB) 9/25/212 018 9125/2018 3.0.0 0 INTRM2 CSGDRL PUTB P PJSM, P/U and run 7" Tenaris Blue 0.0 2,277.0 13:00 16:00 liner M/U 32# Reamer shoe and 29 joints 26# L-80 TN Blue with crimped on Hydroform centralizers per detail to 2254' MD. Make up lower 7" quick connect to 2277' MD. Torque turn connections to 15,000 ft/lbs with Seal Guard ECF dope. S/0=86k 9/25/2018 9/25/2018 0.75 INTRM2 CSGDRL RURD P Clean and clear rig floor of casing 2,277.0 0.0 16:00 16:45 tools. Rig up work platform and false table. 9/25/2018 9/25/2018 1.25 INTRM2 CSGDRL BHAH P PJSM-RIH w/inner string rotary 0.0 180.0 16:45 18:00 steerable BHA to 50' MD. Load nuclear sources. Continue to RIH to smart battery sub @ 166' MD. Plug in and verify comms. Continue to make up BHA to 180' MD. 9/25/2018 9/25/2018 1.00 INTRM2 CSGDRL TRIP P RIH with BHA on 4" 14# DP. 180.0 2,363.0 18:00 19:00 9/25/2018 9/25/2018 0.50 INTRM2 CSGDRL HOSO P No-go for space out, set down 5k, lay 2,342.0 2,342.0 19:00 19:30 down single jt DP and pick up pup jt. 2333.52' DP (68 jts 4" DP) + 9,30' pup jt=2342.82 9/25/2018 9/25/2018 0.50 INTRM2 CSGDRL HOSO P M/U liner running tool as per Baker 2,342.0 2,363.0 19:30 20:00 reps to 2363' MD. PU wt=135k SO wt=130k R/D false bowl and work platform. 9/25/2018 9/25/2018 0.50 INTRM2 TSGDRL CSGDRLBHAH P M/U flow diverter, string stabilizer, 2,363.0 2,396.0 20:00 20:30 sensor sub and flapper float to 2,396' MD, 9/25/2018 9/25/2018 0.25 INTRM2 CSGDRL TRIP P RIH w/SDL on 5" DP from 2396' MD to 2,396.0 2,865.0 20:30 20:45 2,865' MD. 9/25/2018 9/25/2018 0.25 INTRM2 CSGDRL DHEO P Shallow test MWD @ 270 gpm, 1600 2,865.0 2,865.0 20:45 21:00 psi with flow diverter closed. 550 gpm=1900 psi with diverter open. 9/25/2018 9/26/2018 3.00 INTRM2 CSGDRL TRIP P RIH w/SDL on 5" DP from 2,865' MD 2,865.0 6,650.0 21:00 00:00 to 6650' MD. Fill pipe every 20 stds. PU wt=185k SO wt=132k Calc disp=59 bbls Act disp=55 bbls 9/26/2018 9/26/2018 2.25 INTRM2 CSGDRL TRIP P RIH w/SDL on 5" DP from 6650' MD to 6,650.0 10,117.0 00:00 0215 10117' MD. Fill pipe every 20 stds. PU wt=277k SO wt=80k 9/26/2018 9/26/2018 0.50 INTRM2 CSGDRL —NTP—DA P Remove trip nipple and install RCD 10,117.0 10,117.0 02:15 02:45 bearing. 9/26/2018 9/26/2018 1.00 INTRM2 CSGDRL WASH P Break circulation. 100 gpm„ 600 psi. 10,117.0 10,400.0 02:45 03:45 RIH from 10117' MD to 10308' MD. Wash down from 10308' MD to 10400' MD. 9/26/2018 9/26/2018 0.75 INTRM2 CSGDRL MPDA P Obtain survey. Break in RCD bearing. 10,400.0 10,400.0 03:45 04:30 250 gpm, 1560 psi, 30 rpm, 13k tq. PU wt=277k SO=185k Rot wt=220k. Begin reducing mud weight to 10.3 ppg 9/26/2018 9/26/2018 7.50 INTRM2 CSGDRL DCSG P Drill from 10,400' MD to 10,566' MD @ 10,4000 10,566.0 04:30 12:00 575 gpm, 2310 psi, 40 rpm, 15k Tq. 2- 4k WOB. Open underreamer at 10470' MD and flow diverter at 10491' MD. Pump at 290 gpm, 2200 psi until diverter opened. Maintain 11.56 ppg EMW with MPD on connections. Page 12131 ReportPrinted: 10/25/2018 D Operations Summary (with Timelog Depths) MT6-06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Time End Time Dw(hr) Phase Op Cotle Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth(RKB) 9/26/2018 9/27/2018 12.00 INTRM2 CSGDRL DCSG P Drill from 10,566' MD to 10,972' MD @ 10,566.0 10,972.0 12:00 0000 560 gpm, 2400 psi, 40 rpm, 16k Tq on 14k tq off. 2-8k WOB. ADT=10.4 his. Rot wt=224k. ECD=11.55 Maintain 11.5 ppg EMW with MPD on connections. 9/27/2018 9/27/2018 12.00 INTRM2 CSGDRL DCSG P Drill from 10972' MD to 11423' MD 10,972.0 11,423.0 00:00 12:00 7832' ND@ 560 gpm, 2300 psi, 40 rpm, 14.5k tq on 15.5k tq off. 2-3k WOB. ADT=11.1 hrs. Rol wt=220k. ECD=11.5 Maintain 11.5 ppg EMW with MPD on connections. 9/27/2018 9/28/2018 12.00 INTRM2 CSGDRL DCSG P Drill from 11423' MD to 11811' MD 11,423.0 11,811.0 12:00 00:00 7976' TVD@ 580 gpm, 2450 psi, 40 rpm, 16k tq on 15k tq off. 2-9k WOB. ADT=10.5 hrs. Rot wt=225k. ECD=11.46 Maintain 11.5 ppg EMW with MPD on connections. 9/28/2018 9/28/2018 5.00 INTRM2 CSGDRL DCSG P Drill from 11811' MD to 11912' MD 11,811.0 11,912,5- 00:00 0500 8004' TVD@ 580 gpm, 2320 psi, 40 rpm, 15k tq on 14.5k tq off. 4-5k WOB. ADT=4.6 hrs. Rot wt=220k. ECD=11.5 Maintain 11.5 ppg EMW with MPD on connections. Close underreamer at 11898' bit depth, drill 14' with underreamer closed. 9/28/2018 9/28/2018 1.00 INTRM2 CSGDRL CIRC T Circulate OH x liner volume x3. 580 11,912.0 11,912.0 05:00 0600 gpm, 2320 psi, 40 rpm, 15k tq, Rot wt=225k. 9/28/2018 9/28/2018 1.25 INTRM2 CSGDRL CIRC T Close flow diverter. Decision made to 11,912.0 11,912.0 06:00 0715 continue to circulate with diverter open. Open diverter. Circulate at 580 gpm, 2290 psi, 40 rpm, 16k to. Pump 20 bbls 10.6 ppg mud for weight up. Suspend weight up due to decision made to drill another 30'. 9/28/2018 9/28/2018 3.75 INTRM2 CSGDRL DCSG T Attemp to open under reamer while 11,912.0 11,912.0 07:15 11:00 drilg from 11912' MD to 11914 MD. Immediately stall motor as underreamer opened in 6" hole. Stop pumps and release trapped torque as per procedure. Pick up and breakover string at 320k. PU w1=290k. Start pumping at 1500 gpm, 1000 psi. Establish rotary at 40 rpm. Observe motor stall with torque at 25k. Release torque as per procedure. Pick up to 350k without breakover. Slack off to 225k neutral wt. Break circulation with diverter closed 300 gpm, 2000 psi. Pressure increassed to 3000 psi indicating motor stall. Rot wt=205k, 40 rpm, 22k tq. Release torque as per procedure. Pick up to 11897' MD. Regain circulation and open diverter. 600 gpm, 2500 psi, 40 rpm, 15.5k tq 9/28/2018 9/28/2018 0.25 INTRM2 CSGDRL REAM P Ream down to 11914' MD with 11,912.0 11,914.0 11:00 11:15 underreamer closed 9/28/2018 9/28/2018 3.25 INTRM2 CEMENT CIRC P Weight up from 10.3 ppg to 10.8 ppg. 11,914.0 11,914.0 11:15 14:30 600 to 360 gpm and 2500 to 1210 psi while maintaing 11.5 ppg EMW. Page 13/31 ReportPrinted: 1 012 5/2 01 8 Operations Summary (with Timelog Depths) MT6-06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Adryity Code Time P -T-% Operation Start Depth (flKB) End DBpm(flKB) 9/28/2018 9/28/2018 0.50 INTRM2 CEMENT CIRC P Drop 1.75" bronze ball. Slack off to 11,914.0 11,914.0 14:30 1500 180k. Pump ball down at 2 bpm 650 psi, Ball on seat at 662 Mks. Slack of to 160k. Pressure up to 3640 psi to shear ball off seat. Circulate at 1.5 bpm, 500 psi. 9/28/20189/28/2018 1.75 INTRM2 CEMENT PMPO P Pump OOH from 11914' MD to 11895' 11,914.0 11,811.0 15:00 16:45 MD. 1.5 bpm, 540 psi, PU wt=260k SOwt=170k. At 11895' MD observed overpull to 300k. Increase pump rate to 220 gpm, 1480 psi and attempt to pull into 7" liner x3. Overpull to 300k and pressure increase each time. Slack off and free travel oberved seen at 230k. Continue to attempt to pull into liner observing overpulls and pressure increases with 300 gpm, 2300 psi and overpulls with no pump. Unable to obtain free travel down. Pick up to 200k and break over with rotation at 9.5k to. Pull up into liner with 1 bpm, 460 psi. Pull to 11811' MD. 9/28/2018 9/28/2018 0.50 INTRM2 CEMENT OWFF P Monitor well. Static. Blow down TD. 11,811.0 11,811.0 16:45 17:15 Line up to SOOH 9/28/2018 9/28/2018 6.50 INTRM2 CEMENT SMPD P SOOH as per trip schedule from 11,811.0 2,581.0 17:15 23:45 11811' MD to 2581' MD 9/28/2018 9/29/2018 0.25 INTRM2 CEMENT OWFF P Monitor well. Static. Sim-ops/Hold 2,581.0 2,581.0 23:45 00:00 PJSM on BHA handling 9/29/2018 9/29/2018 0.50 INTRM2 CEMENT MPDA P Remove RCD bearing. Install trip 2,581.0 2,581.0 00:00 00:30 nipple. 9/29/2018 9/29/2018 0.50 INTRM2 CEMENT TRIP P POOH racking back 5' DP from 2581' 2,581.0 2,396.0 00:30 01:00 MD to 2396' MD. 9/29/2018 9/29/2018 1.00 INTRM2 CEMENT BHAH P POOH from 2,396' MD to 2,342' MID 2,396.0 2,342.0 01:00 02:00 Lay down float sub, stab, flow-diverier and liner running tools as per Baker 9/29/2018 9/29/2018 1.00 INTRM2 CEMENT TRIP P POOH racking back 4" DP from 2,342' 2,342.0 179.0 02:00 03:00 MD to 179' MD 9/29/2018 9/29/2018 0.50 INTRM2 CEMENT OWFF P Monitor well. Slight ddrop. Sim- 179.0 179.0 03:00 03:30 ops/PJSM on laying down BHA. 9/29/2018 9/29/2018 2.00 INTRM2 CEMENT BHAH P Lay down BHA as per Baker DD and 179.0 0.0 03:30 0530 MWD. Remove nuclear sources. 9/29/2018 9/29/2018 1.00 1 INTRM2 CEMENT BHAH P Pick up back up steering head . Break 0.0 0.0 05:30 0630 off bit and lay back down. 9/29/2018 9/29/2018 0.75 INTRM2 CEMENT BHAH P Clean and clear rig floor of BHA tools. 0.0 0.0 06:30 07:15 Mobilize cementing assy tools to rig floor. 9/29/2018 9/29/2018 1.75 INTRM2 CEMENT TRIP PJSM - MU cement retainer and RIH 0.0 2,213.0 07:15 09:00 to 2,213' MD. 9/2912018 9/29/2018 1.50 INTRM2 CEMENT PUTB P PJSM - MU seal assembly, SLZXP 2,213.0 2,264.0 09:00 1030 and space -out pups from 2,213' MD to 2,264' MD. 9/29/2018 9/29/2018 0.25 INTRM2 CEMENT TRIP P RIH w/5" DP from 2264' MD to 2450' 2,264.0 2,450.0 1030 1045 MD. 9/29/2018 9/29/2018 0.50 INTRM2 CEMENT CIRC P Circulate 1 string volume at 3 bpm 170 2,450.0 2,450.0 10:45 11:15 psi. PUW/SOW = 89k 9/29/2018 9/29/2018 4.00 INTRM2 CEMENT TRIP P RIH from 2,450' MD to 9,514' MD. 2,450.0 9,514.0 11:15 15:15 9/29/2018 9/29/2018 0.75 INTRM2 CEMENT WASH P Break circulation. Stage pump up to 3 9,514.0 9,702.0 15:15 16:00 bpm. Wash down from 9514' MD to 9702' MD at 3 bpm390-410 psi. Blow down TD. Page 14131 Report Printed: 10/25/2018 r Operations Summary (with Timelog Depths) MT6-06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Time End Time Our (hr) Phase Op Code ggivily Code Time P -T -X Operation Start Depth (ftKB) End Depth (WB) 9/29/2018 9/29/2018 1.25 INTRM2 CEMENT TRIP P RIH from 9702' MD to 11490' MD. 9,702.0 11,490.0 16:00 17:15 9/2912018 9/29/2018 1.25 INTRM2 CEMENT W ASH P Establish circulation and rates. 1 11,490.0 11,774.0 17:15 1830 bpm=360 psi, 2.5 bpm=500 psi.Wash down from 11490' MD to 11774' MD at 1 bpm, 370-400 psi. PU wt=230k SO wt=170k 9/29/2018 9/29/2018 0.50 INTRM2 CEMENT RURD P Make up cement swivel and 14' pup it. 11,774.0 11,774.0 18:30 1900 9/29/2018 9/29/2018 0.25 INTRM2 CEMENT HOSO P Wash down at 1 bpm,390 psi. 11,774.0 11,774.0 19:00 19:15 Observe pressure increase of 40 psi when entering seals at 11779' MD. Shut down pump. Slack off and no-go at 11 784'MD. Set down 30k. Pick up 30k over to confirm latch. Set down -1 10k. 9/29/2018 9/29/2018 25 INTRM2 CEMENT CIRC P Stage pumps in 0.5 bpm increments to 11,774.0 11,774.0 19:15 20:30 2.5 bpm: 0.5 bpm = 350, psi 1.0 bpm = 404 psi, 1.5 bpm=440 psi. 2 bpm=490 psi 2.5 bpm=562 9/29/2018 9/29/2018 1.25 INTRM2 CEMENT CIRC P Monitor well. Static. Drop 1.75" bronze 11,774.0 11,764.0 20:30 21:45 ball and pump down at 2 bpm, 520 psi. Ball on seat at 440 stks. Increase pressure to 4000 psi and hold for 1 minute. Bleed off to 500 psi and hold. Observe pressure drop after 7 1/2 mins. Pick up and break over with 230k to release from liner. Set K-1 retainer as per Baker Rep. Pick up to PU wt + 10'. Rotate 15 turns to the right w/7k tq. Slack off 2'. Pull 25k over and set down 25k x3. Pick up to 215k and rotate to right w/7k tq while picking up to shear out of retainer. Top of retainer set at 11767' MD. 9/29/2018 9/29/2018 1.50 INTRM2 CEMENT CIRC P CBU at 8 bpm 1260-1170 psi. 11,764.0 11,764.0 21:45 2315 -0 9/29/2018 9/30/2018 75 INTRM2 CEMENT CIRC P Sting into retainer and set down 25k. _711 76-70 11,767.0 23:15 0000 Stage pumps in 0.5 bpm increments to 2 bpm:370 psi. 9/30/2018 9/30/2018 0.75 INTRM2 CEMENT CIRC P Stage pump up to 2.5 bpm, 470 psi. 11,767.0 11,767.0 00:00 0045 Sim-ops/Hold PJSM on cementing 9/30/2018 9/30/2018 3.00 INTRM2 CEMENT CMNT P Flood lines with 2 bbls water. Test 11,767.0 11,767.0 00:45 0345 lines to 4000 psi (Good). Pump 20 bbls 11.5 ppg mud push., 55 bbls 15.8 ppg cement, 20 bbls water. Displace with 163.3 bbls of 10.8 ppg LSND with rig pump (1620 stks). Complete job pumped at 2 bpm until 112 bbls of displacement pumped then reduce rate to 1 bpm. CIP @ 03:40 his. 018 9/30/2018 0.25 INTRM2 CEMENT PACK P Set packer as per Baker. Pick up to 11,767.0 11,734.0 03:45 03:45 04:00 230k. Expose dog sub, SO to 140k 2x. Pick up to 230k. Rotate at 15 rpm, &A tq. Slack off to 1901k 2x. Confirm packer set. 9/30/2018 - 9/30/2018 1.50 INTRM2 CEMENT CIRC P Pump 20 bbls water at 3.7 bpm, 800 11,734.0 11,734.0 04:00 05:30 psi. followed by 10.8 ppg _SND at 12 bpm, 2500 psi. Reciprocate from 11734' MD to 11714' MD. PU wt=220k SO wt -170k. 9/30/2018 9/30/2018 0.50 INTRM2 CEMENT OWFF P Monitor well. Static. Lay down cement 11,734.0 11,734.0 05:30 0600 head and pup it. Blow down lines. 9/30/2018 9/30/2018 1.75 INTRM2 CEMENT TRIP P POOH from 11 734'MD to 9608' MD. 11,734.0 9,608.0 06:00 07:45 Page 15131 ReportPrinted: 10/25/2018 Operations Summary(with Timelog Depths) MT6-06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur(hr) Phase Op Code I Acbvity Code Time P-T-X Operation Stan Depth (ftKa) End Dear(ftKa) 9/30/2018 9/30/2018 0.50 INTRM2 CEMENT CIRC P Break circulation. 500 gpm, 1660 psi. 9,608.0 9,514.0 07:45 08:15 Wask liner sealing area from 9608' MD to 9514' MD. PU wt=190k SO wt=148k. Sim-ops/PJSM on slip and cut drilling line. 9/30/2018 9/30/2018 1.25 INTRM2 CEMENT CIRC P CBU. 500 gpm, 1560 psi. Reciprocate 9,514.0 9,514.0 08:15 09:30 from 9514' MD to 9419' MD. OWFF. Static. Pump 30 bbls dryjob. Blow down TD and mudlines. 9/30/2018 9/30/2018 0.50 INTRM2 CEMENT SLPC P Slip and cut 51' drilling line. 9,514.0 9,514.0 09:30 1000 9/30/2018 9/30/2018 0.50 INTRM2 CEMENT SVRG P Service top drive, blocks and 9,514.0 9,514.0 10:00 1030 drawworks. Calibrate block height. 9/30/2018 9/30/2018 6.25 INTRM2 CEMENT PULD P POOH laying down 5" DP on trip tank 9,514.0 2,264.0 10:30 1645 from 9,514' MD to 2,264' MD while checking and cleaning cement rings (became more substantial from std #27) 9/30/2018 9/30/2018 0.25 INTRM2 CEMENT OWFF P Monitor well. Static. Function upper 2,264.0 2,264.0 16:45 17:00 and lower pipe rams. 9/30/2018 9/30/2018 2.75 INTRM2 CEMENT TRIP P Lay down liner packer running tools. 2,264.0 0.0 17:00 19:45 POOH with 4" DP. Check and clean cement rings every connection. 9/30/2018 9/30/2018 0.25 INTRM2 CEMENT BHAH P Lay down retainer running tool and 0.0 0.0 19:45 20:00 pupjts. 9/30/2018 9/30/2018 0.50 INTRM2 CEMENT BHAH P Clean and clear rig floor. 0.0 0.0 2000 20:30 9/30/2018 9/30/2018 0.50 INTRM2 CEMENT PRTS P RU and test 7" liner top packer to 0.0 0.0 20:30 21:00 1,000 psi for 10 minutes on chart. RD test equipment 9/30/2018 9/30/2018 0.50 INTRM2 CEMENT RURD P Pull wear ring as per FMC and blow 0.0 0.0 21:00 21:30 down kill line 9/30/2018 9/30/2018 2.25 INTRM2 CEMENT RURD P RU to run 7" 26# L-80 BTCM/H563 tie 0.0 0.0 21:30 23:45 back 9/30/2018 10/1/2018 0.25 INTRM2 CEMENT PUTB P Pick up Baker 7" tie back seal assy. 0.D 0.0 23:45 00:00 j 10/1/2018 10/1/2018 0.25 INTRM2 CEMENT PUTB P Make up Baker 7" seal assy as per 0.0 20.0 00:00 00:15 Baker Rep. 10/1/2018 1011/2018 9.75 INTRM2 CEMENT PUTB P Pick up and RIH w/ 7" BTC-M/H563 20.0 5,350.0 00:15 10:00 liner to 5350' MD. SO wt=125k. Avg torque on BTC-M=7500 ft/Ibs. Make up H563 to 9400 fl/Ibs. 10/1/2018 10/1/2018 5.25 INTRM2 CEMENT CIRC T Make up headpin, cement hose. Break 5,350.0 5,350.0 10:00 15:15 circulation. Circulate and condition mud due to cement contamination. 1-6 bpm, 320-510 psi. Pump 27 bbl 12.8 ppg dry job. 10/1/2018 10/1/2018 1.00 INTRM2 CEMENT PUTB P Pick up and RIH wl 7" BTC-M/H563 5,350.0 5,827.0 15:15 16:15 liner from 5350' MD to 5827' MD. SO w1=127k. 10/1/2018 10/1/2018 2.25 INTRM2 CEMENT CIRC P Circulate and condition mud. Reduce 5,827.0 5,U7-0- 16:15 1830 mud weight to 10.3 ppg. 6 bpm, ICP=690 psi, FCP=360 psi. Pump 30 bbl 13 ppg dry job. 10/1/2018 10/1/2018 5.00 INTRM2 CEMENT PUTB P Pick up and RIH wl 7" BTC-M/H563 5,827.0 9,488.0 1830 2330 liner from 5827' MD to 9488' MD. PU wt=253k SO wt=160k. Calc disp=88 bbls Act disp=86.5 bbls 018 10/2/2018 0.50 INTRM2 CEMENT RURD P Rig down CRT and casing slips. 9,488.0 9,488.0 E3:3 00:00 018 1012/2018 0.50 INTRM2 CEMENT RURD P R/U head pin & cement hose. 9,488.0 9,488.0 00:30 Page 16/31 Report Printed: 10/25/2018 Operations Summary (with Timelog Depths) MT6-06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Staff Time End Time pur (hQ Phase Op Cotle Activity Code Time P -T -X Operation Stan Depth (ftKB) End Depth(ftKS) 10/2/2018 10/2/2018 2.00 INTRM2 CEMENT CIRC P M/U jt# 233. Break circ w/2 bpm. 9,488.0 9,528.0 00:30 0230 Stage rate to 6 bpm / 450 psi & circ & cond. Reduce pumps to 1 bpm / 220 psi. S/O & locate liner top @ 9,528.2' (P/U wt 242 k / SIO wt 155 k) 10/2/2018 10/2/2018 1.25 INTRM2 CEMENT HOSO P M/U space outjt # 234. Reverse circ. 9,528.0 9,547.0 02:30 03:45 S/O & no go out @ 9,547.49'w/5 k WOB. 10/2/2018 10/2/2018 0.25 INTRM2 CEMENT PRTS P Test hanger seals 01000 psi for 10 9,547.0 9,547.0 03:45 04:00 min (good) 10/2/2018 10/2/2018 2.00 INTRM2 CEMENT HOSO P LID space out jts & M/U 9.83' space 9,547.0 9,528.0 04:00 06:00 out pup. M/U hanger & landing it. Break circ w/1 bpm & locate liner top. 10/2/2018 10/2/2018 3.00 INTRM2 CEMENT CRIH P PJSM. test ball mill lines to 2500 psi. 9,528.0 9,542.0 06:00 0900 Pump 20 bbl spacer. Pump 260 bbls CI brine w/5 bpm / 890 psi & chase w/40 bbis diesel. Land on hanger @ 9,542.59' (4.9' from fully located) 10/2/2018 10/2/2018 0.50 INTRM2 CEMENT RURD P R/D circ lines & LID landing it. R/D 9,542.0 9,542.0 09:00 0930 casing running tools & equip. 10/2/2018 10/2/2018 3.25 INTRM2 CEMENT PRTS P FMC Test hanger seals 250 psi for 5 0.0 0.0 09:30 12:45 min / 5000 psi for 15 min. Ball mill test annulus 2500 psi for 30 min. SIMOPS - C/O saver sub to XT -39 10/2/2018 10/2/2018 0.75 INTRM2 CEMENT RURD P B/D & R/D lines & testing equipment. 0.0 0.0 12:45 13:30 10/2/2018 10/2/2018 2.25 INTRM2 CEMENT BOPE P C/O upper rams to 3-1/2" X 6". Test 0.0 0.0 13:30 15:45 250/3500 psi for 10 min. RID testing equip. 10/2/2018 10/2/2018 0.25 INTRM2 CEMENT RURD P Set 6.25" OD wear ring 0.0 0.0 15:45 16:00 -10/2120-18 70/2120-18 1.00 INTRM2 CEMENT SHAH P Bring BHA tools & equip to rig floor. 0.0 0.0 16:006:00 17:007:00 10/2/2018 10/2/2o18 1.75 INTRM2 CEMENT BHAH P M/U clean out BHA *5 as per Baker 0.0 240.0 17:00 18:45 reps to 240' 10/2/2018 10/2/2018 1.00 INTRM2 CEMENT PULD P RIH while picking up 4" DP f/240' to 240.0 1,407.0 18:45 19:45 1,407' 10/2/2018 10/2/2018 0.50 INTRM2 CEMENT SVRG P Service rig 1,407.0 1,407.0 19:45 20:15 10/2/2018 10/2/2018 1.75 IN TRM2 CEMENT PULD P RIH while picking up 4" DP f/1,407'to 1,407.0 2,878.0 20:15 22:00 2,878' 10/2/2018 10/2/2018 1.00 INTRM2 CEMENT RGRP T Replace hydraulic hose on irpn 2,878.0 2,878.o 22:00 23:00 roughneck. 10/2/2018 10/3/2018 1.00 INTRM2 CEMENT PULL) P RIH while picking up 4" DP f/2,878'to 2,878.0 3,838.0 23:00 00:00 3,838' 10/3/2018 10/3/2018 7.50 INTRM2 CEMENT PULD P RIH while picking up 4" DP f/3,838'to 3,838.0 11,544.0 00:00 07:30 11,544' (RIH 25 stnds out of derrick) 10/3/2018 10/3/2018 1.25 INTRM2 CEMENT PRTS P R/U testing equipment. Break circ. 11,544.0 11,544.0 07:30 08:45 Pressure test casing to 3500 psi & chart for 30 min (good). RID testing equipment. 10/3/2018 10/3/2018 7.00 INTRM2 CEMENT DRLG P Wash down & tag cement retainer @ 11,544.0 11,914.0 08:45 1545 11,767'. Drill out cement retainer, shoe track & rat hole to 11,914'w/300 gpm, 1720 psi, 50 rpm, 11.5 k trq. (Having issues with mud motor stalling out in shoe track) 10/3/2018 10/3/2018 1.00 INTRM2 CEMENT DDRL P Drill 20'new formation f/11,914'to 11,914.0 11,934.0 15:45 16:45 11,934' MD / 8,009' TVD, ADT .5 Hr, 300 gpm, 1580 psi, PIU wt 230 k, S/O wt 125 k, ROT wt 155 k, 50 rpm, 11.5 k trq, 5-16 WOB. Page 17/31 Report Printed: 10/25/2018 F- Operations Summary (with Timelog Depths) MT6-06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code An" Time Time P -T -X Operation Stan Depth (RKB) End Depth (RKB) 10/3/2018 10/3/2018 1.50 INTRM2 CEMENT CIRC P Pump sweep & circ hole clean w/300 11,934.0 11,829.0 16:45 18:15 gpm, 1770 psi, 50 rpm, 11 - 12 k trq. Rack back 2 stands to 11,829' 10/3/2018 10/3/2018 1.00 INTRM2 CEMENT FIT P F/C static. B/D top drive & R/U testing 11,829.0 11,829.0 18:15 19:15 equipment. FIT to 12.5 ppg @ 920 psi. R/D testing equipment. 10/3/2018 10/4/2018 4.75 PROD1 DRILL TRIP P POOH f/11,829'to 5,812' 11,829.0 5,812.0 19:15 00:00 10/4/2018 10/4/2018 0.50 PROD? DRILL TRIP P POOH f/5,812'to 4,700' 5,812.0 4,700.0 00:00 0030 10/4/2018 10/4/2018 0.25 PROD1 DRILL CIRC P Pump 15 bbl 12.3 ppg dry job 4,700.0 4,700.0 00:30 0045 10/4/2018 10/4/2018 2.00 PROD1 DRILL TRIP P POOH f/4,700'to 240' 4,700.0 240.0 00:45 0245 10/4/2018 10/4/2018 0.25 PROD1 DRILL OWFF P F/C (mud aired up). PJSM on UD 240.0 240.0 02.45 0300 BHA 10/4/2018 10/4/2018 0.75 PROD1 DRILL BHAH P Rack back HWDP & jars. L/D BHA as 240.0 0.0 03:00 0345 per Baker reps. 10/4/2018 10/4/2018 0.50 PROD1 DRILL BHAH P Clean & clear floor of BHA tools & 0.0 0.0 03:45 04:15 equipment. 10/4/2018 10/4/2018 1.75 PROD1 WHDBOP RURD P Pull wear ring. Install test plug. R/U to 0.0 0.0 04:15 06:00 test BOPE. Purge air from system. Flood lines w/H20. 10/4/2018 10/4/2018 6.75 PROD1 WHDBOP BOPE P Test BOPE w/4 & 4-1/2" testjoint. 0.0 0.0 06:00 12:45 Annular low 250 psi for 5 min & high 2500 psi for 10 min, Remaining test low 250 psi for 5 min & high 3500 psi for 10 min. 4" Demme, Choke valves 1 - 14; IBOP's, Choke needle valve, Upper/lower 3-1/2" X 6" VBR's & blind rams, 4" Dart/FOSV, HCR / Man choke/kill, Accumulator test, Initial 2,925 psi, final 1,450 psi, 1st 200 psi recharge = 31 sec's, full recharge = 173 seconds. Nitrogen Bottles z4 = 2,100 psi. Gas alarms and PVT alarms tested. Draw down on chokes t/1100 psi. AOGCC Lou Laubenstein waived witness, BLM Quinn Sawyer witness test. 10/4/2018 10/4/2018 0.50 PROD1 WHDBOP RURD P R/D testing equipment. Set 6.25" ID 0.0 0.0 12:45 13:15 wear ring. 10/4/2018 10/4/2018 0.75 PROD1 DRILL BHAH P Bring BHA tools & equipment to rig 0.0 0.0 13:15 14:00 floor. 10/4/2018 10/4/2018 3.75 PROD1 DRILL BHAH P M/U 6" production BHA #6 as per 0.0 335.0 14:00 17:45 Baker reps. to 335'. (PJSM & load sources) 10/4/2018 10/4/2018 0.75 PROD1 DRILL TRIP P RIH f/335'to 1,756' 335.0 1,756.0 17:45 18:30 10/4/2018 10/4/2018 0.25 PROD1 DRILL DHEQ P Shallow hole test MWD tools w/250 1,756.0 1,756.0 18:30 18:45 gpm / 1020 psi 10/4/2018 10/4/2018 5.00 PROD1 DRILL TRIP P RIH f/1,756'to 11,163' 1,756.0 11,163.0 18:45 23:45 10/4/2018 10/5/2018 0.25 PROD1 DRILL PULD P Pick up & RIH 15 jts 4" 15.7# DP from 11,163.0 11,266.0 23:45 00:00 pipe shed f/11,163'to 11,266' 10/5/2018 10/5/2018 0.50 PROD? DRILL PULD P Pick up & RIH 4" 15.7# DP from pipe 11,266.0 11,639.0 00:00 0030 shed f/11,266'to 11,639' 10/5/2018 10/5/2018 0.25 PROD1 DRILL TRIP P RIF f/11,639'to 11,829' 11,639.0 11,829.0 00:30 00:45 10/5/2018 10/5/2018 1.00 PROD1 DRILL SLPC P Slip & cut drill line 11,829.0 11,829.0 00:45 01:45 Page 18/31 ReportPrinted: 10/25/2018 4 Uperations Summary (with Timelog Depths) MT6-06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Tima our (hr) Phase Op Cotle Activity Code Time P -T -X Operabon (0K13) End Depth(ftKB) 10/5/2018 10/5/2018 0.50 PROD1 DRILL SVRG P Service rig, top drive, drawowrks & 11,829.0 11,829.0 01:45 02:15 blocks. 10/5/2018 10/5/2018 0.25 PROD1 DRILL MPDA P Pull trip nipple & install RCD bearing. 11,829.0 11,829.0 0215 0230 10/5/2018 10/5/2018 1.75 PRODt DRILL DLOG P Obtain torque & drag parameters. Log 11,829.0 11,924.0 0230 0415 open hole f/11,829'to 11,924'w/220 gpm, 1600 psi, 60 rpm, 12 k trq @ 180 ft/hr max. (Had minor issue with MWD stabilizer hanging up on shoe. Pick up & worked thru once. Clear) 10/5/2018 10/5/2018 2.25 PROD1 DRILL DISP P Pump 40 bbls deep clean space & 11,924.0 11,829.0 04.15 06:30 displace to 8.8 ppg OBM w/200 gpm, 1700 psi, 60 rpm, 12 - 6 k trq. Obtain new SPR's. Pull inside shoe to 11,829'. BHA hanging up on shoe. 10/5/2018 10/5/2018 0.50 PROD1 DRILL OWFF P Formation finger print. Pressure build 11,829.0 11,829.0 06:30 07:00 to 16 psi max. Wellborn static 10/5/2018 10/5/2018 0.75 PROD1 DRILL REAM P W&R f/11,829'to 11,934'w/220 gpm, 11,829.0 11,934.0 07:00 0745 1950 psi, 60 rpm, 7 k trq 10/5/2018 10/5/2018 4.75 PROD1 DRILL DDRL P Drill ahead f/11,934'to 12,294' MD / 11,934.0 12,294.0 07:45 1230 8,042' TVD, ADT 4.2 Hrs. Drilled out of zone @ 12,265'& observed gamma spike 10/5/2018 10/5/2018 1.50 PROD1 DRILL CIRC X Circ & cond B/U & evaluate cuttings 12,294.0 12,294.0 12:30 14:00 samples 10/5/2018 10/5/2018 1.50 PROD1 DRILL DDRL X Drill ahead f/12,294'to 12,355' MD / 12,294.0 12,355.0 14:00 1530 8,043' TVD, ADT 1.2 Hrs. Dropping inclination trying to find sand 10/5/2018 10/5/2018 1.50 PROD1 DRILL CIRC X Circ & cond B/U & evaluate cuttings 12,355.0 12,355.0 15:30 1700 samples 10/5/2018 10/6/2018 7.00 PROD1 DRILL DDRL X Drill ahead f/12,355' to 12,616' MD / 12,355.0 12,616.0 17:00 0000 8,053' TVD, ADT 5.4 Hrs, ECD 10.29 ppg, 220 gpm, 2130 psi, PU wl 215 k, SO wt 125 k, ROT wt 162 k, 140 rpm, On/Off trq 9/8 k ft/lbs. Dropping inclination trying to find sand 10/6/2018 10/6/2018 1.75 PROD1 DRILL DDRL X Drill ahead f/12,616'to TD 12,687' 12,616.0 12,687.0 00:00 01:45 MD / 8,058' TVD, ADT 1.8 Hrs, ECD 10.25 ppg, 220 gpm, 2140 psi, PU wt 225 k, SO wt 130 k, ROT wt 165 k, 140 rpm, On/Off trq 9/8 k fUlbs. TD'd called due to out of zone. 10/6/2018 10/6/2018 3.50 PROD1 PLUG CIRC X Circ & cond & wt up active system to 12,687.0 12,687.0 01:45 05:15 9.1 ppg w/22o gpm, 2200 psi, 120 rpm, 8 k trq. 10/6/2018 10/6/2018 0.25 PROD1 PLUG OWFF X F/C. Close in MPD chokes for 5 min. 12,687.0 12,687.0 05:15 0530 No psi increase. Open chokes & open to atmosphere (static). 10/6/2018 10/6/2018 1.00 PROD1 PLUG SMPD X Strip OOH as per MPD schedule 12,687.0 12,035.0 05:30 0630 f/12,687' to 12,035'. Started pulling tight & not able to work thru. 10/6/2018 10/6/2018 2.75 PROD1 PLUG BKRM X BROOH f/12,035'to 11,734' 12,035.0 11,734.0 06:30 0915 10/6/2018 10/6/2018 7.50 PROD1 PLUG SMPD X Strip OOH as per MPD schedule 11,734.0 1,155.0 09:15 16:45 1 1f/11,734'to 1,155' 10/6/2018 10/6/2018 0.25 PROD1 PLUG OWFF X F/C (static). B/D lines & PJSM. 1,155.0 1,155.0 16:45 17:00 10/6/2018 10/6/2018 0.50 PROD1 PLUG MPDA X Pull RCD bearing & install trip nipple 1,155.0 1,155.0 17:00 17:30 10/6/2018 10/6/2018 0.50 PROD1 PLUG TRIP X POOH f/1,155'to 335' 1,155.0 335.0 17:30 18:00 10/6/2018 10/6/2018 0.25 PROD1 PLUG OWFF X F/C (static). 335.0 335.0 18:00 18:15 Page 19131 Report Printed: 10/25/2018 C Operations Summary (with Timelog Depths) -y fa j i 1 �y MT6-06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log StartTime End Time Dm (hr) Phase Op Corte Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth(ftKB) 10/6/2018 10/6/2018 1.75 PROD1 PLUG SHAH X L/D BHA as per Baker reps. (PJSM & 335.0 0.0 18:15 20:00 remove sources) 10/6/2018 10/6/2018 0.50 PROD1 PLUG SHAH X Clean & clear floor of BHA tools & 0.0 0.0 20:00 20:30 equipment 10/6/2018 10/6/2018 1.00 PROD1 PLUG BOPE X Pull wear ring & set test plug. R/U to 0.0 0.0 20:30 21:30 test BOPE 10/6/2018 10/6/2018 1.25 PRODi PLUG ROPE X Test BOPE w/3-1/2" test joint. Annular 0.0 0.0 21:30 2245 low 250 psi for 5 min & high 2500 psi for 10 min. Upper & lower VBR's low 250 psi for 5 min & high 3500 psi for 10 min 10/6/2018 10/6/2018 0.50 PROD1 PLUG BOPE X RID testing equipment & set 6.25" 0.0 0.0 22.45 23:15 wear ring. 10/6/2018 10/7/2018 0.75 PROD1 PLUG RURD X R/U to run 3-1/2" tubing. M/U power 0.0 0.0 23:15 00:00 tongs, 3-1/2" slips & elevators. 10/7/2018 10/7/2018 1.00 PROD1 PLUG RURD X Cont. RID to run 3-1/2" tubing. 0.0 0.0 00:00 01:00 10/7/2018 10/7/2018 1.75 PROD1 PLUG PULD X M/U 3-1/2" EUE cement stinger assy 0.0 993.0 01:00 02:45 to 993'. C/O elevators. 10/7/2018 10/7/2018 5.50 PROD1 PLUG TRIP X RIH w/cement stinger f/993' to 12,685' 993.0 12,685.0 02:45 08:15 10/7/2018 10/7/2018 0.25 PROD1 PLUG RURD X R/U cement lines & FOSV 12,685.0 12,685.0 08:15 08:30 10/7/2018 10/7/2018 5.00 PROD1 PLUG CIRC X Circ & cond for cement job. Stage flow 12,685.0 12,685.0 08:30 13:30 rate to 6 bpm, 1800 psi. SIMOPS - L/D remaining 5" DP from derrick. Mix 12.5 ppg Mud Push spacer in pill pit. 10/7/2018 10/7/2018 1.75 PR0D1 PLUG CMNT X PJSM. Pump abandonment cement 12,685.0 12,685.0 13:30 15:15 plug #1. Dowell flood lines & PT to 3500 psi (good). Rig pump 25 bbls 12.5 ppg Mud Push w/6 bpm, Dowell pump 22.6 blots 15.8 ppg 1.16 ft3/sk yield class G cement w/4 bpm, Rig pump 10.1 bbls 12.5 ppg Mud Push w/6 bpm, & rig displace w/ 110 bbls OBM w/8 bpm @ 2730 psi ICP 12 bpm 450 psi FCP. FIC Balanced 10/7/2018 10/7/2018 0.75 PRODt PLUG TRIP X POOH f/12,685'to 12,171' (pipe pulled 12,685.0 12,171.0 15:15 1600 dry) CIP 16:00 Hrs 10/7/2018 10/7/2018 4.00 PROD1 PLUG CIRC X Drop nerf ball. Circ & cond for cement 12,171.0 12,171.0 16:00 2000 job. Stage flow rate to 8 bpm, 2600 psi. Reciprocate pipe. Dumped 110 bbls of mud push. cement & cement contaminated mud. SIMOPS - Mix 12.5 ppg Mud Push spacer in pill pit. 10/7/2018 10/7/2018 1.00 PROD1 PLUG CMNT X PJSM. Pump kick off cement plug #2. 