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
217-072
P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Oct 13, 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jessie Chmielowski: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, Roger Mouser ConocoPhillips Well Integrity Field Supervisor Roger Mouser Digitally signed by Roger Mouser Date: 2020.10.13 13:10:42 -08'00' By Samantha Carlisle at 1:21 pm, Oct 13, 2020 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 10/13/20 2K 2M 3K 3O 3Q 3R 3S pad Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal 2K-30 50103207580000 2170720 22" 0.3 6" 3/8/2020 2.5 9/29/2020 2K-32 50103207570000 2170420 29" 0.5 6" 3/8/2020 3 9/29/2020 2M-37 50103207450000 2160820 30" 0.4 9" 7/31/2020 2.1 9/29/2020 2M-38 50103207460000 2160830 4" N/A 4" N/A 2.5 9/29/2020 3K-32 50029227630000 1970760 10"Conductor extension 10" 4/27/2019 2.5 9/27/2020 3K-34 50029228790000 1980770 14" Conductor extension 14" 4/27/2019 9 9/27/2020 3O-01A 50029218360000 2151910 62" 0.70 11" 3/8/2020 4.25 9/27/2020 3O-19 50029227530000 1970500 13"Conductor extension 13" 4/27/2019 4.25 9/27/2020 3O-20 50029227500000 1970450 21 5.00 17" 9/27/2020 6 9/27/2020 3Q-22 50029226250000 1951860 20' 3.25 8" 3/8/2020 4.25 9/26/2020 3R-101 50029235740000 2170130 21" 0.40 8" 8/14/2020 1 9/26/2020 3R-102 50029235720000 2161570 54" 1.10 6" 8/14/2020 6 9/26/2020 3R-105 50029236510000 2191340 22" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-106 50029236410000 2190970 36" 0.60 9" 8/14/2020 3.5 9/26/2020 3R-107 50029236600000 2191810 32" 0.60 9.5" 8/14/2020 1 9/26/2020 3R-111 50029236430000 2191050 25" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-112 50029236370000 2190850 36" 0.60 14"8/14/2020 7 9/26/2020 3S-611 50103207740000 2181030 11' 10" 2.50 8"6/30/2019 2.5 9/27/2020 3S-612 50103207770000 2181110 43" 0.75 8" 6/30/2019 3.5 9/27/2020 3S-613 50103207350000 2160200 22" 0.75 8" 6/30/2019 1.7 9/27/2020 DATA SUBMITTAL COMPLIANCE REPORT 1/12/2018 Permit to Drill 2170720 Well Name/No. KUPARUK RIV UNIT 2K-30 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20758-00-00 MD 22055 TVD 6437 Completion Date 7/23/2017 Completion Status 1 -OIL Current Status 1 -OIL UIC No REQUIRED INFORMATION Mud Log No ✓ / Samples No Directional Survey Yes DATA INFORMATION tAN NSI List of Logs Obtained: GR/Res ) T�„i,: c� (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OHI Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C28492 Digital Data 42 3318 8/11/2017 Electronic Data Set, Filename: CPAI 2K-30 - Scope Service_RM_LW D001.las ED C 28492 Digital Data 3278 11966 8/11/2017 Electronic Data Set, Filename: CPAI 2K-30 - Scope Service_RM_LW D002.1as ED C 28492 Digital Data 11828 22055 8/11/2017 Electronic Data Set, Filename: CPAI 2K-30 - Scope Service —RM _LWD003.las ED C 28492 Digital Data 100 22055 8/11/2017 Electronic Data Set, Filename: CPAI 2K-30 Scope Service RM.las ED C 28492 Digital Data 8/11/2017 Electronic File: CPAI 2K-30 Scope Service RM ' LW D001.html ED C 28492 Digital Data 8/11/2017 Electronic File: CPAI 2K-30 Scope Service RM LWD002 DLIS.html ED C 28492 Digital Data 8/11/2017 Electronic File: CPAI 2K-30 Scope Service RM. LW D003.diis ED C 28492 Digital Data 8/11/2017 Electronic File: CPAI 2K-30 Scope Service RM' LWD003.html ED C 28492 Digital Data 8/11/2017 Electronic File: CPAI 2K-30 Scope Service RM DLIS.dlis ED C 28492 Digital Data 8/11/2017 Electronic File: CPAI 2K-30 Scope Service RM. DLIS.html ED C 28492 Digital Data 8/11/2017 Electronic File: CPAI _2K- K- 30 — 30_ Scope_Service_2in_MD.pdf , ED C 28492 Digital Data 8/11/2017 Electronic File: CPAI 2K- 30_Scope_Service_2in_TVD.pdf' ED C 28492 Digital Data 8/11/2017 Electronic File: CPAI_2K- 30_Scope_Service_5in_MD.pdf AOGCC Page 1 of 3 Friday, January 12, 2018 DATA SUBMITTAL COMPLIANCE REPORT 1/12/2018 Permit to Drill 2170720 Well Name/No. KUPARUK RIV UNIT 2K-30 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103.20758.00.00 MD 22055 TVD 6437 Completion Date 7/23/2017 Completion Status 1-0I1 Current Status 1-0I1- UIC No ED C 28492 Digital Data - 8/11/2017 Electronic File: CPA - P _2K 30_Scope_Service_Sin_TVD.pdf ED C 28492 Digital Data 8/11/2017 Electronic File: 2K-30 NAD27 EOW Compass Surveys.pdf ED C 28492 Digital Data 8/11/2017 Electronic File: 2K-30 NAD27 [Canvas].txt ED C 28492 Digital Data 8/11/2017 Electronic File: 2K-30 NAD27 [Macro].txt ED C 28492 Digital Data 8/11/2017 Electronic File: 2K-30 NAD27 [Petrel].txt ED C 28492 Digital Data 8/11/2017 Electronic File: 2K-30 NAD27 [Surveys].txt ED C 28492 Digital Data 8/11/2017 Electronic File: 2K-30 NAD83 EOW Compass Surveys.pdf ED C 28492 Digital Data 8/11/2017 Electronic File: 2K-30 NAD83 [Canvas].txt - ED C 28492 Digital Data 8/11/2017 Electronic File: 2K-30 NA083 [Macro].txt . ED C 28492 Digital Data 8/11/2017 Electronic File: 2K-30 NAD83 [Petrel].txt ED C 28492 Digital Data 8/11/2017 Electronic File: 2K-30 NAD83 [Surveys].txt . ED C 28756 Digital Data 9/18/2017 Electronic File: 2K-30.pdf ` ED C 28756 Digital Data 9/18/2017 Electronic File: READMEAxt - Log C 28756 Log Header Scans 0 0 404 CD - PTD Hydraulic Fracture Data ED C 28890 Digital Data 11875 12250 8/22/2017 Electronic Data Set, Filename: COP_2K- - 30_SonicScope_TOC_Dri Ili ng Data.las ED C 28890 Digital Data - 8786 11967 8/22/2017 Electronic Data Set, Filename: COP 2K- . 30_SonicScope_TOC_Reaming Data.las ED C 28890 Digital Data 8/22/2017 Electronic File: COP _2K- 30_ SonicSoope_TOC_DrillingData.dlis ED C 28890 Digital Data 8/22/2017 Electronic File: COP_2K- 30_SonicScope_TOC_ReamingData.dlis ED C 28890 Digital Data 8/22/2017 Electronic File: COP 2K-30 SonicScope TOC 240.pdf Log C 28890 Log Header Scans 0 0 404 CD - PTD Hydraulic Fracture Data Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments A0G(.1 Page 2 of 3 Friday, January 12, 2018 DATA SUBMITTAL COMPLIANCE REPORT 1/1212018 Permit to Drill 2170720 Well Name/No. KUPARUK RIV UNIT 2K-30 Operator CONOCOPHILLIPS ALASKA, INC. MD 22055 TVD 6437 Completion Date 7/23/2017 Completion Status 1-0I1 Current Status 1 -OIL INFORMATION RECEIVED Completion Report T) Directional / Inclination Data Production Test Information YN , Mechanical Integrity Test Information Y / NA Geologic Markers/Tops 0 Daily Operations Summary V COMPLIANCE HISTORY Completion Date: 7/23/2017 Release Date: 6/1/2017 Description Date Comments Mud Logs, Image Files, Digital Data Y /6 Composite Logs, Image, Data FilesTO Cuttings Samples Y//NA/ API No. 50-103-20758-00-00 UIC No Core Chips Y /OA Core Photographs Y/6 Laboratory Analyses Y / I� Comments: - - -- - - - -- --- — - _. _.-- - Compliance Reviewed By: _._ _ _ _ _ _ Date:. AOG(( Page 3 of 3 Friday, January 12, 2018 STATE OF ALASKA I ALASKA OIL AND GAS CONSERVATION COMMISSION 2A-1,511 REPORT OF SUNDRY WELL OPERATIONS SEP IS 2017 ON f 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development p Exploratory ❑ Stratigmphic❑ Service ❑ 217-072 3. Address: P. O. Box 100360, Anchorage, 6. API Number: Alaska 99510 50-103-20758-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25588, ADL 25605, ADL 25604, ADL 25607 KRU 2K-30 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 22,055 feel Plugs measured None feet true vertical 6,437 feet Junk measured None feet Effective Depth measured 22,055 feet Packer measured 11,724 feet true vertical 6,437 feet true vertical 6,354 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 91 feet 20 130' MD 130 TVD SURFACE 3,270 feet 10 3/4 " 3,309' MD 2840 TVD INTERMEDIATE 11,920 feet 7 5/8 " 11,957' MD 6368 TVD LINER 10,117 feet 4 1/2 " 21,914' MD 6436 TVD Tubing (size, grade, measured and true vertical depth) 3.5" L-80 11,824' MD 6,360' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER PREMIER PRODUCTION PACKEF 11,724' MD 6,354' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 12,224-19,701 Treatment descriptions including volumes used and final pressure: Total Well - 15 stages 1,485,087 placed......... See attached schematic for full FRAC details 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Waiting for Hook-up Subsequent to operation: lWafting for Hook-up 14. Attachments (required per 20 AAC 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations o�c,%,4I11 to� Exploratory ❑ Development ❑ Service ❑ Stratigraphic ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data 21 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: 317-309 contact Name: Adam Klem Authorized Name: Adam Klem contact Email: Adam.Klem@cop.com Authorized Title: Com letio PeEngineer ') Date: Contact Phone: (907) 263-4529 Authorizetl Si nature: i a / Form 30-404 Revised 4/2017 000/0 t g/' `//// 6bw 1'019/2,,7 R130FAS i i. ` 7 5 201/ `/ Q S✓�""-;Q� Submit Original Only 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): Total Base Non Water Volume: 8/11/2017 8/19/2017 Alaska Harrison Bay 50-103-20758-00-00 ConocoPhillips Company/Burlington Resources 2K-30 70.24228900 Hydraulic Fracturing Fluid Composition: -150.01364800 NAD27 NO NO 6,437 1,008,526 0 r • �1 �c>ttCitK3aa C41 :�.•: 4 Oil & 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 80.08394 Density = 8.450 Ingredients Listed Above Listed Above Water 7732-18-5 100.00000 0.11922 CL-22 LIC Halliburton Crosslinker Listed Below CL-31 CROSSLINKER Halliburton Crosslinker Listed Below LVT-200 Penreco Additive Listed Below 20/40 Wanli Xinmi Wanli Industry Development Co.,Ltd Additive Listed Below Silica Flour Halliburton Additive Listed Below WG-36 GELLING AGENT Halliburton Gelling Agent Listed Below SP BREAKER Halliburton Breaker Listed Below Optiflo-IIA Halliburton Additive Listed Below Carbol-ite 20/40 Carbo Additive Listed Below SAND -COMMON Halliburton Proppant WHITE -100 MESH, SSA -2, 2500 LB SACK Listed Below BE -6 Halliburton Biocide MICROBIOCIDE Listed Below LOSURF-300D Halliburton Non-ionic Surfactant Listed Below MO -67 Halliburton pH Control Additive Listed Below OPTIFLO-III Halliburton Breaker DELAYED RELEASE BREAKER Listed Below Items above are Trade Names with the exception of Base Water Items below are the individual ingredients, Corundum 1302-74-555.00000 7.18030 Mullite 1302-93-8 45.00000 5.87479 Sodium chloride 7647-14-5 4.00000 3.33847 Ceramic materias and 66402-68-4 100.00000 1.60923 wares, Chemicals Crystalline silica, quartz 14808-60-7 100.00000 1.04824 Guargum 9000-30-0 100.00000 0.31833 Hydrotreated Distillate, 64742-47-8 100.00000 0.24540 Light..C9-16 Ei Borate salts Proprietary 60.00000 0.06515 Potassium formate 590-29-4 60.00000 0.06515 Ethanol 64-17-5 60.00000 0.04161 Potassium metaborate 13709-94-9 60.00000 0.03165 Oxylated phenolic resin Proprietary 30.00000 0.02774 Ammonium persulfate 7727-54-0 100.00000 0.02139 Heavy aromatic petroleum naphtha 64742-94-5 30.00000 0.02080 Sodium hydroxide 1310-73-2 30.00000 0.01650 Cured acrylic resin Proprietary 30.00000 0.00592 Naphthalene 91-20-3 5.00000 0.00347 Poly(oxy-1,2-ethanediyl), alpha -(4-n onylphe nyl )- omega -hydroxy-, branched 127087-87-0 5.00000 0.00347 Potassium hydroxide 1310-58-3 5.00000 0.00264 2-Bromo-2-nitro-1,3- propanediol 52-51-7 100.00000 0.00167 Acrylate polymer Proprietary 1.00000 0.00109 Denise Tuck, Halliburton, 3000 N. Sam Houston Pkwy E., Houston, TX 77032, 281-871-6226 Sodium carboxymethyl cellulose 9004-32-4 1.00000 0.00109 Sodium glycollate 2836-32-0 1.00000 0.00109 1,2,4 Trimethylbenzene 95-63-6 1.00000 0.00069 Sodium persulfate 7775-27-1 100.00000 0.00023 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 may be 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 provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Sheets (MSDS) 2K-30 DTTMSTARiJOBTYP SUMMARYOPS 8/11/17 FRACTURING FINISH LOADING AND HEATING FRAC TANKS, PRESSURE TEST SURFACE LINES TO 9500 PSI WITH SW, RETURN IN MORNING TO FRAC STAGES 1-6, IN PROGRESS. 8/12/17 FRACTURING PERFORM DATAFRAC FOLLOWED BY FRAC STAGES 1-4. PLACED 410,155 LBS OF WANLI 20/40 PROPPANT OVER 4 STAGES, IN PROGRESS 8/16/17 FRACTURING FRAC STAGES 5-10, PLACED 598760 LBS OF WANLI 20/40 PROPPANT OVER 6 STAGES, IN PROGRESS 8/19/17 FRACTURING FRAC STAGES 11-15,471 K LBS OF 20/40 PROPPANT PLACED OVER 5 STAGES, RAN OUT OF WATER DURING STAGE 15 WHILE PUMPING 4PPA SAND CONCENTRATION, DISPLACE REMAINING FLUSH VOLUME WITH HOTSHOT TRANSPORT OF SEAWATER AND LVT FOR FREEZE PROTECT, IN PROGRESS. 8/22/17 FRACTURING ATTEMPT TO BRUSH n' FLUSH & TBG PRESSURED UP TO 3000 PSI AFTER 15 BELS; BRUSHED & GAUGED TBG W/ 2.79" GAUGE RING DOWN TO 11,565' RKB (STOPPED DUE TO DEVIATION); SET 3 1/2" P2P RBP (8.53' OAL) @ 2779' RKB; MITT TO 3000 PSI (PASS) & PERFORMED 30 MIN. NO FLOW TEST (PASSED); SET 2.75" AVA CATCHER ON RBP @ 2779' RKB & PULLED DV @ 2752' RKB. LRS PERFORMING CMIT TO 2500 PSI. IN PROGRESS. Conoco`Phillips Raska.Inc. HPNGER', SVRFFLE: 3463,3]09 GRS IJFT; 3,d1] GIS LIR; qW&3 O UR. &m.5 MULE 3XGE; Hybe Fn M. IZM0 1 1 Hy JC Fz 1Z{O 1 1 HyW wFs .13 MO 1 1 H . F.. 13,i�.0 Myh F .. 14.W1 D 1 1 Hy1'wtic F.. 15.1ma 1�1 T .N... F.m,.; 15.d6.0 HyN.JJ FreReq 16.130.0 I 1 x1Jwsr F.a<m.: leela0 1 1 Hµ F m. 17,M0 XyAVJs Frxpve', 1].6190 HyGrw4 F,i'dre: I6,1A,0 I I XyM1aWp FIxNe: 16,0810 E 1 HO..F Axa: 191eo.0 1 1 .y .I ., 19.101Y r 1 HOk l rs. 4,2160 1 1 FERFP; 20.�2.0.a1,a320� � PERFP;A.510.0.91.E O PERFP; W.MA .,MD— I - PERFP', a1.952.,MO— FERFP; 21.113G ,1d.D� PERFP;212M61,3160-- PERFP; 31,630621A]&0� PERF P; 21,E8162183]D�� _ PERFP; 31,]f30.T,T5i.0�� I1NER: 11.I�.&21,BI0.0`� KUP F )D I 2K-30 C. Perforations & Mots ;MM -111 C.. S"I 1"( 8) 1 — B) I mm I 6Um( FW I - - &.; "I vm sw,,.INen I StlM .Mu. KUP F jD Cono4hillips NSSkb. r, G19 LIFT: i.]R.1 PCE; 9R63,AB.5 GP6 LIFT: RW1 ] Q93 LIFT MS LIFT: C GE I FL.PF Hp.. Flvn ,12]N.0 S diiiiiiiiiii S F., IZA90 r t Nyenub F,ecWq'13ZG.p r � nverewe Flmw;13]aRo 1 1 nveFw&Fx9va,".. r r fir IrymawK Frew,.. Is 1A.0 rr I s1P1 1 X,a..wm Fre.pre'.,s,6F6p 1 1 q Nrxw�Fr:.nY.:1a.1Ao 1 1 P,oPr Xva�E F,><e..: 16.6130 F 6 Stln S13Y 1 X.JvuAC F... 11,0WO E r 2 3 4 HO -1. F., 17.6190 1 1 S 6 7 NyJeitic Fnwn: 14108.0 1 1 Fst; .Creak F., 16,M10 Nyleub F,xpa, 18,16,,0 rE X0. Fable: l9,ryN0 6 r XytlreefcFz .M.,3100 E PERFP, A,M8 M, 320 4 i PERFF; MW4e ME O— ! PERFP; A,R3.PA,A2,0�� I I = PERFP, A,F52DA... PERF': 21,113. 2 JM.0 PERFP, 21 TO.pN,918.0� PERFP; 0..9 21,06.p— PERFP; 2., L21,07 per- PERFP, 21,]136 ,7] ll — MIN D.. WR stiTR FIuw M11*11l 2K-30 I sy#i T"b 6) i Bt IRRSI i pep i 811.-1 Mid i (8811 I Vol 8'..IEM KUP F. JD 2K-30 ConoboPhillips AIBSka. Ir1C. Dab SVflFACE: GAS WS GR$ NIPPIE: 11,]tlT 1 1 Spar ToPI3H01 I BMIMBI Om. I SXmrtrent Flux! yon) I Vd woY sot PERFP.205140.20.5 0- i 1 18,661,0 18,6630 81192017 HYBOR G 3520, <Auidryp> 86. 501 591! LOWTOB: 11.iP1.e l0WTDRnUm.e 2 18,661,01 18,683.0 B119/2017 HYBOR GMe, <8uidryp> 118.48 122.E 3 1s661.TF 18,6630 8119/2017 HYBOR G 350, <AuiEty, 17645 192.E MULE SHOE: 11'.. 4 18,6610 18,663.0 811912017 HYBOR G 35e, <AuIdW 189.84 213.5 5 18,661.0 18,6630 8119201) NOR G 35e,<fiuidryp> 189.97 217.5 6 18,661.0 18,6630 81191201) IHYBOR u me,<Buidryp> 19309 2225 ITERMEOPM.37s11. T.o ] 16.6610 I 18663.0 &1912017 HYBOR G 35e, c0uidryp> 11 69 11.] PwpWnl Oes rvl pb) wppnntln Fwmdlon ppl Dae 1011,8]6.5 81192017 Hy4rmiM Fmwm:lz,a4.o 1 ' 3timulatlons & Treatments vd Clean Pump sipa IP ( --j film inrc3l om sllnurrtae Fwn Ibbq Vol3mrry lbb .pm. Frecm.: 12,m4.o 1 1 1 19,1840 19,186.0 8/192011 1 HYBOR G 35A,<Ouidryp> 603.)0 fi06] 2 19,1840 19,186.0 8/19/2017 HYBOR G 35e,<fluidryp> 3 19.184.0 19,1860 8119201) HVBORG35p, <fluMryp> 1]8.83 1931 4 19,184.0 19,186.0 6/19201] HYBORG35Y, eAubryp' 190.02 2133 eybaecF .13.2250 1 1 5 19,184.0 19,186.0 8/192017 HYBOR G Me, <Auidryp> 189]0 2ID3 6 19.184.0 19,186.0 8/1912017 HYBOR G 35e, <fluidryp> 192.43 220.9 ] 19,1840 19,1860 81192017 HVBORG35e,<fiuimyp' 12.65 12.6 Hpaeuk Fadme, 13.]150 ' ' PwpWm DemgnM(M) P(oppoln FOlmalbn E) Dale 100,36].5 8119201] Stimulations & Treatments VOI Clean Pump Slgp ToplKKal SIm 19731 pale SIIMTtdtyp> tl (bep Vd31Y(ry16G Hyme.M F.<Ve; 14,M 0 1 1 t 19901.0 19,]03.0 &19201) HYBORG35#, <fluidryp> 60)]8 612& 2 19,701.0 19,703.0 &19201] HYBOR G 354, <flwdryp> 119.59 1241. 3 19,]01.0 19,703.0 &19201] HYBOR G 359, <fluidtyp> 178.51 192.1! .I.. 1.. 151mo 1 1 4 19,]01.0 19,703.0 &192(11] HYBOR G 35e,<Buidryp> -189V 213.31 5 19,701.0 19,703.0 8/19201] HYBOR G 3W, <fluidryp> 190.35 218.81 6 19701.0 19,703.0 81192017 HYBOR G Me, <fluidryp> -18767 216.11 � � ] 19,]01.0 19.]03.0&19201] HYBOR G Me Auldryp> 15.09 15.11 Hyb.YMFrcneen56le.0 P(opW nl peslBntd 11b PNppMIM Fo(mgbn pd pab ]6 91,29 8h 9201) Stimulations & Treatments NpNaub FwcWn: 18,1310 1 1 SIg1 100@688 SM 101X81 pqe SH.Mum Cleanp Vd3lurrylbM 1 20,218.0 20,220.0 &19801] HYBOR G 35e, <fluidryp> 8 559 0: XyaaM Finauw 1gm30 1 1 2 20,218.0 28220.0 &19201] HYBOR G 35e, <fluidryp> 12].5' 3 28218.0 28220.D 8119201] HYBOR G 35A,<Buidgp> ) 193.11 4 28218.0 20,220.0 81191201) HYBOR G 35N, <Avitllyp> 214.4! Xyaa„w FmWm:lTaes.O 1�1 5 28218.0 20,220.08119801] HYBOR G W,<6uidty, 1 MWO. 244.5: 6 20,218.0 20,2200 8/19201] HYBORG35e, <fluidryp> 50.1; ] 20218.0 28220.0 &19201] WATER FRAC G 35N, <fluidryp> 21 61. .0.. F. Re+Bp � � 8 20,218.0 28220.0 8/19201] Sea WaW 4uidryp> 0.0E9 202180 28220.0 8119201] WATERFRAC G 30e-SBM(1534]), 55.61.<Auidryp>10 28218.0 20,220.0 8119201] O.0 Hmmec F-uee, 19.IXo Mandrel Inserts e" 0 Lu.. Tap (ND) Vdw tete pM Sba TW Bun I XybauBC Frecwra:l&E8f0 1 1 Tap 6tl(01 (IS01 Mahe MOGeI Op Dn) SmTyye Type Dn1 (WII IMn Dan Com Hmraec Fn> ,19.1840 1 1 .p .1....191010 1 E .empe. F. 20,2180 1 � 1 PERFP, M.MG,n,4 O PERFP.205140.20.5 0- i PERFP:XLT93.0-Ma120- . I� PERFP.20MLL.WO-- 1 �� PERFP:2111d621,1%0� I= PERFP:21,Mp-lo.3160� PERFP 21,434.6310]0.0 PERFP 21 5060-31,6370 _ PERFP.21,713621.JU O� STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION NECEIVED AUG 2 2 2017 WELL COMPLETION OR RECOMPLETION REPORT A 1a. Well Status: Oil 2] Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1b. Well Class: 20AAC 25 IM 20AAC 25.10 Development [Z, Exploratory El GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: I12.4f2949� 7ILI1r; 14. Permit to Drill Number / Sundry: 217-072 , 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 6/16/2017 50-103-20758-00-00 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: 139' FNL, 94' FEL, Sec 11, TI ON, ROBE, UM 7/10/2017 KRU 2K-30 , Top of Productive Interval: 9. Ref Elevations: KBA54.91 17. Field / Pool(s): 2227' FNL, 144' FEL, Sec 15, T10N, ROSE, UM GL: 115.7 BF: Kuparuk River Field/Kuparuk River Oil Po Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1637' FNL, 1484' FEL, Sec 27, T1 ON, R08E, UM N/A ADL 25588, ADL 25605, ADL 25604, ADL 25607 41b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 498310 y- 5938165 Zone- 4 22055/6437 , 2674, 2675, 2677, 2678 TPI: x- 492985 y- 5930801 Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- 491650 y- 5920833 Zone- 4 N/A 1532/1505 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 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, rasing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM PULLED 20 154.9 GRX52 39 130 39 130 142 Driven 103/4 45.5 L-80 39 3309 39 2840 13.5 1377 sx 11.0 ppg LiteCrete, 75/8 29.7 L-80 37 11957 37 6366 11 658 sx 15.8 ppg, Class G 41/2 12.6 L-80 11796 21914 6358 6436 6.75 Liner 24. Open to production or injection? Yes ❑Z No ❑ 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perf l): SIZE DEPTH SET (MD) PACKER SET (MD/fVD) 31/2 11824 11724/6354 FRAC SLEEVE @ 12224 MD and 6380 TVD FRAC SLEEVE @ 12704 MD and 6394 TVD FRAC SLEEVE @ 13225 MD and 6402 TVD FRAC SLEEVE @ 14651 MD and 6443 TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes E]No ❑� FRAC SLEEVE @ 15128 MD and 6447 TVD Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED FRAC SLEEVE @ 15648 MD and 6456 TVD FRAC SLEEVE @ 16130 MD and 6453 TVD COMPLETION FRAC SLEEVE @ 16613 MD and 6447 TVD DATE, FRAC SLEEVE 17096 MD and 6453 TVD FRAC SLEEVE @ 17619 MD and 6468 TVD VERIFIED FRAC SLEEVE @ 18139 MD and 6478 TVD FRAC SLEEVE @ 18661 MD and 6491 TVD -- - - FRAC SLEEVE @ 19183 MD and 6497 TVD FRAC SLEEVE @ 19701 MD and 6470 TVD 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): WAITING FOR HOOK-UP Date of Test: Hours Tested: I Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period Flow Tubing P Casing Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity -API (torr): Form 10-¢OK7�R igeeQ7�017 p`n l 2ll,l� CONTINUED ON PAGE 2 RBDtIIIS (l. AUG Y 5 2Q1%Submit ORIGINIAL onlG 28. CORE DATA Conventional Core(s): Yes ❑ No F±1 Sidewall Cores: Yes ❑ No E] If Yes, list formations and intervals cored (MDrTVD, 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 1532 1505 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 11966 6368 information, including reports, per 20 AAC 25.071. Formation @ TPI - Kuparuk A W Salk D 2287 2167 C-80 4140 3213 C-37 8252 5031 HRZ 10436 5993 Kalubik 10964 6201 Kuparuk C 11286 6290 Kuparuk A5 11453 6324 TD 22055 6437 Formation at total depth, Lower Kalubik 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematics Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, len I production I test results,r 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: Jake Voss Authorized Title: Alaska Drilling Manager Contact Email: LaLkc.voss co cora Authorizedoo� Contact Phone: 265-6935 iif Signature: 22120,1 -�_ _.