12,171.0 12,171.0 20:00 21:00 Dowell flood lines & PT to 3500 psi (good). Rig pump 24.1 bbls 12.5 ppg Mud Push w/6 bpm, Dowell pump 25.5 bbls 16.5 ppg 1.06 ft3/sk yield class G cement w/3 bpm, Rig pump 10.8 bbls 12.5 ppg Mud Push w/6 bpm, & rig displace w/ 103 bbls CBM w/8 bpm @ 2450 psi ICP 12 bpm 270 psi FCP. FIC Balanced 10/7/2018 10/7/2018 0.75 PROD1 PLUG TRIP X POOH f/12,171'to 11,632' (pipe pulled 12,171.0 11,632.0 21:00 21:45 dry) CIP 21:45 Hrs 10/7/2018 10/7/2018 1.00 PROD1 PLUG CIRC X Drop nerf ball. Circ clean w9 bpm 11,632.0 11,632.0 21:45 2245 3300 - 2800 psi. Reciprocate pipe. Dumped 90 bbls of mud push. cement & cement contaminated mud. 10/7/2018 10/7/2018 0.25 PROD1 PLUG OWFF X FIC (slight drop then static) 11,632.0 11,632.0 22:45 2300 Page 20/31 Report Printed: 10/25/2018 Operations Summary (with Timelog Depths) MT6-06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start rate End Time our (hr) Phase Ov Cooe Activay Cone Time P -T -X Operation Stmt Depth MKa) End Depth (ft(a) 1017/2018 10/7/2018 0.25 PROD1 PLUG CIRC X Pump 21 bbi 10.4 ppg dry jab. 11,632.0 11,632.0 23:00 23:15 10/7/2018 10/8/2018 0.75 PROD1 PLUG TRIP X POOH as per trip schedule f/11,632'to 11,632.0 11,062.0 23:15 00:00 11,062' 10/8/2018 10/8/2018 8.50 WR-ODIIPLUG TRIP X POOH as per trip schedule f/11,062'to 11,062.0 993.0 00:00 08:30 993' (F/10,500' to 9,446' had to screw into stand & rotate 3-1/2" tubing collars off of quick conned) 10/8/2018 10/8/2018 0.25 PROW PLUG RURD X F/C (static) C/O handling equip & R/U 993.0 993.0 08:30 08:45 to UD tubing. 10/8/2018 10/812018 1.25 PROD1 PLUG PULD X UD cement stinger assy. 993.0 0.0 08:45 10:00 10/8/2018 1018/2018 0.50 PROD1 PLUG KURD X RID tubing running equip. 0.0 0.0 10:00 10:30 1018/2018 10/812018 1.50 PROD1 WHDBOP RURD X R/U to test ROPE. Pull wear ring. Set 0.0 0.0 10:30 12:00 test plug. Fill stack & lines w/1-120. Purge air from system. 10/8/2018 10/8/2018 6.00 PR0D1 WHDBOP TOPE X Test BOPE w/3-1/2" & 4-1/2" test joint. 0.0 0.0 12:00 18:00 Annular low 250 psi for 5 min & high 2500 psi for 5 min, Remaining test low 250 psi for 5 min & high 3500 psi for 5 min. 4" Demco, Choke valves 1 - 14; IBOP's, Choke needle valve, UpperAower 3-1/2" X 6" VBR's & blind rams, 4" DarUFOSV, HCR / Man choke/kill, Accumulator lest, Initial 2,900 psi, final 1,400 psi, 1st 200 psi recharge = 32 sec's, full recharge = 178 seconds. Nitrogen Bottles x4 = 2,150 psi. Gas alarms and PVT alarms tested. Draw down on chokes V1100 psi. AOGCC Brain Bixby waived witness, 10/8/2018 10/8/2018 1.00 PROD1 WHDBOP RURD X R/D testing erquipment Set 6.25" ID 0.0 0.0 18:00 19:00 wear ring 101812018 10/8/2018 0.75 PROD1 PLUG RURD X Clean rig floor of OBM 0.0 0.0 19:00 19:45 10/8/2018 1018/2018 0.50 PROD1 PLUG SVRG X Service rig, top drive & draw works. 0.0 0.0 19:45 20:15 1018/2018 10/8/2018 0.25 PROD1 PLUG RURD X M/U Baker BPA & install 4" elevators. 0.0 0.0 20:15 20:30 10/8/2018 10/8/2018 2.25 PROD1 PLUG BHAH X M/U 6" production BHA#7 as per 0.0 335.0 20:30 22:45 Baker reps. to 335'. (PJSM & load sources) 10/8/2018 10/8/2018 0.75 PROD1 PLUG TRIP X RIH f/335'to 1,756' 335.0 1,756.0 22:45 23:30 10/8/2018 10/812018 0.25 PROD1 PLUG DHEQ X Shallow hole test MWD tools w/220 1,756.0 1,756.0 23:30 23:45 gpm 11010 psi 10/92018 0.25 PROD1 PLUG TRIP X RIH f/1,756'to 2,712' ,712' 1,756.0 2,712.0 23:45018 23:45 00:00 101912018 10/9/2018 4.75 PROD1 PLUG TRIP X RIH f12712,'to 11,449' MD 2,712.0 11,449.0 00:00 04:45 10/9/2018 10/9/2018 1.00 PROD1 PLUG WASH X Wash down and tag cement stringer at 11,449.0 11,633.0 04:45 05:45 11,633' MD with 2 bpm. 10/912018 1019/2018 1.00 PROD1 PLUG SLPC X Slip and cut 45' of drill line. (circulated 11,633.0 11,633.0 05:45 06:45 w/ 2 bpm and 590 psi). 10/9/2018 10/912018 1.75 PRODt PLUG '9'V -RG X Serviced rig, adjusted drum break, 11,633.0 11,633.0 06:45 08:30 and calibrated block height. 10/9/2018 1019/2018 0.25 PROD1 PLUG WASH X Wash down f/ 11,633'to 11,651' MD w/ 11,633.0 11,651.0 08:30 08:45 215 gpm, 2050 psi, 80-100 rpm, 7.5k TQ. Tagged hard cement at 11,651' MD w/ 2k down weight. Page 21131 ReportPrinted: 10/2512018 Operations Summary (with Timelog Depths) MT6-06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Statl Time End Time our (hr) Phase Op Code Achvlty Code Time P -T -X Operation Start Depth (flKB) End Depth (ftKB) 10/9/2018 10/9/2018 2.25 PROD1 PLUG KOST X Drill out cement f/ 11,651' to 11,842' 11,651.0 11,842.0 08:45 11:00 MD w/ 215 gpm, 2050 psi, 100 rpm, 7.51k Tq, and 2-7k WOB. 10/9/2018 10/9/2018 5.50 PROD1 DRILL DDRL X Drilled 6" Alpine C f/ 11,842'to 12,019' 11,842.0 12,019.0 11:00 16:30 MD / 8,021' TVD, (kicked off cement highside/right) 10/9/2018 10/9/2018 0.50 PROM DRILL CIRC X Circulated and conditioned mud w/ 12,019.0 12,019.0 16:30 17:00 220 gpm, 2140 psi, 100 rpm, 8k TO, 10/9/2018 10/9/2018 0.50 PROD1 DRILL MPDA X Pulled RCD and installed 4" MPD 12,019.0 12,019.0 1700 1730 bearing. 10/9/2018 10/10/2018 6.50 PROD1 DRILL DDRL P Drilled f/ 12,019' to 12,467' MD, 8,029' 12,019.0 12,467.0 17:30 0000 TVD. Dropped MW f/ 9.2 ppg to 8.8 ppg on the Fly. 10/10/2018 10/10/2018 12.00 PROD1 DRILL DDRL P Drilled fl 12,467' MD to 13,575' MD, 12,467.0 13,575.0 00:00 1200 8,033' TVD w/ 220 gpm, 2190 psi, 140 top, 4-7k WOB, and 10.33 ppg ECD. 10/10/2018 10/10/2018 8.25 PROM DRILL DDRL P Drilled fl 13,575' MD to 14,303' MD, 13,575.0 14,303.0 12:00 20:15 10/10/2018 10/10/2018 0.25 PROD? DRILL RGRP T Soft Speed faulted out and had to be 14,303.0 14,303.0 20:15 20:30 trouble shot. Will be revisited in the morning by electrician. 10/10/2018 10/11/2018 3.50 PROD? DRILL DDRL P Drilled f/ 14,303 to 14,587' MD, 8032' 14,303.0 14,587.0 20:30 00:00 TVD w/ 220 gpm, 2260 psi, 140 rpm, 5 -10k WOB, and 10.29 ppg ECD. 10/11/2018 10/11/2018 3.75 PROD1 DRILL DDRL P Drilled f/ 14,587'to 14,797' MD w/220 14,587.0 14,797.0 00:00 03:45 gpm, 2473 psi, 140 rpm, 5-10k WOB, and 10.29 ppg ECD. 10/11/2018 10/11/2018 1.25 PROM DRILL CIRC T Baker server was down, trouble 14,797.0 14,797.0 0345 05:00 shooting. 10/11/2018 10/11/2018 7.00 PR0D1 DRILL DDRL P Drilled f/ 14,797'to 15,449' MD w/ 220 14,797.0 15,449.0 05:00 12:00 gpm, 2360 psi, 140 rpm, 5-10k WOB, and 10.29 ppg ECD. 10/11/2018 10/12/2018 12.00 PROD1 DRILL DDRL P Drilled f/15,449' U16,535'MD w/ 220 15,449.0 16,535.0 12:00 00:00 gpm, 2473 psi, 140 rpm, 5-10k WOB, and 10.29 ppg ECD. 10/12/2018 10/12/2018 4.50 PROD1 DRILL DDRL P Steering down, attempting to drill back 16,535.0 16,745.0 00:00 04:30 into C sand to 16,745', encountor high GR (highest 194API reading) formation. Decide to ream out of hole due to instability concern. Dynamic connections w/MPD holding 500psi AP. 10/12/2018 10112/2018 4.00 PROD1 DRILL BKRM T Reaming out of hole to 16,530', 16,745.0 16,745.0 04:30 08:30 holding 500psi connection pressure, decision was made to go back to bottom to continue drilling and detect if any sand exist, ream back to bottom at 16,745' with 220gpm and 140rpm. 10/12/2018 10/12/2018 2.00 PRODi DRILL DDRL P Drill to 16,803', steering down with 84 16,745.0 16,802.0 08:30 10:30 degree in target. Pump pressure and ECD spike up, accompany with torque spike, indicate slightly hole packing off. Holding 500psi connection pressure. 10/12/2018 10/12/2018 0.50 PROD1 DRILL BKRM T BROOH f/16,802 t/16,747' w/220- 16,802.0 16,747.0 10:30 11:00 185gpm 2,400-1,860psi, 120-80rpm, 9 -10k torque, pack off. 10/12/2018 10/12/2018 1.00 PROD1 DRILL TRIP T POOH f/16,747'U16,655'w/2.5bpm 16,655.0 16,591.0 11:00 12:00 960psi, holding 220psi AP w/MPD. 10/12/2018 10/12/2018 3.00 PROD1 DRILL BKRM T BROOHf/16,655't/15,829'w/185gpm, 16,591.0 15,829.0 12:00 15:00 80-100rpm. Page 22131 Report Printed: 10/25/2018 Operations Summary (with Timelog Depths) MT6-06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stall Time End Time our (hr) Phese Op Code Anvity Code Time P-T-XStart Operation Depth (ftKB) Ek Depth (fIKB) 10/12/2018 10/13/2018 9.00 PROD1 DRILL DDRL T Troughing from 15,794'to 15,829', 15,833.0 15,859.0 15:00 00:00 time drilling to 15,833' per Baker DD open hole sidetrack procedure. 10/13/2018 10/13/2018 12.00 PRODI DRILL TO—ST T Time drilling f/15,833' 1115,859' 15,829.0 15,859.0 00:00 12:00 w1120rm, 245gpm. 10/13/2018 10/13/2018 1.00 PROD1 DRILL KOST T Continue time drill f/15,859't/15,864' 15,859.0 15,864.0 12:00 13:00 MD for open hole sidetrack. 245gpm, 120rpm, 11k torque, 10.23ppg ECD, 2 -12k WOB. 10/13/2018 10/14/2018 11.00 PROD1 DRILL DDRL T Drill Alpine C f/15,864 to 16,802' MD, 15,864.0 16,802.0 13:00 00:00 tvd 8,085', 140rpm, 220gpm. SPR @ 16,210' TVD 8,087', MW 8.81ppg. #2 @20spm=780 psi, #2@25spm=900psi. 10/14/2018 10/14/2018 9.75 PROD1 DRILL DDRL P Drilling Alpine C sand f/16,802' 16,802.0 17,482.0 00:00 09:45 1117,482', 140rpm, 225gpm, 2560psi SPP, 10.34ppg ECD, WOB 10k. Hold 600psi on connections-Erratic pump pressure @17,482'-Call TD. 10/14/2018 10/14/2018 0.75 PROD1 CASINrKR P BROOH t/17,353' w/220gpm, 120rpm. 17,482.0 17,393-0- 09:45 10:30 10/14/2018 10/1412018 1.50 PROW CASINP Circulate holeGean w1220gpm 17,353.0 17,353.0 10:30 12:00 120rpm, 9.5k torque, 2510 psi SPP, RIB stand T/17,257'. 10/14/2018 10/14/2018 2.50 PROD1 CASINP Finger print pore pressure, rotate 17,353.0 17,353.0 12:00 14:30 @5rpm 9k torque. Start pressure 14.4 392psi, end choke pressure 123psi, bbls from bleed back. 10/14/2018 10/14/2018 3.50 PRODI CASING CIRC P Continue circulate hole clean, weight 17,353.0 17,353.0 14:30 18:00 up to 9.1 ppg@ 220gpm, 120rpm, 1 Ok torque, 10/14/2018 10/14/2018 1.75 PROD1 CASING OWFF P Finger print with 5rpm. Start choke 17,353.0 17,353.0 18:00 19:45 pressure 120psi, end choke pressure 12.5psi. 0.8bbls from bleed back. Monitor well, static. 10/14/2018 10/14/2018 3.00 PROD1 CASING CIRC P Circulating, weight up to 9.4ppg for trip 17,353.0 17,353.0 19:45 22:45 margin w/220gpm, 120rpm. 10/14/2018 10/14/2018 0.25 PRODI CASING CIRC P SPR@17,250' MD with 9.4ppg mud. 17,353.0 17,353.0 22:45 23:00 #2pump @20spm=790psi, @30spm=1,160psi. Break down Top Drive, drop 2.1" hollow drift R prepare to SOON. 10/14/2018 10/15/2018 1.00 PROD? CASING SMPD P SOOH f/17,257't/16,995' MD, 300psi 17,353.0 16,995.0 23:00 00:00 out of slip, 40psi on slip. 10/15/2018 10/15/2018 1.50 PRODI CASING §MPD P SOOH f/16,995' 1115,800' MD, 300psi 16,995.0 15,800.0 00:00 01:30 out of slip, 40psi on slip. 10/15/2018 10/15/2018 0.25 PRODI CASING SMPD P RIH through OHST area ok 15,800.0 15,924.0 01:30 01:45 10/15/2018 10/15/2018 3.25 PROD1 CASING SMPD P SOOH f/15,924'1112,020'w/MPD hold 15,924.0 12,020.0 01:45 05:00 300psi/40psi pull/slips. 10/15/2018 10/15/2018 2.00 PRODI CASING BKRM P BROOHf/12,020'1111,734'w/220gpm, 12,020.0 11,734.0 05:00 07:00 120rpm. Drift shoe and sidetrack point with no pump and no rotation, good. 10/15/2018 10/15/2018 0.50 PROD1 CASING BOPE P Flow check well, static. Function test 11,734.0 11,734.0 07:00 07:30 annular, upper and lower pipe ram, good. 1o/15/2o18 10/15/2018 6.25 PROD1 CASING '§MPD P Continue SOOH 1/11,734'111,333' 11,734.0 1,333.0 07:30 113,45 10/15/2018 1 10/15/2018 0.75 PRODi CASING MPDA Blow down MPD, clean rig floor. Pull 1,333.0 1,333.0 13:45 14:30 1 RCD, install trip nipple. 1011512018 10/1512018 0.50 5R0D1 CASING TRIP P POOH on elevator f11,333' 11335' MD. 1,333.0 335.0 14:30 15:00 Page 23131 Report Printed: 10/25/2018 Y . Operations Summary (with Timell Depths) c MT6-06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Time End Time Dur (hd Phase Op Code Activity Code Time P-T-X Operabon Start Depth (ftKB) End Depth (WB) 10/15/2018 10/15/2018 2.50 PROD1 CASING BHAH P PJSM and UD BHA. 335.0 0.0 15:00 1730 10/15/2018 10/15/2018 1.00 PROD1 CASING BHAH P Clear rig floor and equipment. 0.0 0.0 17:30 1830 10/15/2018 10/15/2018 1.00 COMPZN CASING RURD P Mobilize casing tools and equipment 0.0 0.0 18:30 1930 to rig floor, rig up same. 10/15/2018 10/16/2018 4.50 COMPZN CASING PUTB P PJSM, run 4.5" 12.6# TXP liner as per 0.0 2,509.0 19:30 00:00 1tally t/2,509'. 10/16/2018 10/16/2018 3.50 COMPZN CASING PUTB P Pick up and run in hole with 4%" TXP 2,509.0 5,125.0 00:00 03:30 liner and pert pups per detail from 2,509' MD to 5,125' MD. (123 total 4%" x 5%" Hydroform centralizers, 20 pert pups). 10/16/2018 10/16/2018 0.50 COMPZN CASING OTHR P Change elevators to 4", M/U HRDE 5,125.0 5,185.0 03:30 0400 ZXP liner top packer with 41/V x 7" Flex Lock liner hanger. M/U Bumper sub and XO to 4" DP. P/U=105k, S/0=97k. 10/16/2018 10/16/2018 0.25 COMPZN CASING RUNL P Run in hole on 4" DP to 5,277' MD 5,185.0 5,277.0 04:00 04:15 10/16/2018 10/16/2018 0.25 COMPZN CASING CIRC P Circulate and establish parameters, 1 5,277.0 5,277.0 04:15 0430 bpri psi, 2 bpri psi, 3 bpm=150 psi. SIMDPS- Rig down double stack power tongs. 10/16/2018 10/16/2018 4.75 COMPZN –CASING RUNL P Run liner on 4" DP from 5,277' MD to 5,277.0 11,800.0 04:30 0915 11,800' MD 10/16/2018 10/16/2018 0.25 COMPZN CASING CIRC P Circulate and establish parameters, 2 11,800.0 11,800.0 09:15 0930 bpm=400 psi, 3 bpm=550 psi. P/U=185k, S/0=135k, Rotating 20 rpm=160k, 5.5k Tq. 30 rpm=5.7k Tq. Shut down and blow down top drive. 10/16/2018 10/16/2018 2.50 COMPZN CASING RUNL P Continue RIH from 11,800' MD to 11,800.0 14,665.0 09:30 1200 14,665' MD. String took 10k down weight @ 14,544' MD. P/U and wiped through OK. P/U=210k, S/0=130k. 10/16/2018 10/16/2018 2.00 COMPZN CASING RUNL P Continue RIH from 14,665' MD to 14,665.0 16,M-0- 12:00 1400 16,822' MD (with 19 stands 4" HWDP). String took 10k down weight @ 14,763' MD. P/U and wiped through —2 OK. P/U=212k, S/0=130k. 10/16/2018 10/16/2018 00 COMPTN CASING CIRC P P/U single, set liner on depth @ 16,822.0 16,830.0 14:00 16:00 16,830' MD. Establish circulation @ 3 bpm, 850 psi. Circulate bottoms up, no gas. Flow check, static. 10/16/2018 10/16/2018 0.50 COMPZN CASING CIRC P Spot 20 bbl VersaPro in pipe @ 3 16,830.0 16,830.0 16:00 16:30 bpm, 840 psi. Drop 1-5/8" Phenolic setting ball, pump down @ 3 bpm, 850 psi. Slow to 2 bpm, 550 psi @ 80 bbl away, ball on seat @ 85 bbl pumped. 10/16/2018 10/16/2018 0.50 COMPZN CASING PACK P Set liner hanger as per Baker rep, 16,830.0 16,830.0 16:30 17:00 pressure up to 2000 psi, hold 2 minutes, S/0 to 85k. Continue pressue up to 3300 psi, observe hanger set and weight drop to 75k. Bleed off pressure. P/U to 225k, observe bumper sub travel. Slack off to 125k, observe shear. P/U and expose dogs, set down 10k to set packer. P/U and rotate 20 rpm, set down 10k 2x to confirm packer set. Liner top @ 11,663' MD. Page 24/31 Report Printed: 10/25/2018 B Operations Summary (with Timelog Depths) +r. y�, MT6-06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur(hn Phase Op Code Adivity Code Time P-T-x Operation Start Depth (ftKB) End Depth(MB) 10/16/2018 10/16/2018 1.00 COMPZN CASING PRTS P Rig up and test ZXP liner top packer 16,830.0 16.830.0 17:00 1800 to 3300 psi for 10 minutes charted. Rig down test equipment. 10/16/2018 10/16/2018 1.00 COMPZN WELLPR PMPO P Lay down single to 11,713' MD. Pump 16,830.0 11,614.0 18:00 1900 out of hole for final displacement of VersaPm pill to 11,614' MD. 10/16/2018 10/16/2018 2.50 COMPZN WELLPR DISP P Displace wellbore to 9.3 ppg Clear 11,614.0 11,614.0 19:00 21:30 Brine per plan. Pumped 50 bbl weighted Deepclean spacer @ 4 bpm, 45 bbl DeepClean spacer, 60 bbl High Vis brine followed by 435 bbl 9.3 ppg NaCl brine. Reciprocate pipe 11,614' to 11,519' during displacement., P/U=210k, S/0=160k. Obtain SPR's, shut down. 10/16/2018 10/16/2018 0.50 COMPZN WELLPR OWFF P Observe well for flow while made up to 11,614.0 11,614.0 21:30 22:00 top drive, IBOP closed. Observe well slowly oozing, appears to be relaxing but not slowing down. Decide to break stand and blow down to determine if DP/Annulus is out of balance, Blow down top drive, stand back stand. 10/16/2018 10/16/2018 0.50 COMPZN WELLPR OWFF P Top off hole and observe well static for 11,614.0 11,614.0 22:00 2230 30 minutes. 10/16/2018 10/17/2018 1.50 COMPZN WELLPR PULD P POOH laying down HWDP from 11,614.0 10,314.0 22:30 0000 11,614' MD to 10,314' MD. P/U=195k, S/0-150k. 10/17/2018 10/17/2018 1.50 COMPZN WELLPR PULD P Continue POOH, laying down 4" DP 10,314.0 9,548.0 00:00 01:30 from 10,314' MD to 9.548' MD. Note: Overpull 5-20k where top dust cover on running tool pulling into Quick Connect @ 9,564' MD. Rotate 7 rpm and roll running tool into OC with no overpull. P/U=175k, S/0=140k, ROT=155k. 10/17/2018 10/17/2018 0.50 COMPZN WELLPR SFTY T Observe ice falling from derrick due 9,548.0 9,548.0 01:30 02:00 freezing rain. Shut down operations, clear rig floor and send up derrickman to remove ice from derrick. Monitor well via trip tank, 0 static gain/loss. 10/17/2018 10/17/2018 7.50 COMPZN WELLPR PULD P Continue POOH laying down 4" DP 9,548.0 72.0 02:00 0930 from 9,548' MD to running tool @ 72' MD, proper hole fill. Culled out total 7 jts 4" 14# DP due hard banding. Joints from stands #56 (2), 58, 78, 101 and 104. 10/17/2018 10/17/2018 0.50 COMPZN WELLPR BHAH P Lay down Baker running tools, 72.0 0.0 09:30 10:00 observe no damage. Close blind rams. 10/17/2018 10/17/2018 0.50 COMPZN WELLPR BHAH P Clean and clear rig floor, P/U and M/U 0.0 0.0 10:00 10:30 stack washer. SIMOPS- Pressure test Mud pump #2 to 3500 psi (new liner) 10/17/2018 10/17/2018 0.50 COMPZN WELLPR WWWH P Flush stack with 16.5 bpm, 80 psi, 20 0.0 0.0 10:30 11:00 rpm, .4k Tq. Lay down stack washer and blow down top drive. 10/17/2018 10/17/2018 0.25 COMPZN RPCOMP RURD P Drain stack and pull wear ring per 0.0 0.0 11:00 11:15 FMC rep. SIMOPS- Rig down Baker BPA and lay down via beaverslide. 10/17/2018 10/17/2018 0.75 COMPZN RPCOMP RURD P P/U tubing running tools and 0.0 0.0 11:15 12:00 equipment via Beaverslide. I-Wire reel, cannon clamps. R/U 4%" Tubing elevators. Page 25131 Report Printed: 10/25/2018 Operations Summary (with Timelog Depths) MT6-06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Thre End Tens Our (hr) Phase Op Code Activity Cada rime P4 -X Operatlon Start Depth (flKB) End Depth (flK 10/1712018 10117/2018 1.50 COMPZN RPCOMP RURD P Continue mobilizing tools and 0.0 0.00 12:00 13:30 equipment for completion run. Calibrate tongs for torque turn. 10/17/2018 10/17/2018 0.50 COMPZN RPCOMP PUTB P PJSM, M/U seal assembly, locator no- 0.0 128.0 13:30 14:00 go with pup, 1 joint TN Blue, 3.813" XN landing nipple (3.75" No -Go) with RHC plug body, joint #2 and SLB solid gauge mandrel assy to 128' MD. 10/17/2016 10117/2018 1.00 COMPZN RPCOMP PUTB P Terminate I -Wire to mandrel assy and 128.0 128.0 14:00 15:00 test. 10/17/2018 10/18/2018 9.00 COMPZN RPCOMP PUTB P Continue P/U and RIH with 4112" 128.0 5,902.0 15:00 00:00 Tenads Blue completion per running IS/0=100k, order from 128' MD to 5,902' MD, torque turning to 5,360 ft/lbs and installing Cannon clamps on each connection. 145 jts in hole. Constant monitoring of I -Wire as per SLB. Calc Disp=27 bbl, Actual Disp=19bbl. 10/18/2018 10/18/2618 2.75 COMPZN RPCOMP PUTB P Continue P/U and RIH with 4%' 5,902.0 7,835.0 00:00 02:45 Tenaris Blue completion per running order from 5,902' MD to 7,835' MD, torque turning to 5,360 ft/lbs and installing Cannon clamps on each connection. Constant monitoring of I - Wire as per SLB. S10=1 05k, 10/18/2018 10/18/2018 0.50 COMPZN RPCOMP SFTY T Observe ice falling from derrick due 7,835.0 7,835.0 02:45 03:15 freezing rain. Shut down operations, clear dg floor and send up derrickman to remove ice from derrick. Monitor well via trip tank, 0 static gain/loss. 10/18/2618 10/18/2018 6.50 COMPZN RPCOMP PUTB P Continue P/U and RIH with 4%" 7,835.0 11,607.0 03:15 09:45 Tennis Blue completion per running order from 7,835' MD to 11,607' MD, torque turning to 5,360 ft/lbs and installing Cannon clamps on each connection. Constant monitoring of (- Wire as per SLB. P/U=165k, S/0=125k, 10/18/2018 10/18/2016 0.50 COMPZN RPCOMP HOSO P Make up XO, head pin and 1502 11,607.0 11,679.0 09:45 10:15 equipment on jt @289, pump 2 bpm @ 110 psi, slack off and observe seals engage with 220 psi and lack of returns. Pumps off, open bleeder and continue to slack off to no-go out. Set down 5k, pick up 5', S/O and confirm no-go. 10/18/2018 10/18/2018 0.50 COMPZN RPCOMP HOSO P POOH laying down joints #289, #288, 11,679.0 11,566.0 10:15 10:45 #287. Calculate space out. 10118/2018 10/18/2018 1.25 COMPZN RPCOMP HOSO P Make up space out pups 9.82', 6.01', 11,566.0 11,639.0 10:45 12:00 7.87' and 9.78', then joint #287 to 11,639' MD 10/18/2018 10/18/2018 1.00 COMPZN RPCOMP THGR P Make up hanger, landing joint and 11,639.0 11,639.0 12:00 13:00 circulating equipment. Change out hanger XO collar to 270° timed collar for production port alignment. 10/18/2018 10/18/2018 1.00 COMPZN RPCOMP CRIH P Pump 40 bbl inhibited brine, chase 11,639.0 11,639.0 13:00 14:00 with 168 bbl 9.3 ppg clean brine @ 3 bpm, 210 psi. SIMOPS- Terminate I -Wire to hanger, test to 5k for 10 mimnutes 10/18/2018 10/18/2018 0.50 COMPZN RPCOMP OWFF P Flow check, static 11,639.0 11,639.0 14:00 14:30 Page 26131 Report Printed: 1 012 512 01 8 r Operations Summary (with Timelog Depths) MT6-06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Time End This, Dur (hr) Phase Op Code Activity Code Time P -T-% Operation Stag Depth (ftKB) End Depth (ftKB) 10/18/2018 10/18/2018 0.50 COMPZN RPCOMP THGR P Land hanger, wash down @ 1 bpm, 11,639.0 11,674.0 14:30 15:00 150 psi, observe pressure increase as seal enter seal bore. Shut down, continue slack off and land hanger. seal depth 11,674.6' MD. 10/18/2018 10/18/2018 2.00 COMPZN RPCOMP THGR T RILDS, attempt to test hanger seals. 11,674.0 11,639.0 15:00 1700 Observe leak at lower hanger seal monitoring port. Repeat test with same results. Pull hanger to floor to inspect. Observe galling on hanger and torn bottom seals, up to bottom upper seal. Dress hanger free of nicks and change out seals. 10/18/2018 10/18/2018 1.00 COMPZN RPCOMP THGR T Land hanger, RILDS, attempt to test, 11,639.0 11,674.0 17:00 18:00 leaking at production flange and quick connect on test pump line. Re -torque bolts on production flange and replace OC on test pump line. 10/18/2018 10118/2018 1.00 COMPZN RPCOMP THGR P Test tubing hanger seals 250 psi low, 11,674.0 11,674.0 18:00 19:00 5000 psi high for 10 minutes via production port, good. 10/18/2018 10118/2018 0.50 COMPZN RPCOMP PRTS P Drop 1-7/8" ball and rod on roller 11,674.0 11,674.0 19:00 19:30 stem, rig up testing equipment. PT lines to 4300 psi. 10/18/2018 10/18/2018 2.00 COMPZN RPCOMP PRTS P Test tubing / IA. Pressure up on tubing 11,674,0 11,674.0 19:30 21:30 to 4200 psi charted for 30 minutes, reduce tubing pressure to 2000 psi, pressure up IA to 3300 psi charted for 30 minutes. Bleed off IA, then tubing pressure to 0 psi. With tubing open for returns, pump down IA to shear out SOV, observe shear at 2300 psi. Pump through SOV @ 2 bpm 1400 psi -0 for 3 bbl. 10/18/2018 10/18/2018 50 COMPZN RPCOMP OWFF P Rig down test equipment, lay down 11,674.0 0.0 21:30 2200 landing joint A. Flow check static. 10/18/2018 10/18/2018 1.00 COMPZN WHDBOP MPSP T Install HP-BPV, install landing joint B. 0.0 0.0 22:00 23:00 Attempt to test to 2500 psi, observe pressure bleeding off. Top off landing joint with water, observe flow out landing joint. Bleed off pressure, pull landing joint. SIMOPS- Lay down casing equipment from rig floor. 10/18/2018 10/19/2018 1.00 COMPZN WHDBOP MPSP T Redress BPV, found small amount of 0.0 0.0 23:00 0000 tape balled up inside of poppet. Change poppet, install new external seal. Re -set BPV, re -install landing joint B. Attempt to test BPV to 2500 psi, appears to be leaking at same rate. 10/19/2018 10/19/2018 1.50 COMPZN WHDBOP MPSP T Continue testing BPV #2, leaking at 0.0 0.0 00:00 01:30 the same rate. Pull landing joint B, pull BPV Observe debris in BPV (Tape). Set clean BPV #3 and landing joint B, attempt to test to 2500 psi, still leaking at the same rate. Pull BPV #3 and again found tape debris in BPV. 10/19/2018 10/1912018 0.75 COMPZN WHDBOP CIRC T Rig up landing joint B and 1502 01:30 02:15 circulating equipment, reverse circulate @ 1.3 bpm, 350 psi down IA, up tubing to flush tubing of debris. Pumped total 27 bbl, no junk observed on shakers. Rig down circulating equipment. Page 27/31 Report Printed: 10/25/2018 Operations Summary (with Timelog Depths) MT6-06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur(hr) Phase op Code Activity Code Time -IT -XOperation Stan Depth (ftKB) End Depth(ftKB) 10/19/2018 10/19/2018 0.75 COMPZN WHDBOP MPSP T Set HP-BPV #4, with test dart also. 02:15 03:00 Set landing joint B. Attempt to pressure test again no good. Inspect BPV and found no junk causing leak. 10/19/2018 10/19/2018 1.00 COMPZN WHDBOP PRTS T Rig up landingjomt A, pressuretest 0.0 11,674.0 03:00 04:00 down IA with needle valve on production port open to test lower hanger seals. Pressure up to 1000 psi and observe leakage out production port, confirming lower seals damaged. 10/19/2018 10/19/2018 0.75 COMPZN WHDBOP THGR T Consult with team, Back out lock 11,674.0 11,644.0 04:00 04:45 downs and pull hanger to floor (165k up). Observed both bottom hanger seals damaged and scarring on hanger itself. 10/19/2018 10/19/2018 0.25 COMPZN WHDBOP WWWH T Rig up and flush wellhead via -]A@ 11,644.0 11,644.0 04:45 0500 10.5 bpm, 1550 psi for 125 blot in attemp to flush debris out of tubing spool. Drain stack and rotate hanger 2" in order to re-land and observe any change in sealing surface damage. 10/19/2018 10/19/2018 2.00 -COMPZN WHDBOP THGR T Slack off and land hanger, pull to rig 11,644.0 11,644.0 05:00 07:00 floor and inspect for damage, appears to be lesser damage but still scraping the seals. Repeat exercise, moving the landing joint centralizer up to aid in landing hanger preferentially towards draworks, away from damaged area. Appears to be better. 10/19/2018 10/19/2018 0.50 COMPZN WHDBOP THGR T FMC changed out all hanger seals, 11,644.0 11,674.0 07:00 07:30 2 above production port, 2 below. RIH and land hanger in tubing head. 10119/2018 10119/2018 0.50 COMPZN WHDBOP THGR T FMC RILDS, SIMOPS- R/U to test 11,674.0 11,674.0 07:30 08:00 hanger seals. 10/19/2018 10/19/2018 1.00 COMPZN WHDBOP PRTS T Attempt to test tubing hanger seals, no 11,674.0 11,674.0 08:00 09:00 good. 10/19/2018 10/19/2018 0.50 TOMPZN WHDBOP THGR T FMC back out lock downs, pull tubing 11,674.0 11,644.0 09:00 09:30 hanger to the floor. Both seals damaged. 10/19/2018 10/19/2018 0.50 COMPZN WHDBOP OTHR T PJSM, R/U power tongs and tubing 11,644.0 11,644.0 09:30 10:00 equipment, prep to L/D tubing. 10/19/2018 10/19/2018 0.50 COMPZN WHDBOP PULL T Lay down tubing hanger and landing 11,644.0 11,566.0 10:00 10:30 joint A. Lay down jt #287 and space out pups to 11,566' MD. (Joint #286 in hole). 10/19/2018 10/19/2018 1.00 COMPZN WHDBOP MPSP T Mobilize 7" storm packer to rig floor, 11,566.0 11,566.0 10:30 11:30 XO from TSH Blue to NC38, make up storm packer to completion string. 10/19/2018 10/19/2018 0.50 COMPZN WHDBOP MPSP T RIH and set storm packer @ 45' MD. 11,566.0 11,611.0 11:30 12:00 POOH, rack back stand, lay down running tool. 10/19/2018 10/19/2018 0.50 COMPZN WHDBOP PRTS T Rig up and test storm packer from top 11,611.0 11,611.0 12:00 12:30 to 250/1000 psi, 5 minutes each charted. 10/19/2018 10/19/2018 2.50 COMPZN WHDBOP MPDA T PJSM, Drain stack, blow down lines. 11,611.0 11,611.0 12:30 1500 Pull trip nipple, clean flow box and remove. Lay down Orbit valve. SIMOPS- Lay down hanger from floor, lay down mousehole, prep stack for N/D. 10/19/2018 10/19/2018 1.00 COMPZN WHDBOP NUND T Nipple dawn BOP stack. 11,611.0 11,611.0 15:00 16:00 Page 28131 ReportPrinted: 10/25/2018 Operations Summary (with Timelog Depths) IYl MTS -06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Cotle Activit' Code Time P -T -X Operation Start Depth (fiKa) End Depth(ftKa) 10/19/2018 10/19/2018 1.00 COMPZN WHDBOP NUND T Inspect tubing spool, observe 11,611.0 11,671.0 16:00 1700 significant gouge in lower seal area. Rig dawn scaffolding, rack back BOP stack. 10/19/2018 10/19/2018 3.00 COMPZN WHDBOP NUND T Test 7" packoff void t05000 psi for 10 11,611.0 11,611.0 17:00 20:00 minutes, good. Bleed pressure off. N.D tubing spool and prep for new install. SIMOPS- Mobilize new tubing spool to cellar and prep for install. 10/19/2018 10/19/2018 1.00 COMPZN WHDBOP NUND T N/U new tubing spool, test packoff 11,611.0 11,617.0 20:00 27:00 seals to 250/5000 psi 10 minutes, good. Install actuator and wing valve. 10/7912078 10/19/2018 2.50 COMPZN WHDBOP THGR T Dress new tubing hanger, make up to 11,611.0 11,611.0 21:00 2330 landing joint A. Dummy run hanger in new tubing head, land and RILDS. SIMOPS- R/U cellar scaffolding. 10/19/2018 10/20/2018 0.50 COMPZN WHDBOP THGR T Test hanger seals via production port 11,611.0 11,611.0 23:30 0000 to 250 psi min, 5000 psi 10 minutes charted. 10/20/2018 10/20/2018 0.25 COMPZN WHDBOP THGR T Continue to test dummy run hanger 11,611.0 11,611.0 00:00 00:15 seals to 5000 psi to r10 minutes on chart, good. 10/20/2018 10/20/2018 0.50 COMPZN WHDBOP MPSP T Pull landing joint, Install HP-BPV and 11,611.0 11,611.0 00:15 00:45 test dart per FMC. 10/20/2018 10/20/2018 1.75 COMPZN WHDBOP NUND T PJSM, Nipple up BOP stack, choke 11,611.0 11,611.0 00:45 02:30 and kill lines, rig up stack turnbuckles. 10/20/2018 10/20/2018 1.00 COMPZN WHDBOP NUND T Fill BOPE and choke manifold with 71,611.0 11,611.0 02:30 03:30 water, purge air from system. 10/ 20/2018 10/20/2018 1.25 COMPZN WHDBOP NUND T Test breaks, pressure test speed head 71,611.0 11,611.0 03:30 04:45 connection, choke and kill connections to 250 psi for 5 minutes, 3500 psi for 10 minutes charted. 10/20/2018 10/20/2018 1.00 COM PZN WHDBOP THGR T Pu11 test dart and BPV, Install landing 11,611.0 11,611.0 04:45 05:45 joint A. BOLDS, pull hanger to rig floor. 10/20/2018 70/20/2018 0.75 COMPZN WHDBOP THGR T Install mousehole, lay down hanger 11,611.0 11,611.0 05:45 06:30 and landing joint assy. 10/20/2018 10/20/2018 2.00 COMPZN WHDBOP MPSP T Break single off top of stand of DP, 11,671.0 11,566.0 06:30 08:30 install TIW on double. M/U Storm packer twin thread retrieval tool. RIH and close annular, open equalization valve, verify zero pressure. Release storm packer, pull to floor and lay down. 10/20!2018 10/20/2018 2.00 COMPZN WHDBOP OTHR T P/U tubing string, SLB Cameo perform 11,566.0 11,561.0 08:30 10:30 splice on I -Wire. 10/20/2018 10/20/2018 1.00 COMPZN WHDBOP PUTB T P/U the 4 pup joints, joint #287, make 11,561.0 11,646.0 10:30 11:30 up hanger to landing joint A per FMC. 10/20/2018 10/20/2018 0.50 COMPZN WHDBOP THGR T SLB Cameo terminate I -Wire through 11,646.0 11,646.0 11:30 1200 hanger, test to 5000 psi, good. 10/20/2018 10/20/2018 1.00 COMPZN WHDBOP THGR T Land hanger, RILDS. S/0=125k 11,646.0 11,674.6 12:00 1300 10/20/2018 10/20/2018 1.00 COMPZN WHDBOP THGR T Rig up and pressure test hanger seals 11,674.6 11,674.6 13:00 14:00 to 250/5000 psi, good test. 10/20/2018 10/20/2018 1.00 COMPZN WHDBOP PRTS T Rig up and test down IAwith tubing 11,674.6 11,674.6 14:00 15:00 closed, 3300 psi charted for 30 minutes, good test. Page 29/31 Report Printed: 10/25/2018 Operations Summary (with Timelog Depths) MT6-O6 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time EM Time Dur(hr) Phase Op Code Act"i Code Tim P -T -X Operation (nK6) End Depth(BKB) 10/2012018 10/20/2018 2.50 COMPZN WHDBOP SLKL T PJSM, set landing joint A. R/U 11,674.6 0.0 15:00 17:30 Slickline with tubing test plug for X profile. Run in hole with test plug, tag up at 27'. X Plug would not pass through landing jointA (ID 3.25"). Pull X plug out of landing joint, L/D landing jointA. 10/20/2018 10/20/2018 1.00 COMPZN WHDBOP SLKL T RIH open with 4%;' tubing X profile test 0.0 2,108.0 17:30 18:30 plug. Locate and set in X nipple @ 2,108' MD 10/20/2018 10/20/2018 0.50 COMPZN WHDBOP SLKL T Rig up and attempt to test tubing to 2,108.0 2,108.0 18:30 1900 2,108' MD via kill line, with blinds closed, IA open. Pressure up to 3400 psi, observe pressure bleeding off and returns coming out IA. Bleed off pressure, re -attempt test with same results. Not a small leak, pressure dropping quickly. 10/20/2018 10/20/2018 1.00 COMPZN WHDBOP SLKL T Run in hole with Slickline and retrieve 2,108.0 0.0 19:00 20:00 1 1 test plug. No obvious damage to plug. 10/20/2018 10/2012018 1.50 COMPZN WHDBOP SLKL T Redress test plug, RIH and set at 0.0 2,108.0 20:00 21:30 2,108' MD. No problems setting or releasing from plug. 10/20/2018 10/20/20180.50 COMPZN WHDBOP SLKL T Re -attempt to pressure lest tubing, 2,108.0 0.0 21:30 22:00 pressure up to 1000 psi and observe returns coming out IA at significant rale. Not a small leak, pressure drop quickly from 1000 psi to 0 in 1 minute. 10/20/2018 10120/2018 0.50 COMPZN WHDBOP SLKL T Set landing joint Ato attempt tubing 0.0 0.0 22:00 22:30 test, while filling landing joint observed returns coming out IA from hydrostatic pressure. Abort and pull landing joint A. 10/20/2018 10/20/2018 0.75 COMPZN WHDBOP SLKL T Run in hole with 4%" DBD hole finder 0.0 2,106.0 22:30 23:15 tool on slickline. Set on top of tubing test plug @ 2,108' MD. Release from hole finder and and POOH. 10/20/2018 10/21/2018 0.75 COMPZN WHDBOP SLKL T Pressure test tubing from surface to 2,106.0 2,106.0 23:15 00:00 hole finder/ plug @ 2,108' MD to 900 psi, 30 minutes charted. Good test. 10/21/2018 10/2112018 1.25 COMPZN WHDBOP SLKL T Retrieve hole finder and test plug on 2,106.0 0.0 00:00 01:15 Slickline. Rig down slickline sheaves. Clean and dear rig Floor 10/21/2018 10121/2018 1.25 COMPZN WHDBOP MPSP P Install BPV and landing joint B. Test 0.0 0.0 01:15 02:30 BPV via IA to 2500 psi for 15 minutes on chart, good test. Bleed off and remove landing joint B. 10/21/2018 10/21/2018 2.50 COMPZN WHDBOP NUND P N/D BOPE, perform BWM and rack 0.0 0.0 02:30 05:00 back same. SIMOPS- C/O saver sub on top drive to NC50. 10/21/2018 10121/2018 4.00 COMPZN WHDBOP NUND P SLB Camco Terminate and test I -Wire, 0.0 0.0 05:00 09:00 FMC install Smooth Bore Metal Seal and install HP-BPV Test Dart. 10/21/2018 10/21/2018 2.00 COMPZN WHDBOP NUND P Nipple up tree and adapter flange. 0.0 0.0 09:00 11:00 Test void to 5000 psi for 10 minutes CPAI witnessed, good. 10/21/2018 10/21/2018 1.00 COMPZN WHDBOP PRTS P Fill tree with diesel, pressure test to 0.0 0.0 11:00 12:00 250 psi low, 5000 psi high for 10 minutes each charted. 10/21/2018 1021/2018 1.00 COMPZN WHDBOP MPSP P Rig up lubricator, pull BPV 0.0 0.0 12:00 13:00 Page 30131 Report Printed: 10/25/2018 Uperations Summary (with Timelog Depths) MT6-06 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Tlme End Time our (hr) Phase Op Code Activity Code Time P-T-x Operabon Start Depth (ftKB) End Depth(flKB) 10/21/2018 10/21/2018 1.75 COMPZN WHDBOP FRZP P PJSM, rig up and pump 47 bbl diesel 0.0 0.0 13:00 14:45 freeze protect down IA with Ball Mill pump, taking returns out tubing @ 1.5 bpm, 745 psi. 10/21/2018 10/21/2018 1.25 COMPZN WHDBOP FRZP P Line up and allow tubing and annulus 0.0 0.0 14:45 1600 to U-tube. SIMOPS- R/U to lay down drill pipe. Clean up rig floor 10/21/2018 10/21/2018 0.50 COMPZN WHDBOP FRZP P Blow down and rig down tubing side 0.0 0.0 16:00 1630 pumping equipment. 10/21/2018 10/21/2018 0.50 COMPZN WHDBOP MPSP P Rig up lubricator, test to 2000 psi. Set 0.0 0.0 16:30 17:00 Type H BPV. Rig off High Line power @ 17:15 hrs. 10/21/2018 10/21/2018 1.00 COMPZN WHDBOP MPSP P Test BPV to 2500 psi with Ball Mill 0.0 0.0 17:00 18:00 pump, charted 15 minutes. Blow down and rig down testing equipment. Final tubing pressure=100 psi, IA(A) =275 psi, IA(B)=0 psi, IA(C)=120 psi. 10/21/2018 10/21/2018 1.00 DEMOB MOVE RURD P Prep kill line for rig move, remove 0.0 0.0 18:00 19:00 working valve on IA, install gauges and flange. Secure well. 10/21/2018 10/22/2018 5.00 DEMOB MOVE PULD P PJSM, Lay down 4" Drill pipe via 0.0 0.0 19:00 00:00 mouse hole, 60 stands laid down. SIMOPS- Prep for rig move 10/22/2018 10/22/2018 2.75 DEMOB MOVE PULD P Continue laying down remaining 19 0.0 0.0 00:00 02:45 -Islands 4" 14# DP from derrick. 10/22/2018 10/22/2018 0.75 DEMOB MOVE RURD P Lay down lubricator, Install skate 0.0 0.0 02:45 0330 roller. Remove mousehole, C/O elevators. Install drain hoses. 10/22/2018 10/22/2018 3.50 DEMOB MOVE RURD P Clean and clear rig floor, Clean under 0.0 0.0 03:30 07:00 pipe rack and pollution pan of MOBM. SIMOPS- Move Pipeshed and Ball Mill Complexes. Install flanges on tree. Rig release @ 07:00 hrs. Page 31/31 ReportPrinted: 10/25/2018 vI ConocoPhillips ConocoPhillips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-O6 50-103-20773-00 Baker Hughes INTEQ Definitive Survey Report 02 November, 2018 BA f�ER UGHES ConocoPhillips fatme O ConocoPhillips Definitive Survey Report Comparry: ConocoPhlMpeAlaile) Inc-WNS Local DpoMmata Renronce: Wal MT6-06 PmJech Madam Norm Slope TVD Reference: ACTUAL MT6-06®89.14us8(Actual Doyon19) Sle OMTI Lookout Pad MD Reference: ACTUAL MTS -08 @ 89.14us8 (Actual Doyon 19) Well: MT646 North Reference: Tme Waltham: MT6.06 Survey Calculation McNoM Mimmumcurvature Design: B1-wp02 Database: EDT 14 Alaska ProducBon Project Western North Slope, North Slope Nests United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Map Zone: Alaska Zone 04 Using ge clefic scale factor Well MT6-06 Well Position 'NIS 0.00 usg Nadhing: 5,945.536.92usn Latdude: 70°15'22.892N 'EI -W 0.00 usn pasting: 317.Ml.19us8 Longitude: 151.28'43.4nW Position Unceminy 600 usd Wellhead Elevation: O.wusfl Ground Level: 37.20 ash Wellbom MT646 Magnetics Model Name sample Data Declination Dip Angb Field strcn9m rl (-T) BGGM2010 B/9/2018 16.45 60.70 57,397 Design MT646 Audit Notes: Version: 1.0 Phase: ACTUAL Te on Depth: 15,799.03 Veftical 8ectlon: Depth From (WD) .WS 41uN Direction (.an) (ush) loan) 1.1 0.00 600 0,00 234.01 114/1018 1'47.'SSAM Page 2 COMPASS 6000.14 Boo! 850 .. ConocoPhillips 8�4 4 ConocoPhillips Definitive Survey Report Compeer., COOocuPh'IIIIpS(Alaskd) Inc. -ANS Local Coordinate Reference: Well MT6-06 Pro1wil: Western North Slope TVD Reference ACTUAL MT6-06 @ 89.14usX (AOWal Doyonl9) wrtlaal SXe: GMT1 Lookout Pad MD Reference: ACTUAL MT6-06®89,14usfl(Actual Doyonl9) +WS Well: MT6-06 Sewnin g North Reference: True (9 Wellbore: MT6-06 (MMD Survey Calculation Method: Minimumcumature lel (n) Deal, 61-,02 36.94 Dandase: EDT 14 Alaska Production Was 6220 Survey Pro'mm 0.00 Data 317041.19 060 0.00 UNDEFINED 115.00 Frem To 115.80 25.60 834 Survey Survey (use) (use) so., Wellleme) Too[ resume Description Sten Deb End Da% 115.00 1,021.00 Gymdala GymSS 16"(MT6-OBPB1) GYD-CT-DMS Gynodata conidAlpipe We 9/10/2010 9/102010 1.106]4 2,063.83 BHGE MWD+SAG+IFR+MSA16"(MT60 MM+IFRAK-CAZ-SC MWDHFRAKCAZSCC 91112018 91122010 2,160.09 10.285.05 BHGE MWD+SAG+IFR+MSA 12 W(M MWD+IFRAK-CAZ-SC MWD+IFRAKCAZSCC 91152018 91172010 10,371.52 11,985.07 BHGE MWD+SAG+IFR+MSASx3W4"(M MWD+IFRAK-CAZ-SO MM -IFR AK CAZ SCC 92612018 92812018 11,84200 15,799.83 BHGE MWD+IFR+MSA 6"(MT646PB2) MM.IFRAK-CAZSC MWD+IFR AK CAZ SCC 1O/102018 1011212018 15,829.00 17,419.01 BHGE MWD+IFR+MSA 6"(MT646) MWDNFR-AK-CAZ-SC MWD+IFR AK CAZ SCC IW1312018 1W1412018 Survey 11WO18 3:47:55AM Page S COMPASS 5000.14 Budd BSD wrtlaal MD loan) In. Aal TVD TVD89 +WS +n4N Noreing Sewnin g DLS Seattle Survey Test Name Annotation (9 (1) (-Mo (MMD leen) (-to lel (n) MINI ln) 36.94 060 000 Was 6220 060 0.00 5,845.530.92 317041.19 060 0.00 UNDEFINED 115.00 0.51 16722 115.80 25.60 834 0,08 590.5,536.58 317041.20 065 014 GNUCTDINS(1) 2Nxo On 16]04 .,as 115.85 -1.31 020 5,945,535.60 317041.45 020 054 GYDCT-0M6(1) 300.00 086 X6.24 2 S. 21005 -242 010 5,945534.50 311.041.32 050 1.27 GYDCTLMO(1) WIN on 24751 360.98 21184 3.88 -032 5,945,534.00 311,040.81 019 195 GYDCT-0MS(1) 455.00 1.60 290.97 454.99 365.82 -246 -2.00 5,945,534.51 317.039.14 1.37 386 GYMTAM5(1) 550.60 379 30.88 549.85 46071 019 -457 5.945,53725 317.0563 Z. 439 GYD-CTDWS(1) 60500 6.03 311.84 644.50 555.36 5.54 -It 69 5,945,54214 317.16N64 2,36 621 GYCOT-0Ma(1) Y3a00 8.81 311]1 126.11 541.51 13 ,t -XI ES 6M.550.95 317,020.88 2.99 8]5 GYPCT-0M0(1) 812,011 1103 312.24 829.30 74016 24.38 3261 5,945,56200 317009.12 2.36 12.11 GYDCT-DMS(1) 926.00 12.93 312.92 M1.25 03241 3759 41.03 5,94557504 315,995.09 203 15.97 GYDCT-OMS(1) 1,02100 15.01 31360 1,013.43 924.29 5331 -63.13 5.945 591.76 316,978.10 220 20.24 GYDLT-DIMS(1) 1]60]4 1730 31412 1NOW 1,000.66 6880 -60.87 5945.608.66 316.962.05 256 2442 NANDHFRr AZSC(2) 1.149.12 1.70 31517 1,18[-9 104755 79.19 -9321 5,94581a2H 316,952.94 3.79 2546 MNDHFR-PH-0AZSC(2) 1.24934 20.78 316.64 1,225.74 11860 102.8 -11224 5,94564196 31fie31.40 2.22 30.68 MWDNFRJ-CAZSC(2) 1,33761 22.41 We. 1,31245 1,2X132 1P.59 -13561 5,945,661.76 316,900.03 182 M68 MWD+1FR-cCAZSC(2) 1432.48 23.8 318.88 1,39d.M 1,3108 155.20 -15890 5,945,595.95 316,885.04 107 3836 M IFR-AK1ALSC(2) 1526.88 24.13 31560 1.48.31 1,397.23 183.13 -185.00 5,945 ,84.60 315859.91 1.58 4273 NVND+IFRAKCPZSC 12) 11WO18 3:47:55AM Page S COMPASS 5000.14 Budd BSD ConocoPhillips ConocoPhillips Defnithe Surrey Report Company. ConomPhilips(Alaska) Inc. -NMS Local Coordinate Reference: NON MTB -0 Project Motem North Slope TMD Reference: ACTUAL MT84W@ 89.14us0(Actual DOyon19) sea GMT1 Lookout Pad MD Reference: ACTUAL MT6-06 Rt 89.14us0 (Actual Doyonl9) Well: MT6-06 North Reference: True Wellbore: MTS -06 Survey Calculation MetLad Minimum Cu.ture 0e519n: 31-np02 Dau6ase: EDT 14 Alaska Producton survey Annotation 13.318"A 16" 11101018 3:47:55-094 Page 4 COMPASS 5000 14 Build 850 p Pact, Vertical MC 19mq Inc 1+1 AC M TVD (and"(ural TVp&S 4py3 lam) ♦F/JY Wen) Northing Eamng DLS 1-1100'j(nl Sepdon Survey ToolWme MI (n) 1,Q1 B9 2574 314.42 1,571Q 108329 2M" -214.07 5.945,753.49 3f6Q233 1.79 MM MJNHFRAK-CAZSC(2) 1]16.26 27..14 31461 165.92 1,567]8 240.90 -2M,m 5,945.783.5 316.80310 1.49 Mal MWD+IFR-PKGSBC(2) 1,809.69 29.23 314ad 1,739.27 1,607,13 27160 -27545 5.94&01539 31677243 2.24 WA4 MWD+IFR-PH-CAZSC(2) 1,903.5 30.26 31104 1,0-01.77 1]3.63 3N,Q 410979 5,945.84&71 316.739.90 1.13 71.00 MWD+IFR-AK-CAZSC(2) 1,997.7 3160 315.37 190167 1,812.53 338.37 343.10 59458"m 316,70.43 141 70,80 MW IFR-AK-0AZSC12) 2.0383 3218 316.15 1,957.73 1.8458 69 363,19 367.70 5,945908.91 316,682.M 1,64 84.12 NMD+IFR-AKLAZSC(2) 2118,5 33.38 315.10 2003.68 1,91454 384.30 360.5 5945.930.52 318,6810 ." ka. MND+IFRAK AZSC(31 2,16089 34.07 315.2) 2,038.07 1,94873 40.0 <024 6945.947.58 3ffiti 5,M 164 92.30 MWDNFR- AZ-SC(3) 2.183.49 34.38 315.10 2,057.5 1,968.2 4097 414.20 &94595.81 316,637.10 1.31 94.26 MWD+IFRJ-CAZSC(3) 2277.93 0143 316.27 2134.54 2045.40 44911 452.40 5,94695.88 316,599.0 231 102.16 MWD+IFRAK-CAZSC(3) 2,371A1 3675 316.97 2,5 Isl 2119.47 490.0 49156 5,8a,'ade9 316.51.73 2.52 10949 MWD+IFRAK-0AZSC(3) 2,46&52 40.55 3128 2281.07 2191.93 524.73 53224 5.946,084.39 310.622.13 .90 11646 MND+IFRAKCAZSC(3) 2,59.45 420 3111,30 2351.63 2,26K49 590.01 ZM,71 5.946.131.46 31648169 165 IMA4 MND+IFRJ AZSC(3) 2654.14 440 318.95 2420.111 2331.67 5MM S16.44 5,948.10103 316,440.26 219 129.0 MWDAFR-MR AZSC(3) 2,748.39 4605 318.24 2,487.49 2,398.35 67920 660.49 59462320 316.397.44 185 135.30 MWDOFRAK-CAZ4C(3) 28425 45.83 3t&0 2,55341 248397 729.59 -005.60 5,946283.39 316353.57 0.18 14223 MJrD+IFRAk-0K (3) 2,938.53 4583 31&11 2,618,57 2.52943 779.71 -050.84 5,946.334.59 316,309. To am 14923 MND+IFRA-CAZSC(3) 30120 45.5 31643 2664.53 2,595.39 030.40 -70.0 5,946,30.35 316,20.83 024 156.03 MWOHFRJJ(-CPLfiC(3) 3,124.70 4&M 318.41 2,749.64 2,66050 00.59 640.38 5.916.43161 316,222.50 004 162.57 MWD+IFR-AK{AZ86(3) 3,219.39 45.08 317.92 2,015.5 2)26.42 931.24 -88512 5,946,489.34 316,17040 037 16949 MWD+iFRJ CAZSC(3) 3,313.34 4589 31&0 2,88.0 2,79162 981.35 930.5 5,946.540.53 316,134.48 0.08 in so MWJHFRAK-0AZSC(3) 340746 45.05 31&19 2.946.28 2857.14 1,031.48 97585 5,946.591.74 316.600)5 043 18.51 M IFRAK-0AZSC(3) 3,50146 456 318" 3,011.0 2,92281 1,082.02 -1 =as 5,946.643.35 316,046.99 019 19023 MND+IFRAK A? -SG (3) 3.59588 4504 318,14 307171 2,988.9 "'most -1,00.93 5,94&600.0 3160345 023 19699 MND+IFRJJ AMC 13) 3,890.61 4607 318.53 3,143.57 3,054.43 118.46 -1.111.19 5..746.95 315959.14 call 2073 MWDNFR-AK-0AZ6C(3) 3)04.21 4691 318.75 3.208.01 3,118.87 1,234.41 -1.15.04 5946.79897 315915.54 0.91 210.08 MWD+IFR.-CAZSO(3) 3 B78.79 48.08 3A2(I 3.271.92 3,102.78 1,28242 4,20135 5,946,853.0 315.071,55 1.68 215.59 M IFRAK6AZSC(3) 3973.0 0.97 32.5 3,334.31 3245.17 1,342.10 -1,245.97 590.900.81 315,028.26 1.32 21957 MNDNFRA-CAZSC(3) 9.08.8 Wn 32220 3.395.57 3,30.43 1,399.15 -1,29089 6946.95.92 315]84]5 196 222.39 MNDHFRAKAA28C(3) 446251 51@3 324.09 3454.h 3.365.58 11450.13 4335.09 5,947.Mati 315 742M 1.93 223.50 MNDHFR-N(-C C(3) 4,2578 5203 326.78 351279 342365 1S.. y37772 5947089.87 315)0.88 249 22162 MWDNFRAA-0A250(3) Annotation 13.318"A 16" 11101018 3:47:55-094 Page 4 COMPASS 5000 14 Build 850 survey ConocoPhillips ConocoPhillips Definitive Survey Report C,mpany'. ConocoPhilllpa(Alaska) Inc. -MS Local Coar6lnate Reference: N 11 MT&00 pispa: Western NorN Slope MReference: ACTUAL MT"S@ 89.14usn(Aclual Detain 19) Site: GMT1 Lookout Pad MD Reference: ACTUAL MT641S@ 0944ua5(Actual Doy,n19) Well: MD546 North Reference: hue Wellbore: MT6.06 Survey Calculation Method Minimum C..tu. Deaden: B1-'40702 Daub.., EDT 14 Alaska Production survey Annotation 11?11018 3'476MM Pae, 5 COMPASS 500D. 14 B.W BSD MD Inc Aal TVD TVDSS NiI +Bm 045 Northing Short, Semon wrvay Too[ Nam (Malty 1`1 M loon) learn loan) Will (re) Int Vnon) (n) 4.352.09 54.04 32$49 3.569.15 3,480.01 1.584.20 -141930 5,947,155.01 315,66190 194 216,81 MWDHFR-PX-02ZSC(3) 4,447.23 5.31 32974 3r524 16 3.53502 1.65002 -1,458.22 594],2225] 315.623.59 111. 26990 MWDHFR- .AZ-6rsI 5680 332M 36]6,02 3,59769 1,719.24 -1496,13 5,947,291.89 315.57.36 272 20037 WADAFR-PI(-CP C(3) 4635.37 575 33469 3,72]]3 3,638.59 1,789.77 -1,53132 5,947,363.24 315,563.5 230 187.41 MVVDAFR--CAZSO(3) Anti.10 5745 337,51 3777.59 3,688.45 1061.24 -1,56299 5,947,43546 31652,497 25 17104 MND+1FR-AK-0PZ50(3) 4,822.5 57.54 330.55 3,828.32 3,739.10 1935.07 -1,592]] 5,94],507.07 315,49559 093 15V6 MND+IFR-AK-0AZSC(3) 4,916.98 5789 338,11 3.876.79 375.65 200&29 -1,62227 5,947564.5.0 315,46631 0.54 13201 MWD+1FR-AK-0AZSC(3) 5.011.33 5791 33810 3,91692 3,839.76 2,00345 -1o"OT 5.947,65976 315.44031 002 112,55 MWD+IFR-AK-0,4280(3) 5.1025 57.5 337.5 3pn tete 3 m5 2155A5 -1,681.13 5,94].]3243 315.413.02 0.15 9375 MWDHFRIJ AZSC(3) 5,19&07 57,5 33]]7 402713 3,937.99 222&24 4711.18 5.90,608,93 315,30474 071 75.31 MWD+IFR-N(-0AZ4C(3) 5.291,12 5807 336,35 4,07764 3,98&50 3,30230 -0,742.99 594],990.]4 315354.74 075 57.52 MWD+FA- -CAZSC(3) 5,59.57 57.9 336.64 4,129,89 4.04075 2,378.82 -1,776,P 5,947.9584 315323.33 027 3949 MNDHFR-A AZSC(3) 5,485.75 57.80 33616 4181,02 4,091.88 2,453.47 -1,007,80 5,940.03345 315392.5 042 Mon M IFRA-CAZSC(3) 5,579.70 57.83 335.29 4,231.05 4.141.91 2,526.04 -1.84162 5948,106.79 315261.5 0,79 595 MNDAFRAK-CAZ-SC(31 5,575.14 57.05 334.31 4,281.81 4192.67 2,559.99 -1.6]599 5,948,1WB5 315.22900 0.87 9.25 MNO+1FRAK4AZSC(31 5]69.46 5784 334.17 433148 4,24234 26]O.X -1,910,32 6.90 mAl 315.15.41 0.13 3328 MVDNFR-AK AZSC(3) 505369 5787 333.52 438214 4,293.00 2742.62 -1,945.97 5.940,32682 315.15.2.5.4 0.58 41705 MWDHFRAKCAZSC(3) 5.95725 57.89 .:tes 4,43180 4,342.]8 2013.59 -1,90112 5,948,39707 315,129,12 012 -6023 MWD+IFR-AH AZS (3) 6,05255 57.0 303.38 4,4625 4,393.44 288.13 -2,016.48 5,948471.00 315,095.54 065 1424 MWDHFRJJ AZSC(3) 6.14820 AP 335.8 053247 440.1.33 2,857.95 -2049.96 5.940,543.61 315,063.81 1.13 -79.35 MUW+IFflAKCPLuC(3) 6.24093 57.85 13&41 4,582.93 4,49379 3,03121 $002,54 5,948.617.63 315,033.0:2 070 -96.03 MJVD+IFR- -CAZSC(3) 6,334.8 67.82 337.09 4.63294 4,54300 3,104.26 -211393 5,948.691.42 316 MAI 0.61 -113.5 WAND+IFR-A CAZSC(3) 6.42932 57.8 33&32 468320 4.594.06 3,17]]2 -214556 5949.7655.2 31497358 0.68 -131.13 M4VD+IFPAK AZSCsu 6,52330 57.8 33521 4,733.19 4.644,05 3,25.29 -2,1]&23 5,94&&3896 31494269 100 -14734 MND+IFRAK-CAZSCsl 6617.W 57.82 335.23 470330 469424 3,322.77 4,211.69 5,948,91222 314,911.00 0.05 -16295 MWDAFRAK-CA2-6C(3) 6,711.36 5TW 335.64 Attal29 4744.15 3,394.96 -2,244.60 5,94898.19 314.879]] 0.3T -1]85] MJID+IFRAK-CAZSC(3) 6,80680 ST79 331.20 4,883]3 4,794.5 3,46757 -2,278,5.7 5,949,05607 314.847.5 1.29 49374 MWD+IFRFKCAZSC(3) 8.9D182 5762 334.62 4.934.31 4,045.17 3.540.03 -2313.37 5949131.89 314,01463 0.38 -20624 MWD+JFR-AK( -SC (3) 6,99205 57.8 334,25 4...19 4,11.05 3.61016 -2346.92 5,94820280 314,782.80 034 -22230 MWDHFRAX.AZSC(3) 7.08715 57.8 334.30 5,03337 4941M 3,682.11 -238152 5949275.5 314,]49.95 012 -225.5 MND+IFRJ -CA C(3) 7.18014 5768 No 66 5.08290 4993,04 3,752.81 -241597 5949347.8 31471723 0.69 -250.25 MND+lFR-AK-CAZ4C(3) Annotation 11?11018 3'476MM Pae, 5 COMPASS 500D. 14 B.W BSD �- ConocoPhillips Conocophillips Definitive Survey Report Company: ConowPh'lylps(Alabka) Inc.-yyNS Local Coordinate Reference: MR MT6-% Pnoji Masson Nonh Skip. ND Reference: ACTUAL MT646 @ 59.44usft (Actual Doyon19) She: GMT1 Lookout Pad MO Reference: ACTUAL MT646®89.14usft(Actual Doyonl9) Well: MT"6 North Reference: Tme Wellbore: MrB Survey Calculation MHhod: Minimum CurvaWre Deslpn: 811,02 Oalahase: EDT 14 Alaska Production Survey MD Inc Aar TVD TVDSS +al aVM Msp Map Vertical (uaftl 1°1 (% (-ft) tuaR) its") Draft) NorthingF4e,Mp OLS SeNe0 Stark, Total Name hq pll 1°npp9 pt) 7274.18 57.84 M70 5.133.30 3674.16 3,82002 -2,45120 5,949.419.12 314603.75 u'. -MI359 MWD+11FR% -nCOu 7.356" 5768 33404 5.183.03 5,094.69 3,8958] -2,486.35 5,949491.60 314650.35 031 -2]]25 MNDNFR-AK-0A25C(3) 7 46329 57,63 33471 5,2%.4] 5.145.33 3,967.77 -2,520.91 5.949.%4.51 31461]" 0.60 -MI.63 MWDNFRAK-0AZSC(3) 7.556.76 57,67 336,04 5204.52 5,195.30 4,038.54 -$553.02 5,M,0?04 314,5136.40 I.W 567.18 MWo+IFRr CAZSC(3) 7.851.68 57,70 336.44 5.335.29 5246.15 4,11295 -25. is 5949711,21 314,555,87 on -32417 MNOHFRAK-CAZSO(3) 7,745.90 57.69 MW 5.385.64 5,296.50 4,1505.61 -2,61821 5,949.704.85 314,525.59 0.34 341,0$ MND+IFR-AK-CAZSC(3) 7,840.35 57.66 335.70 5A3614 5,347.67 4,250.60 -2650no 5,94,M4,,8 3144M.75 032 35?45 MWR+IFR-PX-CPZSCI3) 7,93370 57.87 3358 5.403.12 5,390.98 4,33063 -2,683.30 5,949,931.10 314,4"04 002 17346 MJ9DHFR-AH-CAZSC(3 902700 55.41 314.12 5,538.05 5,440.91 4,401.01 -2716.59 5,950.003.14 314.43240 2.79 -388.35 MWD+IFRAK-OAZSC(3) 8,122]5 51.95 33123 5,59419 5505.05 4,46933 -275217 594.671.67 314,39865 4.93 -679.24 MWWIFR-PKF 43C(3) 831645 5190 3X03 5,651.67 5,55285 453223 -276066 5,950,135.31 314,36161 2.06 40505 MJNHFRA-CAZSC(3) 8.311.41 50.31 323.82 5,711.62 5 48 4,59300 -283260 5.950.197,09 314,321.W 298 - ,76 MND+IFRAK-0AZSC(3) 8,40352 4625 322.41 5,77170 6ffl 6 4,648.84 -2,874.57 5.9%.253.&3 31421811% 2.51 -005,68 MW IFR%-CAZSC(3) 9498.40 46,67 320.67 5,83621 574707 4703.33 . 917.02 5,850,30944 314.23815 2.05 40269 MJ40HFR✓0(-CA CD) 0.59227 4392 317.91 51902.94 5,81380 4]53.92 -ZW131 5,950,301.07 314,196.40 3.08 -J97.23 MNDNFRAR-CAZSC(31 8,065.1] 42.19 31375 5,no,17 5.88ll3 4,]99.1] 3,067,22 5,9150.40737 314153.61 3.67 388,29 MW0+IFR- AZSC(3) 0,779,40 4080 30943 0.041.06 5,951.92 4,M.61 4,051.87 5,950,44993 314,107.93 330 37490 16AND+1FR-AKLA-nC(3) 6,873.97 3903 3D4.15 6.113.62 6.f24.48 4,8]697 5,10039 6.9W,48745 314,06036 4.04 -35700 MNDN1PRAK-0AZSC(3) 8.91 37,06 299.42 6,18793 6830,79 4905," -3.1W,48 5967,51973 314.01165 3.34 534.73 MMY)+IFR CAZ4IC(3) 9,063.42 3].0 29447 6,263.02 6,17380 4,4%,11 3,20172 3867.547.04 313,96o.46 329 50658 MNOHFP.-CAZ43C(3) 9,15747 3691 2117.03 8.33866 8,24852 4,954.31 3,25390 5,950.568.49 311908.09 437 -278,31 MND+IFRAKLAZSC(3) 9,252.10 35.59 279.91 6,41551 8,3X37 4,677.55 -3,30].3] 5,&'0.58303 313655.66 490 -24215 MND+IFRAWCPZSC(3) 9,345.12 35.96 274,19 6491,W 6401.86 4,974.21 436138 5,950,590.67 313,001,. 362 40304 MND+IFRAK-CAZEC(3) 943997 35.94 X9.47 6,677,8) 647688 4,97599 1.416.90 5.950.594.12 313,]463] 292 -15908 MND+lFR-AK-OAZ4C(3) 9.5X3.07 35.93 264.10 6,643.X 6,554.. 497292 -3,471.40 5,967.672.38 313.691.81 338 -113.17 MW0+11FR-AK-04ZSC(3) 9627.60 35.94 25929 6,719.76 663062 4674.91 5,52626 596,511571 313.68.78 259 E400 MWD+IFR-AH-CAZ43C(3) B,Y12W VZ3 253.02 6.795.60 6)06.54 4,951.46 5,500.69 5,950.573.511 31350205 4.11 -12.13 MND+IFR-AK-CA25C(a) 9,815.57 38.10 246.83 5.869." 6,78070 4,931.89 -3,iim.X 5.967,53,32 313,52802 4.16 4271 MWONFRAK-0PZSC(31 9,90.91 38.92 24121 6943." 685450 49..19 -3.687,08 5.967530.91 313.47460 3.86 100.55 MWDHFP--CAZ4;C(3) 10,005.11 4018 23700 7017. 6,92792 4875. 1.73908 5950,501.09 313.421.86 3.06 160,90 MWD+IFRJO AZ43O(3) 10099.83 4191 231.38 7089.52 6,967.38 4,.aR -17NA? 5,967,4658 313,37001 435 21304 MDrIFR-AK-0gZSC(3) Annotation m a. 0 11?11018 3'4755AM Pape 6 COMPASS 500014 &W 650 3: Cof)ocoPhillips ConocoPhillips Act lYD Definitive Survey Repon a1111d Company: ConowPhillips(Alaska) Inc. MS Local C.aWknale Rehmnw: Nbll MT6-06 PwjM: Western North Slope TVD Reference: ACTUAL MT6-06 C 89.14us0 (Actual DWon19) She: GMT1 Lookout Pad MD Renrence: ACTUAL MT6-06@ 89.14us0(Actual Doyon19) Well: MT6-06 North Reference: Two Wellbore: MT6-06 Survey Calculation Method Minimum Cui,naurc Design: 81-Wp02 Database: EDT 14 Alaska Production Survey MD Inc Act lYD 1VD86 a1111d aErm Map Map *Mo.[ /luralM (9 (cax) (-am loan) (carry xonnm9 Sending OILS Said n Borvey Toolxama IRl (try / npp) (n) 10.1938] 4150 22739 71S7,63 ].069.49 4j9Z19 S,&T].80 5,9584X63 31332124 334 286 5B MWD+IFRAK-CAZSC(3) 10.05.85 44.90 22452 7.M458 713444 4,75261 -3,803.90 5950,3821] 313.274.11 215 35n06 14WDaIFR-PSCA25C(3) 10,3160 4q.94 22394 7244,93 T,155.79 4,]3].35 41Sell 5,850,3970 313,258.89 1,37 371,04 MWDHFRAK-0PZSL(41 10,371.52 4502 2 87 7,254.0 7,195.06 4,)04].84 $9258 5,850.33943 313 Z11,25 1.37 40861 MWD+IFRr AZSC(4) 1p.,[34 4695 218.03 ],345]0 7,259.56 4,658.74 -3,96880 5,950,29042 313.185.96 3,12 47432 MNo+IFRAK-0gZSC(4) 10.5600 50.65 215'. 7,411.85 ],322.)1 4,601.81 -4,01403 59`0.234.59 313140.37 4,113 54395 MNDHFRA1<-0AZSC(4) 10.655.11 5353 21245 [4]0.04 7=90 4539,79 -0,056.11 5,950.17361 313,09579 435 61445 MWD+IFRA-CAZSC 0) 10.711"1 5629 09.17 7524.83 7,435fi6 44860 -0,0%.14 5,850.107.41 313.055.14 3.89 686.33 MJ AFR-PI(-C&ZS (4) 10,84473 saw 20694 ],57523 7,48609 4,402.46 4,13349 5,959,030.21 313,016.10 3.44 757.76 1NaOHFRAK-CAZSC(4) 10,9b.% 6156 20500 7,60.01 ],53287 4,328.15 4,16983 5,948,95001 312,97&w 299 030.23 MWD+IFR- AZSC(4) 11,03200 63.74 20,81 7,664,75 ],5]5.61 4254,17 -4,204.47 594909169 312.941.55 3,112 90233 MND+IFRJJ(-CAZSC(4) 11,125.52 Son 202,54 ],]05.30 761624 4,17673 -0,0761 5.949,815.39 312.901 1.64 97464 MWDHFRAK-0AZSC(4) 11219.37 ".74 01.0 7.745.41 7,656.27 4399.11 4,26859 5,849,]37.2] 3128806 0.78 1,M.M MM+IFR-P AZSC(41 11,31200 .469 01.24 7,784.97 7,695.83 40017 4,300.27 5,a.No, 11 312.840.10 0.40 1,117.34 MWDHFR-qK-LA2SC(4) 11,400.62 65.03 200.35 7,625.17 7,70.03 3,940.09 433169 5,84,W,w 31280776 0.92 1,189.00 )N0a1FRAWCA C(4) 11,501.01 65.63 18503 7,810,59 7,77545 3.05858 4,35730 5,9494%95 3127M17 4.40 125643 MWD+WRr AZSC(4) 11.594.40 67.51 106.0 7, ell 7,81263 3,775.15 4,376.97 5.949,41704 312.]5].48 539 1,323.37 MND+]FRA-CAZSC(4) 11,609.55 69.51 15151 7,936.511 ],84].45 3,6117.71 43910 5,94932995 312.74213 ASS 1,38547 MNDNFRAK-0AZSC(4) 11.785,07 7107 183.08 7.995.15 7,87901 3.5974 4,39636 5,949,24041 312)31.80 3.56 1,44481 MWDHFR-N(-CAZSC(4) 11,84200 73.36 161.91 7985.39 7,595.03 3,54168 4,40110 5,949,189.0 3128).]4 4.21 1,470.91 MNMAFRAK-CAZSC(5) 11.87559 7596 184.73 7,994.06 7,064.91 3,511.36 4,40288 5,919,15387 312725.06 11'0 1,49942 MWDHFRAKCAZSC(5) 11,594.46 76.12 INSS 7,99860 7,839,46 3,493.10 4404.52 5,949,13526 312.72309 tat 1,51140 MWD+]FRP AZSC(5) 11989142 81 S4 184.14 8,01589 7,92785 3,40027 4411.90 5,949.043.14 312.713.46 En 1,571.91 MND+IFR-AI(-CA C(6) 1239558 85.77 10107 Bonn 7.93800 3M4,83 441623 5,94890.8W 312706,81 5.42 101.50 ~+lFRAK-CAZ4C(6) 12180.38 80.10 177.57 0.03104 7,64190 3,21814 441510 5948,85115 31270584 5.87 1,6880 MVWryFR-AK-CA C(5) 12215'0 9045 1]4.55 8.03059 7,941.44 3.115.05 4,408.55 5,94675794 312,709.88 319 1,73800 MNDaIFR-pl(-0gZSC(5) 12.371.47 90.45 10.28 0,029.03 7,840,69 3.@0.15 4,3959, 5946,[3926 31270,21 4.40 1182.34 ~+IFRAKLAZSC(5) 12.468.57 8998 16651 6029.47 7,94033 zavo, 4,3]6T9 590569,19 312,737. 199 1,82159 MWDaIFRAKLA75C(5) 12.56202 5942 162.69 8,@997 7940.83 2,83500 4,M104 5940.06.61 312760.16 4.04 1,85515 MND+IFR-AI({AZSC(5) 12657. .16 158.90 8.0.90 ],911.]8 2744.93 430.. 51948385.)7 312759.35 3.97 1882.70 MWDHFRAPi A C(5) 12.75267 W. 155.17 8,03172 794258 2,657.25 -4,28282 5,948297.25 312,824.35 392 1,804,14 MWDHFRAK-0AcSC(5) Annotation 9-5I8" x 12-1b" 11? 0183:47'55AM Papel COMPASS 500014 BUO 858 v CorkocoPhiiiips ConocoPhillips Aal 11 153]] 151. 151.54 1046 10.% 153.19 15100 152.40 15168 15166 151.14 160]0 15075 TVD luam 8.032.95 Ramat 8,031 8=27 993270 8,03279 0,032M 0,033.27 8,03144 903536 8,039.1. 8.0420 0,045.47 Definitive Survey Report +WS (usft) 2,4036 2,487.33 2,404.0 231903 2,23791 2,15130 206968 1,984,51 1901.33 1,817.32 1,733.65 1,65035 1,558]4 Co.": COnOmPhilips(Alaska) Inc.