� Date: V INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. , Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only v KUP PROD Conn P illip5Nell Atttib, (#eske, irlC. � weupam APwpn Fmle NONE I I 11-ASTWO' 2K-30 aMa .......... .............. ........ .IewcER.x5- ........................ ......._.... /,nnofaWn DnpN lflttBl En40M LAST TAG: L- Mae BY EM s REV REASON: NEW WELL REASONjennalt 7242011 .__......_ ................ ......_............ ... .... axing mings 2T¢ONCULTOR:3B.B1ID.8 Let: ° cramp De.cripron 21 CONDUCTOR oDpio to On 20 18.500 Top IBMB) sefomm 386 like) Bel pope OVD).-WILnll... Grave 129.6 129.6 154.19 GRX52 TOPTnmaa caelnp o""Uun SURFACE ODpij to 0&4 9950 Tpp Kate) See 3816 Depth )BNB) SN DepN tllhdj. Witten (I... Gmee 3,308.9 2,839.9 45.50 L-80 Top Thr.. HydU563 cbinp 0ewlptlon ODlln) l)pio Tep MK01 3H (WBJ -WBI SN DepM IIVD)... WNen p... Grave -P IDreae 6URFACE3Gap3a'a INTERMEDIATE 7518 6.8]5 37.4 11,95]0 6,367.9 29]0 LA0 Hyd563 WS MFi: s}M1) LINER Cexnpflon LINER OD(In 412 ID llnl 3.980 iapl 1 Se[DePek 11)96.8 IBk81 See Dep01(NDIWDLen 11... Greve 21,914.0 6,4360 1260 LA0 iop Th,vae Hid 563 Liner Details GAsuFT:aema G1514'T: 9,sli.T TapinkB) Tap nrlOr lBKe) roplrol r) IMm Des core Noires'to Gxs uFr: e,eres 11.816.7 6,359.1 86.64 NIPPLE(RS) EWef55-W Recite Seal Nipple 165 opt LAO Hyd 563 box x box 4250 GAS OUT. 10We 11,819.0 6,359.3 86.64 HANGER Baker 5.5'x7.625'Flex-Lock Liner Ha7g` 125 4.800 GPUGE /PUMP SENSOR, .apes Hyd 563 pin x pin 12,000.9 6,3)0] 88.41 SWELL Baker -"Swell Packer#D-b" 699"00 3.910 v,ap.: 11.723.9 PACKER NIvpLE: 11,7w T 12,224 0 6,379.9 8802 FRAC SLEEVE Baker Frac Point #16,2.6110" Ball seat IU Bak OD 26W LocArDR: 15,T¢Ee 2.695", driMd w12.645" OD Ball LOD.xroR:n}93a 12442.] 6387.4 8].99 SWELL Baker -"Swell Packer #16- "P" 5.99"00 3.910 Mum SHOE: 11e 0_:::: PACKER 12,703.8 6,394.5 88.41 FRAC SLEEVE Baker Frac Poise #15,2.610" Ball seat ID, Ball OD 2610 2.645", drifted w12.595" OD Ball wTERMEDIATE: 3T4n,93/.0 12.9622 6,4000 89.16 SWELL PACKER Baker -"Swell Packer #15-"0"6W'OD 3.910 13,224] 6,402.2 90.90 FRAC SLEEVE Baker Frac Point p14, 2.580" Ball leak Ba11 OD 2.580 2595", drifted W 2.545"OD Ball 13,446.5 6,400.7 90.35 SWELL Baker -"Swell Reck¢t#10. "N' 6.00"OD 3.920 PACKER 13,706.3 6,4018 89.57 FRAC BLEEVE Baker Frac Point #13,2.510" Ball seat BallOD 2.510 2.545', United w12495" OD Ball 13,928.3 6405.1 8863 SWELL Baker -"Swell Packer #13-"M"5.950D 3.900 PACKER 14,390.0 61426.1 05.58 SWELL Baker -"Swell Packer #12- "L' 6,00" GO 3.910 PACKER 14,650.9 6,4426 88.80 FRACSLEEVE Baker Frac Point #12,2.470- Ball seat ID,Ball OD 2,470 2.495", drifted w12.455" OD Ball 14,9079 6,445.9 8952 SWELL Baker -"Swell Packer #11-"K'5.99"OD 3.920 PACKER 15,127.9 6,4467 89.70 FRACSLEEVE Baker Frac Point #11,2430" Ball seat ID, Ball OD 2AW 2.455", drifted w12.415" OD Bell 15,3848 6,4497 8891 SWELL Beier -"Swell Packer #10. "8' 6.W UD 3.900 PACKER 15,648.3 6,455.3 88.47 FRAC SLEEVE Baker Frac Poiret #10, 2.390" Ball seat ID, Ball OD 2.390 2.415", drifted wl 2.375" OD Bell 15,9075 6,460.1 90]9 SWELL Baker -"Swell PackW# -1"6.01"00 3.900 PACKER 16,130.0 6,453.5 92.10 FRACSLEEVE Baker Frac Point ll9, 2.350' Ball seat lD, BallOD 2.350 2375", drafted wf 2.335" OD Ball 16,3494 6,4483 91.15 SWELL Baker -"Swell Packer #8-"H"602"00 3920 PACKER 16.613.0 6,447.5 89.48 FRACSLEEVE Baker Frac Prior 48,2.310' Ball seat lD, Ball OD 2.310 2.335', drifted ad 2,2W OD Ball 16,872.8 6,450.7 8904 SWELL Baker -"Swell Packer #7-"G"6.00"OD- 3.900 PACKER 0,095.9 6455.3 88.69 FRACSLEEVE Baker Frac Point 117,2270" Ball seat ID, Ball OD 2270 2.295", drifted w/ 2.255 OD Ball 17,3528 6,481.9 86.32 SWELL Baker -'Swell Packer#6-"F" 6.01"OD 3900 PACKER 17,619.4 6,4671 89.15 FRAC SLEEVE Baker Frac Point #8, 2.230" Ball seat ID, Belt OD 2.230 2.255", drifted .12.21500 Bell 17,8789 6,4]1.8 89.15 SWELL Baker -"Swell Packer #5 E- 6.1Z OD 3.900 PACKER 18,139.4 6,478.1 8735 FRACSLEEVE Baker Frac Point 115.2.197 Ball seat ID, Bel OD 2.190 2215'. drifted w/ 2.175" OD Ball 18,398.5 6,487.1 88.36 SWELL Bake,- SweU Packer its. "D" 6,02 OD 3900 PACKER as 1 18,661.2 6,4910 90.25 FRAC SLEEVE Baker Frac Pant #q 2150" Ball seat ID, Ball OD 2.150 2.175", drafted w12.135.OD Ball 18,922.3 6,4909 90.0] SWELL Beker-"Swell Packer #&'C"5.99"OF- 3.900 1 WePACKER kae 19,183.8 6,487.0 91.67 FRACSLEEVE Baker Frac Point #3,2.119' Ball seat lD, Ball OD 2110 2.135', driftedw/2.096" OD Bell 19,442.1 6.4778 92.40 SWELL Baker -"Swell Packer k2 -"B"6010 3900 PERWI MM.0-24.1320PACKER i PEAFP, m,5laom,sss(l - 19,701.1 SAWS 90.85 FRACSLEEVE Baker Frac Point 92.2070'Bell seat 15, 8.I1OD 2.095", drifted W 2p55" OD Bail 20]0 PERFP: 20 MIC0.e320- - 19,95].] 8,4706 90.10 SWELL Baker -"Swell Packer#1-"A"6.W"OD 3890 PERFP: XwN2.0-2pk = - PACKER II PERFRm113,( o= - 20,2185 8,46].9 9225 FRACSLEEVE I Baker Frac Point #1,2030"Ball seatlD, Ball OD 2055", drifted w12.015" OD Ball 2.030 PERFP_ , $1.2Fv 621,3180 - - PERFP 21,&.4730 PERFP: 215Ba.XiPalO21.Wi.0� PERFP: 21.713 GM.351.0� Tubing Strings TUEin9 Daxripeon TUBING 44inp MB... 3112 ID lin Top 2.992 lflk8) 8ef 34.5 [Iep8274.. sdo"Me Z5'9'... WI(Idl# Grave EUE-a 11,824.0 6,359.6 9.30 LA0 EUE-m neclbn LINER: 11,)%.621,9140� KUP PROD Top NtKE) Top (WD) PIKE) Hem Dee REDUCING LIRT. 5.041.1— 6,352,3 86,37 PUMP HES ROD GMugE 287 GAS UP7. a.M,3— SENSOR —6,3578 —86,68 GAS 11"; 117928 LOCATOR F.-k—.1Sh.8r pinned no go Lao;e OD above lacefled —3 ODD NIPPLE. 11.7407— -- ass 21,596.0 21.631T, s 54,9 9 435v 7QM017 2147130 "..0 lr2V2U 17 Mandrel Inserts at an T Top(—) To M Valve Laech PodSoo TRO Run men Make Model OD na) Sen, PnPa Twa (w) (W) RU.DEW Con, Notes; General & Safety PERIFP 2K-34 (Gulper) ConocoPhillips Grassroots Horizontal A -Sand Producer Proposed Wellbore Schematic(wp12) Last Edited: 4-r' Hee. lop jout is 4-W 12.6# IBTIJ IQem 7/25117 20" Conductor to —179' 13.5" Surface Hole Top West Sak: 2321' AD/ 2199' TVD Bme West Sak: 3315' MD/ 2742' TVD i— x 1" Gamco KBMG GUN JSurface Casina 10-3W'45.5# L-80 Hydril 563 3,270'MD/3,309'TVD(61- INC) GLM vA SOV 9-7/8" x 11" Intermediate Hole 7ubina: 3-112" 9.3 # L-80 EUE 8RD-MOD C37:'8464`IAD r 5110' TVD Fauk: — 9755' MD C-35:97 M0 f 5676',NU cp G G c - 321.' z 7-513", Preinier Parker HR2: 10425'MDI5970'TVD 3-''2.75"0 Hipple Kalubilc 10738'MO/6105'TVD w HES DHG-_..�.. -.. _ 7-5r8'x5-'"Bala:r7XP PackedFlex Lock Liner Hanger Intermediate Casing 7-5/8" 29.7# L-80 Hyd563 Casing 11,957 MD / 6,368' TVD (85n INC) 713' IAD 16350' ND TD: 22,055'FAD / 6.438' TVD Production Liner. 6-3/4" Production Hole 4-1/Z'12.6# L-80 Hydril 563 21,914' MD / 6,438' TVD Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Tnne Our (hr) Phase Op code Agrvi Code h Time P -T -X O partition n De Stetl Depth EM Depth (ftKB) 6/14/2017 6/14/2017 1.50 MIRU MOVE RURD P Continue disconnecting service lines 0.0 0.0 13:00 14:30 at interconnects. SIMOPS Stage rockwasher at end of pad. 6/14/2017 6/14/2017 3.00 MIRU MOVE MOB P Pull pump, motor, pit, and pipeshed 0.0 0.0 14:30 17:30 modules away from well and stage on pad. Remove air heater from end of pump complex and set on bed truck. 6/14/2017 6114/2017 1.25 MIRU MOVE MOB P Skid rig floor. SIMOPS Install towing 0.0 0.0 17:30 18:45 tongue on sub. 6/14/2017 6/14/2017 1.00 MIRU MOVE MOB P Hook up sow truck and bulldozer to 0.0 0.0 18:45 19:45 sub. SIMOPS Slide stompers into setting for next well. 6/14/2017 6/14/2017 1.50 MIRU MOVE MOB P Pull sub off 2K-32 - observe rig mats 0.0 0.0 19:45 21:15 uneven and sinking in. Stage sub on edge of pad to perform dirtwork. Remove all dg mats from in front of 2K -30. Observe top layer of pad still covered with ice under rig mats. 6114/2017 6/15/2017 2.75 MIRU MOVE MOB T Toolhouse perform dirt work in front of 0.0 0.0 21:15 00:00 2K-30 to prep for spotting rig. Remove dirt with ice still in it and haul in fresh gravel and level pad. SIMOPS Tie onto comer shell at rig floor with boom crane, unpin hatch, and remove cover. Changeout drilling line spool. 6/15/2017 6/15/2017 5.00 MIRU MOVE MOB T Toolhouse continue prepping pad, 0.0 0.0 00:00 05:00 haul in new gravel and level out. SIMOPS Install guard on drilling line spool. Change out willis choke on rig floor bleeder. Install studs on surface annular system and install hydraulic hoses on knife and annular valve. Note: Total of 1 x load of junk ice/gravel mixture stripped out of pad in front of 2K-30 and hauled off and 6 x loads new gravel hauled in to level pad for rig. 6/15/2017 6115/2017 1.00 MIRU MOVE MOB P Lay rig mats for sub. 0.0 0.0 05:00 06:00 6/15/2017 6/15/2017 2.00 MIRU MOVE MOB P Spot sub over 2K-30 and set down 0.0 0.0 06:00 08:00 back stomper jacks. 6115/2017 6/15/2017 1.00 MIRU MOVE MOB P Skid dg floor. SIMOPS Remove tow 0.0 0.0 08:00 09:00 tongue from sub, level pad for placing pits, and lay rig mats. 6/15/2017 6/15/2017 0.50 MIRU MOVE MOB P Spot pit module. 0.0 0.0 09:00 09:30 6/15/2017 6/15/2017 1.00 MIRU MOVE MOB P Level pad for pump and motor 0.0 0.0 09:30 10:30 modules. Lay rig mats and spot pump module. 6/15/2017 6/15/2017 1.00 MIRU MOVE MOB P Lay rig mats and spot motor module. 0.0 0.0 10:30 11:30 6/15/2017 6/15/2017 2.00 MIRU MOVE MOB P Hook up sow to pipe shed and spot in 0.0 0.0 11:30 13:30 place. Continue hooking up interconnects and torque bolts on diverter system. Page 1145 ReportPrinted: 7/31/2017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Siert Time End Time Ow(M) Phase op CMe Activity CMe Time P -T -X Operation Start Depfll (WS) EM Cepm MKS) 6/15/2017 6/15/2017 1.50 MIRU MOVE RURD P Spot rockwasher. Spot cuttings box 0.0 0.0 13:30 15:00 and install berms. Raise and secure pipe skate. Secure landings and handrails. Rig accepted at 15:00 hrs. 6/15/2017 6/15/2017 2.00 MIRU MOVE NUND P Nipple up surface riser. Post diverter 0.0 0.0 15:00 17:00 signs, take on fluid, and start building 580 bbls unweighted spud mud. 6/15/2017 6/15/2017 3.50 MIRU MOVE RURD P Clear floor and install mousehole. 0.0 -6-0- 17:00 20:30 Change out handling equipment to 5", make up 2 x joints of 5" DP and function diverter. Pull measurements for rig elevation sheet. 39.91' from RKB to top punch mark on conductor. RKB to MSL = 154.91'. Continue building spud mud per mud engineer. 6/15/2017 6/15/2017 1.00 MIRU MOVE BOPE P Perform diverter test, witness waived 0.0 0.0 20:30 21:30 by AOGCC rep Brian Bixby. Bag closed in 18 seconds, knife valve opened in 8.5 seconds. For koomey lest, initial pressure 3150 psi. Pressure after functioning = 2000 psi. System built 200 psi in 7 seconds with 2 x electric pumps. Full pressure attained in 46 seconds with 2 x electric pumps and 2 x air pumps. 