-WNS Local Co,mdinato Reference: Well MTS -06 Project Western North Slope TVD Reference: ACTUAL MT6-06 (@ 89.14us6 (Actual Doyon 19) Sme: GMT1 Lookout Pad MD Reference: ACTUAL MT6416@ 89.14ua0(Actual Dayon19) Well: MT6-06 North Reference: Tlua Wellbore: MT6C6 Survey Calculation Method: Minimum Curvature Dookii 31-w 02 Database: EDT 14 Alaska Pmd.0on Survey Mo (-amP) 12.84922 12,943.01 13,0224 13.135.01 13 MM 13.32293 1341847 13,51180 1360906 13,704.52 13,799,05 13.895.24 13,991.14 Inc 8B98 00 90.90 8059 9001 890 898. 8949 89.0 0880 BBAl 0789 8967 Aal 11 153]] 151. 151.54 1046 10.% 153.19 15100 152.40 15168 15166 151.14 160]0 15075 TVD luam 8.032.95 Ramat 8,031 8=27 993270 8,03279 0,032M 0,033.27 8,03144 903536 8,039.1. 8.0420 0,045.47 TVo33 (uam 7,94302 2,9454] 2,945.46 7,94113 7,943.64 7,94365 7,94368 2,944.13 7,94530 7,94732 7,950.04 7853.45 7,95633 +WS (usft) 2,4036 2,487.33 2,404.0 231903 2,23791 2,15130 206968 1,984,51 1901.33 1,817.32 1,733.65 1,65035 1,558]4 .0m (usf) -0,240.055,9480 419727 4152.06 4,104.91 4,069.0 4,014.39 S,90.19 -3,925.00 3188085 -3,11 -3,78994 -3743.61 3,696]4 111, NoB 12,3) 5,940.4531 5,M,., 00 5947,954.82 5,947,82262 5,9,,78.1.0 594270229 5,90,616.06 5947,531.84 5,94],446]6 5.947362,01 5.94737761 5.947.19289 Eaetlnp 312`861.28 312,90583 312,949.01 312994.08 313,0797 313AM57 313,42.0 313.16&80 313.207,91 313.25115 313,29122 313.339.0 313,312.83 OLS (0110w)Survey 216 185 2. da, 1.18 0,63 270 156 8.89 087 0.51 082 048 862 wanton Tool Name 1 MIA7 MWDNFR-PI(-CAZ50(5) 1,83489 MW WPAK-0A2SC(6) 1,94702 MND+IFR- -CAZSC(5) 1959a5 MWDOFRAK-OAZSC(5) 1,93939 1nAD+IFRA AZSC(5) 1982.35 MNDNFR-PI(-CAZSC(5) 1.996.36 M IFR-AK-CPZSC(5) 2,W983 MM+IFRN-CAZSC(5) 202298 MWDOFR-N(-CAZSC(5) 200570 W0+IFR-AI(-CAZSCI5) 2,04795 M D+IFR--CAZSC(5) 205941 MWO+IFR-0K-CAZSC(5) 2.07062 MND+IFRN-C2IC(5) 14.08504 14,181.0 14,276.65 14,372" 14,467.9 "4,56283 14,6560 14 MAS 14,848b3 14,943.06 15.03699 1513374 1523034 1532371 15419.41 15,51514 15.61016 157MOn 91.01 9195 9244 9160 9127 89.73 8980 8918 Ms. 8792 87.42 .882 8796 0790 8795 88.94 a. 50 881. 152.50 15308 153.16 152.0 1538 10.65 15257 15280 15263 151.97 Mad 150.37 15243 154.42 15134 155.0 IM 62 154.15 8,4,5.74 8,0439 Both 8,03525 L.33.87 AW&N 8,03.53 8,03447 803835 0,0360 8,04297 BodsM 8.050,9 sands 0,0%92 605951 808163 8.04.13 7,95690 7,951.13 7,95049 7,947.11 7,944.73 2,94390 7,90.39 7,945.33 7,947.11 7,949.92 7,953.83 7,99.55 7,960.95 2,96432 7,962]0 7,97037 79849 7,97499 1,48335 1,39932 1,31358 1,22659 t,t"35 1,05633 97393 .900 805.07 7M,0 63aaa 55528 47061 38700 3081 21432 120.31 4226 3,651.64 1,607.92 3,5W5.0 35=95 -347680 3,133.87 $350.57 3,34727 3,30041 330.17 3,212.80 y1ek" -3,12038 3,07649 -3,03714 -299336 -295587 -2,914.86 5947, IM33 5947,022.8 5,946936,82 5,946,850.60 5,946.76531 594667930 5916.59285 5,9465040 5,94542194 6,84833662 5,946,251.41 5916,160.82 59160&316 5,945.998.63 5.915,91143 5,945,82394 5,945]36,99 5945650,17 313.4M.68 313,46952 313509.35 313,55131 313,50,43 313.63427 313,9549 313716]4 313,758.51 313,00.M 313.845.03 313,09937 313933.46 313,73211 314,01245 314.01.21 31109.49 31412841 308 IAS 0.52 118 081 IN 14 0.58 051 10. 1.81 Dad 213 213 010 1.28 0.67 050 2083,19 MWD+IFR-AK-CAZSC(5) 2,0777 NYAD+IFRA AZSC(5) 2.112.79 MDNFRJ -CAZSO(5) 2127.07 MW(>FR-AK-CPZSC(5) 2,140.91 MWD+IFR-MX ALSC(5) 2156.07 M +IFRAKLAZS (51 2,17121 MND+IFRAK-0AZSC(5) 2105" MWD+IFR- -CAZSC(5) 2199,91 M IFR-AKCAZSC(5) 2213.63 MND+IFR- CAZ£C(5) 222554 MWDAFRAK-0AZSC(5) 2,235.85 MNp+1FRA AZSC(5) 224825 MWD+IFRAK-CAZSC(5) 226352 M IFR -AK -C -aC(5) 3,280.73 MWDHFR-N(Cg23C(5) 229.50 MMOFR- .CL SC(5, 231636 MND+IFR-N(-0AZSC(5) 2,333.44 MWD+IFR-W(-CAZSC(5) Annota0on l PR 11( 1834756AM Page8 COMPASS SOOO.1d Build BSD Annotation MT646 KOP 4-112" x 6° 4 1122018 3:1):S54M Pope 9 COMPASS 500014 BuiM BSD ConocoPhillips ConocoPhillips Definitive Survey Report Company: GM.,,.Phlllips(Alaaka) Inc. -MS Local Ooorc finale Reference: Wa8 MT6-06 Project: Motion Nom, Slope TVB Reference: ACTUAL MT6-N ® B944us8 (Actual DWonl0) 51. GMT1 Lookout Pad MD Reference: ACTUAL MTB -06@ 09.14usn(Actual Doyonl9) Well: MT6-06 North Reference: True Wellborn: MTS -06 Survey Calculation Named: Minimum Curvature Design: 81- 02 Database: EDT 14 Alaska Pmtluction Survey MD Inc Ael TVD lVDSS • `S +EIJy/ Map Map Veftkal (usltlI°) (7 Juan) (14571) IuaRl lusrtl Alumina, settled OUR Survey Tool Name 15793,83 ('/OUR,) .0.48 15335 SOBSE5 7,9]].51 -0218 -208.9] 5945'564.54 3Ift;4(,168.22 004 23494fi MrVO+IFR-AK A&5C(5) 15,82903 8993 153.19 B,W]31 ],9]&1] -WM -2&59,&5 5945,53sd9 314,180.]0 1.64 2,354.15 MWDNFR-PI(-CAZSC(6) 15,895,la 091. 15355 8.06902 ],9]900 42736 -2,830.20 5,94547835 314,208.91 1.37 2,364.90 MWDNFRAK-cP.RC(6) 15.98972 8836 13540 9071.94 7,932,80 31296 -2,790.23 5,945.391.]9 314.X9]0 303 2,302.07 MN➢HFR-pl(LALSC(g) 16,05115 08.33 15629 0,0]4]3 7,98S% 40127 -275156 5,945,30259 314,203.E 0,12 240348 MWDOFR--CAZSC(5) 16 WAS 8943 156.65 907659 ],98].44 dB9M -2,]13]1 5,945,21478 314,31937 122 2,42391 MM➢+)FRA CAZSC 0) 1627586 89.96 15633 8,677.00 ].987,W 47521 -287583 5945,126.M 314.351711 0.67 244439 MND+lFR- -CAZSC(6) 18,37409 0915 154.99 6,07 SO 7, 90060 561.84 .263657 5945.03922 314.39192 1.62 2,463.58 MWD+IFRANLPZSC(6) 16456.37 89.25 153.80 0,079.16 7,990$ 540.05 -2,595.37 5,844.952.14 314,431X1 11T 2,40085 MWD+IFR-AKLAZSC(6) 16.561.50 0792 15295 0,001.50 7, 99336 .]3292 .255290 5944,56527 314471.40 114 249635 MWD+IFR-FI(LAZSC(1) 16,65722 0&]6 154.01 8.08427 7,995.13 416M -2510.18 5.944,]]9,65 314,512IX4 141 2,512,09 MM➢+IFRAK-CAMC(6) 16.]5292 0996 154.51 8,085.34 79%20 404.73 -2.46882 5,944.69242 314,551,48 136 252911 MWD+lFR44tLAZSC(6) 16.846.71 .9.95 lN63 0,00542 7,89&28 48908 3,427.61 5.944.60716 314,59043 094 2,54549 MWDOFRAK-0 -RC(6) 16,94210 8.95 15337 0,085.50 T,9WW -1,074.45 -230505 5.9HS20.79 314,630.90 0.27 2,561.21 XfiYD+IFR-AK-CAZ43C(6) 1],03].61 07.51 152.14 9037.59 7,99945 -1,15933 .234134 5,944,434.87 314,6]253 293 25]5]2 MWO+IFR-FK-CP2SC(6) 17.132.92 07.46 15267 8.09175 8,00261 4,2438 -2.29723 5,94434944 314.71457 0.56 2,589.62 MJu➢ryFRAWCA C(6) 17,22&31 8&39 153.15 8X96)1] SX773 -1328.52 -2253.&5 5,944,2$62 314)55.80 1.24 2604,35 MWD+lFR-AK-CAZSC(6) 1732366 87.93 152.91 slDlel 0,01247 -1441338 -221066 5.94417]]3 314.796.99 164 2,61927 M IFRAK-0AZSC(6) 1741901 8614 155,43 6.106.51 8,017.40 -1,499.09 -2,16.18 5,944.091.37 31413&38 324 263&W MND+IFR-MHCAZSC(6) 17,48200 8&14 155,43 9110.78 8,02164 4,556,25 -2,143.37 5,844,03320 314,861.11 "M 2,640.50 PROJECTED to TO Annotation MT646 KOP 4-112" x 6° 4 1122018 3:1):S54M Pope 9 COMPASS 500014 BuiM BSD ConocoPhillips ConocoPhillips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-06PB1 50-103-20773-70 Baker Hughes INTEQ Definitive Survey Report 02 November, 2018 BA<ER HUGHES GF-,;,-, �. Conocolehillips Nc Rs A Gonocolphilli � " Definitive Survey Report Company: Con ... Phlllpe(Alaska)Inc.-WNS Local Coatdmate Refeteesa: Wel MT6406 Pmlect: VVestem North Slope TVD Reference: ACTUAL MTB-06 Q 89.14ush(Actual Doyon 19) Site: GMT1 Lookout Pad AND Reference: ACTUAL MT646@ 89.14us8(Adual Doyon 19) Well: MT646 North Reference: Tme Wellbom: MT6.06PB1 Survey Calculation Method: Malimum Ourvatme Design: B1-wp02 Database: EDT 14 Alaska Pmduction Project Western North Slope, North Slope Alaska, United States Map Spasm: US State Plane 1927 (Exact solution) Syetem Datum: Mean 5ea Level Geo Datum: NAD 1927(NAOCON CONUS) Map2one: Alaska Zone 04 Using geodetic scale tactor Well MT6U6 Well Posgion aNl-6 0.00 hall Northing: 5,945,536.92ush Latitude: 70°15'22+892N ♦EI-W OOO ush Easgng: 317,041.19usit Longitude: 151°28'43.472W Position Uncergi 000 ush Wellhead Elevation: 0.00uah Ground Level: 3720 ush Wellbore MTS-06PB1 Magnetics Model Naim Sampte Date [Nettlesome Dip Angle Fteld Shari fl PI Inn BGGM2018 6/9/2010 1645 80,70 57,397 Design MT606 P81 Audit Notee: Version: 1.0 Phase: ACTUAL To On Depth: 3694 Vertical Sea..: Depth Fmm(ND) AWS Em Direction (us") rum) (me) V) 0.00 (loo 0.00 18827 1f?12016 34u4 4,14M Page 2 COMPASS 5000.14 Build 85D Survey Conmofshillips 4 ConocoPhillips Map rap Vertical MD Inc Atl Definitive Survey Report 14055 -NIS Company, ConocoPhillips(Alaska) Inc.-WNS Local Coamdlrete Reference: Well MT6-O6 Project Western NOM Slope MRmrenca: ACTUAL MT6-06 Q 89.14usft(Actual Doyan 19) (carni Sea GMT1 Lookout Pad MD Rmnnn: ACTUAL MT646 ® 89.14usft (Actual Dayon19) Section g0ry ToolWme AniWt6ti00 89 Well: MT6.06 With Retemnce: True Wellbem: MT5-06PB1 Ik) SUM" Calculation Method: Minimum Curvature 8.94 Dentgn: 81-wp02 36.94 Cmbasa: EDT 14 Alaska Produclion 000 Survey Program 317041.19 Dm 0.00 UNDEFINED 115.00 0.51 From To 25.00 -0.34 Survey Survey (dark) 1deM Survey(Wellbme) Tool Name Description Sled Mfe EM Me 115.00 1,021 on Gymdala GymSS 16'(MTMOPB1) GY0.CT-OMS Gyrodala corulddllplpe Ms 911D2a18 9110/2018 1,106.74 2,063.83 BHGE MWI)+SAG+IFR+MSAl6"(MIT" MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 91112018 W12n(110 2.160.89 1D,285A5 BHGE MWD+SAG+IFR+MSA 12 VV (M MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC 9/152010 911T201B 10,371.52 11,879.62 BHGE MWD+SAG+IFR+MSA 6x9314"(M MWDAFR-AK-CAZSC MM -IFR AK CAZ SCC 92612010 912812018 11894.64 12,651.21 BHGE M4YI3+SAG+IFR+MSA 6"(MT64 MWO+IFRAK-CAZSC MWD -IFR AK CAZ SCC 114512018 108/2018 Survey 1122018 3J4:44AM Pepe 3 COMPASS 5000.14 Bold BSD Map rap Vertical MD Inc Atl NO 14055 -NIS +FJiV DLS (us01 (°) 1°) (usft) (carni (usfti (-to NorMing Earning Section g0ry ToolWme AniWt6ti00 89 (k) Ik) (9100'( (k) 8.94 000 0.00 36.94 5220 O.W 000 5,945,535.92 317041.19 0.0 0.00 UNDEFINED 115.00 0.51 167.22 11500 25.00 -0.34 000 5.94558.58 312,04126 065 0.32 GYMT-0MS(t) 205.00 076 167.04 204.99 115.05 -1.31 0.29 5,94558.60 317.0,11.,45 020 t8 GYMT-0MS(1) 30.00 D.80 206.24 299.99 210.85 -242 0.18 5945,534.50 317,041.32 050 232 GYD T-DMS(i) 81.00 0.70 24751 80.90 2884 -200 4M 5,945.514.0.5 317000.01 0,79 289 GYD-CT-DMS(1) 455.00 1.80 29097 454.90 365.82 -2.46 -2.0D 5,945,534.51 31703914 1.37 272 GYD-CT-DM5(1) MODO 3]9 3098 54955 450]1 Od9 -5.52 5,945.53]25 317,,035.63 2.8 0.61 GYD-GT-DMS(1) 64500 6.03 311.84 64LSO 555.8 S54 -1169 5945.542.74 312.029.64 28 d.80 GYMT-DMS(1) 238-00 &81 31172 78.71 647.52 13M -8.65 SMS'SSOM 317.500.8 2.99 -10.43 GYMT-DW(1) 832M 11.03 31234 029.30 74016 2438 6297 5,915,562.08 317.003.12 236 -1943 GYDCT-DMS(1) 9MOO 1293 312.93 WI.25 832.11 32.59 47.03 5,BM`,52SW 316.995M 2.03 40.43 GY T-DMS(1) 1,Mrw 15.01 31360 1,01343 Mn 53.31 53.73 5,945591.14 316978.79 2.20 -03.59 GYD-CTDMS(1) 1,105]4 17.23 31412 1,145.90 1 tt6.66 Met FAa7 5945.600.66 31696205 256 S7,44 M IFR -A CAZ43C(2) Mann 1&2(1 316.12 1.18.69 1,047.55 79.19 14.21 5,945,610.20 316.953.94 379 65.39 MWD+IFR-AW AZ4lC(2) 1.241.34 20.79 316.64 1]2574 1,13&60 102.35 -11224 5.945.64196 316,931.48 222 -95.14 MWDHFR- CAZSC(2) 1,33761 2241 317.90 131.46 1,223.32 12].59 -13551 5,M,66776 316.906.83 1.02 -106.77 MND+IFR-M-CAZSC(2) 1,43248 238 310.8 1399.96 I.M.n 155.20 -15990 5945.895.95 316805.04 LOT -13057 MD -IFR- AZSC(2) tuem, 24.13 31663 1,41Ifi.37 1.397]3 18313 -195.90 5,945724.50 316.859.91 150 -154.50 MWD+IFR-MK AZSC(2) 162189 Mrs 31442 1,92.43 1,414.29 M. -214.07 594575349 316832.33 1,79 -12&45 MNO+IFRAK-0AZSC(2) 1122018 3J4:44AM Pepe 3 COMPASS 5000.14 Bold BSD COnocoPhilllps ConoeoPhillips De(nitlye Survey Report Company: ConocoPhl9lps(AMeka) Inc.-WNS Local Coordinate Reference: We11 MT6-% Proleou Westem North Slope TVD Reference: ACTUAL M1`6A8 @ 89.14usR (Actual Doyonl9) Sne: OMT1 Lookout Pad MO Reference: ACTUAL MT6-06 C 8944us8(Actual Doyonl9) Well: MT6-06 North Relerence: True Wetlbom MT"5P81 Survey Calculation Meshed: Minimum CumaWre Dai9n: B1 -m02 Oalabau: EDT 14 Alaska Production survey Annotation 13-318"x16" 11414018 344:44AM Pape4 COMPASS 5000.14 Build 55D NO Inc Ag! TVD TVDSS +WE aB)yy DIS (gaD) P) (°) 1.011 (-am luso ) to") Northing soarer, rnDlr) Seodon Survey Tool laima (111 (n) re) 1)16,26 27.14 314.61 1,85692 156778 240.90 444.03 5945.]8366 316003.10 149 -.a,. MND+IFR-AI( C(2) 150869 29.23 314,55 V3827 1650.13 27168 -27548 5.945.81539 31677243 2.24 -22843 MWDAFR-AK-0KSCD) 1.903.56 30.26 314.04 1,820,77 113163 30440 509,78 5945,04071 316,738.90 1.13 425682 MWDrIFR-A AZSC(2) 188777 3140 31537 1.90167 1,81253 33837 543.10 5.945.88350 316]05.43 141 -05,50 MW➢+IFR-A A240(2) 2,063.83 3240 31515 1,914.73 166859 363.18 557.70 5,945,90091 31SM44 1.84 -305.53 MWDHFR-MH AZSCt2) 2,11&58 33.38 31548 2,00365 1,914.54 38430 Sam 5,945.930.52 316.661.96 164 .,M MWD+IFR-AK-CAZ4iC(3) 2lease 3107 315.20 2,030.87 1,949.73 40.56 .40524 6945947.50 310,64504 1.64 13050 MNDAFR-AK-0 -SC (3) 2,183.49 34.36 315.10 2057.56 1,96342 40597 41420 594595681 316,63710 1.31 -346A3 M IFRAK AZSC(a) 22893 no 316.27 2,134.54 200.540 449.11 45240 5,945996,05 316,589.63 231 -379.37 1a%D+1FRr AZSC(3) 3.37141 3075 316.0 2,209.61 2119.47 49055 -09156 5,949139.25 316.56173 252 <14]8 MW➢HFR-A AZS (3) 29058 4055 31772 2,201.07 2,19193 534]3 53224 5.905.00414 316 SM 13 1.98 .45261 MNDNFR-A CAZSC(3) 2.55845 4205 318,30 2,351,63 2,282.48 5811,01 57311 5,946,13146 31640100 1.65 492,25 MWDHFRAK-0 SC(3) 2654.14 44.05 318.95 2.420.81 2,331.67 Mw 516.44 5,946181.80 316.44025 2.19 -534.12 MND+1FRAK AZSC(3) 2740.39 45.85 31024 2487.49 2,398.35 137820 68049 5,941;232.50 318.387.44 195 -57721 M IFRAKCAZSC(3) 2842,59 45.83 318.00 2,553.11 248397 72959 1405130 5,945,283.39 316,35357 010 ffi051 1#0d➢+1FR- A2SC(3) 2.93653 4503 31811 2618.57 252943 7M71 -050.54 5,9,6,334.59 316.30576 060 S63.63 MND+IFR-A CAZSC(3) 3,031.20 4505 318.43 260453 2595.39 05040 -795.B5 5,946,38635 316285.00 0.24 -00729 MNDNFRAK-0 4iC(3) 3,124.70 45.89 310.41 2,74964 2,560.50 00059 4!40,38 5946437.131 316.22250 0.04 -75056 MWDOFRAKLAZSC(3) 3,21030 45.88 31792 2,015.55 2,726,42 831.20 68572 5,948409.34 316178.40 0.37 494.16 MIMAFRN( AZSC(3) 3.31334 48.89 318IXi 2,880.90 $791,82 981.35 630.80 5.946,54053 31649048 008 537.25 MNDNFR-AI(-CAZSC(3) 3,40716 45135 318,19 294626 2,857.14 1,031.0 -97505 5.990.503]4 316,090,75 013 4B8039 MND+1FRAK-CAZSC(3) 3,501.45 45.05 318,44 3,011,95 2,92281 1,00202 -0,090.85 5,946,64335 318046.99 0.19 b2393 MWDNFRAKLAZSL(3) 359588 45.84 310.14 3,077.71 2,963.57 1,13259 -1,055.93 5,846,69500 31600315 on -90750 MWD+IFRAK -SC (3) 3690ai 46.07 318.53 3.143.57 3054,43 118345 -1.111,19 5,946745.95 315.959.14 038 -1011.32 MW➢+IFR-PX-CA2SC(3) 3.7!4111 46.91 31875 3.213.01 3110.87 1,234.41 -115604 5,945.79897 315,915.54 (,91 -1,055.29 MND+IFRJJ AZSC(3) 3.8T&M 40.08 3MM 3,271M 3.18270 1.28742 -1,201.35 5,946.85350 315,871,55 160 -1,10123 MND+IFR-MH AZSC(3) 3,97300 4897 321.35 3.334.31 3,245.17 1,34210 -1,245.97 5,946.9'9,01 315,020.26 1.32 -1,14093 MNDNFRAK-0PZSC(3) 4,05000 5072 322.20 3,395.57 3,386.43 1,35815 -1290.89 5,9413,966.92 315.704.75 1.96 -1,180.92 M 1FR1KCAZSC(3) 4,162.51 51.80 324.05 3,454]2 3,36558 1458.13 -1.33509 5,94705.% 315,742.00 193 -1,250.93 61WD+IFR-A AZsC(3) 4.257.50 52.03 35]8 3,512.79 3,,42365 14520.03 -1,377.8 5,94708887 315,700.08 248 -1,306.06 MJUD+1FR-AH AZSC(3) 4352.05 54.04 322,49 3,589A5 3,400.01 1.584.20 -1,41030 5.947.155.01 315661.00 1.94 -1,38371 MNDNFRAKCAZ4tC(3) Annotation 13-318"x16" 11414018 344:44AM Pape4 COMPASS 5000.14 Build 55D ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConowPhilips(Alasko) Inc. -Ai Local Coaminate Rate...: MR MT"15 Project: Westem NoM Sla, TVD Reference: ACTUAL MT6-06@ 69.14usd(Actual Doybn19) Saw GMT, Lookout Pad MO Reference ACTUAL MT646@ 89,14usfl(Actual Doyon 19) Welk. MT"S North Referent.: Tme Wellloom MT6-06PR1 Survey Calculation Method: Minimum Cul... Design: 31-wp02 Database: EDT 14 Alaska Production Survey Annotation Hou 0 11 b 018 3:44'44AM Page 5 COMPASS 500014 BWd850 WAIcal MD Iwtll Inc 1°I Aal (1) TVD Juan) MOSS Ies1ry MLS load) .dal' Noun) NnriIMng Ending DLS 1°11001 SMlen Survey Toel Name M) M)(.11001 M) 4,450.23 5531 329.74 3,624.16 3,53502 1,650,82 -1,458.22 5,94],222.52 ais6rw.59 1]1 -142391 MJu➢HFR-ASCAZ5 (3) 4541.54 56,80 33226 3.626.82 3,582.88 1,21924 -1,496.13 5,94729199 315,582.36 272 -1,486.12 MWDaIFR-FKLAZSC(J) 4,63532 6T.50 334.69 3,M.23 3.638,59 178952 -1,53L32 5,942.36324 315.55389 33o -1,55089 MWD+JFR-FK -SC (3) 4,228.10 52.45 33T51 3522.59 36WAS 1,861.24 -156299 5942,43545 315,523.97 256 1,617,05 MWDAFRMJ VSC(3) 4822.50 ST54 MISS 3820,32 3239,18 1.935.02 -1,59222 5,94750990 315495.99 093 -160594 MWD+IFRAK-0AZSO(a) 4,91898 5TBB 339.11 3,828]9 3589.65 200929 -1.822.22 5,942,584.50 aisme.31 054 -0555.06 MrVO+IFRAKCAZSC(3) 5,01133 52.91 a.10 3.928.92 3.83950 208345 -1.852.02 5,942,859.26 315440.31 0.02 -1,824.16 MrW+IFR-M(-0ALSC(3) 5102.88 5289 332.95 3.922.65 3,888,51 2,1545 -1,60113 5,947.232,40 315.41302 0.15 -1,Set M &AND.Iffn K-0AZSC(3) 5.19600 5285 332.12 4,0271 3.932.99 2,22924 -151119 5942.80593 315.38454 021 -1850.91 MWpa1FRAK-0PZSC(3) 51291.12 5800 336.35 4,022.61 3.999.50 2,30..30 -1242. 5,942,80074 315,354,24 075 -2.02755 MWD+IFRAK AZSC(3) 5.38952 57,. MeM 41N89 4040,25 2320.82 -1,226.22 5,942,0.5904 315,321.33 022 -2,09959 MWD+1FRAKCA C(3) 5.485]5 52.88 Me16 4,18102 4,091.99 2,45342 -1,80.88 5948.0M45 315292.55 0.42 -2.16722 MWD+1FR-AK-CAZSC(3) 5,52928 52.91 335.29 4M1.05 4,141.91 2,526.04 -1,04162 5948,106]9 315.261.59 0.28 -2,23468 MWO+IFRrV(-0PZSC(31 5,625.14 5285 33431 420181 4192.62 2,591 -1,82599 5.910,160,65 315.29.50 002 -230222 MJD+11FR✓J(-CAZ1C(3) 5,26046 5]84 33412 433148 4,242,34 2,820,24 -0,910.]2 5,915252.61 315.19541 0.13 -2,362,20 VWDAFR-AK-CAZ3C(3) 506389 52.02 33352 4,382.14 4,29300 224262 -1,94502 5948.325.82 315.16284 058 -2,434.21 MWO+IFRAKCAZSC(3) 5.95236 57,. 33365 4,43191 4,34256 201359 -1,801.12 5,948,397,63 315,129,12 0.12 Q499.32 MWD+IFRAKCAZSC(3) 6,05255 57,85 Meat, 4482.58 4,393.44 288613 -2,01548 5940.421.00 315085.54 Res -2.588.02 MD+IFR-AK-CAZSC(3) 6.146.20 52]2 335.[3 453242 444333 2952.96 -2049,96 5,945543.61 315.06381 1.13 -263234 M IFRJNL C(3) 6,240.. 67.. 336,41 4,58293 449359 3,03121 -200254 5.946,617,63 315.033.02 0]0 -250014 MND+IFR- CAZSC(a) 6,334.88 5762 332.06 4,632.94 4,543.00 3,10426 4.113.93 5849.69142 315.003,41 0.61 -2,262.92 MAO+IFRALCAZSC(3) 542932 ST. 33532 4.503.20 4,594.06 3,1W72 -2,145.56 5948,26562 314,920.78 M89 -2830.06 MWDHFR-M-CAZSC(3) ,,SM30 5286 335.21 4,233.19 4,64405 3,25029 Q128.M 5948.83990 314942. 1,00 3,9.,18 MWD+IFR-AK-OAZSC(3) 6.612.60 52.82 33553 428330 4,694,24 3,32222 -2,21189 5940.91222 314911.00 005 -2.920.09 MWDdFR-AK-CAZSC(3) 6.211.35 57M 335.64 4,833.M aWI5 3,394.96 -22M.68 5,940.95519 314,829.22 0.32 a,036.20 MWD+IFRAK-CAZSC(3) 6,806.06 52.29 3e.20 4laa53 429459 3.462.52 -2220.62 5.949.050.60 314,84758 139 .1,10355 MWDNFR-AKCAZSC(3) 6,901.02 5782 334.62 4,934,31 484512 3.5400 3313.32 5,949.131%a 314,81403 039 -3.12042 M IFRARCA24C(3) 6.2.85 5786 33425 4,903.19 4894.05 3,61016 -2.346.92 5,949,202.50 31428200 034 1,235.09 ~+1FR- -CAZSC(3) 708715 W95 33430 5,033.32 4,944.23 3682.11 -2,38152 5949.22556 31424995 0.12 1,3019 MWDdFR-AK-CAZSC(3) 2,18014 52.85 333.50 5082.98 4,.3.64 3,25281 -241592 5949,34208 314,71233 069 y3662B MWD+4FRAK-CAZSC(3) 7224.10 5764 33320 5.133.30 S.,. 3.02402 -2451.20 5,949.419.12 314.883.75 004 143,68 MWD+IFR-AKCAZSC(3) Annotation Hou 0 11 b 018 3:44'44AM Page 5 COMPASS 500014 BWd850 �. ConocoPhillips ConocoPhilllps Definitive Survey Report Content: ConocoPhillips(Alaska) Inc. -MS Local Coordinate Reference: Well MT6-0(l Prejem: Weatem North Steps TVD Reference: ACTUAL MT6-06 C 89.14u.ft&tOA Doycn19) Slee: GMT1 Lookout Pad MO Reference: ACTUAL MT6-06 ® 89.14 .11 Doyon19) Well: MTB -06 North Reference: Tian Wellbore: MT64)6PB1 Survey Calculation Method: Minimum Curvature Design: Bt-wp02 Database: EDT 14 Alaska Production Survey Annotation e°Iguoklfi�s 1IM018 3:44: "AM Page 6 COMPASS 5000.14 Budd 850 MO lug" Inc (°) AM M TVI) TVOSS +Wd .EI4N NOMing Eeating 0125 Saw.Sury Tool Name °y (-ft) lean) IusIIl Items) III) III) (.1100.) In, 7,358.64 57611 334.4 51.183 5,09469 0ssa] .2.486 35 5,949.49f.6p 3146WM 031 1497.53 MW➢+IFR-AK4AZSC(3) ].463.0) 57,63 334.71 5.234.47 5,14533 3,967.77 -2,520.93 5,94956.51 314 61T!4 OFA 5.56391 MWD+IFRAK-CAZSC(3) 7,"+676 57.63 336.4 526.52 5,19538 4039.54 -2,55382 5,949,63704 314.5011.40 1.20 -3,80019 MWD+IFR-AK-0AZSC(3) 7,65169 5].]0 336.4 5.335.29 52466.15 4,11395 5,555.14 5.949,71121 314.555.07 036 1698.19 MWD+lFRAK-CPZSC(31 ],]4590 57.69 336.08 5,3.5.6 5399.50 4,185.83 -26l&21 5,949,76.85 314,52559 034 JAiS11 M1dD+IFRAK-CAZSC(3) 7.60.35 57.60 335.70 5,436.14 SU7.00 4,250.68 -2,65003 5,944858.46 314,481J5 0.32 5.833.10 M IFRAK-CALSC(3) 7,03.78 5767 135.72 54MA2 5,3%,98 4,330.63 -2,683.30 5.949.931,18 314,46.W 0.02 5,899.6 MN➢+IFR-AK AZSC(3) 8,027,99 55.41 3%362 553806 5,448.91 4,401.91 -2,716.59 5950,MA4 314,43240 2.79 5,96528 MWD+IFR-PN-0AZSC(3) 8,1".75 51.95 3an.Z3 5.594.19 Samos 4,469.33 -2]$2.1] 5.950.071.50 314,390,55 4.93 4.0X,99 MWD+IFRAK -SC (3) 0,216,45 51.90 3M,w 5.651.99 5,5d"s 4.53223 -2790.66 5,950,135.31 314,36161 206 4, WIN MND+IFRAK-0AZSC(3) 831141 50.31 323.82 6]11.62 5,6"48 4,593.00 -$832.68 5,980.197.06 314,32180 290 413180 MNDOFRAK-0A25C(3) 840352 4&25 3"At 5171.]0 5682,56 4,646.M -2,.7457 5,950.253.93 314280,56 2.62 -0,18]03 MWD+IFRAK- AZSC(3) 8,498.40 4808 3X.67 6036.21 5,747.07 4703.3 -2,917.82 5980306. 314,238.[5 2,611 4.23473 MWD+IFRVWiaSSC 13) 8592.P 43,112 317.91 5.93281 5,813.80 4,753.92 -2,561.31 5,950.361,07 314,195.40 308 4.27054 MWDNFRA -CAZS013) 8,885.17 4219 31375 5,970.47 5.081.33 4,7017 5,CO522 5,950,40].3] 314.153.61 360 1367.03 WiVDNFR-AK-0AZSC(3) 87]840 40,80 30843 6.041.35 5,95182 4,04061 105167 5,950,449.93 314107,93 3.30 435130 MArD+(FRAK AZSC(3) 8 8739 39.03 381.15 8,113.62 6,024.4. 4,8]5.9] 5,18039 5,950,48]45 314,6150.36 4.04 4.380.30 NAM)OFRAK-W.(3) 8,968.83 37.86 299.42 6,10].93 doll 4,908.04 -3,15040 5,950.518]3 314,811.06 3,34 -0,403.81 MWD+IFRAK-CPZSC(3) 9,053.42 3]0] 294.47 6,263.02 6173.88 4,934.11 -3201.72 5,950,547.04 313,900.40 3.28 44"26 MWO+IFR-N AZSC(3) 9,15].4] 3581 287.83 6,338.66 624952 4,95431 3253.80 5,950,568,49 313.900.09 437 4,434]] MWONFRAK AZSC(3) 8X2.10 35.58 27891 6,415.51 83X.37 4,907,55 5,307.37 5,9W.503.03 313.855.. 090 4,440.9 Mr19+IFRAK-CA25C(3) 9.5,12 35.93 274.19 6.491.00 6,401.86 4,974.21 13613. 5980.59].98 31380181 362 4,43900 MWD+IFR-AK-CAZSC(3) 9439.97 366 289.47 6.56].. 6,478.66 4,975.93 -3,416.90 599059412 31374680 241 4,432.76 NMO+IFRAK-CAZSC(3) 9,5330] 3593 2E4.10 6,641.. 6,554.93 4,98192 5,471.40 5,950,59239 313.691.81 3.38 4,421.09 MWO+IFq-PI(-0AZSC 13) 9,¢7.80 35.94 250.. 6,719.76 ...A2 4,96,91 1526.26 5,9504585.71 313.636.70 299 4,46.08 MWD+IFRAK-CAZSC(3) 9.8121.0 3T.03 25302 619568 670654 4,95146 .,58069 5,950,573.58 313.5.205 4.11 -03".93 MWD+IFR-AK-0AZSC(3) 901557 WAS 24593 6,869,81 618070 493169 5,681,. 5,950,555.32 313,5X.02 416 4,357.86 MND+IFR-AWCAZSC(31 9.90.91 38.P1 24131 6.84]." 6.854.50 4.90619 -3.607.08 5,850.53].91 313.474.60 386 -032403 AW IFRAK-CAZSC(3) 1000511 4018 237.00 7,09.80 892].42 487509 -3.739.08 5980,50606 313421,06 3.80 4.2.6.57 "D+IFR-PIFCPZSC(3) 10,09963 Out 23I'm 7,088.52 6969.3. 4,836.8 3711847 5,950465.95 3133]061 4.35 4,813.33 MWD+1FR-A1C -SC (3) 10.19307 4350 22]39 7,157.63 7MA. 4.797.19 1837.84 5,950.425.62 313.32124 334 4.195.28 MAD+lFR-AK-CAZSC(3) Annotation e°Iguoklfi�s 1IM018 3:44: "AM Page 6 COMPASS 5000.14 Budd 850 CormoPhillips ConocoPhillips Definitive Survey Report C.P.W. Conowlehiliips(Alaska) Inc.-WNS Local Loa7dlnate Reference: Wbll MT6-W Pmlect. Weslem Nodh Slope TVD Reference: ACTUAL MT646 C 89.14us8(Actual Doyonl9) elle: GMT1 Lookout Pad MD Reference: ACTUAL MT646@ 09.14s8(Actual Doyon19) Wen: MT6-06 No"Reference: True Wellbore: MT6-06P81 Survey Calculatlon Method: Minimum Curvmure Design: 81-wp02 Database: EDT 14 Alaska Production Survey Annotation 9518" x 12-1l4' I"`n"' is 11RR018 300."AM Page 7 COMPASS 5000.14Build SO Map Step dented MD Ilm 11I Aa P) 111p Insn) TVDSS N -m ♦008 luaft) eE14M Nen) No Emana DLS I'M6P) Secnnn SUMO Tool mmlush Y (n) In) IN 1028585 44.90 224.52 7,22350 7.134.44 4,75261 -3,003.90 5,9503821] 313,27411 2.65 4,144.53 "O+IFRAK-GSSC(3l 10.318.00 44.94 223.94 7,2".93 2155.79 4,737.35 1,89075 5.950,39.20 31315389 137 1127.30 VNVDHFRA-CP C(4) 10,3]1.52 45.02 222.8! 7,284.20 7,195.06 4,70804 1,92592 5,950.339.43 3134231.25 13] 4095,21 MND,IFR#-CA230(4) 10,454.34 46,95 21985 ],340.70 7,259.56 4,65814 J,969.00 5,950,511.42 313,185.00 312 403829 MWDNFRJ -CAZSC(4) 10.%020 WAS 21594 7,41L0S ],3R]1 4,601 at 4011.03 5950234.59 313,140.37 4.93 4,97659 MWDNFRA-CAZSC(4) 10.655.11 51n 21245 ],4]004 7,380.90 4,539.79 4056.11 5,950,1]3.61 313096]9 4.35 3,0916 VN IFRAK-0AZSCA) 10.750.61 5629 20117 ].524.00 7.435.66 444]3.60 4096,14 5.95D,19.41 313.05514 389 3,8'6.91 MWD+IFR-AK{ Sc (41 10,844.73 50.92 200,94 7,575.23 ],406.09 4,402.46 4,13319 5,950.030.21 313,016.10 3A4 JM.13 MNDNFRx-CAZSC(4) 10,938.90 6156 20550 7,82201 ],632,8] 4329.15 4,16903 5,949.965.81 313,978.00 2.99 560438 MWD+IFR-N(-0AZSO(4) 11,032.00 W.74 .3Si 7,864]5 ],5]5.61 4,254.17 42(1A7 5,949.89169 312.941.55 3.02 4,60517 MM+IPR-A CAZSO(4) 11,125.52 64.]8 50254 7.70530 7,616.24 4,17673 4,237,61 5.949,81569 312.006.54 1.64 3523]] MWD+IFRAK-CA 14) 11.21937 6414 201.]3 ].]4541 7,655,27 109311 4,28959 5949,7372] 31207200 0.78 3."1.35 MWD+IFR-AWCAZSC 14) 11.31200 64.69 201,24 ].]84.97 7,695.03 4,0211.17 4300.27 5,94368011 312MIO 0.48 5,359.82 MVD+IFR-AKL -SC (4) 11,40.62 65.03 20035 7,025.17 ].]2R,03 3,940.09 433068 5.949,58000 31280.76 092 5,27621 M +IHR -CAZSC(4) 11,501.01 65.63 195.83 7,861.59 7,775.45 3.058.59 4.357.30 5949,499,9fi 312779]7 440 d,191,R M1VDHFR-M-CAZSC(4) 11591.40 87.51 190.74 7,901.]] 7SIZS3 3,]]5.15 d, 398.97 5,949,417.01 312]5].40 5,39 310.32 MWDNFRA -CA (4) 11,609.55 69.54 186.51 793559 7,04245 3,68211 4.39111 5,949329,90 312,742.12 465 3017.80 MWD+IFR-M({AZS (4) 11.]05.0] ]40] VP.W 7,968.15 7S71ID1 3,597.94 4,39336 5,94924041 312 M1,80 3.56 -2,917.87 MWD+IFRAK-CAL C(4) 11,99.62 7435 18062 7,995.63 7,905 49 3,50255 4401.89 5,949]50.14 312 ,]5.0] 4.21 -2,837.92 M✓uD+IFR-AK-0A C(4) 11,894.64 ]4]9 10gfi0 7.93963 7,910.49 3,493.08 4402.04 5949,135.9 3127558 293 -2,023,57 MNONFR- CAZSC(5) 11001.52 79.91 179.35 8.0504 ],931]0 3,39050 4401.99 5,949,04111 3127Z132 543 -2,]30.07 MND+IFRA AZSC(5) 12.086.64 04.75 5]7.97 0,031.53 7,9",39 3,304.37 4,399.78 5948916.90 31272324 529 5,637.15 MWD+IFR-AK-CAZSC(5) 12,101.5 to 00 175.98 803933 795039 3,5900 439470 6,948052.32 312,71594 401 -2,51429 MWD+IFRA-CAZSC(5) 1227651 089 173.08 0,041.96 7,95282 3,11532 436513 5,948]5265 312,]3269 3.25 -2.45209 MWDOFR-A AZSC(5) 12,371.59 89AC 168.92 8043,5 7,954.09 3,021.30 4,3]160 5,940fi61.33 312711]5 3.34 1,51.9 MWD+IFRN(-0&ZSC f5) 1246210 STU 1014 8,045.46 7,955.32 2,9502 4351.06 5.940569.50 312,]6281 5.23 2,27173 7AND+IFRAK-0AZSC(5) 12561.50 8200 16221 8,04964 7,900.50 2,837..60 4.MAST 5.948.478.55 31270208 325 -2,18606 MWO+IFR-AKCAZSC(5) 12.01,21 85.95 158.71 8.055,16 7,968.02 2,753.23 45463 5,948393.49 3128149 49 -2106.87 MWD+IFRA-CAZ-SC(5) 12,687.21 85% 158.71 8,07.70 ],969$ 2,]19]7 428,59 5,948.3 ,n 312,827.19 n00 -2,9554 PROJECTED N TO Annotation 9518" x 12-1l4' I"`n"' is 11RR018 300."AM Page 7 COMPASS 5000.14Build SO ConocoPhillips ConocoPhillips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-06PB2 50-103-20773-71 Baker Hughes INTEQ Definitive Survey Report 02 November. 2018 BAKER JUGHES Ecr""r" �. ConocoPfllllps Conocolahillips 0.00 uaft Northing: Definitive Survey Report 0.09 as" Comparry: ConocoPNillips(Alaska) Inc. -WNS Local Coordinate Relerence: Well MT6-06 ProJect Westem Noah Slope TVD Reference: ACTUAL MT646@89.14us%(Actual DWonl 9) Site: Gi Lookout Pad MD Reference: ACTUAL MT&06 @ 89 lament (Actual Doyon 19) Well: MT6-06 North Reference: True Wellbore: MT8-06PB2 Survey Calculation Method: Minimum Curvature Design: 81.wp02 Centsase: EDT 14 Alaska Production P.Ject Wastem Noah Slope, Noah Slope Alaska, United States Map System: US State Plane 1927 (Exact soknion) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Map Zane: Alaska Znne 04 Using geodetic a.le factor Well MT6�06 Well Instance +Nl 0.00 uaft Northing: +ELW 0.09 as" Easing: Position Umermusty 000 usa Wellhead Elevation: Wellbore MT6.061PS2 Magnatlas Model Wms Semple Data BGGM2018 8/912010 Design MT6-06PB2 Audit Notts: Version: 1.0 Phase: ACTUAL wriest Section: Depth Faun (TVD) lural 0 ort 5,945,536.92usa 317,041.19usa 0.00usa DeWnaaon (9 16.45 Tle On Depth: 11,785.07 eN 3 (u -g) 0.00 Latitude: Longitude: Ground Level: Dip Angle 1°) 8070 +EI Dlracti (ata) 1') 0.00 100.27 BA Efl �W6 70° 15' 22.892 N 151° 28'43+472 W 37.20 sell Field Strength Inn 57,397 11? 183:4636AM Paget COMPASS 5900 14B"850 ConocoPhiliips COIIOcoPhillips Definifive Survey Report Company: ConocoPishps(Alaska) Inc. -ANS Local Co-ordinate Reference: 1740 147&06 ND55 Prolem: Aestem North Slope ND Rehrence: ACTUAL MTBA6 @ 89.14usa (Actual Doyonle) DLa SIh: GMTI Lookout Pad MO Reference: ACTUAL MTfi-06®89.14us8(Actual DWonl9) lusal Viet: MT646 Nenh Reference: Two EasMng Wellbore: MT6-0BPB2 Survey Calculation Method: Minimum Culvalure Desl9n: B1-wy02 Database: EDT 14 Alaska Production IRI Survey Pregrm Date 36.94 0.00 From To 52.20 Survey Survey Iona) Iden) Survey(Wsllbore) Tool Mame Description Start pace End Daft 115.00 1,021.00 Gyrodata GymSS 16- MT646PBl) GY0. T -DMS Gyrodaia c0ntdnl(pipe Ws 9/1012018 9110.2018 1,106.74 2,063.83 BHGE M44D+SAG+IFR+MSAI6"(MT69 MAD+IFR-AK-CAZSC MWD+IFR AK CAZ SCO 91112018 91212018 2,160,89 10,285.05 BHGE MWD+6AG+IFR+MSA 121/4"(M MWDAFRAK-CAZSC MWD+IFRAKCAZSCC 91182018 91172018 18371.52 11,785.07 BHGE MWD+SAG+IFR+MSA 6.8W4" (M MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SOC 92612018 91282018 11842.00 16,752.22 BHGE MWD+IFR+MSA 6"(MT696PB2) MWD+IFRAK-CAZSC MWDNFR AK CAZ SCC 10/102018 1011212018 Survey -242 010 5,945,534.84 317,041.32 MO Inc Atl ND ND55 +NIS +6184 Map Map DLa Vertical 1'1 19 lusal (uaR) lusn) (uncal Northing EasMng Sen Survey Tool Name Annotation(usfl) IRI Int (-/low) 36.94 0.00 O.CO 35.94 52.20 003 000 5,945.53692 317.041,19 000 0.00 UNDEFINED 115.00 0.51 167.22 11500 25.83 434 008 5.945.536.58 317,04126 065 0.32 GYMT-DM6(t) 205.00 0.76 167.84 204,99 11565 -131 0.29 5.945,535.60 317,041.45 0.28 126 GYMT-DMS(1) mato 0E6 206.24 299.99 21085 -242 010 5,945,534.84 317,041.32 050 237 GYDCT-DMS(1) mlool 0.>0 247.51 Mo.89 271.84 3.88 432 5,945534.06 317.040,01 079 289 GYD-CT-DMS(1) 455.00 1.60 298.97 454.95 385.82 -2.46 -2.03 5,945,534.51 317,039,14 1.37 2.72 GYMT-OMS(1) 55000 3.79 30p. sagas 46071 Mo 5.57 5.945.53225 39,035.63 2.36 0.61 GYDCT-DM6(1) 84500 6.03 311.64 644.50 555.36 554 -1169 5,945.542.74 317029.64 236 Sec G MT -0066(1) 738,01) Sol 311.77 738)1 647.57 1354 30.65 5,845,684.96 317,02066 299 -1043 GYDCT-DMS(1) 032.00 11.03 312.24 628.30 74016 24.38 32.67 5945.862. 317.849A2 236 -1843 GYDCT-DMS(1) 926.00 12.93 31292 92125 832.11 37.59 4703 5,945,575.64 316.995.0 2.03 -30.43 GYDCT-DM6(1) 1,021.00 15.01 31360 1,013.43 924.29 5331 5373 5,945.591]6 316,978.78 220 1.59 GYDCT-0M6(1) 1,106.74 17.20 314.12 1Dow 1,0.6,66 6880 410.97 5,945.608.66 31695205 256 57A4 MD-IFR-A<-CAZ-SC (2) 1,149)2 IBM 316.9 1,135.69 1,04755 MA9 93.21 5945,61826 316,852,04 3,79 55.39 MWDHFR.-CAZSC(2) 1.244.34 20]9 31664 122514 1135.60 10235 112N 5,945641.95 316.931.40 222 -85.14 MAV.IFRAKCAZSO(2) 1,33781 MAI M790 1,31246 1,223.32 12759 -135.51 5.945.06776 31690683 182 -106]7 ~+1FRAK AZSC(2) 1.43246 23.36 316.BB 139966 1]101 15523 -159.98 5,945,695.95 316805,04 1.07 -13057 MWD+IFRA CAZSC(2) 1,528.99 24.13 315.69 1,489.37 139723 183.13 -185,80 5,945,8450 316,053.91 1.50 -154.50 MWDNFR--CAZ-SC (21 1162189 2514 31442 157243 1,48320 211.44 11007 5,945753A9 316,83233 1.79 -17845 Md✓GHFRAKCAZSL(2) 11? 183'4B'38AM Page COMPASS 500014 auto 85D �. ConoaC Phil 1p5 Conocc Phillips Axl ND Definitive Survey Replan +W,5 Company: ConocoPhllllpli Alaska) Inc. -MS Local Co-or6lnate Reference: Well MT6.416 Pmfecl: Medium North Shp Ti Reference: ACTUAL MTE06@ 09.14usfl(Actual Doyon19) She: GMTi Lookoul Pad MD Reference: ACTUAL MT645 @ 89.14usfl (Actual Ooyoul9) Well: MT646 North Reference: True Wellbore: MTS-06PB2 Survey Calcunum Method Minimum Curvalum Design: 01-wp02 Denali EDT 14 Alaska Protluclion Survay MD Inc Axl ND NDSB +W,5 wElm Map Map OLS NRical (USM hl 17 lural loan) lural luso) No]minp Eaasng 0 Section survey Tool Name ml ml ml 1,71626 2740 314.61 1,856.92 1,567.78 240.9p -2M.03 5945]6383 316,80310 149 -203.29 MND+IFR-P AZSC(2) 180969 2933 31456 1,73927 1,650.13 27168 -27546 5.945,81539 316]]2.43 224 -2]943 MWDHFR-AK-0AZSC(2) 1,90356 3026 314 Di 1,Won 1,73163 30440 408]9 5.945848.71 316,73990 113 456.82 MWDaIFR-AK-CAZSC(2) 1,997.7] 3140 31537 1.901.67 1,81253 33827 443d0 5,845 call 316.706.43 Ut -285.50 VMID+FRAKCA C(2) 2.05383 31M 315.15 1,95]]3 1,868.59 am 19 -36770 5945,909.91 316,682,44 164 S06.53 MWDNFR-N(CAZSC(21 2,116.8 3330 31540 2,00368 1,914.54 38430 -388.68 5,845830.2 31666198 1.64 -32439 MWDAFR--CAZSC(3) 2,160.69 34.07 31530 2038.07 1,90.9.73 400,98 -40524 5,945947.56 316.645,84 1.64 -33850 MrVD+1FR-AKCAZ430(3) 2,183,19 3436 315.10 2,057.55 1,869.42 40837 41420 5,9459°x'.81 316,637,10 1.31 -346.13 MDIFR-N(LALSC(3) 2.07.93 3643 31637 2134,54 2045.40 44%11 45240 5645995.5 316599.86 2.31 -37937 MNDOFRJJ4 ,SC (3) 2371.41 36,76 31683 2,20961 2,119,47 490.56 -491.55 5,946.3925 316.561.73 252 414,76 MWD+lFR-AI(CAZ4iC(3) 2,46552 mm 317.9 2281.07 3.191.93 534.73 -63224 5,94606439 316.522.13 180 -452.61 MMDHFRAKCAZSC(3) 255845 4205 318.30 2,351.63 2,262.49 SW61 473,71 5946,13146 316481.80 1.65 -49125 MWOHFR-Al(CAZSC(3) 2.654.14 "..08 318,95 2,420.81 233167 62933 61644 5,946, lei on 316440.26 219 -53412 MWD+IFR--CAZSC(3) 2,74829 45.5 31824 246749 2390.35 67926 {660.9 5,946232.00 316,39744 1.95 -5]]21 MM+IFR-AKCAZSC(a) 284250 45.83 310.04 2,553,11 2,463,97 79,59 -75.0 5,94638339 316,353.57 0.18 620.51 ~.IFR-AWCP C(3) 2,930.53 45,83 318.11 2,618.57 2,529.3 779.71 -750.84 5946234.63 316.308.76 063 SWti3 MWD+IFR-AI AZSC(3) 3,031.9 45,05 310.3 2.68453 2595.39 me 40 -795.65 5,946,366.35 31626580 034 -70739 MVNHFR-AKCA C(3) 3.124.70 45.63 318.41 2,749.611 aced 60 680.59 64039 5949437..61 31622283 0.04 -050.56 MJU1D+IFRAK-CAZSC(3) 321938 45.80 317,92 2,81556 2,]26.42 0124 -BS.R 5,Wally. 316,178.40 037 -79416 MNOHFR-N(-CAZSC(3) 331334 4689 310,13 2,080.95 2,791ffi 98135 -93088 5,946,540.5 316,134,40 0.06 6025 MWDOFRAKCAZSC(3) 3,407.16 4565 310.19 294528 289.14 1,031.40 57565 5.9.591.74 316.090]5 013 400.39 MWO+IFRAKCAZSL(31 3501.16 45M 31844 3.011.0 2.M.81 1,082.02 -109,85 594664335 316,146.99 019 ffi3.93 MAOHFR-AKCA25C(3) 3.59568 45.84 318.14 3,0]].71 2,980.57 1,13259 -1,06593 5,946.69503 316003,15 023 56]50 MND+IFR-N(CAZSC(3) 3.00,61 45.07 318.63 3,14 57 3,54.3 1,103A6 -0.11149 5946,]46.95 315.95914 030 24,01132 MWOa1FR-AK-CAZSC(3) 3,784.9 46,91 310.75 3,90.01 3418.87 1,234.1 4,15.04 5645]98.9] 315.91554 091 -1.059 MJUD+IFR-AKCAZ6 (a) 3.678.79 0.9 3209 3,271.92 3,182]0 1,287.42 -1,201.35 5.946.853.03 315,871.5 168 -1110123 MADHFR-A -BC(3) 39300 48.97 32136 3,33431 3,245.17 1,342.10 -1,24597 5946906.61 3156269 132 -1,14693 MADHFR.ix AZSC(3) 4,058.00 50]2 3229 3,30.57 3,309.43 1,399.15 -1,29089 594698392 315.754.75 1.96 -1,19692 MWD+1FR-AK-CAZSC(3) 4,162.51 51.90 32909 3,45472 3,355.50 1,450.13 -1,33583 5,947.026.95 315.742,00 1.93 425090 MMD+IFR-AK-CAZSC(3) 4,267.50 52.83 336.70 3,51279 3.42365 1,59,24 -1,37]77 5947.089.8] 315,700.63 249 -1383.06 MADwIFRAKCAZEC(31 4.352,09 5404 32949 3.55.15 348001 1,%L20 -1,41638 5947,155.01 31566180 194 -1,353.71 MWDa1FR-AKCAZSC 13) Annotation 13-310" x 16" -Tec T cN6�5 1123016 3:46:36AM Page 4 COMPASS 5900.14 Budtl 683 ConocoPhillips ConocoPhillips DeNnlfive Survey Report Al Company: CononPhill,s(Alaske) Inc. -MMS Local CooNinate Reference: Well MT&06 Project. Weslem N.Ah Sbps TVD Refeence: ACTUAL MT6-06 @ 09.14usn (Actual Doyon 19) Sift. GMT1 Wakout Pad MD Reference: ACTUAL MTM6@ 8944uea(Actual DWonl9) Well: MTMS North Reference: True Wellbore: MT656PB2 Survey Calculation McMod Minimum Curvature Design31-wp02 Database: EDT 14 Alaska ProEuclum MD Inc Al TV0 TVDSS +W4 «Em Me, Map DLS Vertical 1.011 M (°I (-am (use) load) (am) Numbing Eandin9 Section S.rvey Tool Name ht) (n1 (v10a) (11 4,M]23 5$31 )29]4 3,62Qtfi 3.53502 1,65002 q,956Y2 5,94],2225] 315.623.59 1>1 -1,42391 sMMD+IFR-AKCPISC(3) 4,541.54 5580 332,26 3.676.82 3,587 60 ,71934 -1,45513 5,947,291.09 31558)36 272 -1.40617 MW DHFR -AK -C L C(3) 4.63537 57W 33L59 3.]2]M 3,638.59 1,789]7 -1,53132 5947,36324 315,55389 231 -1,550.89 MWDHFR-A AZSC(3) 4;20.10 57.45 337.51 3,77759 3.68645 1,861.24 4,5,299 5,947,435.46 315523.97 256 4,617.06 MWD+1FRAK-0AZSC(3) 4,0 ,W 57.54 338.55 342032 3,739.18 1,9350] -1,592.77 5.947.509,98 315.49599 0.93 -1,805.84 MVM➢+1FRAK-CAZSC(3) 4,91690 5789 338.11 3,078]9 3,78965 200939 462227 5,947,584.99 315460,31 0.54 -1,]5506 MWDHFR-P AZSC(3) 5.01133 57.91 33610 3,934.92 3039.78 2,00345 .1,6520] 5,94765976 31544031 0.02 4024.16 MWDHFRA -CA -SC (3) 5.1a299 57M 337.95 3,9]7b5 3,88651 2,15545 -1,681.13 5,94].]32.43 315.413.02 015 4991.22 M +IFRAK-CAZSC(3) SAWN 5].00 337.17 4,027.13 3.937.99 222834 -1711,18 5,90,05.93 315,384.74 0,71 -1.958.94 kWDHFR-PH-0 C(3) 529112 5600 33635 4,07,64 3.98,150 2.30230 -1,74299 5947,090,74 315351.74 0]5 2027b5 MWDHFRAI CAZSC(3) 53869 5789 335,64 4.129.89 4,040.75 2,37682 -1,77637 5947,95801 31532333 0.27 -2.09659 MWD+IFRAK-CAZSC(3) 548575 57AS 335.16 4,101.02 4.091.80 245)47 -1,08.08 5.94603345 315292$ 0.42 8.16777 MMW+1FRAK-CAZSC(3) 55]9]8 5783 33529 4,23105 4,141.91 2,52604 -1,04,62 5.948,106]9 315,261.59 0.79 -224]80 MND+IFRVW -SC 13) 6 675A 5785 33]31 4.281.81 4.192.9 2,599.09 -1,87599 5940,180.[5 31522980 0.87 -2,3028 MNDHFR-A AZ4C(3) 576646 57.84 334.17 4,33148 4,24234 2WON -1.910.32 5,94825261 315,19941 0.13 -2,36770 MWDHFRAK-0AZSC(3) 6,863.69 5],8] 333.52 4,382.14 4,293.00 274262 -1,9450] 5,948325.82 315,16264 050 12 121 MJM➢+IFRAK AZSC(3) 5,997.26 5709 333.65 4,43190 4,)42)6 2,61359 -198112 5.M,.7.W 315.129,12 0.12 -249937 MWDHFRJJ AZSC(3) 6,052.55 5705 33438 4,40250 4,39344 2086.13 -201640 5,940.471.00 315,09554 0.65 -3.569 MWDHFR-PH-CAZSC(3) 6,14620 579 335.0.21 4,53247 444333 2,957.96 -2,04996 594854361 315,63.61 113 -2,062.34 AIWDHFR-AWCAZSC(3) 6,24D.93 57.99 335.41 4,582,3 4,49379 3,03121 -2,082.54 S,94t1.617.63 315,033.59 070 -2.700.14 MJMOAFR-AK-CAZSC(3) 6,334.86 5782 37,09 463294 4,543.80 3.1114.26 -2,11393 5.940,691.42 315,063.41 0.61 -2,76792 MWDHFRA-CAZSC(3) 542932 57.88 33632 4,44120 4,594.06 3,17].72 214556 5,948765,62 314 an 0.69 -2,83506 MWDHFRAK-CAZSC(3) 6.53330 5786 33521 4,733.19 464405 3,206.29 -21]623 5,948,03896 31494269 10O -2503.18 1AWD+IFRAK-CAZSC(3) 6,617.. 5752 335.23 4783.38 4694.24 3,32]]7 -2.21169 5948.91222 314,91133 005 4 970d AVOOFR-AK-CAZSC(3) 8,71136 9.06 399.64 4,833.29 4.7"15 3,394.96 -2,2".68 5,946905.19 314,879]7 0.37 5,036.70 hMD+1FR-AM-CAZSC(3) 880600 57.79 33450 4,993.73 4,794.59 3467.57 -227667 5949050,60 314,84]56 129 410375 MWDHFRAK-CAZSC(3) 6.061.02 57,. 33482 4,934,31 4,045.1] 3.540,03 -2,31337 5,949.13180 314,81483 038 5.1]04] MMWHFRAK-CAZSC(3) 6,9YL85 5786 33425 4983.19 4894.05 3,61016 -2346,82 5,949,20280 314.78299 034 )235.04 M 11FAA-CAZSC(3) 7,007,15 9.65 JJ438 5,03)37 49".23 3,682.11 -238152 5919275% 314 749,9!i 0.12 y30127 MND+1FRAH-0AZSC(3) 7,180.14 5766 33399 5.08290 4,&93.04 3,752.81 -241597 5549347N 314,71723 069 5,3%10 MWDHFR-AK-CAZSC(3, 7,274,18 57," 333.70 513330 5,0".16 3.824.02 -2,451.20 5.949419.12 314.68375 004 5,431.68 MWY)+IFR-N(-0q2-SC(3) Annotation ,0 11=16 146:35AM Page, 5 COMPASS 5000.146uir 650 r- ConocoPllllips ConocoPhillips Definitive Survey Report Compan, ConowPhillips(Alaska) Inc. -WNS Local Coandinata Reference: Wall MT6-o6 Project: WMtam NoM Slope MReference: ACTUAL MT6-06®09.14us8(Actual Ooyonl9) site GMTt Laokeut Pad MO Reference: ACTUAL MT646 ® 89.14us0 (Actual Dayon 19) Well: MTe-06 North Reference: Tme Wellbore: MT6-06PB2 Survey Calculation MetM1otl: Minimum CurvaWre Design: Bt-wp02 Database: EDT 14 Alaska P.duction Survey 1122010 3'46'3MV PoPe 5 Annotation COMPASS 5000.14 SuOC BSD Map Map Mutual MD 1-11) Inc I7 Ata 1°) TVD (-am TVDSS (-am ON'S luslq 4Em luakl Northing Easgng DL3 Said an So, Tool Name (ft) (R) (-RW) IRI 7 Matto 57.60 3.,. 5183.83 5,00469 3,8956] -2,086.35 5,949.49160 314453135 031 4.497.53 MJNNFR-AKAAZSC(3) 7,48329 57,63 33411 5,234.47 5,14533 3,96)]] -2,5M,. 5,949.56451 314,61751 0.60 4i, 3al MADH1FR-AK-CAZSC(3) ].558]6 57b3 336.04 5.204.52 5.195.38 4.OM54 -2553.02 5,94963]44 314,565.40 1.20 361019 MWDHFR-MK AZ -SC (3) ],651.53 5].]0 335.44 5,335.29 5.24545 0,11295 -2586.14 5.949.71121 310,55507 036 389&18 MWDAFR✓J(-CAZSC(3) )]4690 5753 338.06 5,38564 5,29550 4,18563 -2618.21 5,949.711 310,52559 034 J765.71 M IFRAK-CAZSC(3) 7.035 STW 335.711 5,43614 5.34].00 4,250.60 -2530.03 51949,053.45 314,494]5 032 $033.10 MJ4D+IFRAKL SC(3) 7,903.76 57.67 335,]2 54861.12 5.396.90 4330.. -2683.30 SBW,931 ft 314,464.01 a02 5,814.64 MND+IFR#.AZSC(3) 8,027.90 0541 3M012 5.538,05 54QP1 4,401.81 -2,71659 5,95000344 31443240 2.79 -3.995,20 MNOHFR-MR AZSC(3) 8.122.75 5195 33023 5,591.19 5,505.05 4,469.33 $75217 5,950071.50 314,390.56 4.93 4,026.99 MWOHFR-AK-CPZSC(3) 8218.45 51.93 326.83 565159 556285 4,53223 -2790. 5,950,135.31 31435161 286 4.083 fig MWD.WR--CAZSC(3) 8,311,41 5031 323.02 5,711.62 5,622.48 4,593.00 $2=60 5950,107.09 314,321. 290 A13780 MND+IFRAK-0AZSC(3) 840352 48.E 322.41 5,771.70 S,M,M 4,648.84 -2,874.57 5,950.M33 314.280.56 252 4,10].0] MWDHFRA-CAZSC(3) 8.498.40 46,08 314,67 5.83531 5,74]0] 4,703.33 -2,917.82 595036e. 31423&65 265 4,214.,73 MWD -IFR -P CPZEC(3) 8592]] 4392 31791 5.50294 5,81380 475392 -20131 5.950.361.07 314195.40 3.58 4.27854 MWDNFR-MK A SC(3) 8,685,17 4219 313.75 5,97047 5,881,33 4,799.17 4,00522 5.950.407.37 314,153.61 360 4317. MW IFR-AI(-CAZSC(3) 0,719.40 4083 309.43 6041. 5,951.92 404061 5,051.87 5950.440.93 314,10],89 330 435132 MWD+IFRAK-0AZSC(3) BB]3.9] 39.03 3.,15 6113.62 6,624.40 4076.97 -3,100,39 5,&14,48745 314,050.36 404 -0.300.30 MND+IFRAKCAZSC(3) 8,961803 3186 299.42 6.187.0 6,.a.70 4,908.04 4.160.48 519M 519.73 314011.05 330 4,403.04 MWDHFR-4 AZSC(3) 9.663.42 37X7 294,47 6,263.@ 6,19388 493411 320172 5.950,50101 313.046 3.29 4,2220 MWDa1FR-M-AZSC(3) 9,157.47 35.91 287.03 6,33866 6,249.52 4,854.31 325380 5,95D.WB.49 313.006,89 437 4434.]] MMa1FRAK-0AZSC(3) 9,25210 35.58 279.91 6415.51 6.3E.37 4,.7.55 -3.30].3] 5950.683.03 313.85.. 4.80 4,410.9 MN12+IFRAKLA -SC (3) 9,345,12 35% 21419 6491.00 6,401.86 4,97421 -3,36128 59505..53 313.00193 362 4.439,00 MND+IFRAK-CPZSC(3) 9.43997 3594 269,7 6,587.80 6,47866 4,975.98 -341660 5.95059412 313746.37 202 4.432.76 MNDHFRAK-0PLSC(3) 9,533.07 3593 264.10 8.%1.211 6550.% 4,9892 3471411 5,85059239 313,691.81 330 4,421.09 MW"FR-PI(-CALSC(3) 9,621% 35.84 259.29 611976 6630.62 4,954.91 4526.26 5.950,585.71 313.636]8 2.99 -0,06,011 MWDaIFRAK-0AZSC(3) 9,7M.% 3703 253.02 6.]9560 6)06.54 4,95146 ,7,580.68 5,950.573.50 313,582,06 4.11 A311 MND+IFRAK-0AZSC(3) 8,8159 M.I. 246,93 6869.84 6,]53]0 4,931.89 -3,63426 6&14,55632 313.528.02 4.16 4.357.86 MND+IFRAK cZSC(3) 9,9119.91 38.92 24121 6.M M 6,854.50 4,906,19 .,807X8 5.950.530.91 313474.50 3. 4,32483 MDNFR-r AZ-SC(3) 1069541 4018 237.08 7,017M 692792 4,875.09 .73900 5,95D.501.09 313,421.03 3.06 4,20657 MWDOFR-W(-0AZSC(3) 10,%9.&1 41.91 231.30 7,00652 6,999.30 4,.0.72 4.]88,] 5950.485.95 313.370.61 4.35 4.243.33 MWDaIFRAK-04255(3) 10,193,87 4350 W.39 715763 7068.49 479719 -3,037.84 6960AM62 313.321 ,24 334 A19528 MWD+IFRAK-0AZSC(3) 1122010 3'46'3MV PoPe 5 Annotation COMPASS 5000.14 SuOC BSD r- ConocoPhiillps ConmoPhillips Definitive Survey Report Aai Company: ConomPhillips(Aiss") Inc. -ms LocalC rdlnate Repal Well MTfi-00 P.J.d: Western North Slope Tub Reference: ACTUAL MT6-06@ 0944use(Actual Doyon19) SRa: GMT1 Wokoul Pad MDReRrcnce: ACTUAL MT646®09.1"S11(Actual Doyon 19) Well: MT646 North RNelence: Tree WeWple: MT646PB2 Survey Calculauan Method Minimum Curvature Design: 111 W 02 Dabeasa: EDT 14 Alaska Production survey MD Inc Aai m NDSB +W4 +E1-ly Map Map OLS witiwl (-00 V) 19 1722 ( -ft) (us7 lusrtl Nerthl, Ewwn,, SacOon Survey Tool Nama IRI (ft) (+1100.1 IR) 10285. 95 4490 2218 22233.58 ],134.94 4,]55 261 .7,0&190 5,9..3821] 313,22441 265 4.1"53 MWbIFR-MCAZSC(31 10.316.05 4494 MM 2244.93 2,15529 4,23235 5,898]5 5,95836728 313,25889 132 A.1273D MM+IFR--CAZSC(4) 10,321.52 4502 22202 7,28120 7,195.05 4 7M -3,925]2 5,950,339,83 313,231.5 1.37 4,09521 MJUDHFR--CAZSC(4) 10.46434 46.95 219,05 2.340.70 2,259.56 4,65824 -3,90580 5.950,3942 313.195.95 3.12 4039X MWDNFR-AKC -SC(4) 10,560.1 5065 21591 2,411.05 2,322]1 4,601.61 4,01003 5,950,23459 313,14D32 493 -3,976.59 MWD+IFR-AWCAZSC(4) 10.855.11 53.73 21245 2420.04 2,380.90 4539.79 4,056,11 5,958123.61 31309519 435 5,90546 ~+IFRAI CAZSC(4) 10.750.61 Sfi29 209.12 T,SN.80 7,43508 4Man 4.09544 895D.107.41 313055.14 389 5,83680 MWD+lFR✓ -CAZSC(4) 10 Man 58.92 206.94 2,57123 7,486.09 4,40246 4,13349 5,905,03821 313,016,10 344 5,762.13 MWDOFR-AK.AZSC(4) 10,93899 61M 215.05 2,0]2.01 2,532.87 4,329.15 4,16983 5,919.965.01 312,970.3 2.99 -3,68438 MND+1FRAKLAZ-SC(4) 11.052.03 63.74 X3.81 7.65415 7,57561 4,2548 4,204.42 5,949,09169 312,94155 302 .7,605.17 MWD+IFR-PRCAZSC(41 114258 6476 20254 7,705.30 7,61624 4,176.73 4,232.61 5,94981505 3490654 ifi4 183.72 MWD+11R-A-CAZSC(4) 11,219.32 64.24 201.73 7.245A1 7,55827 4,09811 -0,269.59 5949.]82] 312.022.66 028 444136 MND+IFR-AK-CAZ£C(4) 11,3120D 6469 201.24 7.284.97 2695.83 402017 4 3M 5,949.660.11 31284810 OAB 535982 MWDAFRAK-0AZSC(4) 11405.62 65.03 2X35 7,825.12 2,73603 3,90509 4,33860 5, Se 580.80 312,807.76 092 5276.1 IAhDAFR-AK AZSC(4) 11,50101 85b3 195.83 7.051.59 7,77545 3,859.59 -035730 5,999,49996 312,779.17 440 y191.72 MWD+IFR- AZS0(4) 11,59440 67.51 19024 7.01.77 7,012.63 3275.15 4,376,97 5,94941205 312.257A8 5.39 110632 MWD+IFRAKAAZ-SC(4) 11.68955 6954 105.51 2,936.59 2,84].5 3.68221 4,381121 5,94932995 312,742.12 405 5.017.05 MNDAFR-AKL SC(4) 11785.02 71.82 18380 2,96845 2,87901 3,592.94 4,39936 5,949,240.41 312.731.W 356 -2.92282 MW IFR- CAZ4C(4) 11,842.00 73M 10191 7.985.12 2,896.03 3,50.1.68 4,401.10 $949]0524 312,222.74 421 -2,87379 MWD+lFR-.-CAZSC(5) 11825.68 25% 18423 7,991.0 7,901.91 3,51136 -0,402.98 5,949.15397 3128508 1120 5,841.53 MAIDMFRAK-CAZSC(5) 1189496 76.12 18905 7,90560 7,909,16 3,49310 4,124.52 5.919.13578 31220.05 141 -2.8324 MWDNFR-AKLAZSC(5) 11.989.2 81.54 104.14 0.01599 2,92285 3.40527 4,41190 5919093.14 312,713.46 5]7 -2,730,31 MW13+1FRAKCAZSC(5) 4,055.58 8577 10107 6.02262 7,93040 3,324.83 4,41623 5,999947M 312.7W.01 5.42 -2,91524 MW➢+IFR.CAZSC(5) 12,18030 9040 122.57 8.031.04 2,91190 3210,14 4,415.10 5,940.853.15 312.205.64 5.87 -2,541.70 MWD+lFR-AKCAZSC(5) 12,275]0 90.5 174,55 80X58 7,94141 3,11505 4,408.55 5,948.75294 312203.88 319 -2,44851 MND+IFRAK-CAZSC(5) 12,321.7 90A5 170.211 don" 2a9069 302D.15 439591 59/866226 312,7.21 4.46 -23te" MWD+IFRAK-CAZSC(5) 12466.52 0998 16651 8ON.42 2,94033 2,922.01 4,376]9 5,940$69.19 312.732.06 3.99 -2,262" MWD+IFRV CAZSC(5) 12582.02 09.42 16269 11029.92 2,905.83 2,03500 435144 5,94847661 312260.16 4,114 -2,12862 W10+1FR-AKCAZSC(5) 4,657.6 0946 158,90 8."0.05 7,94176 2299.90 -0,320.06 8998395]7 312,79935 392 -2094.96 MND+lFRAK-CAZSC(5) 12.]526] RED, 155.4 0,"18 794260 265225 428292 5,948X725 312a2435 392 -2,013.52 MND+IFRlJ(-0.250(5) 12,849.2 80'5 1"17 6032.96 2943,82 2,57035 424085 59/620932 312.86420 2.16 -1053.83 MWD+IFRAKCAZSC(5) al a Anm3letion 95/8" x 12-1/4" MT6-06PB2 NOP 11th 1e 3:46:364M Pagel COMPASS 5000.14 Baird BW ConocoPhillips ConocoPhillips Definitive Survey Report Company: Conoc0Phl9lps(Alaska) Inc. -M5 Local Co-ordinate RMemnce: WbII MTS -06 Project: Westem Nodh Slope TVD Reference: ACTUAL Mn -06 C 89.14usS (Actual Doyon 19) Sea GMT1 Lookout Pad MD Reference: ACTUAL MT6436®89.14ua8(Actual Doyonl9) Well: MT6416 Nunn Reference: Tme Wellbore: MT64)6PB2 survey Calculation ktethoul: Minimum Curvaline Design: Bl -w 02 Database: EDT 14 Alaska Production Survey ND Inc Aad TVD TVDSS rwS rvaW Map we OLS Vertical loan) (1) 19 lura (-am loan) laen) Northlrp EasHng Section Survey Tool sumo M) In) 1°neral telll II,943.01 69.03 151.44 8034.61 ].9454] 3,487.33 -4 t9],Z1 5949.mYal 312,905.03 1.85 -1.85274 MWD+IFRAKLAZSC(5) 1303274 90.88 15154 808460 7,945.46 2404.09 -0,15206 5,84804L00 312949D1 306 -1,]81.8] MWDHFR-AK-CAZ3C(5) 13,135.01 80.59 is.. 0,0331] 7,944.13 2319743 <, 104.91 5,942,954.82 312994.08 1.16 -1,7,4.47 MJr➢aIFR-N AZSC(5) 13.22820 90.01 150.56 0, Dun 7,94364 3,237.91 4,068743 5,947.822.62 313,W797 0.63 -1,630.60 MJJD+IFRA-CAZSC(5) 13,322.83 09.98 153.19 8.032.29 ],943.65 2.15138 4.014.36 5,947,7sJ%W 313DNIZ7 2.78 4,554.55 MWDOFRAK-CA24iC(5) 1341847 89.90 151.]D 8.033.83 7,943.68 2,Men 41,97019 5,94],]02.28 31312269 1.56 -10]].50 MWD+IFRJ AZ4tC(5) 13.514.80 0949 152.40 6=27 2,84013 1,9".51 3,acsm 5,947616.06 313.165.80 0.89 -1,399.31 IVNW+IFR-N(-CPZSC(5) 13,50906 89.M 151.50 003044 7,"5.30 1,901.33 3,850.05 5."7,531" 313.21891 0.82 -1,32335 MWD+IFRAKLPLSC(5) 13,2".52 Saw 151% 8,036.36 2,94222 1,817.32 4835.48 5.942,44676 313151.15 0,51 -1.248]3 MWD+1FR-AK-0AZSc(5) 13799.86 sent 151.14 8.039.10 2,950." 1733.65 3,70994 5,"7,362D1 313,294.8 Dug -1,170.49 MWD+IFR- -cAZSC(5, 13,50524 8788 15D.70 6,04259 ],95345 1650.35 -3,743.61 5,942Z]].61 313.33900 0,48 -1..094.8 NIWD+IFRA-CAZSC(5) 13,991.14 68.67 150]5 0.045.4] 2956.33 1.565]4 S,69614 5,947.19289 313,383.81 0.03 -101621 MWD+IFR-AWCPZSC(5) 14.D86." 91.01 15350 8,04574 7.956.] 1,48315 5,651.64 5."2,10833 3134680 306 94258 MWD+IFR-AKCAZ-8,5) 14,181.88 9195 153.00 8,04337 7,9".13 1398.22 -3,607.92 5, 947 OM28 313,468.53 1.15 564.73 MWD+IFR-N AZAC(5, 14276.65 9244 16316 B,mem 7,950.49 1,313.58 -3,565.@ 5946936.83 313.509.35 0.52 -78213 M +IFRAK-OA C(5) 14.321.44 9160 153.02 6038.25 2"2.11 1228.59 3574.95 5.0fies50.Eo 313,551.34 1.48 -709.37 MWD+IFRAK-CAZSC(5) 14,46762 91.27 152.8 0.033.87 7,9,4.23 1144.25 5,4".00 5,946m.21 313.59343 091 53326 MWDOFRAKLAZSC(5) 14,56283 6973 Ymes 01031." 7,94380 17459.33 -3,433.87 5,94667918 313,6".27 1.09 554.39 MND -IFR. AZSC(51 14.658.59 seen 14.57 80 fo 7,944.39 50393 3390.57 5946.593.85 313,61549 113 $7&ll MWDNFR-AK-0AZSC(5) 1175295 B9.1B 152.80 8,034.47 2,945.33 SB0.09 4,34212 5,946.65000 31321674 um -39937 MWD+FRAWCAZSC(5) 14,"863 HAD 15263 0,03615 7,94211 895,07 41.30341 5,946431" 313)58.51 0.54 42154 MWD+IFRAK-CAZSC(5) 14,94385 87.92 151.97 0,03806 2"9.92 ]Lt] -3,259.17 5,949,336.62 313,]0]0 1.50 -24451 "JVD+IFR-AK-CAZSC(6) 15.039.99 6242 190.30 80429] 295303 635.68 5112.00 5.946.25141 313.84510 181 -16294 MWDNFR- CAZSC(5) 15,13]4 86.03 15u32 8,046.70 ].95].56 565.28 5,166.44 6.946 1601.92 313,889.37 ,64 -".05 MWD+IFR-AK-CAZSC(5) 15.23924 67,69 15243 8,om0w 7,96095 470.61 -3,120.28 5,use came 313933.46 3.13 -16.91 M IFR -A AZSC(5) 15313.71 67.90 1".42 6,053.46 7,964.32 X7,06 3,67649 5945.990.63 313,97320 2.13 59]5 ~+IFR -MA 4674 0(5) 15,419.41 87.95 154.34 0,05692 ],967]8 30n" 5,03].14 5,945.911.43 314,D1245 (110 139.14 MWD+IFR-MK AZSC(5) 15,515.14 08." 166.08 6.05851 29793] 214.32 -2995.26 5,945.823." 314,051.21 126 218.60 MWD+IFR-AK-0AZSC(5) 15610.18 0650 154a2 0.061] 2,9849 128.31 -3,955.87 5,90 7W.98 314,08949 067 298.19 l,WD+IFR-AK-CAZSC(51 15]05] 8848 154.15 8,064.13 2,974.99 42.75 -291486 5.94SAWA7 314126.41 050 37695 MWD+IFRAK AZ43C(5) 1579963 88.46 15335 6065.65 7.97751 42,18 -26]292 5,945.5"54 3141.. 0.84 454.98 MWD+IFRA aZSC(5) Annotation 110 018346:36AM PeBea COMPASS 5000.14 Bo8d 80 .� ConocoPhillips 49k, ConocoPhillips Definitive Surrey Report Compan, ConocoPhlllips(Alaske) Inc -NMS Local Cooramate Reference: Mil MTS -06 Project: Western Nom Slope ND Reference: ACTUAL MT6 ®89.14us8(Actual Doyanl9) a": GMT1 Lookout Pad MD Reference: ACTUAL MT646 @ 09.14us8 (Actual Doyonl9) Well: MT646 North Reference: Thee Wellbore: MT64)6Pa2 Survey Calculation Method: Minimum Curvalure Design: Bl-wp02 Database: EDT 14 Alaska Production Survey MD 1. Aal TVD TVD55 sW We ♦R14M Map Me, OLS wrgcsl (aef) M 17I IMMt) (.to (ash) (deft) Nonhing EaMlny Semon surnYi4olwme (ft) (n) 17/100') ph 15.894.95 SQ. 15283 8,067.94 ),9]600 -126.99 -2823.93 5945,4]8.]2 314309.19 1M 532.72 M .IFR- AZSC(5) 15,990.03 Sam 15229 8067.24 7,978.10 -211.37 -218511 5,94539130 314,2 94 1.12 60992 MN➢HFR- -CAZSC(5) 1608599 91.68 152.17 8,06510 7,91558 -296,25 2,74141 5,945,30736 314,293.% 084 .7.49 MWDNFRAK-CAZSC(S) 18.18105 91.95 16359 6062.06 7.9895 380,02 .2698.10 5.915,221.]0 314334.80 1.52 16085 MWD-IFRAKZP C15) 16,27575 81.98 153.58 8,45604 7,96610 465.57 -2,655.98 5,9A5jasm 314.374.85 004 8421 M IFR -P AZSC(5) 16.310]1 9201 153. 8,o55,54 7,98540 55042 -2,613.48 5,945,050.17 314,41528 036 910.61 MNDAFRAK AZS0(5) 16456]8 9204 15392 8.05216 7N3.02 535.95 -2,570% 5194496165 31445570 0.73 999.14 MND.IFRAKLAZSC(5) IGSSIS0 8652 153,38 8,051.89 7,95255 -021,62 3,528.53 5,944.07698 314,49604 3.72 1,077.81 MWD+IFRAKLAZSC (5) 16,65650 %.91 15355 6055.46 7,955,32 S%1B -2.48630 5,944.79142 314,536.20 1.71 1,15542 MW➢rIFRAKZAZSC(5) 16]52.1 8561 153,31 01761.11 7,973.57 991.61 -2,443.58 5944)04.98 314,57863 138 1,233.82 M -IFR-PA-CA ,SC(5) 16,802.00 6581 1%.31 8,005.52 7,9MU 435.96 -2421.29 5.944.%011 314,SM.04 000 1,27150 PRWECTECto TD Annotation 11? 2018 146.36AM Page 8 COMPASS 600014 Bulcism I Page 1/1 ReportPrinted: 11/13/20181 Cement Detail Report MT6-06 String: Conductor Cement Job: DRILLING ORIGINAL, 9/10/2018 00:00 Cement Details Description Conductor Cement Cementing Start Date 2/7/2016 14:00 Cementing End Date 2/7/2016 1600 Wellbore Name MT6-06 Comment Cement Stages Stage # 1 Description Conductor Cement Objective Top Depth (ftKB) Cement Conductor 36.9 Bottom Depth (ftKB) 115.0 Full Return? No Vol Cement... I Top Plug? No Btm Plug? No Q Pump Init (bbl/m... O Pump Final (bbl/... O Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? I No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Bim (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (°/,) Density (Iblgal) Plastic Viscosity (c P) Thickening Time (hr) CmprStr 7 (psi) Additives Additive Type Concentration I Conc Unit label I Page 1/1 ReportPrinted: 11/13/20181 m Cement Detail Report 3/g MT6-06 13 String: Surface Casing Cement Job: DRILLING ORIGINAL, 9/10/2018 00:00 Cement Details Description Cementing start Date Cementing End Date Wellbore Name Surface Casing Cement 9/13/2018 17:45 9/13/2018 21:15 MT6-06 Comment :{- y65 in Ip'r Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Retumv Vol Cement... Top Plug? Btm Plug? Surface Casing Cement Cement Surface Casing 37.1 2,118.0 No 1 l 5 99.0 Yes Yes O Pump Init (bbl/m... O Pump Final (bbl/... O Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? S oke (ft) Rotatetl? Pipe RPM (rpm) 5 3 4 400.0 1,000.0 Yes 20.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 2,017.0 Drill Bit 2 1/4 Comment 99 bbls of 11.0 lead cement to surface Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Elm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 37.1 1,618.5 1,020 LiteCRETE 361.7 Yield (ft /sack)Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.92 6.87 11.00 185.1 5.33 Additives Type Concentration Conc Unit label Fluidve Fluid Fluid Type Fluitl Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 1,618.5 2,118.0 328 G 69.9 Yield m --sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.12 15.80 108.5 5.45 Additives Additive Type Concentration Conc Unit label I rage in ReportPrinted: 11/13/20181 r _� Cement Detail Report m 7. rP. „ 6/1 � MT6-06 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 9/10/201800:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 9/22/2018 20:30 9/22/20182334 MT6-06 Comment Full returns through job, bumped plugs, floats held. Cement Stages Stage # <Stage Number?> Description Objective Top Depth (ftKB) Bottom Depth IRKS) Full Return? Vol Cement... Top Plug? Son Plug? Intermediate Casing Cement Intermediate 9,281.0 10,326.0 Yes Yes I Yes Cement casing "'Pump Init (bbl/m... O Pump Final (bbll... IQ Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 3 6 580.0 1,100.0 No No Tagged Depth IRKS) Tag Method Depth Plug Drilled Out To IRKS) Drill Out Diameter (in) Comment Bumped plugs. Floats held. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (RKB) Est Stn (ftKB) Amount (sacks) Class Volume.0 Pumped (bbl) Iniermediate Lead 9,281.0 9,816.0 95 G 39 Cement Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (0) Thickening Time (hr) CmprStr 1 (psi) 2.31 13.09 12.20 12.6 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Tail 9,816.0 10,326.0 256 G 53.0 Cement Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.08 15.80 156.1 Additives Additive Type Concentration Conc Unit label Page 111 ReportPrinted: 11/13/2018 r Cement Detail Report MT6-06 Job: String: 7 Liner Cement DRILLING ORIGINAL, 9/10/201800:00 Cement Details Description 7" Liner Cement Cementing Start Date 9/30/2018 00:53 Cementing End Date 9/30/2018 03.40 Wellbore Name MT6-06 Comment Cement Stages Stage # 1 Description 7" Liner Cement Objective Cement Liner Top Depth (ftKB) ) 10,047.0 Bottom Depth KB) (ftKB) 11,833.0 Full Return? Yes Vol Cement... Top Plug? No Btm Plug? No Q Pump hilt (bbl/m... 2 Q Pump Final (bbl/... 