6 x N2 bottle average = 2200 psi. Tested gas and pit alarms. Tested rig evacuation alarm. Confirm no ignition sources near diverter line and signs posted. SIMOPS Load 5" DP in shed and continue building spud mud. 6/15/2017 6/15/2017 2.00 MIRU MOVE PULD P Finish strapping and tallying 5" DP 0.0 0.0 21:30 23:30 and start making up stands in mousehole and racking back in derrick. Tagged up at 49.25' MD. SIMOPS Continue building spud mud. 6/15/2017 6/16/2017 0.50 MIRU MOVE SVRG P Service pipe skate. 0.0 0.0 23:30 00:00 6/162017 6/16/2017 4.50 MIRU MOVE PULD P Pick up and rack back total of 33 x 0.0 0.0 00:00 04:30 stands 5" DP (regular pipe dope - MUT 28,000 ft -lbs). 6/162017 6/162017 1.00 MIRU MOVE PULD P Pick up jar stand and 5 x 5" HWDP 0.0 0.0 04:30 05:30 stands and rack back in derrick. 6/16/2017 6/16/2017 1.25 MIRU MOVE BHAH P Mobilize BHA components to dg floor 0.0 0.0 05:30 06:45 and hold PJSM for BHA. 6/16/2017 6/16/2017 1.50 MIRU MOVE BHAH P Pick up and rack back 2 x 7" NMDC w/ 0.0 0.0 06:45 08:15 9-3/4" NM stab, saver sub, and 1 x jt 5" HWDP. Pick up 8-1/4" PowerPak mud motor w/ 1.5" bend and 13-3/8" stabilizer and make up 13-1/2" Baker VM -3 bit w/ 4 x 18's. 6/16/2017 6/16/2017 0.50 MIRU MOVE SEQP P Run in w/ 1 z stand 5" HWDP, fill 0.0 50.0 08:15 08:45 conductor and lines with spud mud and check for leaks - none observed. Pressure test mud lines to 3500 psi and check for leaks - none observed. Page 2145 Report Printed: 7/3112017 Operations Summary (with Timelog Depths) WI 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sten Time Enq Time Dur(hr) PhaseOp Cage Ag ity Cada Time RT -X Operation SI iMDaB)pM End Depth (W13) 6/16/2017 6/16/2017 0.50 SURFAC DRILL DDRL P Spud 13-1/2" surface hole at 08:45 50.0 133.0 08:45 09:15 hrs. Cleanout conductor and new formation from 50'- 133' MD w/ 400 gpm, 430 psi on btm, 430 psi off btm, 37% F/O, 40 rpm, 1.5k Tq, 3k WOB, PUW 61 k, SOW 65k, ROT 62k w/ 0.51k Tq, MW 8.85 ppg, AST = 0, ADT = 0.58, Bit hr 0.58, Jar hr 59.51. 6/16/2017 6/16/2017 1.75 SURFAC DRILL BHAH P Pull OOH and rack back 5" HWDP 133.0 133.0 09:15 11:00 stand. Make up NM XO, 8-1/4" GyroPulse, 8-1/4" MWD, 8-1/4" NM UBHO, and NM Bottleneck XO. Scribe per MWD and GWD hands. Make up NMDC stand and run in to 133' MD. 6/16/2017 6/16/2017 1.00 SURFAC DRILL DDRL P Drill 13-1/2 hole f/ 133'- 166' MD 166' 133.0 166.0 11:00 12:00 TVD, Pump @ 400 gpm = 500 psi on btm, 460 psi off btm, 37% FO, Rotate @ 40 rpms w/ 1.5K Tq on, 0.5K Tq off, 3-5K WOB. P/U= 61 K. S/0= 65K, ROT= 62K. MW 8.85 ppg, AST=0.10, ADT= 0.26, Total Bit hours= 0.84, Total jar hours= 59.77. Note: Kicked off at 145' MD. 6/16/2017 6/16/2017 3.50 SURFAC DRILL DDRL P Directionall Drill 13-1/2 hole f/ 166'- 166.0 385.0 12:00 15:30 385' MD 385' ND, Pump @ 400 gpm = 558 psi on btm, 508 psi off btm, 56% FO, Rotate @ 40 rpms w/ 1.OK Tq on, 1.OK Tq off, 8K WOB. P/U= 74K, S/0= 78K, ROT= 75K. MW 8.85 ppg, AST=0.44, ADT= 1.51, Total Bit hours= 2.35, Total jar hours= 61.28. Note: Observe flowbox slowly filling up and not flowing as efficiently as it should. Jet flowline more often to try and help clean it up. 6/16/2017 0.75 SURFAC DRILL BHAH P Pull OOH f/ 385'- 290' and rack back 385.0 385.0 1611612017 15:30 16:15 1 5" HWDP stand. Run in with jar stand and HWDP stand to 385' MD to bury jars below rig floor. Page 3/45 Report Printed: 7131/2017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sma Time EM Time 0. hr (h) Phase CWa netivdy Cale Time P -T -X Dpe( m Siert �Pm Me) EM Depth (MB) 6/16/2017 6/16/2017 4.75 SURFAC DRILL OTHR T While staging up pumps, observed 385.0 385.0 16:15 21:00 flowline pack off and flowbox start filling up. Kill pumps and troubleshoot. Alternate betwen various let lines and observe flow back at shakers but minimal cuttings returned. Run snake as far as possible down flowline from dg floor but did not observe any obstruction. Stage pumps up slowly, observing decent flowthru at lower flow rate but once at higher rate, flowline started packing off and flowbox started filling up. Kill pumps and continue troubleshooting. Open up hatches in flowline and inspect - observe large chunk of debris upstream of butterfly valve in the 16" flowline in the pits —20' upstream of where it dumps into the shakers. Remove 90° bend in flowline to allow access to debris and break up into smaller pieces and remove from flow line. Discover chunk of debris to be hardened cement / gravel mixture. Once all debris removed and flowline 90° re -installed, jetted flowline and observed large amount of cuttings returned over shakers. Staged up pumps slowly and observed no further issues. 6/16/2017 6/17/2017 3.00 SURFAC DRILL DDRL P Directional] Drill 13-1/2 hole f/ 385'- 385.0 604.0 21:00 00:00 604' MD 602' TVD, Pump @ 450 gpm = 700 psi on btm, 664 psi off trim, 37% FO, Rotate @ 40 rpms w/ 1-2K Tq on, 1K Tq off, 6-8K WOB. P/U= 78K, S/0= 83K, ROT= 81 K. MW 9.35 ppg, AST=0.99, ADT= 1.72, Total Bit hours= 3.55, Total jar hours= 62.48. 6/17/2017 6/17/2017 6.25 SURFAC DRILL DDRL P Directionall Drill 13-1/2 hole f/ 604'- 604.0 1,099.0 00:00 06:15 1099' MD 1092' TVD, Pump @ 500 gpm = 1200 psi on blm, 970 psi off btm, 39% FO, Rotate @ 40 rpms w/ 3- 5K Tq on, 2K Tq off, 10-24K WOB. P/U= 87K, S/0= 91 K, ROT= 87K. MW 9.6 ppg, AST=2.5, ADT= 3.58, Total Bk hours= 7.13, Total jar hours= 66.06. 6/17/2017 6/17/2017 0.50 SURFAC DRILL SVRG P Service lop drive. 1,099.0 1,099.0 06:15 06:45 6/17/2017 6/17/2017 1.25 SURFAC DRILL RGRP T Troubleshoot topdrive. Rack back 1,099.0 1,099.0 06:45 08:00 stand and adjust encoder belt on the encoder. Function test top drive and confirm working correctly. Run in hole back to bottom. Page 4146 Report Printed: 7/31/2017 Operations Summary (with Timelog Depths) WaN ) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time EM Time Daft) Phase op Code Aclivrty Code Time RT-X ope m Start DePM (MS) End Depth (ftKB) 6/17/2017 6/17/2017 4.00 SURFAC DRILL DDRL P Directionall Drill 13-112 hole f/ 1099'- 1,099.0 1,440.0 08:00 12:00 1440' MD 1419' TVD, Pump @ 500 gpm = 1100 psi on btm, 977 psi off btm, 39% FO, Rotate @ 40 rpms w/ 3- 5K Tq on, 2K Tq off, 12-25K WOB. P/U= 100K, S/0= 96K, ROT= 97K. MW 9.6 ppg, AST=1.45, ADT= 2.32, Total Bit hours= 9.45, Total jar hours= 68.38. 6/17/2017 6/17/2017 6.00 SURFAC DRILL DDRL P Directionall Drill 13-1/2 hole H 1440'- 1,440.0 1,915.0 12:00 18:00 1915' MD 1854' TVD, Pump @ 600 gpm = 1667 psi on btm, 1426 psi off btm, 39% FO, Rotate @ 60 rpms w/ 5K Tq on, 3K Tq off, 24K WOB. P/U= 113K, S/O= 106K, ROT= 110K. MW 9.6 ppg, AST=1.54, ADT= 3.08, Total Bit hours= 12.53, Total jar hours= 71.46. 6/172017 6/18/2017 6.00 SURFAC DRILL DDRL P Directionall Drill 13-1/2 hole f/ 1915' - 1,915.0 2,558.0 18:00 00:00 2558' MD 2384' TVD, Pump @ 750 gpm = 2281 psi on btm, 2085 psi off btm, 45% FO, Rotate @ 60 rpms w/ 5K Tq on, 3K Tq off, 24K WOB. P/U= 121K, S/O= 109K, ROT= 117K. MW 9.65 ppg, Max Gas = 137 units, AST=1.82, ADT= 3.58, Total Bit hours= 16.11, Total jar hours= 75.04. Note: Observed hole unload cuttings once staged up from 600 to 700 gpm and again once up to 750 gpm. No downhole losses observed for past 24 hours 6/18/2017 6/18/2017 4.00 SURFAC DRILL DDRL P Directionall Drill 13-1/2 hole f/ 2558'- 2,558.0 3,019.0 00:00 04:00 3019' MD 2685' TVD, Pump @ 750 gpm = 2400 psi on btm, 2250 psi off btm, 47% FO, Rotate @ 60 rpms w/ 8K Tq on, 5K Tq off, 25K WOB. P/U= 124K, S/O= 114K, ROT= 121K. MW 9.6 ppg, AST=0.85, ADT= 2.90, Total Bit hours= 19.08, Total jar hours= 78.01. 6/18/2017 6/182017 1.00 SURFAC DRILL OTHR T Observe flowline pack off and flowbox 3,019.0 3,019.0 04:00 05:00 start filling up at dg floor. Kill pumps and clear flowline. Slowly establsih, circulation and stage up pumps until flowline clean and able to sustain drilling rate without blinding off shakers. Observe thick mud coming out of hole, -500 vis. Mud going in at -220 vis. SIMOPS Change out swab on mud pump #1 and Quadoo change out pump on Totoo gaswatch system. Page 5/45 ReportPrinted: 7/3112017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sian TM EndTvne Dur(M) Phase op Coda Activity Code Tirm P -T -x ppe.a. Start Depth (ftKB) End nepth(flKB) 6/18/2017 6/18/2017 1.00 SURFAC DRILL DDRL P Directionall Drill 13-1/2 hole V 3019'- 3,019.0 3,075.0 05:00 06:00 3075' MD 2718' TVD, Pump @ 750 gpm = 2480 psi on btm, 2300 psi off blm, 47% FO, Rotate @ 60 rpms w/ 8K Tq on, 5K Tq off, 25K WOB. P/U= 125K, S/O= 114K, ROT= 122K. MW 9.6 ppg, AST=0.14, ADT= 0.56, Total Bit hours= 19.64, Total jar hours= 78.57. 6/18/2017 6/18/2017 3.50 SURFAC DRILL DDRL P Directionall Drill 13-1/2 hole f/ 3075' to 3,075.0 3,319.0 06:00 09:30 TD of 3319' MD 2845' TVD, Pump @ 750 gpm = 2560 psi on btm, 2366 psi off btm, 47% FO, Rotate @ 60 rpms W/ 8K Tq on, 5K Tq off, 25K WOB. P/U= 131 K, S/0= 109K, ROT= 118K. MW 9.6 ppg, AST=0.59, ADT= 2.03, Total Bit hours= 21.67, Total jar hours= 80.60. 6/18/2017 6/18/2017 1.50 SURFAC CASING CIRC P Circulate 2 x bottoms up w/ 750 gpm, 3,319.0 3,319.0 09:30 11:00 2250 psi, 60 rpm, 5K Tq while reciprocating off bottom. Obtain final survey at TD. 6/18/2017 6/18/2017 0.50 SURFAC CASING OWFF P Monitor well for flow for 30 minutes- 3,319.0 3,319.0 11:00 11:30 well static. 6/18/2017 6/18/2017 5.25 SURFAC CASING BKRM 5 Backream OOH 1/3319'- 1709' MO w/ 3,319.0 1,709.0 11:30 16:45 750 gpm, ICP 2235 psi, FCP 1934 psi, 60 rpm, 2-4k Tq, ROT 103k. 6/18/2017 6/18/2017 1.50 SURFAC CASING BKRM P Backream OOH f/ 1709' - 1515' MD w/ 1,709.0 1,515.0 16:45 18:15 750 gpm, ICP 1934 psi, FCP 1743 psi, 60 rpm, 3k Tq. Stop and re -shoot surveys per SLB at 1670', 1576', and 1515' MD. Slow pulling speed to circulate 2 x bottoms up prior reaching permafrost. 6/18/2017 6/18/2017 0.25 SURFAC CASING OWFF P Blowdown topdrive and monitor well 1,515.0 1,515.0 18:15 18:30 for flow - well static. 6/18/2017 6/18/2017 1.00 SURFAC CASING TRIP 5 Pull OOH on elevators f/ 1515'- 763' 1,515.0 763.0 18:30 19:30 MD, monitoring displacement via pit #1, PUW 107k SOW 100k. Observe 25k overpull at 815' MD. Work through section several times to wipe clean and continue OOH. 6/18/2017 6/18/2017 1.25 SURFAC CASING SHAH P Pull OOH on elevators racking back 2 763.0 101.0 19:30 20:45 x stands 5" DP, laying out 4 x stands 5" HWDP, and racking back 1 x stand 7" NMDC to 101'. 