1 Q Pump Avg (bbl/... I 2 P Pump Final (psi) 640.0 P Plug Bump (psi)Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment 55 bbls of 15.8 ppg Cement. CIP = 03:40 Hrs. Left 5 bbls cement in DP. Cement Fluids & Additives Fluid Fluid Type G -blend Tail Fluid Description 1 Estimated Top (ftKB) 10,047.0 Est Btm (ftKB) 11,833.0 Amount (sacks) 266 Class G Volume Pumped (bbl) 55.0 Yield (Wisack) 1.16 Mia H2O Ratio (gal/sa... 5.07 Free Water (%) Density (Ib/gal) 15.80 I Plastic Viscosity (cP) 1103,1 Thickening Time (hr) 5.28 CmprStr t (psi) Additives Additive Type Concentration Conc Unit label Page 1/1 ReportPrinted: 11/26/20181 BAF . q PRINT DISTRIBUTION LIST a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME MT6-06, MT6-06PB1& MT6-06PB2 FIELD Greater Mosses Tooth Unit COUNTY ALPINE BHI DISTRICT Alaska AUTHORIZED BY Paul Canizares EMAIL Pau l.Can izaresno. bhae.com 11 STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT DELNER TO P.O. BOX) PERSON ATTENTION V W Elgarico. ATO 3.380. 'G' Street. holaee, Alaska 99501 2 ;Alpine Wells Supervisor, NSK-33 TO. Flo. 196860 :Anchoraee. Alaska. 99519-6860 9 'C' Street, Suite 801 I State Offse W. 7th Ave., Suite#13 huraee. Aloka 99513-7504 ]CC ATTN: Natural Resources Tech W- 7th Ave., Suite 100 home, Alaska 99501-3539 21 8093 29959 ;e sign and return a of this transmittal form to: xc Phillips Alaska, Inc. V Elgarico. Richard.E.Elgarico@conocophillips.com 3-380. 'G' Street. Anchorage, AK 99501 LOG TYPE GR-RES-DEN-NEU - LOG DATE October 15, 20 8 !V D TODAYS DATE November 2, 2018 NOV 0 5 2018 Revision tt 0GQC Details: Hy Rev. Requested by: -- FIELD I FINAL CD/DVD FINAL PRELIM LOGS S. dlis, PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) # OF PRINTS # OF COPIES J#OFCOPIES # OF COPIES V V V 0 1 0 01 0 MT6-061 is located in a federal oil and gasunit. Only with respect to the (MT6-061 Well Data, CPA] hereby waives its right to indefinite confidentiality, under 5 U.S.C. 552(b)(4) and (9). Nothing in this communication should be construed as a waiver of indefinite confidentiality on any other wells. Please note that for wells not on State land, a state agency should seek consent from the landowner prior to the release of well data by the state agency. See, e.g., AS 43.55.025(f)(2)(C)(i). Here, the landowner is the Bureau of Land Management (BLM) and/or Arctic Slope Regional Corporation (ASRC). TOTALS FOR THIS PAGE: 0 0 4 0 0 BAI ,.(I ER 0PRINT DISTRIBUTION LIST a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME M76-06, MT6-06PB1& MT6-06PB2 FIELD Greater Mosses Tooth Unit COUNTY ALPINE BHI DISTRICT Alaska AUTHORIZED BY Paul Canirares EMAIL Pau l.Canizares(fthge.com STATUS Final Replacement: No COMPANY ADDRESS (FEDEx WILL NOT DELVER TO P.O. a0%) PERSON ATTENTION V 1 :ConocoPhillips Alaska, Inc. Ricky Elgarico. ATO 3-380. :700'G' Street. :Anchorage, Alaska 99501 21 8093 29960 Please sign and return a of this transmittal form to: ConocoPhillips Alaska, Inc. Ricky Elgarico. Richard.E.Elgarico@conocophillips.com ATO 3-380. 700'G' Street. Anchorage, AK 99501 to acknowledge receipt of this data. LOG TYPE GR-RES-DEN-NEU .5urED LOG DATE October 15, 20 8 TODAYS DATE November 2, 2018 NOV 0 5 2018 Revision AQ G QC Details: Rev. Requested by: FIELD/ FINAL CD/DVD FINAL PRELIM LOGS I (las, dlis, PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) # OF PRINTSR Ur VKUN # OF COPIES I#OFCOPIES # OF COPIES V V 0 1 0 2 !Alpine Wells Supervisor, NSK-33 0 0 1 0 0 —71 :P.O. Box 196860 :Anchorage, Alaska. 99519-6860 3 ASRC,A[tn:Teresalmm 0 0 1 0 0 :3900 'C' Street, Suite 801 ;Anchorage, Alaska 99503-5963 5 AOGCC ATTN: Natural Resources Tech 1 0 0 1 0 1 0 :333 W. 7th Ave., Suite 100 IAnchoraae. Alaska 99501-3539 (MT6-0( is located in a federal oil and AMgas unit. Only with respect to the (MT6-061 Well Data, CPAI hereby waives its right to indefinite confidentiality, under 5 U.S.C. 552(b)(4) and (9). Nothing in this communication should be construed as a waiver of indefinite confidentiality on any other wells. Please note that for wells not on State land, a state agency should seek consent from the landowner prior to the release of well data by the state agency. See, e.g., AS 43.55.025(f)(2)(C)(i). Here, the landowner is the Bureau of Land Management (BLM) and/or Arctic Slope Regional Corporation (ASRC). TOTALS FOR THIS PAGE: 0 0 4 0 0 BAIUGHES PRINT DISTRIBUTION LIST a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME MT6-06, MT6-06PB1& MT6-06PH2 FIELD Greater Mosses Tooth Unit 218093 299E 1 se sign and return a of this transmittal form to: ocoPhillips Alaska, Inc. V Elgarico. Richard.E.Elgarico@conocophillips.com 3-380. 'G' Street. Anchorage, AK 99501 COUNTY ALPINE LOG TYPE GR-RES-DEN-NEU BHI DISTRICT Alaska � LOG DATE _ October 15,2018' (D AUTHORIZED BY Paul Canir�res EMAIL Paul.Canizares@bhge.com TODAYS DATE November 2, 2018 AI(1V p 5 2018 P Revision A0GG a STATUS Final Replacement: No Details: Rev. Requested by: COMPANY ADDRESS(FEDEaW NOT DELIVER TO P.O. BOX) PERSON ATTENTION ..............___.......... __---- ......... _....._........... .__. t jConocbPM1illips Alasla,Inc. :Ricky Elgarieo. ATO 3-390. 70UG' Street. iAnchomee. Alaska 99501 E a,P�ne wens anper "' "'." P.O. Box 196860 Anchorage, Alaska. 99519-6860 FIELD I FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) # OF PRINTS 1 9 OF PRI It OF COPIES 11#OFCOPIES J#OFCOPIES V 3 ;ASRC, Atnl: Teresa Iron, I O O O O 13900'C' Street, Suite 801 ;Anchorage, Alaska 99503-5963 A State Office W. 711, Ave., Suite#13 horage, Alaska 99513-7504 -CC ATTN: Natural Resources Tech W. 7th Ave., Suite 100 0 M 104MI is located in a federal oil and gas unit. Only with respect to the JMT6-06J Well Data, CPAI hereby waives its right to indefinite confidentiality, under 5 U.S.C. 552(b)(4) and (9). Nothing in this communication should be construed as a waiver of indefinite confidentiality on any other wells. Please note that for wells not on State land, a state agency should seek consent from the landowner prior to the release of well data by the state agency. See, e.g., AS 43.55.025(f)(2)(C)(1). Here, the landowner is the Bureau of Land Management (BLM) and/or Arctic Slope Regional Corporation (ASRC). TOTALS FOR THIS PAGE: 0 0 4 0 0 I)'m � 18� Weekly Progress Report for BLM Weekly Pr08ress Report 10/22/18 Well:itill Field:lookout API:5010320773 Hole Depth vs. Dav RepXeL•1 Mpenantl Mu bed, 4enenl lYmelo Not UIWBamnry 30/3Ih018 NoAt$.0 p an X1811 L1ns ad MS. all Drilled Mand CIn 14NYI.. unsMble.." brmatlon, m.BXP6vk an l$A]Y ]]:WPM 12:NAM on Ni{M1 11ne. eOPE's R¢N)D/8/38, and pvlonlapen hole utlM•ak I-Im P=130 Mi./]"DA-SI... em.m18 2oha/2m8 Xa AIS Camponlit,nNe®mS.114 ewfink Woodal lly pMnad ren 5Wele[k dIalon pine Csats 9 Sal .;.a. on XlghlMe.yDPE's iMe!]II/0/1& IO/]</IOIB ]0/11/2038 NO AN, Campari x11 Dne 1.1, Ny DnIIPIpme Csena•n10,tircvlah, penaml porcprewre MneerpnN,wNglltupW 31WRM 11D]PM on X(d. dne. Btin'I Rnen IDAAe 9appy5and.el ok. SIM=1M PSL/1 Of=3WPsi tod'ad ot8 30/)6/2018 Ne. pmPn Xy6Yne®ce" Sd,dd'.1 d'NNtlavn ndd"- NY L2WNA .110. nMgb LMe.40PE'sresletllorei 45/8"W=]0]psl./TOA Wpy 10/16/M18 10/1]/2016 No all dal Camp on N196 Llne. Puna.S`line•to added 168a] NO SN and nat Mnp•/pe[4n)oL=11.668' MDa� 3]COAM ni's tents lO/6/IB. Name MnNan tldon.tagtdId.—OWPFneePPDONtmdngdawna"OPMWDP [esl<JIO NS. Dally ad.. -to I". Ilnn'4.61<s. 4S/8'O1C-)Ndw /11d46=0 e4' 6�c 30/17h016 .,)o 10/1p(2028 12:WgM Xo AR. Xgaand pod XldLllne. .Ph Nal l0/fl/S4 Dams M[Xan ConMnae POOR layigCnna'Wlrytlmm•umlingbda lLNaM �un1X'15Ndue upPe wmplet to I,4R'MD 114S/tl In mai MSMLt", 48/8'OAL=1CV pY /T Ole=O P. 30A.ma. 10/19/2018 No P6, Ni8antl Camp on Xy6 Lim, feai nnnlllg[oned.,.lmne, I. a.t, PN Mnp•/land, lC on -hale• I11 32WAM )2:NPM dool toned l0/e/1H. Xnu of ii Said, ad—on—lnwhini lend—walbn OmP b."Tad. 11 iodnsent 6ev to. 30/15, oN50V InspII6PV antl. IN.BOPE. 45/9' IN.1=1N on /]'.1-0 qi ]11/39h016 ]0/30/201p XPP6.Py NNLbmpon XyALMe. Mesand M/4SL8PV,N nttakon eudn8narye•, (alletl. PUII6mga,m 1L O 1l:NXM 12:N M1 ., ie➢e6lQ/4114Mx Mttnn RAatl10/I5. oItand detsaMetry n'".ai Ae Xaamjaldndpupy PN BSYnsbn PaIXav aMM1ary e6mmpletlan@p5'. W06W.NN NdMSPoalanGrcplax.0ummynn M1arynaM ,eP n 93/8'OA [=SW �I./1dI se# r' PI S, 10()a." 10/21/2038 Xa RIS. d1and Canp.e Xidline see6Pv and Rstplo6 NN OOPS tan 6reaki PUN M1aryeC pull ntl 4D and- ydaid, 13NaM ]2:NAM PE's..ad 30/W38 Na., n.- 1111. ,1.pad, pnlend .ral lnnal Nne new WryeL, land mmdenat. tweed adi 1..1.11. set plug(11In X P•ofileantl IT Ndne to 900 PsiM 30 non. oany.an mnea<a rsx 611,e adp• [amdeFS1 10/12h034 NONSU[an WtlNb.fampan adddddad...dd.n a4.Inp+E SNM5, III III modefide N/Uoeneddi IT Maeom i2'AIAM 3l.W Me NI66LMe. irteln9aXMaM bsW. odand"BW ad SoM 1 adtpter/beeb50DpN Rm1InMIWMe. Eseem Nabn, Set WNPV sswrtwep.NIT type XMMin011edaMeedetl ]D OP 21-38. Mal Nbiny premlrt=lW p. _. ory 30 35 ne n1 4,000 6,000 8,000 10,000 g Y u,aoo 14,000 Weekly Progress Report for BLM Weekly Progress Report 10/15/18 Well: MT6-06 Field: Lookout API: 5010320773 Hale Depth us. Dry Report rem Report End Det' 20 25 30 35 40 Date tate Genial Remahs Inca Urkuesummry 10/6/2018 10/7/2018 No AIS. CamPon High line@CM, Rq IXii1fI12,616'to 32,69]'.Oedaw to Plugba[k Weup to 9l mpg. Pd ]2:OOAM U.WAM on No tine. 90PE's Tested 10/4/19. a6.T. race, &annuNrw/3-1/2" It.ji. RlU ter .n Nking. 35/8 -D/A -Mie./ TOA.0pia 10n12018 SO/8/2018 No A6. Camp an High line dy COS. Rig M/U3-1/2"stinger asst'. RIH to 12,685' atc A cond mud for commit 12:0DAM 12:0GAM an High has, BOPi Tested 10/4/18, plug 41. POOH to u.nl'. Orc& send mud for cement job, pump cen POOH to 11,632'. Core den, POOH w/umant finger any to e1,06T 35/8" O/A=140 psi. /T' 0A= 340 R. ukah2D18 10/9/2018 W AIS. WmP on High Une@CIA. Rig POON&VOc.Act singer Anne. To. WK. M(U 6-produNpn BHA 12:03. ll:DDAM on No Hee lRy an Mneratprs for 63SHntodad SOWi Tested la/8/18. 10/9/209 10/10/2019 No AD Camp -Noun Use @ 035. Rig RIR se/productionBHA 47.Sit, & cul drill line. Drill Aid cement Is kick ]IWAM 120DAM on High line, OOPE's Tested 10/8/18, morucM1m woman to UAST M0.&09' WD. 95/9" O/A=110 psi. / T' OA=3W Psi ukilw018 10/INDIS No A6 .0 pan High une@CM. Rig Wisp Npme C f/ UW' to 14,4STMD SS:WAM M. An High Dne. RDPE's Tested 10/a/Sl, 93/8=O/A=110 psi. / 1° OA -300 psi SO/11/2Di9 30/12/2019 No AN. Camp on High We@ CDS. Rig United Alpine 'C' to 16.529' M0, 121KSM1 1300AM an High une. BOUT Tend 10/8/18. 95/8" OA =120 psr / 7" DA =42D psi 10/13/2018 10/13/2018 He AIS Camp an High Une@ CUs. Rig Pilled Alpine C to 16.80'into unstable shah fiannxpon, rem W Is 12:00AM ".AM on High lin e. SOPE's Tested 10/9/I9, and perform open hole eidetreM. 45/5'OA=120 Ad. /TOre rt)Opu 0'10/13/209 10/24/2019 No A6. Camp en High One@ COS, Rig Successfully performed open hole spanned, drilling Alpine C send. I Y12DO AM 130DAM on High Ime, 80PE's TestM 10/0/18. 95/0"OA=100, /7"OA=SW psi 10/14/208 3015/3018 Ne A6,GmPon High UnefloWitg OMI AIpne C semi A TO, dreulah, perform pare Pressure finger Pmnt U:WAM 1240AM on Highlae.90PE'e Rsted10019. 9.4pp& Strip outofhele. 35/11"OA=10/PSL/7-Col 4w -a M -H E-gv e�ogm im a� s�.: g £5j8 f£ � 05 ,�'^E SEG 3$ G�33�Em ffi mfiv a££ .9E �-E 3 iEmm4i€ xo 92x �frgp p; 29' '£32 m v zt f _ vao �LaE��oi� piiFc EZai 4f_ a�F9i=: �o e8 `x aFe oS pia" ffi=m ts 3 d396N $:3i 72 a'� :n_ au s E.0 d gy gc ga g; 12 2 citco i 5,z o 8$ o$ frS 8 €$ S frS fr$ 8 §$ 8 Q m� E3Q0 Em E• :� � E \ �� V a �� " Ca ii c Q �o`�ua ze zo zo o i`o d'>zo . ao A$za m iE A CL Qof i cn o x.38 e8 CS o8, Co88 08 8 o LL Q > n n o£ mog c£ >, Y 4w -a M -H �� affigQib xf g�E cE 5c 3Z¢ 'uE c�^'i EeE 3=•f�ng'b 'E�gcEP ij$ _.nf a ZEEmEE e`-2gm—`zg"=Gmm E N7_'e �3qn P-�owc`4o�g �E` FE Fedi �ig5i �5`m o££EL�n m�F zFg ` E Y cf cif E�fe MUC ti db,i �ryEry a�: z8c ec mon y+Z xE��r tFa£J aS f3f m�95?Y%�tl��3E g�[ 33p�09`atimn�nW 9053 #c _Em3�n.. iEmEx �6"�?g oc3 36m bEEl F cti F SY fr$ =� xr frm fr$ frS 5$ a pE �w mW. Sm 3� frS frS 25 Yo :a c,a aS a8 a.. m8 a8 S$ m� ! !|! _ & 5 0CL |t 2 § :- ƒ I , ch 0 \§ \ f / 0 )§ \ \ ( cis re B, _ , __ \ ! |t 2 § :- , �_`. )§ { \ - B, _ , __ `_- { . \ / \\ \ \\ / !. !, ! Schwartz, Guy L (DOA) f�-V 7 Z I Y_ From: Schwartz, Guy L (DOA) Sent: Saturday, October 06, 2018 6:24 PM To: Beat, Andrew T Cc: Elganzoory, Mutasim; Quinn Sawyer, Rixse, Melvin G (DOA); Doyon 19 Company Man Subject: Re: MT6-06 Update and Plan Forward Andrew, Your plan is approved as written. The abandoned hole section will use an API suffix -70 (PB1) in order to capture the OH data. Regards, Guy Schwartz AOGCC Sent from my iPhone On Oct 6, 2018, at 9:36 AM, Beat, Andrew T <Andrew.T.Beat(dconocophillips com> wrote: Good morning, Last night we landed our curve with some uncertainty about our position within the reservoir. We decided to continue drifting down in section to confirm the base of the Alpine C sand. If more sand was encountered, we were going to drill ahead but instead we found the bottom of the sand and have decided to stop and plug back to restart our lateral. No tools were lost and the cement to be pumped is just an aid to allow us to get kicked off. Below is an overview of our plan forward on MT6-06. Please review and let me know if you have any questions or concerns. Liner Shoe: 11,833' MD TD: 12,687' MD Current Ops: POOH to shoe Plan Forward: • POOH to surface. L/D production BHA. • Test upper rams and annular with 3.5" testjoint. • MU 1000' of 3.5" tubing below DP for cement stinger. • RIH to bottom and condition mud. • Pump Cement Plug #1 o 500'/ 15.8#/ 12,687'-12,187'/30% excess • PU to calculated TOC and circulate. • Pump Cement Plug #2 o 600'/ 17#/ 12,187'-11,587'/ 30% excess • PU to 150'-200' above liner shoe and circulate wellbore clean to cutoff excess cement. • POOH and L/D tubing. • M/U RSS BHA and RIH. • Test cement hardness. If good, continue drilling to KOP. If soft, wait longer Proposed MT6-06PB1 Schtvmatic Oct 5th, 2018 13-3/8" 68# L-80 x BTC -M 2,118' MD / 2,003' TVD Circ out to — 150-200' 7" x 9-5/8" annulus Cement in 9-5/8" 40# L-80 TXP-HS / TXP I TOC - 10,04T MD 7 @ H563 11,683' MD 10,316' MD / 7,244' TVD ........... 7" 26# L-80 Liner Tenaris Blue 11,833' MD / 7,982' TVD 600' Cement plug 17 ppg Class G Cement 11,587' —12,187' MD — 30% Excess 500' Cement plug 15.8 ppg Class G Cement 12,187' —12,687' MD — 30% Excess Bottom of 6" hole 12,687' MD / 8057' TVD STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Reviewed R—i 9 J P.I. Suprv�6� I'^tI6 DOPE Test Report for: GMTU MT 6-06 Comm Contractor/Rig No.: Doyon 19 PTD#: 2180930 DATE: 9/14/2018 - Inspector Austin McLeod Insp Source Operator: CONOCOPHILLIPS ALASKA, INC. Operator Rep: Dorr/Guzman Rig Rep: Torres/Williams Inspector Type Operation: DRILL Sundry No: Type Test: MIT Rams: 250/5000' Test Pressures: Annular: Valves: 250/2500 ' 250/5000 TEST DATA MISC. INSPECTIONS: MUD SYSTEM: P/F P/F 1 Visual Alarm Location Gen.: P Trip Tank P P - Housekeeping: P _ Pit Level Indicators P P PTD On Location P Flow Indicator P P Standing Order Posted P Meth Gas Detector P P Well Sign P H2S Gas Detector P P Drl. Rig P MS Mise NA NA Hazard Sec. P P Kill Line Valves 2 Mise NA Check Valve 0 FLOOR SAFTY VALVES: BOPSTACK: Quantity Size MASP: 3015 ' Inspection No: bopSAM180915124,13 Related Insp No: ACCUMULATOR SYSTEM: Quantity P/F Upper Kelly 1 P_. Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA BOPSTACK: Quantity Size MASP: 3015 ' Inspection No: bopSAM180915124,13 Related Insp No: ACCUMULATOR SYSTEM: 0 Time/Pressure P/F System Pressure 2950 P Pressure After Closure 1450 P 200 PSI Attained 30 - P Full Pressure Attained 161 P P/F Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4(&2150 - P ACC Mise 0 NA Stripper 0 Quantity NA Annular Preventer 1_ 13_5/8" P #1 Rams 1 3-1/2"x6" P _ #2 Rams 1 Blinds P #3 Rams 1 3-1/2"x6" P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3-1/8" P . HCR Valves 2 3-1/8" P Kill Line Valves 2 3-1/8" P ' Check Valve 0 NA BOP Misc 0 NA CHOKE MANIFOLD: Quantity P/F No. Valves 14 P Manual Chokes 1 _ P Hydraulic Chokes 1 P_' CH Misc 0 NA INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity P/F Inside Reel Valves 0 NA Number of Failures: 0 ✓ Test Results Test Time 5 Remarks: Test conducted with 5' test joint. All tests against test plug. Initial post maintenance test to 5000psi on all components except Annular. High tests were 10min(BLM). Good test. THE STATE °f1-1 - - - GOVERNOR BILI. WALKER Graham Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Greater Mooses Tooth Field, Lookout Oil Pool, MT6-06 Alaska Oil and Gas Conservation Commission ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-093 Surface Location: 266' FNL, 3096' FEL, Sec 6, TION, R3E, UM Bottomhole Location: 4726' FNL, 3855' FEL, Sec. 6, TI ON, R3E, UM Dear Mr. Alvord: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the permit to drill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Hollis S. French Chair DATED this day of August, 2018. STATE OF ALASKA AL_ KA OIL AND GAS CONSERVATION COMM. ON PERMIT TO DRILL 20 AAc 25.On5 JUL 2 4 2018 1a. Type of Work:1 b. Proposed Well Class: Exploratory - Gas LJService - WAG El Service - Disp ❑ Y 1 c. Spec' w I p e for: Drill ❑� - Lateral ❑ Stratigraphic Test El Development - Oil ❑✓ - Service - Winj El Single Zone 9 Coalbed Gas Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service -Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q • Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. S S?��U & 16 /19 MT6-06 • 3. Address: 6. Proposed Depth: T $5 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 20725 . TVD: • 8073 Greater Mooses Tooth Unit Lookout Pool 4a. Location of Well (Govemmental Section): 7. Property Designation: Surface: 266' FNL, 3096' FEL, Sec. 6, T1 ON, R3E, UM AA081818, AA092346, AA081798, AA092342 • Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 2080' FNL, 2582' FEL, Sec. 36, T11N, R2E, UM 932553, 340760, 340763 932533 9/1/2018 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4726' FNL, 3855' FEL, Sec. 6, T1 ON, R3E, UM r 609 �Wq 2469 to Lookout 1 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): , 15. Distance to Nearest Well Open Surface: x. 317041 d y- 5945536 1 Zone- 4 GL / BF Elevation above MSL (ft): �,24� to Same Pool: n/a 16. Deviated wells: Kickoff depth: 319 feet 17. Maximum Potential Pressures in psig (see AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: 3810 • Surface: 3015 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling Length MD TVD MD TVD (including stage data) 42" 20" 94 H-40 Welded 80 34 34 115 115 10 yds 16" 13.375" 68 L-80 BTC -M 2081 34 34 2115 2006 985 sx 11.0 PP9 DeepCmte,331 sx 15.8 ppg G 12.25" 9.625" 40 L-80 BTC -M 10346 34 34 10380 7278 95 sx 12.2 ppg Lead, 205 sx 15.8 ppg tail 8.75" 7.0" ,C }:" 26 L-80 Blue 11916 34 34 11950 8011 42 sx 12.2 ppg Lead, 184 sx 15.8 ppg tail 6" 4.5" 12.6 L-80 TXP 8950 11750 7954 20700 8073 uncemented pert pup liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes❑ No `$ 20. Attachments: Property Plat ❑ Sketch Dive OP ter Sketch Shallow Hazard A alysis 8 D . ring Program mSeabed Report e Dril ngeFluid Prog atm e 20 AAC 25.050 requi ementse 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: Andrew Beat Authorized Name: Graham Alvord (265-6120) Contact Email: AndreW.T.Beat COP.Com Authorized Title: Drilling Manager Contact Phone: 907-265-6341 H/2 7 `/ Authorized Signatu �,(•, r4L MORD Date: /lzen Commission Use Only Permit to Drill mber: API NZ3-2077-3-nn Permit Approval See cover letter for other Number: a.18 -� 3 50- Q3 - O� Date: (u requirements. Conditions of approval : If box is checked,well may not be used to explore for, test, or producecoalbed methane, gas hydrates, or gas contained in shales: Other: pf 3 5,00r. i9c) P 7' Samples req'd: Yes ❑ Noy' Mud log req'd: Yes❑ Noy HzS measures: Yes [-]No[V Directional svy req'd: Yes [VNo 11�,\\ ��)) LU "'"�A.Q N '- V a"4e r Spacing exception req'd: Yes ❑ No[V Inclination -only svy req'd: Yes ❑ No 11 r�y V .A -4c_ Z..j . C 3 1 i-�+� � Z 1 Post initial injection MIT mq'd: Yes F-1No LJ APPROVED BY 11� Approved by: COMMISSIONER THE COMMISSION Date: g (I I. Submit Form and "Kill Form 10-401 Revised 512017 J This permit Is valid for 24 f d oval per 20 AAC 25.005(8) Attachments in plicate ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 July 24th, 2018 Alaska Oil and Gas Conservation Commission 333 West 71s Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill MT6-06 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the MT6 drilling pad. The intended spud date for this well is September 1, 2018. It is intended that Doyon Rig 19 be used to drill the well. MT6-06 is planned to be a horizontal Alpine C sand producer. The 16" surface hole will TD above the C-30 sand and then 13- 3/8" casing will be set and cemented tc surface. The intermediate hole will be drilled in two sections to mitigate issues with shale instability over the long interval. The 12-1/4" intermediate #1 section will be drilled into the top of the HRZ. A 9-5/8" casing string will be set and cemented from TD to secure the shoe and cover 500' above any hydrocarbon -bearing zones. The second intermediate will be drilled with a 7" steerable liner drilling assembly, ultimately landing in the Alpine C sand. This assembly will consist of a 6" pilot BHA ahead of the casing shoe and incorporate a 8-3/4" underreamer for increased annular clearance. Managed Pressure Drilling technology will also be utilized to assist with providing stability through the ec_ HRZ, Kalubik, and Miluveach formations. The drilling assembly inner string will then be tripped and a cement assembly run into the hole to cement the 7" drilling liner annulus. The production interval will be comprised of a 6" horizontal hole that will be geo-steered in the Alpine C sand. The well will be completed as an unstimujated producer with 4.5" liner with pre -perforated pup joints and tied back to surface with a 4.5" tubing upper completion string. The well will be flowed back following drilling operations. It is requested that a variance of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. At MT6, there has not been a ? significant indication of shallow gas or gas hydrates through the surface hole interval. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a) 2. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 ACC 25.035 (d)(2) 6. Directional drilling / collision avoidance information as required by 20 ACC 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 layout as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser setup. If you have any questions or require further information, please contact Andrew Beat at 265-6341 (andrew.t.beat@conocophillips.com) or Chip Alvord at 265-6120. Sincerely, Andre eat Drilling Engineer cc: MT6-06 Well File / Ann Haggerty -Sherrod ATO 1530 Johnson Njoku ATO 1720 Chip Alvord ATO 1570 John Cookson ATO 1750 Applii for Permit to Drill, Well MTU MT6-06 Saved: 24 -Jul -18 Attachment 3 -Completion Schematic MT6-06. B1 Location Proposed Completion Schematic WPO5 20" 79PP f H-40 Insulated 1 Conductor t 80 feet, cemented to surface i 7■�"l I t 733!6" 68 ppf L-80 TXP Surface Casing @ 2115'M0120DM TWD Demented m surfr-e i i 1 '`L 1 1 1 4-V2" 126 ppf L-80 Tenaris Blue to 11,750'MD 7" 26 ppf L-80 Tenaris Blue?H563 Tie Back r 9 Sill" 40 ppf L-80 TXP (to 6390' ) I 95f8010.380 MD!75�) 279 TVD I Tubing I Liner Completion: 1) 4-4i" Landing Nipple (3.813" ID) 2) 4-K' x 1' GLM 3) 4-%'x 1' GLM 4) 434' x V GLM 5) Downhole Gauge 6) Liner Top Packer 7 Hanger w) Tia Back sleeve 7) 4-%' Landing Nipple {3.725' NoGo) sen at 74 deg 6) 4 14' TXP Blank Pipe 9) 4 W TXP Liner with Pert Pups 1 Yr L TOC at least 300' MD ' a O ✓, above Packer S 500' ;° L 4-V" 12.6k 480 Tenaris TXP MID above Alpine C. With Pert Pups Planned to Liner Top. • O O Top Alpine C - 0 o O O o 0 0 0 0 11.930'161D I S.DOO' TVD 7" 26 ppf L-80 Tenaris BluefflM tiler 6" Hole, TD at to 11,950' MD / 8,011' TVD @ 76 deg at 20,725' MD / 8,073' TVD Attachment 4 - Directional Plan MT6-05 ➢lily 2048 -ATB MT6-06 APD Page 17 of 15 Printed., 24 -Jul -18 Applic for Permit to Drill, Well MTU MT6-06 Saved: 24 -Jul -18 MT6-06 Application for Permit to Drill Document E Table of Contents 1. Well Name (Requirements of20 AAC 25.005 (9)............................................................ 3 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) ............................................ 3 Requirements of20 AAC 25.050(b)............................................................................................................. 3 3. Blowout Prevention Equipment Information (Requirements of 20AAC25.005(c)(3)) 3 4. Drilling Hazards Information (Requirements of20AAC25.005(c)(4))........................4 5. Procedure for Conducting Formation Integrity Tests (Requirements of20AAC25.005 (e)(5))......................................................................................................................... 5 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) .......... 5 7. Diverter System Information (Requirements of 20 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 of20 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 of 20 AAC 25.005 (c)(13)) .........................7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 9 (Requirements of 20 AAC 25.005(c)(14))............................................................................. 9 15. Attachments ................................... Attachment) Cement Summary .................... L .............................................. 10 ............. ................. I ............. I ..... ...... 10 MT6-O6 APD Page 1 of 15 Printed., 24 -Jul -18 Applic: for Permit to Drill, Well MTU MT6-06 Saved: 24 -Jul -18 Attachment Drilling Hazards Summary ................................................................................................. 10 Attachment 3 Completion Schematic........................................................................................................ 10 Attachment4 Directional Plan................................................................................................................ 10 MT6-O6 APD Page 2 of 15 Printed. 24 -Jul -18 AppliC . for Permit to Drill, Well MTU MT6-06 Saved: 24 -Jul -18 1. Well Name (Requirements of20 AAC 25.005 (fi) The well for which this application is submitted will be designated as MTU MT6-06 2. Location Summary (Requirements of20AAC25.005(c)(2)) Location at Surface 266' FNL, 3096' FEL, Sec. 6, T10N R3 'UM UM NAD 1927 Northings: 5,945,537 Eastings: 317,134 RKB Elevation AMSL q, Pad Elevation 52.2'AMSL Top of Productive Horizon eel 2081' FNL, 2582' FEL, Sec. 36, Tl lN, R2E UM NAD 1927 Northings: 5,949,111 Eastings: 312,718 MeasuredDe th, RKB: 11,930' Total Vertical De th, RKB: 8,006' Total Vertical De th, SS: 7,917' Total Depth Toe 4726' FNL, 3855' FEL, Sec. 6, T10N, ME, UM NAD 1927 Northings: 5,941,096 Eastings: 316,285 Measured Depth, RKB71 20,725' Total Vertical De th, RKB: 8,073' Total Vertical Depth, SS: 7,984' Requirements of20AAC25.050(b) Please see Attachment 4: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of20AAC25.005(c)(3)) Please reference BOP and diverter schematics on file for Doyon 19. MT6-06 APD Page 3 of 15 Printed. 24 -Jul -18 Applic( for Permit to Drill, Well MTU MT6-06 Saved: 24 -Jul -18 4. Drilling Hazards Information (Requirements of 20AAC25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling o/ffthis well: �t 1 f - - Casing Size in Csg Setting Depth AMMIM ft Fracture Gradient Pore press re si ASP Drilling (psi) 20 115 / 115 10.9 52 54 13.375 2115/2000 14.5 910 o,g 1308 9.625 10380/7279 13.5 3176 a, 3009 7 11950/8011 12.5 3810 ,y 2966 4.5 20725/8073 12.5 3773 N/A PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) 4 A'I 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: 1) ASP= [(FGx0.052)-O.1JD Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in Ib/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.IxD) Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD 1. ASP CALCULATIONS Drilling below conductor casing (2011) ASP = [(FG x 0.052) - 0.1] D = [(10.9x0.052)-0.1] x 115=54 psi OR ASP= FPP - (0.1 x D) = 910 - (0.1 x 2000) = 710 psi 2. Drilling below surface casing (13-3/811) ASP = [(FG x 0.052) - 0.1 ] D = [(14.5 x 0.052) - 0.1] x 2000' = 1308 psi OR ASP = FPP-(0.1 x D) = 3176 - (0.1 x 7279') = 2929 psi Drilling below intermediate casing (9-5/8") ASP = [(FG x 0.052) - 0.11 D = [(13.5 x 0.052) - 0.1 ] x 7279 = 4382 psi OR ASP= FPP-(0.1 x D) = 3810- (O.1 x 801 I') = 3009 psi MT6-O6 APD Page 4 of 15 Printed.24-Jul-18 4. Drilling below production liner (7) MI ASP = [(FG x 0.052) — 0.1] D = [(12.5 x 0.052) — 0.1 ] x 8011 = 4406 psi ASP = FPP — (0.1 x D) = 3773 — (0.1 x 8073) = 2966 psi Applid for Permit to Drill, Well MTU MT6-06 Saved: 24 -Jul -18 (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 gen pressured strata, lost circulation zones, and zones that have a propensityfor differential sticking; Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests (Requirements q(20AAC25.005 (c)(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)) Pv4� Casing and Cementin Program Csy?bg OD (in) Hole Srze Weight (IN Grade Conn. Length Top MDlrVD Btm MD/TVD Cement Program in (h) (re) (h) 20 42 79 H-40 Welded 80 Surf 115/115 Cemented to surface with 10 yds slurry Cement to Surface with 13-3/8 16 68 L-80 BTC 2,079 Surf 2,115 / 2,000 966 sx DeepCrete Lead at 11.0 ppg, • 331 sx Class G Tail Slurry at 15.8 ppg 9-5/8 12-1/4 40 L-80/ TN80 H563/ 10,304 Surf 10,380 / 7,279 95 sx Class G Lead at 12.2 ppg HS TXP 205 sx Class G Tail at 15.8 ppg 7 6 x 8- 26 L-80 BTC/ 11,914 i ^• t"'i"^ 11,950 / 8,011 42 sx Class G Lead at 12.2 ppg 3/4 Blue ,c 65urf 99 sx Class G Tail at 15.8 ppg 4-1/2 n/a 12.6 L-80 563 12,316 Surf 12,350 / 7,850 4 1/2 6 12.6 L-80 TXP 8,950 11,750 / 7,954 20,700 / 81073 Uncemeneted open hole liner w/ pre - perforated pup joints 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) It is requested that a variance of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. At MT6, there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. — MT6-O6 APD Page 5 of 15 Printed: 24 -Jul -18 Applic4 or Permit to Drill, Well MTU MT6-06 Saved: 24 -Jul -18 8. Drilling Fluid Program (Requirements of20AAC25.005(c)(8)) Surface Hole: T A mixed -metal oxide fresh water drilling fluid (Drilplex) will be used for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight <10.0 ppg by use of solids control system and dilutions where necessary. Intermediate #1: Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight from 9.4-10.0 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Intermediate 92: Fresh water polymer mud system. Ensure good hole cleaning by maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the reservoir is penetrated. Ensure adequate LCM material is available Q s on location and in the field to address any expected losses. Maintain mud weight from 10.0-11.0 ppg. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in -'*maintaining wellbore stability. The mud will be weighted up to 10.3 ppg or higher before pulling out of the hole. r� Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate 1� shale instability and cycling. Production Hole: The horizontal production interval will be drilled with an oil-based mud drill -in fluid VersaPro weighted.8-9.5 1 ppg with calcium carbonate. Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. MT6-O6 APD Page 6 of 15 Printed: 24 -Jul -18 Surface Intermediate Intermediate production #1 #2 Hole Size in. 16 12.25 6.0 x 8.75 6.0 Casing Size in. 13.375 9.625 7 4.5 Density PPG 9.0-10.0 • 9.4-10.0 10.0-11.0 -8.8- PV CP 13 10 10 15 YP Ib./10ft2 35-50 20-28 20-28 15-20 Funnel Viscosity s/qt. 200 40-50 40-50 60-80 Initial Gels Ib./1000 50 30 10 10 10 Minute Ib./100 Gels ftz 60 15 20 15 API Fluid cc/30 Loss min. N.C. - 15.0 5.0 5.0 4.0 HPHT Fluid cc/30 n/a 8.0-12.0 8.0-12.0 10.0 Loss min. pH 1 11.0 9.5 - 10.0 9.5-10.0 9.0 Surface Hole: T A mixed -metal oxide fresh water drilling fluid (Drilplex) will be used for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight <10.0 ppg by use of solids control system and dilutions where necessary. Intermediate #1: Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight from 9.4-10.0 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Intermediate 92: Fresh water polymer mud system. Ensure good hole cleaning by maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the reservoir is penetrated. Ensure adequate LCM material is available Q s on location and in the field to address any expected losses. Maintain mud weight from 10.0-11.0 ppg. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in -'*maintaining wellbore stability. The mud will be weighted up to 10.3 ppg or higher before pulling out of the hole. r� Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate 1� shale instability and cycling. Production Hole: The horizontal production interval will be drilled with an oil-based mud drill -in fluid VersaPro weighted.8-9.5 1 ppg with calcium carbonate. Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. MT6-O6 APD Page 6 of 15 Printed: 24 -Jul -18 Applici or Permit to Drill, Well MTU MT6-06 Saved: 24 -Jul -18 9. Abnormally Pressured Formation Information (Requirements gj20AAC25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20AAC25.005 (c)(/o)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis(Requirements of20AAC25.005(c)(1i)) N/A - Application is not for an offshore well. 12. Evidence of Bonding (Requirements of20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program(Requirements of20 AAC 25.005 (c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. I. MIRU Doyon 19 onto GMTU MT6-06 over pre-installed 20" insulated conductor. 2. Rig up and test riser, dewater cellar as needed. 3. Drill 16" hole to the surface casing point as per the directional plan. (LWD Program: GR). 4. Run and cement new 13-3/8" 68 ppf L-80 surface casing to surface. 5. Install BOPE with the following equipment/configuration: 13-5/8" annular preventer, 3-1/2" x 6" VBR, blind ram and 3-1/2" x 6" VBRs. 6. Test BOPE to 250 psi low/ 3500 psi high (24-48 hr. AOGCC notice, 72 Hr BLM notice). 7. Pickup and run in hole with 12-1/4" drilling BHA to drill intermediate #1. 8. Chart casing pressure test to 2500 psi for 30 minutes. 9. Drill out shoe track and 20' of new hole. 10. Perform LOT to maximum EMW of 18.0 ppg. Minimum LOT required to drill ahead is 12.5 ppg EMW. 1 fwl Forward data to the AOGCC. - -- 11. Displace well to 9.4 ppg LSND mud. 12. Drill 12-1/4" hole per directional plan. (LWD Program: GR/RES). 13. Circulate wellbore clean and POOH. 14. Change upper VBRs to 9-5/8" solid body rams. Test same to 250 psi low / 3,500 psi high. 15. Run 9-5/8" intermediate casing to TD. 16. Pump single stage cementjob to isolate the casing shoe or 500' MD or 250' TVD, whichever is larger, above uppermost hydro -carbon bearing zone. 17. Change upper 9-5/8" solid body rams to 4-1/2" x 7" VBRs. Test BOPE to 250/3500 psi. 18. Pick up and run in hole with 8-3/4" bit and clean out assembly. Perform a LOT down the 13-3/8" x 9 5/8" casing annulus with Ball mill qnd freeze protect. Forward data to AOGCC. ,t ;, 19. Pressure test casing to 3,>ao psi for 30 minutes and record results. 20. Drill out shoe track and 20' of new hole. MT6-O6 APD Page 7 of 15 Printed: 24 -Jul -18 MT6-O6 APD Page 8 of 15 Printed. 24 -Jul -18 i Applica or Permit to Drill, Well MTU MT6-06 Saved: 24 -Jul -18 21. Perform FIT to 14 ppg EMW. Minimum required to drill ahead is 12.012.0 pp 22. Circulate wellbore clean and POOH. 23. Pick up and run in hole with the 7" steerable drilling liner. Pick up and stab in 6" pilot BHA assembly. (LWD Program: GR/RES). 24. RIH to bottom with 7" SDL on 5" drill pipe. 25. Drill 6" x 8-3/4" SDL hole to production casing point into the Alpine C sand using Managed Pressure Drilling to maintain constant bottom hole pressure on connections. (LWD Program: GR/RES/Neu. Dens.). 26. Land 7" liner at TD. Disconnect SDL and POOH to surface with inner string and pilot. 27. Run in hole with inner string cementing BHA. Stab into li er. Circulate and condition mud in preparations for cementing. 6 r��� 28. Cement 7" liner. Set liner top packer. Circulate excess cement from top of liner. POOH laying down 5" drill pipe. 29. Run 7" tie -back and engage seals. Space out to land hanger. � / ; 0 30. Displace 9-5/8" x 7" annulus to corrosion inhibited brine and diesel freeze protect. Land the 7" tie back hanger lit and pressure test annulus and seals to 2min and chart. 31. Pick up 4" DP. Test BOPE to 250 psi low / 3,500 psi high. 32. Pick up and RIH with 6" drilling assembly. (LWD Program: GR/Azimuthal RES/Neu. Dens). 33. Chart casing pressure test to 3500 psi for 30 minutes and record results. 't Gk S+ 4_3 34. Drill out and perform FIT t� Minimum acceptable leak -off for drilling ahead is I l.b ppg EMW. //6t U1 35. Drill 6" horizontal hole to section TD 36. Circulate the hole clean and POOH with drilling BHA. 37. Run in hole with 4.5" liner with pre -perforated pup joints on 4" drill pipe. 38. Set liner top packer and release from liner. 39. Displace well to kill weight brine. 40. Run 4.5" upper completion. 41. Space out and land hanger. 42. Install HP back pressure valve and pressure test hanger seals to 5000 psi. Nipple down BOP. 43. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove back pressure valve. 44. Test tubing and tubing -casing annulus separately to 3000 psi / 30 mins. 45. Shear circulation valve in GLM. 46. Circulate tubing to diesel and install freeze protection in the annulus. 47. Set BPV and secure well. RDMO. MT6-O6 APD Page 8 of 15 Printed. 24 -Jul -18 Applict for Permit to Drill, Well MTU MT6-06 Saved: 24 -Jul -18 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of20AAC 25.005 (c)(/4)) Incidental fluids developed from drilling operations on well MT6-06 will be injected into a permitted surface casing .✓ x production casing annulus on CDI. The MT6-06 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 1200' TVD. Significant hydrocarbon zones include only the Alpine sand based on pre -drill interpretations. There will be 500' MD, or 250' TVD, whichever is greater, of cement placed above the top of the Alpine reservoir. Once MT6-06 has been drilled and completed, consideration may be given to permit this well for annular injection. ✓ An application for Sundry Operations form 10-403 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 USD W'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 (C40). 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) * (2,0001) + 1,500 psi = 2748 psi Pore Pressure = 910 psi Therefore Differential = 2748 —910 =1838 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 Grade Range Connection Collapse 85% of Burst 85% of (ppf) Type Collapse Burst 13-3/8" 68 L-80 3 BTC -M 2260 psi 1921 psi 5020 psi 4267 psi 9-5/8 40 L-80 3 BTC -M 3090 psi 2626 psi 5750 psi 4887 psi MT6-O6 APD Page 9 of 15 Printed: 24 -Jul -18 15. Attachments Attachment 1 Cement Summary Attachment 2 Drilling Hazards Summary Attachment 3 Completion Schematic Attachment 4 Directional Plan AppliC . for Permit to Drill, Well MTU MT6-06 Saved: 24 -Jul -18 MT6-O6 APD Page 10 of 15 Printed. 24 -Jul -18 Applic for Permit to Drill, Well MTU MT6-06 Saved: 24 -Jul -18 Attachment I — Cement Summary GMTU MT6-06 wpO5 PMPOSed Casing Cemertr a Scherrati: I Updated Jury 19, 23181 Ow. :MY .JorLo--rMIF IL................ ... w .... . ........ 122 lNEteNuau 1" M TMi cmPi G Wlmy� ftnm T.0 W r U.. 13. IW M r7,1 IV 1,' mm: ..] 2M......... 1£w'rym 1101! .............. eeeeoeoremrrvo ...........T me.... .......... 9'CbIn XON ;-W I . ". L --- MT6-06APD Page 11 of 15 Printed. 24 -Jul -18 Applical r Permit to Drill, Well MTU MT6-06 Saved: 24 -Jul -18 13-3/8" Surface Casing run to 2.115' MD 12,000' TVD. Cement from 2,115' MD to 1,615'(500' of tail) with Class G + Adds. @ 15.8 PPG, and from 1,615' to surface with 11.0 ppg DeepCrete. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (1,350' MD), zero excess in 20" conductor. Lead slurry from 1,615' MD to surface with DeepCrete @ 11.0 ppg Conductor (115'- 36) X 1.0190 ft'/ft X 1.0 (0% excess) = 81 ft' Permafrost to Conductor (1,100'-1151 X 0.4206 ft3/ft X 3.5 (250% excess) = 1,450 ft' Top of Tail to Permafrost (1,615'- 1,100) X 0.4206 ft3/ft X 1.5 (50% excess) =324W Total Volume = 81 + 1,450 + 324 = 1,855 ft' => 966 sx of 11.0 ppg DeepCrete @ 1.92 ft3 /sk Shoe Joint Tail slurry from 2,115' MD to 1,615' MD with 15.8 ppg Class G + additives Shoe to Top of Tail (2,115'-1,6151 X 0.4206 ft3/ft X 1.50 (50% excess) = 316 ft' Shoe Joint (80) X 0.8407 ft3/ft X 1.0 (0% excess) = 68 ft' Total Volume = 316 + 68 = 384 ft' => 331 sx of 15.8 ppg Class G + additives @ 1.16 ft3/sk 9-5/8" Intermediate casing to 10.380' MD / 7.278' TVD Cement 1000' up from 9-5/8" casing shoe from 10,380' MD to 9,380' MD. Assume 40% excess annular volume. Lead slurry from 9,880' MD to 9,380' MD with 12.2 ppg Class G + additives Top of Tail to Top of Cement (9,880'-9,380) X 0.3132 ft3/ft X 1.40 (40% excess) = 219 ft3 Total Volume = 219 ft3 => 94.9 sx of 12.2 ppg Class G + additives @ 2.31 ft3/sk Tail slurry from 10,380' MD to 9,880' MD with 15.8 ppg Class G + additives Shoe to Top of Tail (10,380'- 9,880) X 0.3132 ft3/ft X 1.30 (30% excess) =204W Shoe Joint (80) X 0.4257 ft3/ft X 1.0 (0% excess) = 34 ft' Total Volume = 204 + 34 = 238 ft3 => 205 sx of 15.8 ppg Class G + additives @ 1.16 ft3/sk MT6-06 APD Page 12 of 15 Printed.. 24 -Jul -18 V Applicl for Permit to Drill, Well MTU MT6-06 Saved: 24 -Jul -18 7" Intermediate liner run to 11950' MD / 8,011' TVD Top of slurry is designed to be —1500' up from the 7" liner shoe. Assume 30% excess annular volume. 6" x 8- 3/4" underreamer to be 100ft behind the drill bit. Lead slurry from 10,950' MD to 10,450' MD with 12.2 ppg Class G + additives Top of Tail to Top of Cement (10,950' — 10,450) X 0.1503 ft3/ft X 1.30 (30% excess) = 98 ft3 Total Volume = 98 ft3 => 42 sx of 12.2 ppg Class G + additives @ 2.31 ft3/sk (80) X 0.2148 ft3/ft X 1.0 (0% excess) = 17 ft3 Tail slurry from 11,950' MD to 10,950' MD with 15.8 ppg Class G + additives 8-3/4" Hole to Top of Tail (11,950'— 10,950) X 0.1503 ft3/ft X 1.30 (30% excess) = 196 ft3 Shoe Joint (80) X 0.2148 ft3/ft X 1.0 (0% excess) = 17 ft3 Total Volume = 98 + 17 = 213 ft3 => 184 sx of 15.8 ppg Class G + additives @ 1.16 ft3/sk MT6-06 APD Page 13 of 15 Printed.. 24 -Jul -18 Applica ,r Permit to Drill, Well MTU MT6-06 Saved: 24 -Jul -18 Attachment 2 — Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 16" Hole / 13-3/8" Casina Tnterval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low First well on Pad, traveling cylinder diagrams Gas Hydrates Low If observed — control drill, reduce pump rates and Hole swabbing on trips Medium circulating time reduce mud temperatures Clay Balling Medium Maintain planned mud parameters and flow rates, liner Increase mud weight, use weighted sweeps, Abnormal Pressure in Low reduce fluid viscosity, control ROP Abnormal Pressure in Low Diverter drills, increased mud weight. Shallow Surface Formations material hazard study noted minimal risk Lost Circulation Medium Reduce pump rates, mud rheology, add lost proper hole filling, pump out of hole, real time ECD circulation material, use of low density cement monitoring,Liner will be in place at TD slurries port collar, control pipe running seeds 12-1/4" Hnle / 9-5/R" Cacinn Tntarval Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time High -Strategy MPD for shale stability, Steerable Drilling Liner, ECD monitoring, mud rheology, add lost circulation Increase mud weight, control ROP, connection and material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, circulating density (ECD) monitoring, run casing as proper hole filling, pump out of hole, real time ECD liner monitorinq, MPD stripping ractices Abnormal Pressure in Low Well control drills, check for flow during Overburden Formations ECD monitoring, mud rheology, add lost circulation connections, increase mud weight. Shallow hazard material study noted minimal risk Hole Cleaning Low Monitor ECD and torque/drag trends, control drill proper hole filling, pump out of hole, real time ECD and use best hole cleaning practices R" v 2_'A IA" 14n1a / 7" 1 inor _ f'=&inn Tni- rmiml Event Risk Level Mitigation Sloughing shale, Tight High -Strategy MPD for shale stability, Steerable Drilling Liner, hole Increase mud weight, control ROP, connection and trip speeds, sweeps, and real time equivalent circulating density (ECD) monitoring, run casing as liner Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring,Liner will be in place at TD Abnormal Reservoir Low Well control drills, check for flow during Pressure connections increase mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers MT6-O6 APD Page 14 of 15 Printed: 24Ju1-18 Applic, for Permit to Drill, Well MTU MT6-06 Saved: 24 -Jul -18 6" Hole / 4-1/2" Pre -Perforated Liner - Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring Abnormal Reservoir Low Well control drills, check for flow during Pressure connections increased mud weight Differential Sticking Low Uniform reservoir pressure along lateral, keep pipe moving, control mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers MT6-06 APD Page 15 of 15 Printed.24-Jul-18 Applid for Permit to Drill, Well MTU MT6-06 Saved: 24 -Jul -18 Well Proximitv Risks MT6-06 will be the fourth well drilled on the pad. 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. Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate section. Lower Shale Stability: HRZ/Kalubik/Miluveach in the pilot and intermediate #2 hole sections will require higher mud weights than historically used to enhance wellbore stability. Steerable Drilling Liner and Managed Pressure Drilling will be used in conjunction with a 4 -string casing design to mitigate shale instability. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks MT6-O6 APD Page 16 of 15 Printed: 24 -Jul -18 ConocoPhillips Export Company Western North Slope GMT1 Lookout Pad MT6-06 MT6-06 Plan: MT6-06 wp05 Drilling Summary Report 23 July, 2018 Boo SER F�UGHES aGEcompany Baker HugheslNTEQ Drilling Summary Report Company: _ConocoPhillips Export Company Project: Western North Slope Site: GMTI Lookout Pad Well: MT6-06 Wellbore: MT6-06 Design: MT6-06 wp05 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: BAER ( HUGHES a Glicompany Well MT6-06 MT6-06 Plan RKB @ 89.40usft (Plan Doyonl9) . MT6-06 Plan RKB @ 89.40usft (Plan Doyon 19) i� True Minimum Curvature OAKEDMP2 Project Western North Slope, North Slope Alaska, United States Map System: Geo Datum: US State Plane 1927 (Exact solution) - NAD 1927 (NADCON CONUS) System Datum: Mean Sea Level Map Zone: Alaska Zone D4 Using geodetic scale factor Site GMTI Lookout Pad Site Position: From: Position Uncertainty: Map 0.00 usft Northing: Easting: Slot Radius: 5,945,571.14 usft 317,134.52 usft 0 " Latitude: Longitude: Grid Convergence: 70° 15'23.251 N 151° 28.40.782 W -1,39 ° Well MT6-06 Well Position Position Uncertainty +N/ -S 0.00 usft +El -W 0.00 usft 0.00 usft Northing: Easting: Wellhead Elevation: 5,945,536.92 usft 317,041.19 usft 0.00 usft Latitude: Longitude: Ground Level: Po Mato. 70" 15' 22.692 N 151'28'43.472 W r7 z usft . Wellbore MT6-06 iH- �.Z Magnelics Model Name Sample Date Declination Dlp Angle Field Strength (1) (1) (nT) BGGM2018 9/1/2017 16.96 80.72 57,431 Design MT6-06 wp05 Audit Notes: Version: Phase: PROTOTYPE Tie On Depth: 0.00 Vertical Section: Depth From (TVD) +NIS +E/ -W Direction (usft) (usft) (usft) (I 0.00 0.00 0.00 153.00 723/2018 11:33:22AM Page 2 COMPASS 5000.14 Build 85 Baker HugheslNTEQ Drilling Summary Report BA ER F�UGHES aGEcompany Company: Export Company Project: _ConoccPhillips Westem North Slope Local Co-ordinate Reference: Well MT6-06 Site: 'GMT1 Lookout Pad TVD Reference: MT6-06 Plan RKB @ 89.40usft (Plan Doyont 9) Well: MT6-06 MD Reference: MTB -06 Plan RKB @ 89.40usft (Plan Doyonl9) Wellbore: MT6-O6 North Reference: True Description Survey Calculation Method: Minimum Curvature Design: -MT6-06 wp05 Database: OAKEDMP2 Survey Tool Program Date 7/18/2018 From To (usft) (usft) Survey (Wellbore) Tool Name Description 0.00 1,000.00 MT6-D6 wp05 (MT6-06) GYD-GC-SS Gyrodata gyro single shots 1,000.00 2,114.00 MT6-06 wp05(MT6-06) MWD MWD -Standard 1,000.00 2,114.00 MT6-06 wp05(MT6-06) MWD-IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,114.00 10,833.00 MT6-O6 wp05(MT6-O6) MWD MWD - Standard 2,114.00 10,833.00 MT6-06 wp05(MT6-06) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10,833.00 12,650.00 MTB -06 wp05(MT6-O6) MWD MWD -Standard 10,833.00 12,650.00 MT6-06 wp05 (MT6-06) MWD-IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12,650.00 20,725.76 MT6-06 wp05(MT6-06) MWD MWD -Standard 12,650.00 20,725.76 MT6-06 wp05(MT6-O6) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Eesting (usft) (°) V) (usft) (usft) (°/100usft) 0 (usft) (usft) (usft) 0.00 0.00 0.00 0.00 -89.40 0.00 O.OD 0.00 5,945,536.92 317,041.19 100.00 0.00 0.00 100.00 10.60 0.00 0.00 0.00 5,945,536.92 317,041.19 200.00 O.OD 0.00 200.00 110.60 0.00 0.00 0.00 5,945,536.92 317,041.19 300.00 0.00 0.00 300.00 210.60 0.00 0.00 0.00 5,945,536.92 317,041.19 319.40 0.00 0.00 319.40 230.00 0.00 0.00 0.00 5,945,536.92 317,041.19 Start Build 2.00 400.00 1.61 315.00 399.99 310.59 2.00 .315.00 -1.08 5,945,537.74 317,040.41 500.00 3.61 315.00 499.88 410.48 2.00 0.00 -5.41 5,945,541.04 317,037.27 600.00 5.61 315.00 599.55 510.15 2.00 0.00 -13.06 5,945,546.86 317,031.72 700.00 7.61 315.00 696.88 609.48 2.00 0.00 -24.01 5,D45,555.20 317,023.78 800.00 9.61 315.00 797.75 708.35 2.00 0.00 -38.25 5,945,566.04 317,013.45 900.00 11.61 315.00 896.03 806.63 2.00 0.00 -55.76 5,945,579.37 317,000.75 1,000.00 13.61 315.00 993.62 904.22 2.00 0.00 -76.53 5,945,595.18 316,985.70 1,100.00 15.61 315.00 1,0D0.38 1,000.98 2.00 0.00 -100.52 5,945,613.45 316,968.30 1,200.00 17.61 315.00 1,186.20 1,096.80 2.00 0.00 -127.71 5,945,634.14 316,948.58 1,300.00 19.61 315.00 1,280.96 1,191.56 2.00 0.00 -158.06 5,945,657.25 316,926.57 712312018 11:33:22AM Page 3 COMPASS 5000.14 Build 85 Baker HugheslNTEQ Drilling Summary Report BA ER I IGHIES BAT GEcompany Company: _ConocoPhillips Export Company Local Co-ordinate Reference: Well MT6-06 Project: Western North Slope Site: GMT1 Lookout Pad TVD Reference: MT6-06 Plan RKB @ 89.40usft (Plan Doyon19) Well: MT6-06 MD Reference: MT6-06 Plan RKB @ 89.40usft (Plan Doyon19) Wellbore: MT6-06 North Reference: True (usft) V) Survey Calculation Method: Minimum Curvature Design: MT6-06 wp05 Database: OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easting (usft) V) (°) (usft) (usft) (°I100usft) (°) (usft) (usft) (usft) 1,400.00 21.61 315.00 1,374.56 1,285.16 2.00 0.00 -191.54 5,945,682.74 316,902.29 1,500.00 23.61 315.00 1,466.87 1,377.47 2.00 0.00 -228.10 5,945,710.57 316,875.78 1,600.00 25.61 315.00 1,557.78 1,468.38 2.00 0.00 -267.71 5,945,740.73 316,847.06 1,700.00 27.61 315.00 1,647.18 1,557.78 2.00 0.00 -310.31 5,945,773.16 316,816.16 1,800.00 29.61 315.00 1,734.96 1,645.56 2.00 0.00 -355.85 5,945,807.83 316,783.14 1,900.00 31.61 315.00 1,821.02 1,731.62 2.00 0.00 -404.28 5,945,844.70 316,748.02 2,000.00 33.61 315.00 1,905.25 1,815.85 2.00 0.00 -455.53 5,945,883.71 316,710.85 2,100.00 35.61 315.00 1,987.55 1,898.15 2.00 0.00 -509.55 5,945,924.84 316,671.68 2,115.35 35.92 315.00 2,000.00 1,910.60 2.00 0.00 -518.08 5,945,931.33 316,665.49 Start 100.00 hold at 2116.36 MD -13.3/8" x 16" 2,200.00 35.92 315.00 2,068.56 1,979.16 0.00 0.00 -565.31 5,945,967.29 316,631.24 2,215.35 35.92 315.00 2,080.98 1,991.58 0.00 0.00 -573.88 5,945,973.81 316,625.03 Start Build 2.00 2,300.00 37.61 315.00 2,148.80 2,059.40 2.00 0.00 -622.06 5,946,010.49 316,590.09 2,400.00 39.61 315.00 2,226.93 2,137.53 2.00 0.00 -681.41 5,946,055.67 316,547.05 2,500.00 41.61 315.00 2,302.84 2,213.44 2.00 0.00 -743.32 5,946,102.80 316,502.16 2,600.00 43.61 315.00 2,376.43 2,287.03 2.00 0.00 -807.70 5,946,151.82 316,455.47 2,604.93 43.71 315.00 2,380.00 2,290.60 2.00 0.00 -810.94 5,946,154.28 316,453.12 Start 1000.00 hold at 2604.93 MD 2,700.00 43.71 315.00 2,448.72 2,359.32 0.00 0.00 -873.42 5,946,201.84 316,407.81 2,800.00 43.71 315.00 2,521.00 2,431.60 0.00 0.00 -939.14 5,946,251.88 316,360.16 2,900.OD 43.71 315.00 2,593.29 2,503.89 0.00 0.00 -1,004.86 5,946,301.91 316,312.50 3,000.00 43.71 315.00 2,665.57 2,576.17 0.00 0.00 -1,070.58 5,946,351.94 316,264.84 3,100.00 43.71 315.00 2,737.86 2,648.46 0.00 0.00 -1,136.30 5,946,401.97 316,217.18 3,200.00 43.71 315.00 2,810.14 2,720.74 0.00 0.00 -1,202.02 5,946,452.00 316,169.52 3,300.00 43.71 315.00 2,882.42 2,793.02 0.00 0.00 -1,267.73 5,946,502.03 316,121.87 3,400.00 43.71 315.00 2,954.71 2,865.31 0.00 0.00 -1,333.45 5,946,552.07 316,074.21 3,500.00 43.71 315.D0 3,026.99 2,937.59 0.00 0.00 -1,399.17 5,946,602.10 316,026.55 7/23/2018 11:33.22AM Page 4 COMPASS 5000.14 Build 85 Baker Hughes INTEQ Drilling Summary Report BA ER BAT a GEcompany Company: _ConocoPhillips Export Company Local Coordmate Reference: Well MT6-06 Project: Western North Slope TVD Reference: MTB -06 Plan RKB @ 89.40usft (Plan Doyon19) Site: GMT1 Lookout Pad MD Reference: MT6-06 Plan RKB @ 89.40usft (Plan Doyon19) Well: MT6-06 North Reference: True Wellborn: MT6-06 Survey Calculation Method: Minimum Curvature Design: MT6-06 wp05 Database: OAKEDMP2 Planned Survey MD Inc AN (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easting (usft) (°) (°) (usft) (usft) (°7100usft) (°) (usft) (usft) (usft) 3,600.00 43.71 315.00 3,099.28 3,009.88 0.00 0.00 -1464.89 5,946,652.13 315,978.89 3,604.93 43.71 315.00 3,102.84 3,013.44 0.00 0.00 -1,468.13 5,946,654.60 315,976.54 Start DLS 3.00 TFO 55.00 3,700.00 45.39 318.28 3,170.59 3,081.19 3.00 55.00 -1,532.12 5,946,704.19 315,931.98 3,800.00 47.26 321.53 3,239.65 3,150.25 3.00 52.66 -1,602.55 5,946,760.63 315,886.80 3,900.00 49.21 324.58 3,306.26 3,216.86 3.00 50.42 -1,676.01 5,946,821.32 315,843.46 4,000.00 51.24 327.46 3,370.24 3,280.84 3.00 48.38 -1,752.29 5,946,886.07 315,802.11 4,100.00 53.34 330.17 3,431.41 3,342.01 3.00 46.54 -1,831.17 5,946,954.72 315,762.83 4,200.00 55.49 332.74 3,489.61 3,400.21 3.00 44.88 -1,912.45 5,947,027.08 315,725.76 4,300.00 57.70 335.18 3,544.67 3,455.27 3.00 43.39 -1,995.90 5,947,102.95 315,690.97 4,304.93 57.81 335.30 3,547.30 3,457.90 3.00 42.04 -2,ODO.07 5,947,106.77 315,689.32 Start 3700.00 hold at 4304.93 MD 4,400.00 57.81 335.30 3,597.95 3,508.55 0.00 0.00 -2,080.46 5,947,180.65 315,657.48 4,500.00 57.81 335.30 3,651.23 3,561.83 0.00 0.00 -2,165.01 5,947,258.37 315,624.00 4,600.00 57.81 335.30 3,704.51 3,615.11 0.00 0.00 -2,249.57 5,947,336.08 315,59D.51 4,700.00 57.81 335.30 3,757.79 3,668.39 0.00 0.00 -2,334.13 5,947,413.79 315,557.03 4,800.00 57.81 335.30 3,811.06 3,721.66 0.00 0.00 -2,418.68 5,947,491.50 315,523.54 4,900.00 57.81 335.30 3,864.34 3,774.94 0.00 0.00 -2,503.24 5,947,569.21 315,490.06 5,000.00 57.81 335.30 3,917.62 3,828.22 0.00 0.00 -2,587.80 5,947,646.93 315,456.57 5,100.00 57.81 335.30 3,970.90 3,881.50 0.00 0.00 -2,672.35 5,947,724.64 315,423.09 5,200.00 57.81 335.30 4,D24.18 3,934.78 0.00 0.00 -2,756.91 5,947,802.35 315,389.60 5,300.00 57.81 335.30 4,077.46 3,988.06 0.00 0.00 -2,841.47 5,947,880.06 315,356.12 5,400.00 57.81 335.30 4,130.74 4,041.34 0.00 0.00 -2,926.02 5,947,957.78 315,322.63 5,500.00 57.81 335.30 4,184.02 4,094.62 0.00 0.00 -3,010.58 5,948,035.49 315,289.14 5,600.00 57.81 335.30 4,237.30 4,147.90 0.00 0.00 -3,095.14 5,948,113.20 315,255.66 5,700.00 57.81 335.30 4,290.57 4,201.17 0.00 0.00 -3,179.69 5,948,190.91 315,222.17 5,800.00 57.81 335.30 4,343.85 4,254.45 0.00 0.00 -3,264.25 5,948,268.63 315,188.69 712312016 11:33:22AM Page 5 COMPASS 5000.14 Build 65 Baker HugheslNTEQ Drilling Summary Report BA ER I UGHES a GEcomp w Company: _ConowPhillips Export Company Local Co-ordinate Reference: Well MTB -06 Project: Western North Slope TVD Reference: MT6-06 Plan RKB @ 89.40usft (Plan Doyon19) Site: GMT1 Lookout Pad MD Reference: MT6-06 Plan RKB @ 89.40usft (Plan Doyon19) Well: MTB -06 North Reference: True Wellbore: MT6-06 Survey Calculation Method: Minimum Curvature Design: MT6-06 wp05 Database: OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easting (usft) (°) V) (usft) (usft) (°/100usft) (°) (usft) (usft) (usft) 5,900.00 57.81 335.30 4,397.13 4,307.73 0.00 0.00 -3,348.81 5,948,346.34 315,155.20 6,000.00 57.81 335.30 4,450.41 4,361.01 0.00 0.00 -3,433.37 5,948,424.05 315,121.72 6,100.00 57.81 335.30 4,5D3.69 4,414.29 0.00 0.00 -3,517.92 5,948,501.76 315,088.23 6,200.00 57.81 335.30 4,556.97 4,467.57 0.00 0.00 -3,602.48 5,948,579.47 315,054.75 6,300.00 57.81 335.30 4,610.25 4,520.85 0.00 0.00 -3,687.04 5,948,657.19 315,021.26 6,400.00 57.81 335.30 4,663.53 4,574.13 0.00 0.00 -3,771.59 5,948,734.90 314,987.78 6,500.00 57.81 335.30 4,716.81 4,627.41 0.00 0.00 -3,856.15 5,948,812.61 314,954.29 6,600.00 57.81 335.30 4,770.09 4,680.69 0.00 0.00 -3,940.71 5,948,890.32 314,920.81 6,700.00 57.81 335.30 4,823.36 4,733.96 0.00 0.00 -4,025.26 5,948,968.04 314,887.32 6,800.00 57.81 335.30 4.876.64 4,787.24 0.00 0.00 4,109.82 5,949,045.75 314,853.83 6,900.00 57.81 335.30 4,929.92 4,840.52 0.00 0.00 -4,194.38 