6/18/2017 6/18/2017 1.50 SURFAC CASING BHAH P Pull OOH on elevators and lay down 101.0 0.0 20:45 22:15 13-1/2" drilling BHA #2. Observe upper 9-3/4" stabilizer, 13-3/8" mud motor stabilizer, and bit balled up with clay. All stabilizers were in gauge. Bit was overall in good condition and was 1/16" undergauge with a few worn teeth. Graded 1 -1 -WT -A -E -1 -NO -TD. Actual displacement = 36.8 bbls, Calculated displacement = 36.8 bbls. 6/18/2017 6/18/2017 U. SURFAC CASING BHAH P Clean and clear rig floor of BHA 0.0 0.0 22:15 23:00 equipment. Page 6/45 ReportPrinted: 7/31/2017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL rime Log Start Time End Time Our (hr) phase Op code Activity Code Time Pd -X Opembon Stan Depth (ftKB) End Depth (ttK8) 6/18/2017 6/19/2017 1.00 SURFAC CASING RURD P Mobilize GBR casing equipment to rig 0.0 0.0 23:00 00:00 floor and start rigging up to run 10-3/4" casing. 6/19/2017 6/19/2017 0.25 SURFAC CASING RURD P Finish rigging up GBR Volant and 0.0 0.0 00:00 00:15 casing equipment for running 10-3/4" casing. 6/19/2017 6/19/2017 0.25 SURFAC CASING SFTY P Hold PJSM for running 10-3/4" casing. 0.0 0.0 00:15 00:30 6/19/2017 6/19/2017 1.00 SURFAC CASING PUTS P Make up 10-3/4" shoe track with 0.0 160.0 00:30 01:30 Downhole Products float shoe and float collar, bakerlocking shoetrack and pin of joint #4, torque to 21,500 ft - lbs w/ Volant tool. Install Weatherford set -screw stop ring 10' above shoe, 10' below box on shoe joint, and 10' below float collar. Install Downhole Product 10-3/4" x 13-1/2" bowspring centralizer over each stop ring. Fill pipe and pump through floats at 3-4 bpm, total 18 bbls pumped. Pick up 60' and run back in - confirm floats holding. 6/19/2017 6/19/2017 4.50 SURFAC CASING PUTB P Continue running in with 10-3/4" 45.5# 160.0 1,575.0 01:30 06:00 L-80 Hydril 563 Dopeless casing per tally from 160'- 1575' MD, filling pipe on the fly with Volant tool and topping off every 10. Torque connections with Volant tool to 21,500 ft -lbs. Install Downhole Products 10-3/4" x 13-1/2" bowspring centralizer over each collar. 6/19/2017 6/19/2017 1.00 SURFAC CASING CIRC P Stage up pumps to 6 bpm / 130 psi 1,575.0 1,575.0 06:00 07:00 and reciprocate pipe from 1575'- 1530' below permafrost and circulate 2.5 bottoms up until returns deaned up, total 2800 strokes pumped, PUW 150k, SOW 88k. 6/19/2017 6/19/2017 5.00 SURFAC CASING PUTB P Continue running in with 10-3/4" 45.5# 1,575.0 3,188.0 07:00 12:00 L-80 Hydril 563 Dopeless casing per tally from 1575'- 3188' MD, filling pipe on the fly with Volant tool and topping off every 10. Torque connections with Volant tool to 21,500 ft -lbs. Install Downhole Products 10-3/4" x 13-1/2" bowspring centralizer over each collar. Actual displacement = 27.5 bbls. Calculated displacement = 52.5 bbls. 6/19/2017 6/19/2017 0.75 SURFAC CASING PUTB P Start washing down as we started 3,188.0 3,267.0 12:00 12:45 pushing fluid away. Wash down at 2.5 bpm, 150 psi with 10-3/4" 45.5# L-80 Hydril 563 Dopeless casing per tally from 3188'- 3267' MD, SOW 115k. Torque connections with Volant tool to 21,500 ft -lbs. Install Downhole Products 10-3/4" x 13-1/2" bowspring centralizer over each collar except on last joint before hanger. Page 7/45 Report Printed: 7/31/2017 Operations Summary (with Timelog Depths) d 2K-30 4 b . Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Srari Time I End Time Our (hr) Phase CP Cafe ACGvity Cade Time P -T -X Operaten Slam Depth (ft B) EM Ceprii (WB) 6/19/2017 6/19/2017 0.50 SURFAC CASING PUTB P Make up FMC casing hanger and 3,267.0 3,309.0 12:45 13:15 landing joint. Wash down f/ 3267'-' 3309' wl 2.5 bpm, 150 psi, SOW 115k. Land off on [ending ring at 3309' MD. 6/19/2017 6/19/2017 3.75 SURFAC CEMENT CIRC P Circulate and condition mud, staging 3,309.0 3,309.0 13:15 17:00 up pumps to 7 bpm, ICP 250 psi, FCP 169 psi, 27% F/O, PUW 180k, SOW 128k. Reciprocate pipe fl 3309'- 3289' MD. MW in 9.65ppg, MW out 9.75ppg. Total 1455 bbls pumped. Note: Pumped 65 bbl 11.0ppg 300 Vis red -dye marker w/ 5 Ib/bb] nutplug and 3 gallons red dye. Observed nut plug and slight indication of red dye at surface and at 73 bbls early to calculated gauge hole. Observed good red dye pill at surface at 35 bbls early to calculated gauge hole. Discuss with town and decision made to maintain plan to pump 250% excess through permafrost and 50% excess below permafrost. 6/19/2017 6/19/2017 3.25 SURFAC CEMENT CMNT P PJSM. Line up cementers, pump 5 3,309.0 3,309.0 17:00 20:15 bbls Chemwash100 to flood lines. Pressure test lines to 500/3500 psi - good test. While reciprocating pipe from 3309'- 3294' MD, pump 35 btIls Chemwash100 at 5 bpm, 85 psi, 21 % F/O. Batch up and pump 72 bbls 10.5ppg MudPush II spacer at 4.5 bpm, 122 psi, 21% F/O. Drop bottom plug. Mix lead cement, wet @ 18:17 hrs. Pump 468.4 bbls 11.0ppg LiteCrete Lead slurry at 6 bpm, 320 psi, 21% F/O. First 50 bbls of lead - cement were pumped neat then started adding 1 Ib/bbl CEM -Net LCM into remaining lead slurry. Observe bottom plug land on calculated volume and take 100 psi differential to shear. Land hanger and leave landed at end of lead cement due to hole getting sticky. Mix tail cement, wet @ 19:43 hrs. Pump 61.2 bbls 12.Oppg LiteCrete tail slurry at 4.5 bpm, 220 psi, 21% F/O. Drop top plug. Kick out with 10.1 bbls freshwater at 6 bpm, 357 psi, 24% F/O. Page 8145 Report Printed: 7/3112017 Operations Summary (with Timelog Depths) 2K-30 Y Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Star) Tme EM Time Our (M) Phase Op Code Activity Code Time P.T-X OPers4on s� (fIXB) EM D"M (W) 6/19/2017 6/19/2017 1.25 SURFAC CEMENT CMNT P Line up to rig's mud pump #2 and 3,309.0 0.0 20:15 21:30 displace cement with 9.7ppg spud mud. Attempted to pump at 7 bpm but flowline kept packing off. Once flowline cleared after second time, kept rate at b bpm, ICP 430 psi, FCP 686 psi. Decreased rate to 3 bpm at 2850 strokes. Bumped lop plug on calculated at 2990 strokes at 3 bpm, 490 psi. Pressured up to 1040 psi and held for 5 minutes. Observed fluid level on backside drop -6' below rig floor once pumps were killed. Cement in place @ 21:20 hrs. 220 bbls of good 11.0ppg Lead cement returned to surface 6/19/2017 6/20/2017 2.50 SURFAC CEMENT WOC T Bleed off pressure and monitor for 0.0 0.0 21:30 00:00 flow to check floats - observe floats not holding. Bled off total 8 bbls. Shut in and observed pressure build to 140 psi. Observed fluid level on backside drop total of -20' below rig floor. Discuss with town. Pressure up above final displacement pressure to 550 psi at 3 bpm and shut in, total 3 bbls pumped. Wait on cement to attain necessary compressive strength. Flush out backside down to 4" outlets on conductor and the surface annular with blackwater really good to ensure no issue with backing out landing joint. 100 psi will be attained @ 11:30 hrs 6/20/17 500 psi will be attained @ 20:30 hrs 6/20/17 6/20/2017 6/20/2017 9.50 SURFAC CEMENT WOC T WOC to reach 100 psi compressive 0.0 0.0 00:00 09:30 strength. SIMOPS: load pipe shed with 5" DP. Rig down and blown down cement lines, clean cement valves and flow line. Clean and clear rig floor, grease crown and blocks, perform additional preventative maintenance. 6/20/2017 6/20/2017 1.00 SURFAC CEMENT RURD P Confirm no pressure no pressure 0.0 0.0 09:30 10:30 inside casing, break off cement line, RD and LD volant casing running tool. Back out landing joint and LD to pipe shed. 6/20/2017 6/20/2017 1.50 SURFAC WHDBOP NUND P RD flow riser, air boot from annular, 0.0 10:30 12:00 knfe valve and vent line. 6/20/2017 6/2012017 3.00 SURFAC WHDBOP NUND P Continue to NO diverter. Remove 0.0 0.0 12:00 15:00 lower riser, knife valve from BOP deck. RD HCR valve to allow access to RD the annular. Remove annular and FMC slip-on flange from BOP deck. Page 9145 Report Printed: 7/31/2017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sieh Time End Time Dur (hr) Phase Op Cone Ac4vM1y Code Tima P•T-X operi siert Death MKBt End Depth (WO) 6/20/2017 6/20/2017 2.00 SURFAC WHDBOP NUND P N/U FMC wellhead and obtain RKBs. 0.0 0.0 15:00 17:00 Test metal to metal seals and secondary elastomer seal to 1000 psi f/ 10 min. Test Good. Clean debris from cellar. 6/20/2017 6/20/2017 1.00 SURFAC WHDBOP NUND P NU 2' DSA and 13-3/8" x 11 " adapter 0.0 0.0 17:00 18:00 flange. NU BOPE stack. 6/20/2017 6/20/2017 3.50 SURFAC WHDBOP NUND P TO all connections on BOPE stack. 0.0 0.0 18:00 21:30 1 SIMOPS: RU MPD RCD. 6/20/2017 6/20/2017 1.00 SURFAC WHDBOP MPDA P NU MPD air valve and orient MPD 0.0 0.0 21:30 22:30 choke skid in BOP deck. SIMOPS: NU choke and kill lines. 6/20/2017 6/21/2017 1.50 SURFAC WHDBOP NUND P RU kocmey lines to BOPE stack, 0.0 0.0 22:30 00:00 charge kocmey and set test plug. FIII stack with water, install MPD test cap and shell test air valve, halliburton and RCD flange connections to 500 psi low (5 min) / 2000 psi high (10 mint. Test good. RD test cap and test equipment. 6/21/2017 6/21/2017 0.50 SURFAC WHDBOP NUND P Cont to NIU BOPE, install flow riser 0.0 0.0 00:00 00:30 and secure stack. 6/21/2017 6/21/2017 8.00 SURFAC CEMENT PULD P Pick up and stand back 5" DP in 0.0 0.0 00:30 08:30 derrick. Picked up a total of 35 stands of High torque 5" DP and 30 stands of normal DP. 6/21/2017 6/21/2017 0.75 SURFAC WHDBOP TURD P Rig up to test BOPE, install 5" test 0.0 0.0 08:30 09:15 joint, make up valve assembly and purge air from choke manifold. 6/21/2017 6/21/2017 4.25 SURFAC WHDBOP BOPE P Test all BOPE equipment to 250/3500 0.0 O.0 09:15 13:30 PSI for 5 min each with 5" test joint. Upper and lower rams 3 1/2" X 6" VBR. Koomey draw down test: System pressure = 3000 psi, 1650 psi after closure, attained 200 psi in 9 sec and full system pressure after 66 sec. 6 bottle nitrogen Avg= 2125 psi.. Tested all gas alarms, flow and PVT sensors. AOGCC rep. Jeff Jones waived witness of the test. 6/21/2017 6/21/2017 1.00 SURFAC WHDBOP RURD P Pull test plug, install 10" ID wear 0.0 0.0 13:30 14:30 1 1 bushing and secure w/ (x2) LDS. 6/21/2017 6/21/2017 2.50 SURFAC CEMENT SHAH P PJSM, P/U intermediate BHA as per 0.0 420.0 14:30 17:00 SLB if 420' MD. UP WT = 68K, DN WT = 68K 6/21/2017 6/21/2017 4.00 SURFAC CEMENT PULD P Continue single in hole forth pipe shed 420.0 2,805.0 17:00 21:00 with 75 jnts 5" DP f/ 420' MD U 2805' MD monitoring displacement via pit #1. UP WT = 107K, DN WT = 84K 6/2112017 2.00 SURFAC CEMENT SI -PC P Cut and slip 60' drill line. SIMOPS 2,805.0 2,805.0 16/21/2017 21:00 23:00 1 circulate r@ 3 bpm, 127 gpm, 140 psi, 19% F/O. Total stks pumped = 1827. Page 10/45 Report Printed: 7/3112017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Star/ Time Ertl Time Our (hr)pth phew Op Cote A, ty Cale Time P -T -X Operation Start O e (ft D Fstl Depth (flKB) 6/21/2017 6/21/2017 0.50 SURFAC CEMENT TRIP P TIH on elevators f/ 2805' MD U3087' 2,805.0 3,087.0 23:00 23:30 MD, shallow hole test MWD w/ 500 gpm, 1172 psi, 35% F/0. UP WT=124 DN WT = 100 Trip in hole calc disp = 66 bbls, actual disp = 65.9 bbl 6/21/2017 6/22/2017 0.50 SURFAC CEMENT PRTS P Rig up and pressure test 10-3/4" 3,087.0 3,087.0 23:30 00:00 surface casing to 3500 psi f/ 10 min. 6/22/2017 6/22/2017 1.50 SURFAC CEMENT PRTS P Observed pressure dropped to 3250 3,087.0 3,087.0 00:00 01:30 psi, decision made to retest. Bled off pressure, puped up sensator lines, pumped to purge out any air in the system and retested. Pressured up to 3500 psi and held f/ 30 min (GOOD). 