5,949,123.46 314,820.35 7,000.00 57.81 335.30 4,983.20 4,893.80 0.00 0.00 -4,278.93 5,949,201.17 314,786.86 7,100.00 57.81 335.30 5,036.48 4,947.08 0.00 0.00 -4,363.49 5,949,278.88 314,753.38 7,200.00 57.81 335.30 5,089.76 5,000.36 0.00 0.00 -4,448.05 5,949,356.60 314,719.89 7,300.00 57.81 335.30 5,143.04 5,053.64 0.00 O.OD 4,532.60 5,949,434.31 314,686.41 7,400.00 57.81 335.30 5,196.32 5,106.92 0.00 0.00 4,617.16 5,949,512.02 314,652.92 7,500.00 57.81 335.30 5,249.60 5,160.20 0.00 0.00 -4,701.72 5,949,589.73 314,619.44 7,600.00 57.81 335.30 5,302.87 5,213.47 0.00 0.00 -4,786.27 5,949,667.45 314,585.95 7,700.00 57.81 335.30 5,356.15 5,266.75 0.00 0.00 4,870.83 5,949,745.16 314,552.47 7,800.00 57.81 335.30 5,409.43 5,320.03 0.00 0.00 -4,955.39 5,949,822.87 314,518.98 7,900.00 57.81 335.30 5,462.71 5,373.31 0.00 0.00 -5,039.94 5,949,900.58 314,485.50 8,000.00 57.81 335.30 5,515.99 5,426.59 0.00 0.00 -5,124.50 5,949,976.29 314,452.01 8,004.93 57.81 335.30 5,518.62 5,429.22 0.00 0.00 -5,128.67 5,949,982.13 314,450.36 Start DLS 3.50 TFO -137.20 8,100.00 55.39 332.55 5,570.95 5,481.55 3.50 -137.20 5,208.01 5,950,054.23 314,417.25 8,200.00 52.93 329.49 5,629.51 5,540.11 3.50 -135.69 -5,289.01 5,950,126.07 314,379.75 8,300.00 50.54 326.22 5,691.45 5,602.05 3.50 -133.90 -5,367.18 5,950,193.54 314,339.64 7/23!2018 11:33:22AM Page 6 COMPASS 5000.14 Build 85 Planned Survey Baker HugheslNTEQ BAER Drilling Summary Report UGHES Azi (azimuth) TVD TVDSS a 6Ecompany Company: Export Company Northing Easting Project: _ConocoPhillips Western North Slope Local Co-ordinate Reference: Well MT6-06 Site: GMT1 Lookout Pad TVD Reference: MT6-06 Plan RKB ® 89.40usft (Plan Doyonl9) Well: MT6-06 MD Reference: MT6-06 Plan RKB 0 89.40usft (Plan Doyonl9) Wellbore: MT6-06 North Reference: True -131.87 -5,442.25 Survey Calculation Method: Minimum Curvature Design: MT6-06 wp05 Database: OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easting (usft) V) (°) (usft) (usft) (°/100usft) (°) (usft) (usft) (usft) 8,400.00 48.26 322.73 5,756.53 5,667.13 3.50 -131.87 -5,442.25 5,950,256.39 314,297.09 8,500.00 46.09 318.98 5,824.51 5,735.11 3.50 -129.60 -5,513.94 5,950,314.38 314,252.24 8,600.00 44.05 314.97 5,895.15 5,805.75 3.50 -127.05 -5,581.96 5,950,367.29 314,205.27 8,700.00 42.16 310.65 5,968.16 5,878.78 3.50 -124.22 -5,646.07 5,950,414.93 314,156.34 6,800.00 40.44 306.03 6,043.32 5,953.92 3.50 -121.06 -5,706.04 5,950,457.13 314,105.65 8,900.00 38.93 301.09 6,120.29 6,030.89 3.50 -117.59 -5,761.63 5,950,493.72 314,053.37 9,000.01) 37.63 295.84 6,198.81 6,109.41 3.50 -113.79 -5,812.64 5,950,524.57 313,999.72 9,100.00 36.58 290.30 6,278.59 6,189.19 3.50 -109.66 -5,858.88 5,950,549.56 313,944.87 9,200.00 35.79 284.52 6,359.32 6,269.92 3.50 -105.25 -5,900.18 5,950,566.59 313,689.05 9,300.00 35.30 278.56 6,440.71 6,351.31 3.50 -100.58 -5,936.38 5,950,581.61 313,832.46 9,400.00 35.10 272.50 6,522.46 6,433.06 3.50 -95.73 -5,967.35 5,950,588.56 313,775.31 9,500.00 35.20 266.42 6,604.24 6,514.84 3.50 -90.77 -5,992.97 5,950,589.41 313,717.81 9,600.00 35.61 260.42 6,685.78 6,596.36 3.50 -85.80 -6,013.15 5,950,584.16 313,660.17 9,700.00 36.31 254.57 6,766.75 6,677.35 3.50 -80.91 -6,027.81 5,950,572.83 313,602.62 9,800.00 37.28 248.96 6,846.85 6,757.45 3.50 -76.18 -6,036.89 5,950,555.46 313,545.37 9,900.00 38.50 243.61 6,925.79 6,836.39 3.50 -71.68 -6,040.37 5,950,532.12 313,488.63 10,000.00 39.95 236.58 7,003.28 6,913.88 3.50 -67.46 5,038.23 5,950,502.89 313,432.61 10,100.00 41.61 233.86 7,079.02 6,989.62 3.50 -63.55 -6,030.47 5,950,467.89 313,377.52 10,200.00 43.45 229.45 7,152.73 7,063.33 3.50 -59.98 -6,017.13 5,950,427.24 313,323.57 10,300.00 45.44 225.34 7,224.13 7,134.73 3.50 -56.73 -5,998.26 5,950,381.10 313,270.95 10,340.53 46.29 223.76 7,252.36 7,162.96 3.50 -53.79 -5,989.05 5,950,360.87 313,250.D5 HRZ 10,380.00 47.14 222.26 7,279.42 7,190.02 3.50 -52.69 -5,979.23 5,950,340.34 313,229.96 9.6/8" z 12.1/4" 10,400.00 47.57 221.51 7,292.97 7,203.57 3.50 -51.66 -5,973.93 5,950,329.63 313,219.87 10,500.00 49.82 217.94 7,358.98 7,269.58 3.50 -51.16 5,944.22 5,950,273.04 313,170.52 10,600.00 52.18 214.61 7,421.92 7,332.52 3.50 48.80 -5,909.25 5,950,211.52 313,123.07 7/232018 11:33:22AM Page 7 COMPASS 5000.14 Build 65 Baker HugheslNTEQ Drilling Summary Report BA ER I IGHES aGEcompany Company: _ConowPhillips Export Company Local Co-ordinate Reference: Well MT6-06 Project: Western North Slope TVD Reference: MT6-06 Plan RKB @ 89.40usft (Plan Doyonl9) Site: GMT1 Lookout Pad MD Reference: MT6-06 Plan RKB @ 89.40usft (Plan Doyonl9) Well: MT6-06 North Reference: True Wellbore: MT6-06 Survey Calculation Method: Minimum Curvature Design: MT6-06 wp05 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easting (usft) (1) (') (usft) (usft) ('1100usft) (°) (usft) (usft) (usft) 10,700.00 54.62 211.49 7,481.54 7,392.14 3.50 -46.70 -5,869.15 5,950,145.32 313,077.71 10,800.00 57.14 208.55 7,537.64 7,448.24 3.50 -44.64 -5,824.07 5,950,074.67 313,034.61 10,900.00 59.72 205.78 7,590.00 7,500.60 3.50 -43.19 -5,774.18 5,949,999.84 312,993.92 11,000.00 62.36 203.15 7,638.42 7,549.02 3.50 41.74 -5,719.66 5,949,921.11 312,955.80 11,042.68 63.50 202.06 7,657.85 7,568.45 3.50 -40.47 -5,695.02 5,949,886.39 312,940.35 11,043.06 63.50 202.06 7,658.01 7,568.61 0.00 0.00 -5,694.80 5,949,886.08 312,940.21 Start 372.32 hold at 11043.06 MD 11,100.00 63.50 202.06 7,683.42 7,594.02 0.00 0.00 -5,661.42 5,949,839.34 312,919.93 11,200.00 63.50 202.06 7,728.04 7,638.64 0.00 0.00 -5,602.78 5,949,757.25 312,884.31 11,300.00 63.50 202.06 7,772.66 7,683.26 0.00 0.00 -5,544.14 5,949,675.15 312,848.69 11,400.00 63.50 202.06 7,817.28 7,727.88 0.00 0.00 -5,485.50 5,949,593.06 312,813.07 11,414.78 63.50 202.06 7,823.86 7,734.48 0.00 0.00 -5,476.84 5,949,580.93 312,807.81 11,415.38 63.51 202.03 7,824.15 7,734.75 5.00 -67.10 -5,476.48 5,949,580.43 312,807.59 Start DLS 6.00 TFO -67.10 11,500.00 65.22 197.74 7,860.76 7,771.36 5.00 -67.08 -5,424.34 5,949,509.37 312,779.94 11,600.00 67.40 192.82 7,900.96 7,811.56 5.00 -65.22 -5,356.60 5,949,421.68 312,753.71 11,700.00 69.72 188.06 7,937.53 7,848.13 5.00 -63.25 -5,282.72 5,949,330.62 312,734.66 11,800.00 72.16 183.45 7,970.20 7,880.80 5.00 -61.51 -5,203.25 5,949,236.88 312,722.94 11,900.00 74.71 178.96 7,998.72 7,909.32 5.00 -60.00 -5,118.80 5,949,141.17 312,718.62 11,930.22 75.50 177.63 8,006.49 7,917.09 5.00 -58.72 -5,092.39 5,949,111.96 312,718.78 Alpine C 11,950.00 76.02 176.76 8,011.36 7,921.96 5.00 -58.37 -5,074.90 5,949,092.80 312,719.26 7" x 8-3/4" 12,000.00 77.35 174.58 8,022.87 7,933.47 5.00 -58.16 -5,030.01 5,949,044.21 312,721.75 12,100.00 80.06 170.29 8,042.47 7,953.07 5.00 -57.66 4,937.56 5,948,946.76 312,732.30 12,200.00 82.82 166.08 8,057.37 7,967.97 5.00 -56.82 4,842.16 5,948,849.55 312,750.20 12,300.00 85.61 161.91 8,067.45 7,978.05 5.00 -56.19 -4,744.53 5,948,753.32 312,775.30 12,400.00 88.44 157.78 8,072.65 7,983.25 5.00 -55.77 4,645.40 5,948,658.80 312,807.41 //ZYZUM 77:33.ZZAM Page 8 COMPASS 5000.14 Build 85 Baker HugheslNTEQ Drilling Summary Report BA (ER HUGHES a GEcompany Company: _ConocoPhillips Export Company Local Coordinate Reference: Well MT6-06 Project: Western North Slope TVD Reference: MT6-06 Plan RKB @ 89.40usft (Plan Doyon19) Site: GMT1 Lookout Pad MD Reference: MT6-06 Plan RKB @ 89.40usft (Plan Doyon19) Well: MTB -06 North Reference: True Wellbore: ,MT6-06 Survey Calculation Method: Minimum Curvature Design: MT6-06 wpDS Database: OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS - DLeg TFace V. Sec Northing Easting (usft) (1 (°) (usft) (usft) (9100usft) (°) (usft) (usft) (usft) 12,455.28 90.00 155.50 8,073.40 7,984.00 5.00 -55.56 -4,590.24 5,948,607.54 312,828.09 12,455.67 90.00 155.50 8,073.40 7,984.00 0.00 0.00 4,589.85 5,948,607.18 312,828.24 Start DLS 0.04 TFO.90.00 12,500.00 90.D0 155.48 8,073.40 7,984.00 0.05 -90.00 4,545.57 5,948,566.42 312,845.64 12,600.00 90.00 155.44 8,073.40 7,984.00 0.04 -90.00 4,445.66 5,948,474.47 312,884.95 12,700.00 90.00 155.39 8,073.40 7,984.00 0.04 -90.00 4,345.75 5,948,382.56 312,924.34 12,800.00 90.00 155.35 8,073.40 7,984.00 0.04 -90.00 4,245.83 5,948,290.68 312,963.79 12,900.00 90.00 155.30 8,073.40 7,984.00 0.04 -90.00 4,145.92 5,948,198.83 313,003.32 13,000.00 90.00 155.26 8,073.40 7,984.00 0.04 -90.00 4,045.99 5,948,107.01 313,042.92 13,100.00 90.00 155.21 8,073.40 7,984.00 0.04 -90.00 -3,946.07 5,948,015.23 313,082.59 13,200.00 90.00 155.17 8,073.40 7,984.00 0.04 -90.00 -3,846.14 5,947,923.47 313,122.33 13,300.00 90.00 155.12 8,073.40 7,984.00 0.04 -90.00 -3,746.21 5,947,831.74 313,162.15 13,400.00 90.00 155.08 8,073.40 7,984.00 0.04 -90.00 -3,646.28 5,947,740.05 313,202.03 13,500.00 90.00 155.03 8,073.40 7,984.00 0.04 -90.00 -3,546.35 5,947,648.39 313,241.99 13,600.00 90.00 154.99 8,073.40 7,984.00 0.04 -90.00 -3,446.41 5,947,556.75 313,282.02 13,700.00 90.00 154.94 8,073.40 7,984.00 0.04 -90.00 -3,346.47 5,947,465.15 313,322.12 13,800.00 90.00 154.90 8,073.40 7,984.00 0.04 -90.00 -3,246.52 5,947,373.58 313,362.29 13,900.00 90.00 154.85 8,073.40 7,984.00 0.04 -90.00 -3,146.58 5,947,282.04 313,402.53 14,000.00 90.00 154.81 8,073.40 7,984.00 0.04 -90.00 -3,046.63 5,947,190.54 313,442.85 14,100.00 90.00 154.76 8,073.40 7,984.00 0.04 -90.00 -2,946.68 5,947,099.06 313,483.23 14,200.00 90.00 154.72 8,073.40 7,984.00 0.04 -90.00 -2,846.72 5,947,007.62 313,523.69 14,300.00 90.00 154.68 8,073.40 7,984.00 0.04 -90.00 -2,746.77 5,946,916.21 313,564.22 14,400.00 90.00 154.63 8,073.40 7,984.00 0.04 -90.00 -2,646.81 5,946,824.83 313,604.82 14,500.00 90.00 154.59 8,073.40 7,984.00 0.04 -90.00 -2,546.85 5,946,733.48 313,645.49 14,600.00 90.00 154.54 8,073.40 7,984.00 0.04 -90.00 -2,446.86 5,946,642.16 313,686.23 14,700.00 90.00 154.50 8,073.40 7,984.00 0.04 -90.00 -2,346.92 5,946,550.87 313,727.04 14,800.00 90.00 154.45 8,073.40 7,984.00 0.04 -90.00 -2,246.95 5,946,459.62 313,767.93. 71232018 11:33:22AM Page 9 COMPASS 5000.14 Build 85 Baker HugheslNTEQ Drilling Summary Report BA ER I UGHES a Giicompany Company: _ConocoPhillips Export Company Local Co-ordinate Reference: Well MT6-06 Project: Western North Slope TVD Reference: MT6-06 Plan RKB @ 89.40usft (Plan Doyonl9) Site: GMTI Lookout Pad MD Reference: MT6-06 Plan RKB @ 89.40usft (Plan Doyonl9) Well: MT6-06 North Reference: True Wellbore: MT6-06 Survey Calculation Method: Minimum Curvature Design: MT6-06 wpO5 Database: OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Basting (usft) (°) (°) (usft) (usft) (°7100usft (°) (usft) (usft) (usft) 14,900.00 90.00 154.41 8,073.40 7,984.00 0.04 -90.00 -2,146.98 5,946,368.40 313,806.88 15,000.00 90.00 154.36 8,073.40 7,984.00 0.04 -90.00 -2,047.01 5,946,277.21 313,849.91 15,100.00 90.00 154.32 8,073.40 7,984.00 0.04 -90.00 -1,947.04 5,946,166.05 313,891.01 15,200.00 90.00 154.27 8,073.40 7,984.00 0.04 -90.00 -1,847.07 5,946,094.93 313,932.18 15,300.00 90.00 154.23 8,073.40 7,984.00 0.04 -90.00 -1,747.D9 5,946,003.83 313,973.42 15,400.00 90.00 154.18 8,073.40 7,984.00 0.04 -90.00 -1,647.11 5,945,912.77 314,014.73 15,500.00 90.00 154.14 8,073.40 7,984.00 0.04 -90.00 -1,547.13 5,945,821.74 314,056.11 15,600.00 90.00 154.09 8,D73.40 7,984.00 0.04 -90.00 -1,447.15 5,945,730.75 314,097.57 15,700.00 90.00 154.05 8,073.40 7,984.00 0.04 -90.00 -1,347.17 5,945,639.78 314,139.09 15,800.00 90.00 154.00 8,073.40 7,984.00 0.04 -90.00 -1,247.18 5,945,548.85 314,180.69 15,900.00 90.D0 153.96 8,073.40 7,984.00 0.04 -90.00 -1,147.20 5,945,457.95 314,222.35 16,000.00 90.00 153.92 8,073.40 7,984.00 0.04 -90.00 -1,047.21 5,945,367.08 314,264.09 16,100.00 90.00 153.87 8,073.40 7,984.00 0.04 -90.00 -947.22 5,945,276.25 314,305.90 16,200.00 90.00 153.83 6,073.40 7,984.00 0.04 -90.00 -847.24 5,945,185.45 314,347.78 16,300.00 90.00 153.78 8,073.40 7,984.00 0.04 -90.00 -747.25 5,945,094.68 314,389.73 16,400.00 90.00 153.74 8,073.40 7,984.00 0.04 -90.00 .647.25 5,945,003.94 314,431.75 16,500.00 90.00 153.69 8,073.40 7,984.00 0.04 -90.OD -547.26 5,944,913.24 314,473.64 16,600.00 90.00 153.65 8,073.40 7,984.00 0.04 -90.00 -047.27 5,944,822.57 314,516.00 16,700.00 90.00 153.60 8,073.40 7,984.00 0.04 -90.00 -347.27 5,944,731.93 314,558.24 16,800.00 90.00 153.56 8,073.40 7,984.00 0.04 -90.00 -247.28 5,944,641.33 314,600.54 16,900.00 90.00 153.51 8,073.40 7,984.00 0.04 -90.00 -147.28 5,944,550.76 314,642.91 17,000.00 90.00 153.47 8,073.40 7,984.00 0.04 -90.00 -47.29 5,944,460.22 314,685.36 17,100.00 90.00 153.42 8,073.40 7,984.00 0.04 -90.00 52.71 5,944,369.71 314,727.88 17,200.00 90.00 153.38 8,073.40 7,984.00 0.04 -90.00 152.71 5,944,279.24 314,770.46 17,300.00 90.00 153.33 8,073.40 7,984.00 0.04 -90.00 252.70 5,944,188.80 314,813.12 17,400.00 90.00 153.29 8,073.40 7,984.00 0.04 -90.00 352.70 5,944,098.40 314,855.85 17,500.00 90.00 153.24 8,073.40 7,984.00 0.04 -90.00 452.70 5,944,008.03 314,898.64 723/2018 11:33:224M Page 10 COMPASS 5000.14 Build 85 Baker HugheslNTEQ Drilling Summary Report BA ER BAT aUcompany Company: _ConomPhillips Export Company Local Co-ordinate Reference: Well MT6-06 Project: Western North Slope TVD Reference: MT6-06 Plan RKB @ 89.40usft (Plan Doyonl9) Site: GMTI Lookout Pad MD Reference: MT646 Plan RKB @ 89.40usft (Plan Doyonl9) Well: MT6-06 North Reference: True Wellbore: -MT6-06 Survey Calculation Method: Minimum Curvature Design: MT6-06 wp05 Database: OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Basting (usft) (°) (°) (usft) (usft) (°7100usft) (°) :(usft) (usft) (usft) 17,600.00 90.00 153.20 8,073.40 7,984.00 0.04 -90.00 552.70 5,943,917.69 314,941.51 17,700.00 90.00 153.16 8,073.40 7,984.00 0.04 -90.00 652.70 5,943,827.38 314,984.45 17,733.55 90.00 153.14 8,073.40 7,984.00 0.04 -90.00 686.25 5,943,797.09 314,998.88 17,765.44 90.00 153.14 8,073.40 7,984.00 0.00 0.00 718.14 5,943,768.30 315,012.59 Start 2960.32 hold at 17765.44 MD 17,800.00 90.00 153.14 8,073.40 7,984.00 0.00 0.00 752.70 5,943,737.10 315,027.45 17,900.00 90.00 153.14 8,073.40 7,984.00 0.00 0.00 852.70 5,943,646.83 315,070.44 18,000.00 90.00 153.14 8,073.40 7,984.00 0.00 0.00 952.70 5,943,556.55 315,113.44 18,100.00 90.00 153.14 8,073.40 7,984.00 0.00 0.00 1,052.70 5,943,466.27 315,156.44 18,200.00 90.00 153.14 8,073.40 7,984.00 0.00 0.00 1,152.70 5,943,376.00 315,199.44 18,300.00 90.00 153.14 8,073.40 7,984.00 0.00 0.00 1,252.70 5,943,285.72 315,242.44 18,400.00 90.00 153.14 8,073.40 7,984.00 0.00 0.00 1,352.70 5,943,195.44 315,285.43 18,500.00 90.00 153.14 8,073.40 7,984.00 0.00 0.00 1,452.70 5,943,105.17 315,328.43 18,600.00 90.00 153.14 8,073.40 7,984.00 0.00 0.00 1,552.70 5,943,014.89 315,371.43 18,700.00 90.00 153.14 8,073.40 7,984.00 0.00 0.00 1,652.70 5,942,924.61 315,414.43 18,800.00 9D.00 153.14 8,073.40 7,984.00 0.00 0.00 1,752.70 5,942,834.33 315,457.43 18,900.00 90.00 153.14 8,073.40 7,984.00 0.00 0.00 1,852.70 5,942,744.06 315,500.42 19,000.00 90.00 153.14 8,073.40 7,984.00 0.00 0.00 1,952.70 5,942,653.78 315,543.42 19,100.00 90.00 153.14 8,073.40 7,984.00 0.00 0.00 2,052.70 5,942,563.50 315,586.42 19,200.00 90.00 153.14 8,073.40 7,984.00 0.00 0.00 2,152.70 5,942,473.23 315,629.42 19,300.00 90.00 153.14 8,073.40 7,984.00 0.00 0.00 2,252.70 5,942,382.95 315,672.42 19,400.00 90.00 153.14 8,073.40 7,984.00 0.00 0.00 2,352.70 5,942,292.67 315,715.41 19,500.00 90.00 153.14 8,073.40 7,984.00 0.00 0.00 2,452.70 5,942,202.40 315,758.41 19,600.00 90.00 153.14 8,073.40 7,984.00 0.00 0.00 2,552.70 5,942,112.12 315,801.41 19,700.00 90.00 153.14 8,073.40 7,984.00 0.00 0.00 2,652.69 5,942,021.84 315,844.41 19,800.00 90.D0 153.14 8,073.40 7,984.00 0.00 0.00 2,752.69 5,941,931.56 315,887.40 19,900.00 90.00 153.14 8,073.40 7,984.00 0.00 0.00 2,852.69 5,941,841.29 315,930.40 723/2018 11:33.22AM Page 11 COMPASS 5000.14 Build 85 Company; _ConocoPhillips Export Company Project: Western North Slope Site: GMT1 Lookout Pad Well: MT6-O6 Wellbore: MT6-06 Design: MT6-06 wpOS Planned Survey MD (usft) 20,000.00 20,100.00 20,200.00 20,300.00 20,400.00 20,500.00 20,600.00 20,700.00 4.1/2" z 6-1/8" 20,725.40 Casing Points Baker HugheslNTEQ Drilling Summary Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: BATUGHIES aGEcempany Well MT6-06 MT6-06 Plan RKB Q 89.40usft (Plan Doyon19) MTMS Plan RKB @ 89.40usft (Plan Doyon19) True Minimum Curvature OAKEDMP2 Inc Azi (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Seeking (') V) (usft) (usft) (°/100usft) (°) (usft) (usft) (usft 90.00 153.14 8,073.40 7,984.00 0.00 0.00 2,952.69 5,941,751.01 315,973.40 90.00 153.14 8,073.40 7,984.00 0.00 0.00 3,052.69 5,941,660.73 316,016.40 90.00 153.14 8,073.40 7,984.00 0.00 0.00 3,152.69 5,941,570.46 316,059.40 90.00 153.14 8,073.40 7,984.00 0.00 0.00 3,252.69 5,941,480.18 316,102.39 90.00 153.14 8,073.40 7,984.00 0.00 0.00 3,352.69 5,941,389.90 316,145.39 90.00 153.14 8,073.40 7,984.00 0.00 0.00 3,452.69 5,941,299.63 316,188.39 90.00 153.14 8,073.40 7,984.00 0.00 0.00 3,552.69 5,941,209.35 316,231.39 90.00 153.14 8,073.40 7,984.00 0.00 O.OD 3,652.69 5,941,119.07 316,274.39 90.00 153.14 8,073.40 7,984.00 0.00 0.00 3,678.09 5,941,096.14 316,285.31 Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 2,115.35 2,000.00 13-3/8" x 16" 13-3/8 16 10,380.00 7,279.42 9-5/8"x12-1/4" 9-5/8 12-1/4 11,950.00 8,011.36 7"x8-3/4" 7 8-3/4 20,700.00 8,073.40 4-1/2"x6-1/8" 4-1/2 6-1/8 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (I (°) 10,340.53 7252.36 HRZ / 0.00 11,930.22 8,00649 AlpineC v 0.00 723/2018 11:33:22AM Page 12 COMPASS 5000.14 Build 85 Baker Hughes INTEQ Drilling Summary Report BA (ER I�UGHES a GEcompany Company: _ConocoPhillips Export Company Local Coordinate Reference: Well MT6-06 Project: Western North Slope ND Reference: MT6-06 Plan RKB @3 89.40usft (Plan Doyonl9) Site: GMT7 Lookout Pad MD Reference: MT6-06 Plan RKB @ 89.40usft (Plan Doyon19) Well: MT6-06 North Reference: True Wellbore: MT6-06 Survey Calculation Method: Minimum Curvature Design: MT6-06 wp05 Database: OAKEDMP2 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 319.40 319.40 0.00 0.00 Start Build 2.00 2,115.35 2,000.00 385.19 -385.19 Start ID0.00 hold at 2115.35 MD 2,215.35 2,080.98 426.68 426.68 Start Build 2.00 2,604.93 2,380.00 602.93 -602.93 Start 1000.00 hold at 2604.93 MD 3,604.93 3,102.84 1,091.55 -1,091.55 Start DLS 3.00 TFO 55.00 4,304.93 3,547.30 1,536.65 -1,389.69 Start 3700.00 hold at 4304.93 MD 8,004.93 5,518.62 4,381.23 -2,698.21 Start DLS 3.50 TFO -137.20 11,043.06 7,658.01 4,248.53 4,205.68 Start 372.32 hold at 11043.06 MD 11,415.38 7,824.15 3,939.73 -4,330.84 Start DLS 5.00 TFO -67.10 12,455.67 8,073.40 2,967.20 4,286.55 Start DLS 0.04 TFO-90.00 17,765.44 8,073.40 -1,817.48 -1,985.17 Start 2960.32 hold at 17765.44 MD 20,725.76 Planned TD at 20725.76 Checked By: Approved By: Date: 7/23/2018 1133 22,4114 Page 13 COMPASS 5000.14 Build 65 81OZ obi lsnSny m@'A deW 90-91W Ouise:) a:)ejjnS —101d aapidS 90-91A ConocoPhillips BAKER 0 ConocoPhillips Travelling Cylinder Report HUGHES a G6company Company: ConomPhillips(Alaska) Inc. -WNS Project: Western North Slope Reference Site: GMT1 Lookout Pad Site Error: 0.00 usft Reference Well: MTS -06 Well Error. 0.00 usft Reference Wellbore MT6-06 Reference Design: MT6-06 wp05 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method; Output errors are at Database: Offset TVD Reference: Well MT6-06 MT6-O6 Plan RKB @ 89.40usft (Plan Doyonl9) MTS -06 Plan RKB @ 89.40usft (Plan Doyonl9) True Minimum Curvature 1.00 sigma EDTAlaska Prod Offset Datum Reference Depths are relative to MT6-06 Plan RKB @ 89.40usft (Plan Coordinates are relative to: MT6-06 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927, Alaska Zone 4 Central Meridian is 150° 0' 0.000 W Grid Convergence at Surface is: -1.39 ° CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 7/78/2018 10:48:30AM Page 123 COMPASS 5000 14 Build Ladder Plot 2200 1w y, I I 1650— ' I � L I .0 , Irm I I rn 1 I I I 1 , 1 I 1100 e� U 0 tv c 0 U 550 0 0 3000 6000 9000 12000 15 000 18000 Measured Dl Ah LEGEND CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 7/78/2018 10:48:30AM Page 123 COMPASS 5000 14 Build I 1w y, I I ' I � L I , I I 1 I I I 1 , 1 I 85 From: Boyer David L (DOA) To: "Beat. Andrew T" Cc: Davies, Stephen F (DOA) Subject: RE: [EXTERNAL]Confirmation of KB and GL Elevations for MT -6-06 Date: Thursday, August 2, 2018 9:06:00 AM Andrew, Thank you for clarifying the measurements. I will make the edits to the package and initial them. As an aside, Doyon 19 was my old rig when I geo-steered most of the wells in CD1 & CD2 (1999- 2003) before doing a 9 year stint in the BP office in the GPMA Asset. Cheers, Dave B. From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Thursday, August 2, 2018 6:30 AM To: Boyer, David L (DOA) <david.boyer2@alaska.gov> Cc: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL]Confirmation of KB and GL Elevations for MT -6-06 Dave, Good catches. I should have proofed those before submitting. The RKB for D19 is 37.2' and our pad elevation is around 52' depending on the well and the settling around it. Baker's overall RKB is correct at 89.4' but I think they switched the GL for RKB. The pad elevation for MT6-06 we're using now is 52.2'. So 89.4' and 52.2' with a rig height of 37.2'. Thanks, Andrew (303)378-8881 From: Boyer, David L (DOA) <david.boyer2Palaska gov> Sent: Wednesday, August 01, 2018 2:56 PM To: Beat, Andrew T <Andrew.T.Beat(@conocophilli sp com> Cc: Davies, Stephen F (DOA) <steve.davies(talaska.go > Subject: [EXTERNAL]Confirmation of KB and GL Elevations for MT -6-06 Andrew, In reviewing the Permit to Drill Application, Steve noticed an inconsistency in the reported KB and GL/Pad elevations. On the cover page, the KB=70' and GL=34'. On page 3 in the Location Summary, the RKB=88.7' and the Pad Elevation=52.2'. On the Baker Directional Summary Report, the RKB for Doyon 19=89.4' and the GL=37.2'. Please clarify which values we should use for our records and software here. I would assume that the Baker report should be dead on since they are steering the well but wanted to check in to be sure. Thanks, Dave B. AOGCC Boyer, David L (DOA) From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Tuesday, July 31, 2018 8:18 AM To: Boyer, David L (DOA) Cc: Davies, Stephen F (DOA) Subject: RE: [EXTERNAL] Information Request for GMTU MT -6=06 Well Dave, It definitely does. It would be simpler from a drilling standpoint to drill the lateral south to north but we are still somewhat uncertain on the boundary of the field so drilling north to south allows us to find it. Thanks, Andrew (303)378-8881 From: Boyer, David L (DOA) <david.boyer2@alaska.gov> Sent: Tuesday, July 31, 2018 8:15 AM To: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Cc: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL] Information Request for GMTU MT -6=06 Well Andrew, Thank you for the additional data on MT6-06 well. Without the survey loaded, it looked like the well had quite a hook in it. Hairpin turn may be more like it! Best Regards, Dave B. From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Tuesday, July 31, 2018 6:56 AM To: Boyer, David L (DOA) <david.bover2Palaska.eov> Cc: Davies, Stephen F (DOA) <steve.davies(a alaska.aov> Subject: RE: [EXTERNAL] Information Request for GMTU MT -6=06 Well Dave, 1. Only MT6-03 has been flowed back to date but no H2S was encountered on that well. 2. Slide attached that was used in our planning meeting. Let me know if you would like something more detailed. 3. Excel file attached. Let me know if there is anything else you need. Thanks, Andrew (303)378-8881 From: Boyer, David L (DOA) <david.bover2@alaska.eov> Sent: Monday, July 30, 2018 11:19 AM To: Beat, Andrew T <Andrew.T.Beat@conocophi] lips.com> Cc: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: [EXTERNAL] Information Request for GMTU MT -6=06 Well Hi Andrew, I am a new senior geologist working closely with Steve Davies on Permits To Drill at the AOGCC. After beginning the review of the MT -6-06 application, I had several questions to speed up the process. 1) Has there been any H2S reported in Mooses Tooth Unit or other wells in the area? 2) Can you provide wellbore details from Baker showing the Plan View and Vertical Section view of the well? A visual would help a lot. 3) Is it possible to e-mail the digital file of the directional plan in ASCII or Excel format so we can load it more efficiently? We only need the MD, Inclination, and Azimuth columns for our program.. Thanks, Dave Boyer MT6-06 wp05 - eu\4b!'Y 1S1N' i rY634• \ i �,avu,m ' rsvr Y.ims�m - eu\4b!'Y 1S1N' rY634• \ i �,avu,m TRANSMITTAL LETTER CHECKLIST WELL NAME: M T 6- O6 PTD: a 18 " O9 3 Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: Gy-ea[Pl�MoOSES �oarc� POOL: G—oO�OUf oil Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. 'API No. 50- _- (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - from records, data and logs acquired for well name on ermit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool PTD#: 2180930 Company CONOCOPHILLIPS ALASKA INC Initial Class/type Well Name: GMTV MT 6-06 _ _ Program DEV Well bore seg ❑ _D_EVLaF_b D GeoArea 890 Unit 10750 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31.05.030(j..1.A),0,2.A-D) NA... Commissioner: Date ommis ' r Da e 1 Permit fee attached _ _ - NA _ Conservation Order No. 747, issued_ May 29, 2018, governs Lookout Oil Pool.... 2 Lease number appropriate.. Yes No restrictions as to well spacing except that no pay shall be opened to a well within 500 feet of an. 3 Unique well name and number _ _ Yes external property line where the owners and landowners are not the same on both sides of the line. 4 Well located in.a defined pool _ _ _ Yes As planned, this well conforms with spacing requirements. 5 Well located proper distance from drilling unit boundary _ Yes 6 Well located proper distance from other wells _ _ _ _ _ Yes 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included _ _ _ _ _ _ _ _ _ Yes 9 Operator only affected party.. _ _ Yes 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 SFD 8/16/2018 13 Can permit be approved before 15 -day wait.. _ _ _ Yes 14 Well located within area and strata authorized by. Injection Order # (put 10# in comments) (For. Yes 15 All wells within 1/4 mile area of review identified (For service well only). _ _ _ _ _ _ NA 16 Pre -produced injector: duration of pre production less than 3 months (For service well only) NA.... 18 Conductor string. provided ........ _ _ _ _ _ Yes 20 inch. conductor set at 115 ft.. Engineering 19 Surface casing. protects all known USDWs _ _ NA No aquifers... permafrost 20 CMT vot adequate to circulate on conductor. & surf csg _ _ _ _ _ _ _ Yes 13 3/8" surface casing set at 2115 ft and fully cemented._ 21 CMT vol. adequate. to tie-in long string to surf csg. No Int 1 rasing set at 10380 ft.. 22 CMT. will cover all known. productive horizons.. _ _ _ Yes _ _ Slotted liner in horizontal production section. 23 Casing designs adequate for C. T, B &. permafrost...... _ _ _ Yes BTO supplied for comparable well...... 24 Adequate tankage or reserve pit Yes Rig has steel pit.. All waste to be transported to approved disposal. well. 25 If re -drill, has. a 10-403 for abandonment been approved _ _ _ _ NA. Grassroots well 26 Adequate wellbore separation proposed Yes No collision issues.. MT6-05 is within 500 ft at 12000 ft MD 27 If diverter required, does it meet regulations _ _ Yes Diverter waived -4th well on pad. .................. _ Appr Date 28 Drilling fluid program schematic & equip list. adequate _ Yes Max form pressure =.3810 psi (9,2 ppg EMW) Will drill with MPD and 8.8 - 9.5 ppg GLS 8/16/2018 29 BOPEs, do they meet regulation _ _ _ _ _ _ Yes _ 30 BOPE press rating appropriate; test to (put prig in comments) _ Yes MASP= 3015 psi Will test BOPE.to 3500 psi_ 31 Choke manifold complies WAPI RP -53 (May 84).... _ _ _ _ Yes 32 Work will occur without operation shutdown _ _ _ _ . _ _ _ _ _ Yes 33 Is presence of H2$ gas probable _ .. ..... _ _ _ No Rig has sensors and alarms.. No H2S expected.... 34 .Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures Yes No H2S encountered in the area Geology 36 Data presented on potential overpressure zones Yes . Drilling fluid program. appears adequate to control operator's forecast pressures. Production interval will. Appr Date 37 Seismic analysis of shallow gas zones NA.. be drilled. with 8,8-9.5 ppg mud. using Managed Pressure Drilling Technique. _ SFD 8/16/2018 38 Seabed condition survey (if off -shore) _ _ _ NA 39 Contact name/phone for weekly progress reports. [exploratory only) _ NA _ Geologic Engineering Commissioner: Date: Commissioner: Date ommis ' r Da e