47 strokes required to pressure up to - 3500 psi. 6/22/2017 6/22/2017 0.50 SURFAC CEMENT CIRC P RIH and tag TOC @ 3150' MD (75' 3,087.0 3,150.0 01:30 02:00 high) and establish parameters, P/U 128K, S/0=100K, ROT= 112K, Rotate @ 60 rpm's w/ 6K Tq. Pump @ 500 gpm= 1188 psi. 6/22/2017 6/22/2017 4.00 SURFAC CEMENT DRLG P Drill out plugs @ 3150' MD, DHP 3,150.0 3,219.0 02:00 06:00 Float collar @ 3225' MD, shoe track, DHP float shoe and rat hole to 3219' MD @ 400 gpm= 748 psi with 4-6K WOB. 6/22/2017 6/22/2017 0.50 SURFAC CEMENT DDRL P Drill 20' of new 9-7/8" hole f/ 3219' MD 3,219.0 3,239.0 06:00 06:30 to 3239' MD. TVD= 2854'. Pump @ 500 gpm= 1100 psi wl 42 % FO. Rotate @ 80 rpm's w/ 8K Tq on, 7K Tq off. WOB- 4-8K. P/U= 129K, S/0= 100K, ROT= 112K. ADT=.25, Bit hours -.25, Total jar hours= .25. 6/22/2017 6/22/2017 0.75 SURFAC CEMENT CIRC P POOH inside rasing shoe to 3274' 3,239.0 3,274.0 06:30 07:15 MD. Circulate and condition mud for FIT, 9.6 ppg MW in/out. 6/22/2017 6/22/2017 0.75 SURFAC CEMENT FIT P R/U and perform FIT to 15.5 ppg 3,274.0 3,274.0 07:15 08:00 EMW, pressure up to 875 psi, w/1.4 bbis pumped, bled back 1.3 bbls. 6/22/2017 6/22/2017 2.00 INTRMI DRILL DDRL P DDrill 9-7/8" hole f/ 3239' MD to 3458' 3,274.0 3,458.0 08:00 10:00 MD. TVD= 2909'. Pump @ 650 gpm= 1345 psi w/ 42 % FO. Rotate @ 80 rpm's w/ 8K Tq on, 7K Tq off. WOB- 4- 8K. P/U= 126K, S/0= IOOK, ROT= 112K. ADT=1.25, Bit hours- 1.50, Total jar hours= 1.50. Displace well to 9.6 ppg LSND mud system on the fly while drilling ahead. 6/22/2017 6/22/2017 0.75 INTRMI DRILL CIRC P Drop RFID tags and open 3,458.0 3,458.0 10:00 10:45 underreamer. At 650 gpm, 1345 psi and 3555 turbine rpm. Pump tags down to underreamer and observe pump pressure decrease to 1057 psi, turbine rpm decrease to 2734. PU and pull lest underreamer against shoe at 3309' MD, 1 OK overpull observed. Reamer confirmed open. Ream back to bottom cutting I V hole at 80 rpm. Page 11/45 Report Printed: 7/31/2017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sian Time End Time Dur(N) Phase Op Code Activih Code Time P-TA Operation Stert Depm (flKB) End DepthIfXB) 6/22/2017 6/22/2017 1.25 INTRMI DRILL DDRL P DDrill 9-7/8"x 11" hole f/ 3458' MD to 3,458.0 3,559.0 10:45 12:00 3559' MD. TVD= 2952'. Pump @ 650 gpm= 1060 psi w/ 42 % FO. Rotate @ 80 rpm's w/ 7K Tq on, 7K Tq off. WOB -4-8K. ECD 10.46 ppg, MW 9.6 ppg, max gas 0 units. , P/U= 126K, S/O= 100K, ROT= 112K. ADT=0.95, Bit hours- 2.45, Total jar hours= 2.45 SPR'S @ 3464' MD, 2908' TVD, MW 9.6 ppg, 11:00 hrs MP#1: 30 SPM - 120 psi, 40 SPM - 160 psi MP#2: 30 SPM - 120 psi, 40 SPM - 160 psi 6/22/2017 6/22/2017 6.00 INTRMI DRILL DDRL P DDrill 9-718" x 11" hole f/ 3559' MD to 3,559.0 4,127.0 12:00 18:00 4127' MD. TVD= 3207'. Pump @ 800 gpm= 1639 psi w/ 40 % FO. Rotate @ 140 rpm's w/ 3-1 OK Tq on, 3-8K Tq off. WOB- 5-10K. ECD 10.54 ppg, MW 9.6 ppg, max gas 371 units. P/U= 126K, S/0= 104K, ROT= 115K. ADT=4.67, Bit hours- 7.12, Total jar hours= 7.12. 6/22/2017 6/23/2017 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" x 11" hole f/ 4127' MD to 4,127.0 4,622.0 18:00 00:00 4622' MD. TVD= 3431'. Pump @ 800 gpm= 1844 psi w/ 40 % FO. Rotate @ 150 rpm's w/ 4-11 K Tq on, 4-8K Tq off. WOB- 9-12K. ECD 10.94 ppg, MW 9.65 ppg, max gas 14 units. P/U= 137K, S/0= 104K, ROT= 118K. ADT=4.3, Bit hours- 11.42, Total jar hours= 11.42. Swap to high line power @ 16:30. SPR'S @ 4596' MD, 3419' TVD, MW 9.65 ppg, 23:30 hrs MP#1: 30 SPM - 140 psi, 40 SPM - 160 psi MP#2: 30 SPM - 120 psi, 40 SPM - 150 psi Total losses to formation = 0 bbl Page 12/45 Report Printed: 7/31/2017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time EM End Time Dr D se Phan Op CDde Acway Cade Time P-T-X O peretion alert Oepth (fl ()e End OapMt (fU(B) 6/23/2017 6/23/2017 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" x 11" hole f/ 4622' MD to 4,622.0 5,263.0 00:00 06:00 5263' MD. TVD= 3715'. Pump @ 800 gpm= 1930 psi w/ 40 % FO. Rotate (ova 150 rpm's w/ 4-11 K Tq on, 8K Tq off. WOB- 9-12K. ECD 10.80 ppg, MW 9.65 ppg, max gas 20 units. P/U= 143K, 8/0= 11 OK, ROT= 122K. ADT=5.49, Bit hours- 16.91, Total jar hours= 16.91. 6/23/2017 6/23/2017 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" x 11" hole f/5263' MD to 5,263.0 5,789.0 06:00 12:00 5789' MD. TVD= 3946'. Pump @ 830 gpm= 2400 psi w/ 40 % FO. Rotate @ 150 rpm's w/ 4-11 K Tq on, 91K Tq off. WOB- 9-14K. ECD 10.80 ppg, MW 9.65 ppg, max gas 20 units. P/U= 147K, S/0= 116K, ROT= 128K. ADT=4.39, Bit hours- 21.3. Total jar hours= 21.3 Obtain SPR's @ 5545' MD, 3840' TVD 10:00 hours 9.6+ ppg MW MP#1: 30 spm= 180 psi, 40 spm= 240 psi MP #2: 30 spm= 190 psi, 40 spm= 230 psi. 6/23/2017 6/23/2017 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" x 11" hole f/ 5789' MD to 5,789.0 6,399.0 12:00 18:00 6399' MD. TVD= 4211'. Pump @ 830 gpm= 2577 psi w/ 41 % FO. Rotate @ 150 rpm's w/ 9-11 K Tq on, 9K Tq off. WOB-7-14K. ECD 10.80 ppg, MW 9.65 ppg, max gas 18 units. P/U= 150K, S/0= 118K, ROT= 132K. ADT=4.95, Bit hours- 26.25, Total jar hours= 26.25. 6/23/2017 6/24/2017 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" x 11" hole f/6399' MD to 6,399.0 6,954.0 18:00 00:00 6954' MD. TVD= 4453'. Pump @ 8300 gpm= 2791 psi w/ 42 % FO. Rotate @ 150 rpm's w/ 9-11 K Tq on, 9K Tq off. WOB- 7-14K. ECD 10.89 ppg, MW 9.7 ppg, max gas 54 units. P/U= 156K, S/0= 124K, ROT= 136K. ADT=4.56, Bit hours- 30.81, Total jar hours= 30.81. Obtain SPR's @ 6584' MD, 4292' TVD 20:00 hours 9.6+ ppg MW MP#1: 20 spm= 200psi, 30 spm= 240 psi MP #2: 20 spm= 200 psi, 30 spm= 240 psi. Page 13145 Report Printed: 7/31/2017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time Ems Time Our (hr) Phase Do Code A ity Code Time P-T-x Operation Stan Depth (MB) End Depth IRKS) 6/24/2017 6/24/2017 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" x 11" hole f/6954' MD to 6,954.0 7,536.0 00:00 06:00 7536' MD. TVD= 4712'. Pump @ 830 gpm= 3005 psi w/ 42 % FO. Rotate @ 150 rpm's w/ 12K Tq on, 9K Tq off. WOB- 11 K. ECD 11.05 ppg, MW 9.6+ppg, max gas 45 units. P/U= 167K, S/0= 120K, ROT= 136K. ADT=4.79, Bit hours- 35.6, Total jar hours= 35.6. Obtain SPR's @ 7059' MD, 4499' TVD 00:50 hours 9.6+ ppg MW MP#1: 20 spm= 200psi, 30 spm= 300 psi MP #2: 20 spm= 200 psi, 30 spm= 300 psi. 6/24/2017 624/2017 6.00 INTRMI DRILL DDRL P DDrill 9-7/8"x11" hole f/7536' MID to 7,536.0 8,103.0 06:00 12:00 8103' MD. TVD=4962'. Pump @ 830 gpm= 3130 psi w/ 44 % FO. Rotate @ 150 rpm's w/ 12K Tq on, 9K Tq off. WOB- 11 K. ECD 11.05 ppg, MW - 9.6+ppg, max gas 187 units. P/U= 172K, We 127K, ROT= 142K. ADT=4.72, Bit hours- 40.32, Total jar hours= 40.32. 6/24/2017 6/24/2017 2.75 INTRMI DRILL DDRL P DDrill 9-7/8" x 11" hole 1/8103' MD to 8,103.0 8,388.0 12:00 14:45 8388' MD. TVD= 5090'. Pump @ 830 gpm= 3168 psi w/ 42 % FO. Rotate @ 150 rpm's w/ 13K Tq on, 13K Tq off. WOB- 9K. ECD 11.00 ppg, MW 9.7+ppg, max gas 43 units. P/U= 173K, S/O= 135K, ROT= 149K. ADT=2.29, Bit hours- 42.61, Total jar hours= 42.61. 6/24/2017 6124/2017 0.25 INTRMI DRILL CIRC P Obtain SPRs and final MWD survey. 8,388.0 8,388.0 14:45 15:00 Obtain SPR's @ 8385' MD, 5089' TVD 15:00 hours 9.7+ ppg MW MP#1: 20 spm= 140psi, 30 spm= 200 psi MP #2:20 spm= 140 psi, 30 spm= 190 psi. 6/24/2017 624/2017 1.75 INTRMI DRILL BKRM P BROOH f/ 8388' MD to 8200' MD 8,388.0 8200.0 15:00 16:45 pumping 70 bbl high vis weighted - sweep surface to surface. Pump @ 830 gpm= 3195 psi w/ 42 % FO. Rotate @ 150 rpm's w/ 9K Tq. P/U= 173K, S/0= 135K, ROT= 149K. Total strokes pumped = 17,510 Page 14145 Report Printed: 7131/2017 Operations Summary (with Timelog Depths) 2K-30 a. ft. Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Siert Tune End Tlme Oar (hr) Phase Op code Activity Code Time P -T -X Operation Sfem Depth e) End OapM (WB) 6/24/2017 6/24/2017 0.75 INTRMI DRILL CIRC P Drop RFID tags and close 8,200.0 8,200.0 16:45 17:30 underreamer. Pump tags down @ 650 gpm, 2070 psi, 41 % F/O, 2773 tubine rpm. Reduce rate @ 900 stks V 250 gpm, 500 psi, 24% F/O. Shut down pumps @ 1600 stks. Open bleeder, rotate @ 20 rpm w/ 9K TO & PU 15'. Let reamer relax 15 min to aide in closer the cutter blocks. Confirm reamer closed w/ 650 gpm, 2355 psi, 40% F/O and 2969 turbine rpm. 6/24/2017 6/25/2017 6.50 INTRMI DRILL BKRM P BROOH f/ 8200' MD to 5950' MD @ 8,200.0 5,950.0 17:30 00:00 650 gpm, ICP = 2355 psi, FCP = 2090 psi, 39% F/O, 140 rpm, 7-9k TO, UP WT = 128K. Calculated hole fill: 10.8 bbls Actual hole flle: 17 bbls No losses for tour. 6/25/2017 6/252017 6.00 INTRMI DRILLBKRM P BROOH V 5950' MD to 3270' MD @ 5,950.0 3,270.0 00:00 06:00 650 gpm, 168o psi psi, 39% F/O, 140 rpm,5.5k TO, ECD = 10.44 ppg UP WT = 128K, DN WT = 104K 6/25/2017 625/2017 0.50 INTRMI DRILL CIRC P Circulate while rotate and reciprocate 3,270.0 3,270.0 06:00 06:30 f/ 3270' MD V 3,180' MD, pump 30 bbl hi vis nut plug weighted sweep @ 650 gpm, 1240 psi, 36% F/O, 60 rom, 4.5K TO, 10.14 ppg ECD. Total strokes pumped = 4280. 6/25/2017 625/2017 0.25 INTRMI DRILL OWFF P Drain single and OWFF (10 min.) 3,270.0 3,270.0 06:30 06:45 6/25/2017 6/25/2017 0.75 INTRMI DRILL MPDA P Pull trip nipple & install MPD bearing 3,270.0 3,270.0 06:45 07:30 assembly, drain nipple and RCD service lines. 625/2017 6252017 0.75 INTRMI DRILL MPDA P Calibrate MPD chokes, test ramp 3,270.0 3,270.0 07:30 08:15 schedules and warm up bearing. SIMOPS: Service TD, blocks and crown. 6/25/2017 6/25/2017 1.75 INTRMI DRILL TRIP P TIH on elevators f/ 3270' MD V 4982' 3,270.0 4,982.0 08:15 10:00 MD. Monitor dispalcement via trip ' tank. 6/25/2017 6/25/2017 0.50 INTRMI DRILL CIRC P Circulate while rotate and reciprocate 4,982.0 5,073.0 10:00 10:30 f/ 4982' MD V 5073' MD @ 650 gpm, 1640 psi, 45% F/O, 70 rpm, 6K TO. PU=155K, SO=102K Total strokes pumped = 3300 6/25/2017 6/252017 1.50 INTRMI DRILL TRIP P Continue RIH on elevators f/5073'MD 5,073.0 6,780.0 10:30 12:00 V 6780' MD. Monitor displacement via trip tank. PU = 165K, SO = 104K 6/25/2017 6/25/2017 0.25 INTRMI DRILL TRIP P TIH on elevators f/ 6780' MD V 6970' 6,780.0 6,970.0 12:00 12:15 MD. Monitor diplacement via trip tank. Page 15/45 Report Printed: 7131/2017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time EMT.$ Our (hr) Phase Op Code Tome P -T -X Operation Stan Start Depth (ftKB) Erb Depth (tKB) 6/25/2017 6/25/2017 0.50 INTRMI DRILL REAM P Wash/ream down f/ 6790' U 7064' MD 6,790.0 7,064.0 12:15 12:45 staging pumps up tp 510 gpm, ICP = 300, FCP = 1292,36% NO, ECD = 10.37 ppg Total strokes pumped = 1619 PU = 170K, SO = 114K, ROT = 150K 6/25/2017 6/2512017 1.00 INTRMI DRILL TRIP P TIH on elevators f/ 7064' MD V 8296' 7,064.0 8,296.0 12:45 13:45 MD. Monitor displacement via trip tank. 6/25/2017 6/25/2017 1.25 INTRMI DRILL REAM P Wash/ream down f/ 8296'1/ 8388'MD 8,296.0 8,388.0 13:45 15:00 staging pumps up tp 650 gpm, ICP = 282, FCP = 1822,45% F/O, 50 rpm, 9K TO, IECD = 10.53 ppg, FECD = 10.38. ppg Total strokes pumped = 7591 PU = 180K, SO = 130K, ROT = 150K 6/25/2017 6/25/2017 0.50 INTRMI DRILL CIRC P Drop RFID tags to open underreamer. 8,388.0 8,388.0 15:00 15:30 Rotate and reciprocate V 8385' MD U 8375' MD and pump tags down @ 650 gpm, 1980 psi, 45% F/O, 20 rpm, 9K TO. Reduce rate @ 1100 strokes to 250 gpm, 400 psi, 22% F/O. Confirm reamer is open with reduced pump pressure @ 650 gpm, 1783 psi, MWD trpm reduced t/ 2930 f/ 3516. 6/25/2017 6/25/2017 4.50 INTRMI DRILL DDRL P DDrill 9-7/8" x 11" hole f/8388' MD to 8,388.0 8,827.0 15:30 20:00 8827' MD. TVD= 5284'. Pump @ 830 gpm= 2630 psi w/ 45 % FO. Rotate @ 150 rpm's w/ 11-14K Tq on, 12K Tq off. WOB-8K. ECD 10.82 ppg, MW 9.8 ppg, max gas 57 units. Closing chokes on connections, no pressure build observed. P/U= 180K, S/O= 129K, ROT= 148K. ADT=3.43, Bit hours- 46.04, Total jar hours= 46.04. 6/25/2017 6/25/2017 1.00 INTRMI DRILL RGRP T Service drag chain. SIMOPS: grease 8,827.0 8,827.0 20:00 21:00 wash pipe, rotate and reciprocate pipe f/ 8827' MD t/ 8767' MD @ 512 gpm, 1331 psi, 43% F/O, 60 rpm, 10 K TO. Page 16145 Report Printed: 7/3112017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Lme End Time Dur hr ( ) Phase 0 Cotle P Acti,t Code y Tlme P-T- X Opera4on 3tatl DepN 1 De End Depth (ftKBJ 6/25/2017 6/26/2017 3.00 INTRM1 DRILL DDRL P DDrill 9-7/8" x 11" hole (/8827' MD to 8,827.0 9,123.0 21:00 00:00 9123' MD. ND= 5284'. Pump @ 830 gpm= 2777 psi w/ 44 % FO. Rotate @ 150 rpm's w/ 13-16K Tq on, 12K Tq off. WOB- 15-17K. ECD 10.99 ppg, MW 9.8+ ppg, max gas 62 units. Closing chokes on connections, no pressure build observed. P/U= 180K, S/0= 129K, ROT= 148K. ADT= 2.11, Bit hours = 47.90, Total jar hours= 47.90. No losses for tour Obtain SPR's @ 8387' MD, 5088' TVD 15:30 hours 9.6+ ppg MW MP#1: 20 spm= 150 psi, 30 spm= 210 psi MP #2: 20 spm= 150 psi, 30 spm= 210 psi. 6/26/2017 6/26/2017 6.00 INTRMI DRILL DDRL P DDrill 9-7/8"x 11" hole f/9123' MD to 9,123.0 9,768.0 00:00 0600 9768' MD. TVD= 5696'. Pump @ 820 gpm= 3200 psi w/ 44 % FO. Rotate @ 150 rpm's w/ 17K Tq on, 15K Tq off. WOB- 20K. ECD 11.30 ppg, MW 9.9 ppg, max gas 180 units. Closing chokes on connections, no pressure build observed. P/U= 213K, S/0= 127K, ROT= 153K ADT= 4.72, Bit hours = 52.62, Total jar hours= 52.62. Page 17/45 ReportPrinted: 7/31/2017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stall T.tme End Time our (hr) Phase Op Code AdrvAy Code Time PJ4 Opereuon start Depth (flKB) End Depth MKB) 6/262017 6/26/2017 6.00 INTRM7 DRILL DDRL P DDrill 9-7/8" x 11" hole f/9768' MD to 9,768.0 10,373.0 06:00 1200 10373' MD. TVD= 5961'. Pump @ 820 gpm= 3260 psi w/ 44 % FO. Rotate @ 150 rpm's w/ 11-20K Tq on, 16K Tq off. WOB- 17K. ECD 11.29 ppg, MW 9.9+ ppg, max gas 230 units. Begin ramping on connections targeting 11.2 ppg (300 psi) @ 10092' MD.DDrill 9- 7/8" x 11" hole f/9123' MD to 9768' MD. TVD= 5696'. Pump @ 820 gpm= 3200 psi w/ 44 % FO. Rotate @ 150 rpm's w/ 17K Tq on, 15K Tq off. WOB- 20K. ECD 11.30 ppg, MW 9.9 ppg, max gas 180 units. Closing chokes on connections, no pressure build observed. P/U= 213K, S/O= 127K, ROT= 153K. ADT= 4.72, Bit hours = 52.62, Total jar hours= 52.62. P/U= 213K, S/0= 132K, ROT= 163K. ADT= 3.97, Bit hours = 56.59, Total jar hours= 56.59. Obtain SPR's @ 9141' MD, 5418' TVD 00:10 hours 9.8+ ppg MW ' MP#1: 20 spm= 250 psi, 30 spm= 300 psi MP #2: 20 spm= 260 psi, 30 spm= 310 psi. 6/26/2017 6/26/2017 6.00 INTRM1 DRILL DDRL P DDrill 9-7/8" x 11" hole f/10373' MD to 10,373.0 10,846.0 12:00 18:00 10846' MD. TVD= 6163'. Pump @ 810 gpm= 3404 psi w/ 45 % FO. Rotate @ 150 rpm's wl 17-20K Tq on, 17K Tq off. WOB- 11-15K. ECD 11.33 ppg, MW 10.0 ppg, max gas 1226 units. Ramping on connections targeting 11.2 ppg (300 psi) @ 10092' MD. P/U and S/O discontinued in shales, ROT= 165 K. ADT= 5.01, Bit hours = 61.60, Total jar hours= 61.60. Page 18/45 Report Printed: 713112017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start ime End TimDur(hr) Phase Op Code Activity Code T1me P-T.X Operehon Sled tflK136) EM Depth (flK8) 6/26/2017 6/27/2017 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" x 11" hole f/10646' MD to 10,846.0 11,104.0 18:00 00:00 11104' MD. TVD= 6241'. Pump @ 812 gpm= 3360 psi w/ 47 % FO. Rotate @ 150 rpm's w/ 15-23K Tq on, 16K Tq off. WOB-25K. ECD 11.08 ppg, MW 10.0+ ppg, max gas 991 units. Ramping on connections targeting 11.2 ppg (300 psi). P/U = 220K, SIO = 132K, ROT= 165 K. ADT= 4.87, Bit hours = 66.47, Total jar hours= 66.47. Obtain SPR's @ 10560' MD, 6043' TVD 14:30 hours 10.0 ppg MW MP#1: 20 spm= 250 psi, 30 spm= 320 psi MP #2: 20 spm= 270 psi, 30 spm= 320 psi. No losses for tour. 6/27/2017 6/27/2017 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" x 11"hole f/11104' MD. 11,104.0 11,362.0 00:00 06:00 TVD= 6241'to 11,362' MD 6,304' TVD. Pump @ 810 gpm= 3,430 psi w/ 43 % FO. Rotate @ 150 rpm's w/ 20K Tq on, 18K Tq off. WOB- 20K. ECD 11.11 ppg, MW 10.0+ ppg, max gas 220 units. Holding pressure on connections (320 psi). ROT= 168 K. ADT= 4.63, Bit hours = 71.1, Total jar hours= 71.1. Obtain SPR's @ 11.130' MD, 6,249' TVD 0158 hours 10.0+ ppg MW MP#1: 20 spm= 240 psi, 30 spm= 280 psi MP #2: 20 spm= 240 psi, 30 spm= 280 psi. Page 19145 Report Printed: 7131/2017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time Our(hr) T Phase Op Code Activity Code Time P -T -X Operation Start Depth ptKB) End Depth(flKB) 6/27/2017 6/27/2017 6.00 INTRMI DRILL DDRL P DDrill 9-7/8"x 11" hole f/11,362' MD 11,362.0 11,795.0 06:00 12:00 6,304' TVD to 11,795' MD 6,356' TVD. Pump @ 810 gpm= 3,470 psi w/43 % FO. Rotate @ 150 rpm's w/ 22K Tq on, 19K Tq off. WOB- 18K. ECD 11.12 ppg, MW 10.0+ ppg, max gas 430 units. Holding pressure on connections (320 psi). ROT= 168 K. ADT= 4.66, Bit hours = 75.76, Total jar hours= 75.76 Obtain SPR's @ 11.130' MD, 6,249' TVD 0158 hours 10.0+ ppg MW MP#1: 20 spm= 240 psi, 30 spm= 280 psi MP #2: 20 spm= 240 psi, 30 spm= 280 psi. 6/27/2017 6/27/2017 2.50 INTRMI DRILL DDRL P DDrill 9-7/8" x 11" hole f/11,795' MD 11,795.0 11,966.0 12:00 14:30 6,356' TVD to 11,966' MD 6,363' TVD. Pump @ 810 gpm= 3,425 psi w/ 45 % FO. Rotate @ 150 rpm's w/ 25K Tq on, 20K Tq off. WOB- 15K. ECD 11.23 ppg, MW 10.0+ ppg, max gas 215 units. Holding pressure on connections (320 psi). UP WT = 264K DWN WT = 104K ROT= 167 K. ADT= 1.81, Bit hours = 77.57, Total jar hours= 77.57 Obtain SPR's @ 11.795' MD, 6,365' TVD 1215 hours 10.0+ ppg MW MP#1: 20 spm= 230 psi, 30 spm= 305 psi MP #2: 20 spm= 260 psi, 30 spm= 315 psi. Page 20/45 ReportPrinted: 7/31/2017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Tim Dur (hr) Phase Op Code Adiv¢y Code Time P -T -X Operation start Depth (W) End Depth (aKa) 6/27/2017 6/27/2017 1.75 INTRMI CASING CIRC P Obtain final SPR's then Rotate and 11,966.0 11,891.0 14:30 16:15 recip from 11,966' MD to 11,891' MD pumping 60 BBL high vis 10.4 PPG sweep @ 810 GPM. 3,428 PSI 45% F/O, 150 RPM 18-20K TO with 11.2 PPG ECD. total slks pumped = 10,800. UP WT=167K DWN WT=159K while pumping. ADT= 1.81, Bit hours = 77.57, Total jar hours= 77.57 Obtain SPR's @ 11,966' MD, 6,363' TVD 1450 hours 10.0+ ppg MW MP#1: 20 spm= 310 psi, 30 spm= 320 psi MP #2: 20 spm= 290 psi, 30 spm= 330 psi. 6/27/2017 6/27/2017 4.25 INTRMI CASING CIRC P Rotate and slowly POOH from 11,891.0 11,797.0 16:15 20:30 11,891'to 11,797' MD. while displacing well over to 10.4 PPG LSND @ 840 GPM 3,444 PSI DP, 150 RPM @ 22K TO, ECD = 11.34 PPG, UP WT = 169K DWN WT 158K. 6/27/2017 6/27/2017 1.25 INTRMI CASING CIRC P Take parameter readings for closing 11,797.0 11,797.0 20:30 21:45 underreamer @ 650 GPM w2,252 PSI, 44% F/O 10 RPM with 16 K TO. MWD turbine = 2,813 RPM. Drop RFID chips and rotate at 10 RPM. 17K TO and pump down to 650 GPM. 2,252PSI with 44% F/O. Slow rotations to 250. at 1,500 STKS> with 740 PSI. Shut down pumps at 2,350 STKS and bleed off PSI. PU & ROT at 20 RPM 16K TO from 11,797'; to 11,676' MD. Confirmed underreamer closed with 650 GPM at 2,686 PSI and MWD turbine at 3,555 RPM. 6/27/2017 6/27/2017 0.50 INTRMI CASING OWFF P Bleed off pressure and OWFF. (static) 11,797.0 11,797.0 21:45 22:15 while ROT at 10 RPM. 16K TO. 175K RT WT,. 6/27/2017 6/28/2017 1.75 INTRMI CASING SMPD P Strip OOH on elevators from 11,797' 11,797.0 10,189.0 22:15 00:00 MD to 10,189' MD. up WT = 160K. DWN WT= 122K. 6/28/2017 6/28/2017 0.50 INTRMI CASING SMPD P Strip OOH on elevators from 10,189' 10,189.0 10,000.0 00:00 00:30 MD to 10,000' MD. up WT = 243K. DWN WT = 114K. 6/28/2017 6/28/2017 1.50 INTRMI CASING PMPO P Pump LCM pill as per plan and PMPO 10,000.0 9,334.0 00:30 02:00 from 10,000' MD to 9,350' MD spotting LCM pikll from 9,950' MD to 9,334' MD. UP WT 212K. DWN WT=106K. Spot pill at 3 BPM 610 PSI, 25.5 FPM spotting speed. Page 21145 Report Printed: 713112017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Siert Time End Time Dur(hr) Phase Op Code AGivlyCode Time P -T -X OpetaWn Stan Depth (MB) End DOW (ftKB) 6/28/2017 6/28/2017 0.75 INTRMI CASING SMPD P Continue SMPD from 9,334' MD to 9,334.0 9,328.0 02:00 02:45 9,144' MD UP WT = 235K, Dwn WT = 103K. Noticing 30-40K drag while SMPD along with swabbing from 9,238' - 9,144' MD. Wipe stand and cont to observe drag and swab. RBIH to 9,328 MD' and prepare to BKRM. 6/28/2017 6/28/2017 4.25 INTRMI CASING BKRM P Pumps on line at 650 GPM and circ 9,328.0 8,292.0 02:45 07:00 while Pump OOH with rotary from 9,328' MD to 8,292' MD. 2,235 PSI, 44% F/O, 100 RPM - i 1 K TO and 11.26 ECD. UP WT = 195, DWN WT = 120K. 6/28/2017 6/28/2017 1.00 INTRMI CASING CIRC P Circulate Bottoms up while recip from 8,292.0 8,197.0 07:00 08:00 8,292' MD to 8,197' MD. 650 GPM 2,235 PSI. 44% F/O, 100 RPM 11 K TO, with 10.32 ECD. 7600 STKS pumped. MW in 10.4 - MWO 10.4+, 6/28/2017 6/28/2017 4.00 INTRMI CASING SMPD P SMPD from 8,187' MD to 3,275' MD. 8,197.0 3,275.0 08:00 12:00 heavy overpull at 5,258' MD - Wiped clean on second pass had 7K overpull. UPWT=121K. DWNWT= 103K. 6/28/2017 6/28/2017 1.25 INTRMI CASING CIRC P Circulate bottoms up from 10 3/4 Shoe 3,275.0 3,180.0 12:00 13:15 at 3,275' MD cycle pipe to 3,180' MD. 556 GPM @ 1,251 PSI F/O = 43%. RPM 100. with 4K TO. UP WT = 120 K DWN WT=103K. ROTW=107K. 700 STKS. 6/2812017 6/28/2017 1.75 INTRMI CASING SMPD P SMPD from 3180 MID -1,572'MD 3,180.0 1,572.0 13:15 15:00 6/28/2017 6/28/2017 0.50 INTRMI CASING CIRC P Rotate and recip from 1,572'- 1,47 ' 1,572.0 1,477.0 15:00 15:30 MD wheil pumping 550 GPM @ 1,062 PSI. F/O 43%. RPM 100 with 2K TO. UP WT=94K DWN WT=87K. RWT = 89K. 4100 STKS, 6/28/2017 6/28/2017 0.75 INTRMI CASING SMPD P SMPD Erin 1,477' MD to 437' MD up 1,477.0 437.0 15:30 16:15 WT=7I K, DWN WT=73K. 6/28/2017 6/28/2017 0.50 INTRMI CASING OWFF P OWFF (STATIC) 437.0 437.0 16:15 16:45 6/28/2017 6/28/2017 1.25 INTRMI CASING MPDA P Pull MPD bearing and install trip 437.0 437.0 16:45 18:00 nipple. 6/28/2017 6/28/2017 1.25 INTRMI CASING PUFD- F5 Lay down 5" HWDP and jars from 437' 437.0 187.0 18:00 19:15 to 187' MD. 6/28/2017 6/28/2017 1.50 INTRMI CASING SHAH P Lay down BHA as per slumberger rep 187.0 0.0 19:15 20:45 from 187' to surface. 6/28/2017 6/28/2017 1.00 INTRMI CASING CLEN P Clean dg floor and send out BHA #2 0.0 0.0 20:45 21:45 down beaver slide. 6/28/2017 6/28/2017 0.25 INTRMI CASING RURD P Pull wear bushing 0.0 0.0 21:45 22:00 6/28/2017 6/29/2017 2.00 INTRMI CASING BOPE P Change out 3 1/2" X 6" VBR to 7 5/8" 0.0 0.0 22:00 00:00 pipe rams. Sim ops with bringing GBR casing equipment to rig floor and dg up. 6/29/2017 6/29/2017 1.50 INTRMI CASING BOPE P PU test joint and test 7 5/8" casing 0.0 0.0 00:00 01:30 ram and annular (PASED) to 2501 3500 PSI. RD BD. 6/29/2017 6/29/2017 0.50 INTRMI CASING KURD P Rig up casing running equip and test 0.0 0.0 01:30 02:00 same. Pre -job. Page 22145 Report Printed: 7/31/2017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time EM Time Our (hr) Phew Op code Acbvity Code Time P -T-% Operabon sued DepM (fKe) End Depth(ttKB) 6/29/2017 6/29/2017 0.75 INTRMI CASING PUTS P RIH with 7 5/8" casing baker locking 0.0 92.9 02:00 02:45 shoe/ float collar. check same (PASSED). 1 BPM = 13 % F/0.... 3 BPM = 14% F/0... 5 BPM = 18% F/0.... 8 BPM = 27% F/0.... 6/29/2017 6/29/2017 5.25 INTRMI CASING PUTS P Continue to RIH with 7 5/8" casing 92.9 3,278.0 02:45 08:00 from 93' MD to 3,278' MD Torquing all connection to 12.4K FT/LBS. filling casing on the fly and topping off every ten joints. 6/29/2017 6/29/2017 0.75 INTRMI CASING CIRC P CBU while recip from 3,278'-3,238' 3,278.0 3,278.0 08:00 08:45 MD. Stage pumps up to 8 BPM. 195 PSI 29% F/O, 1,65 STKS pumped 10.4 in/out. 6/29/2017 6/29/2017 3.00 INTRMI CASING PUTS P Continue to RIH with 7 5/8" casing 3,278.0 4,904.0 08:45 11:45 from 3278' MD to 4,904' MD Torquing all connection to 12.4K FT/LBS. filling casing on the fly and topping off every ten joints. 6/29/2017 6/29/2017 0.75 INTRMI CASING CIRC P CBU while recip from 4,904'-4,874" 4,904.0 4,904.0 11:45 12:30 MD. Stage pumps up to 7 BPM. 210 PSI 24% F/O, UP WT = 142K DWN WT = 117K 10.4 iniout. 2,955 STKS pumped 6/29/2017 6/29/2017 0.75 INTRMI CASING PUTB P Continue to RIH with 7 5/8" casing 4,904.0 5,362.0 12:30 13:15 from 4,904' MD to 5,362' MD Torquing all connection to 12.4K FT/LBS. filling casing on the fly and topping off every ten joints. 6/29/2017 6/29/2017 0.25 INTRMI CASING CIRC P Circ to shoe while recip from 5,362'- 5,362.0 5,362.0 13:15 13:30 5330"' MD. Stage pumps up to 7 BPM. 210 PSI 24% F/O, UP WT = 149K DWN WT = 119K 10.4 in/out. 1,225 STKS pumped 6/29/2017 6/29/2017 1.50 INTRMI CASING PUTB P Continue to RIH with 7 5/8" casing 5,362.0 6,141.0 13:30 15:00 from 5,362'-6,141'MD Torquing all connection to 12.4K FT/LBS. filling casing on the fly and topping off every ten joints. 6/29/2017 6/29/2017 0.75 INTRMI CASING CIRC P Circ to shoe while recip from 6,141 - 6,141.0 6,141.0 15:00 15:45 6,120"" MD. Stage pumps up to 7 BPM. 266 PSI 24% F/0, UP WT = 167K DWN WT = 123K 10.4 in/out. 2,756 STKS pumped 6/29/2017 6/29/2017 1.75 INTRMI CASING PUTS P Continue to RIH with 7 5/8" casing 6,141.0 7,369.0 15:45 17:30 from 6,141'- 7,369' MD Torquing all connection to 12.4K FT/LBS. filling casing on the fly and topping off every ten joints. 6/29/2017 6/29/2017 1.00 INTRM1 CASING CIRC P Circ to shoe while recip from 7,369'- 7,369.0 7,369.0 17:30 18:30 7,349""' MD. Stage pumps up to 7 BPM. 280 PSI 24% F/O, UP WT = 195K DWN WT = 130K 10.4 in/out. 3,391 STKS pumped 6/29/2017 6/29/2017 1.50 INTRMI CASING PUTS P Continue to RIH with 7 5/8" casing 7,369.01 8,440.0 18:30 20:00 from 7,369'- 8,440' MD Torquing all connection to 12.4K FT/LBS. filling casing on the fly and topping off every ten joints. Page 23/45 Report Printed: 7/31/2017 ¢.a Operations Summary (with Timelog Depths) -d 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Steri Tim EM Time Dur (hr) Phase Op COEe AtlivM1y Code Time P -T -X Opa20on start Depth (W) Fk Depth(ftw 6/29/2017 6/29/2017 1.50 INTRMI CASING CIRC P Circ to shoe while recip from 8,440'- 8,440.0 8,440.0 20:00 21:30 8,415" "" MD. Stage pumps up to 7 BPM. 351 PSI 25% F/0, UP WT= 220K DWN WT= 125K 10.4 in/out. 6/29/2017 6/29/2017 1.75 INTRMI CASING PUTS P Continue to RIH with 7 5/8" casing 8,440.0 9,418.0 21:30 23:15 from 8,440' MO to 9,418' MD Torquing all connection to 12.4K FT/LBS. filling casing on the fly and topping off every ten joints. 6/29/2017 6/30/2017 0.75 INTRMI CASING CIRC P Circ to shoe while recip from 9,418' to 9,418.0 9,418.0 23:15 00:00 9,393"' MD. Stage pumps up to 7 BPM. 340 PSI 25% F/0, UP WT = 1245K DWN WT = 134K 10.4 inlout. 6/30/2017 6/30/2017 0.75 INTRMI CASING CIRC P Circ to shoe while recip from 9,418'to 9,418.0 9,424.0 00:00 00:45 9,393"' MD. Stage pumps up to 7 BPM. 340 PSI 25% F/0, UP WT = 245K DWN WT = 134K 10.4 in/out. 6/3012017 6/30/2017 1.25 INTRMI CASING PUTS P Continue to RIH with 7 5/8" casing 9,424.0 10,355.0 00:45 02:00 from 9,424' to 10,355" MD Torquing all connection to 12.41K FT/LBS. filling rasing on the fly and topping off every ten joints. 6/30/2017 6/30/2017 1.50 INTRMI CASING CIRC P Circ to shoe while recip from 10,35 10,355.0 10,355.0 02:00 03:30 10319"" MD. Stage pumps up to 7 BPM. 40OPSI 24% F/O, UP WT = 265K DWN WT= 135K 10.4 in 10.5 out. 6/30/2017 6/30/2017 2.25 INTRMI CASING PUTS P Continue to RIH with 7 5/8" casing 10,355.0 11,422.0 03:30 05:45 from 10,355" MD to 11,422' MD Torquing all connection to 12.4K FT/LBS. filling casing on the fly and Popping off every ten joints. 6/30/2017 6/30/2017 0.50 INTRMI CASING CIRC P Circulate while washing down to 11,422.0 11,462.0 05:45 06:15 11,462' MD at 7 BPM 475 PSI 23% F/O. 1,400 STKS pumped DWN WT = 129K. MW in 10.4 -MW out =10.5 6/30/2017 6/30/2017 0.75 INTRMI CASING PUTS P Continue to RIH with 7 5/8" rasing 11,462.0 11,751.0 06:15 07:00 from 11,462' MD to 11,751' MD Torquing all connection to 12.4K FT/LBS. filling casing on the fly and topping off every ten joints. 6/30/2017 6/30/2017 0.75 INTRMI CASING PUTS P Wash down 7 5/8" casing from 11,751 11,751.0 11,917.0 07:00 07:45 MD to 11,917' MD. 4BPM @ 425 PSI, 17% F/O, DWN WT = 95K -115K. 6/30/2017 6/30/2017 0.50 INTRM1 CASING HOSO P Make up hanger and landing joint. 11,917.0 11,956.0 07:45 08:15 Wash down to 11,956' MD. 4 BPM @ 435 PSI. 16% F/O. 103K DWN WTprior to landing hanger. 6/30/2017 6/30/2017 0.75 INTRMI CEMENT CIRC P Circulate while stage pumps up to 5 11,956.0 11,956.0 08:15 09:00 BPM 530 PSI, 17% F/O. UP WT 330K. DWN WT= 115K/. Hole PJSM to R/U cement hose. 6/30/2017 6/30/2017 3.50 INTRMI CEMENT CIRC P Circulate while reciprocating from 11,956.0 11,956.0 09:00 12:30 11,956' MD to 11,916' MD at 7 BPM 430 PSI. 25% F/O. UP WT 330 K, DWN WT = 122K. 10.4 in /out. PJSM W/SLB for cement program. Total STKS pumped 11,943 ( 1203 bbls). Page 24/45 Report Printed: 713112017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log SUM Time End Time Dur (hr) Phew up Code Activity Code Time P -T -X Cperalian SW(Hx epm End Depth (WB) 6130/2017 6/30/2017 1.50 INTRMI CEMENT CMNT P SLB on line 2 BBLS of fresh water, 11,956.0 11,956.0 12:30 14:00 PT lines to 250/4000 PSI. Test trips (GOOD) Batch up cement and pump 40.1 BBLS mud push 12.5 ppg @ 4.5 BPM, 320 PSI, 17% F/O. Drop BTM PLUG. 6/30/2017 6/30/2017 1.00 INTRMI CEMENT CMNT P Pump 137.4 BBLS of 15.8# Class G 11,956.0 11,956.0 14:00 15:00 cement ( yield 1.16 cuf /sx, mix water 5.117 gal/sx, thickening time 4 hr 48 min) with reciprocations @ 5.2 BPM, 190 PSI, 26% F/O, FCP = 2.9 BPM. 75 PSI, 19% F/O. Drop top plug pump 10.1 BBLS water UP WT = 335K DWN WT= 122K 6/30/2017 6/30/2017 1.50 INTRMI CEMENT CMNT P Displace cement with rig pump at 7.8 11,956.0 11,957.4 15:00 16:30 BPM 219 PSI, 28% F/O. 4568 STKS (460 bbls) reduce rate to 4 BPM. 530 PSI, 15% F/O. @ 5,200 STKS (523 bbls) UP WT = 335, DWN WT = 101K. Land hanger at 4,680 STKS (471 bbls). Bump plug @ 3 BPM 500 PSI FCP. 5,333 STK ( 537 bbls) W increase pressure to 1,045 PSI and hold for 5 min. Bleed off to check floats. (GOOD) cement in place at 16:15 hrs 6/30/2017. 6/30/2017 6/302017 1.00 INTRMI CEMENT PRTS P Perform casing pressure test to 3,500 11,957.4 11,957.4 16:30 17:30 PSI and chart same. pumped 7.2 BBLS bled back same. RID B/D test system. 6/30/2017 6/30/2017 1.00 INTRMI CEMENT RURD P UD landing joint and lay down all 11,957.4 11,957.4 17:30 18:30 casing handling equiment. dean floor. 6/30/2017 6/30/2017 1.50 INTRMI CEMENT WWSP P Drain stack and RILDS. Set packoff 11,957.4 11,957.4 18:30 20:00 and RILDS to test to 5,000 PSI witnessed. Install 9" IS wear ring and bushing. RILDS. SIMOPS while cleaning pills and inspect cement manifolds. 6/30/2017 7/1/2017 4.00 INTRMI CEMENT PULD P Lay down 32 Stands of 5" DP via 11,957.4 11,957.4 20:00 00:00 mouse hole. 7/1/2017 7/1/2017 8.25 INTRMI CEMENT PULD P Continue to lay down 5" drill pipe 0.0 0.0 00:00 08:15 breaking stands utilizing 30' mouse hole. 7/1/2017 7/1/2017 0.75 INTRMI CEMENT LOT P SIMOPS, while laying down 5" drill 0.0 0.0 08:15 09:00 pipe perform FIT on 10 3/4" X 7 5/8" ANN. utilizing 10.4 PPG pumped - 4 BBLS befor initial breakover - 13.8 PPG EMW. pumped a total of 8.3 BBLS for FIT. 7/1/2017 7/12017 1.25 INTRMI CEMENT LOT P SIMOPS while laying down 5" DP. 0.0 0.0 09:00 10:15 Flushed OA with fresh water @ 4 BPM ICP = 560 PSI, FCP = 740 PSI, Shut in for 5 min to record SI pressure of 318 PSI. 7/1/2017 7/1/2017 6.00 INTRMI CEMENT SLPC P Hang blocks and splice old/new drill 0.0 0.0 10:15 16:15 line 1,940'calibrate block height. Sim cps with changing out 3 1/2" X 6" uppers in BOP. 7/1/2017 7/1/2017 2.00 INTRMI CEMENT RURD P Change out saver sub TIXT39 while 0.0 0.0 16:15 18:15 Sim ops of loading shed with 4" with SS installed as per program. Page 25/45 Report Printed: 7/3112017 Operations Summary (with Timelog Depths) 2K-30 .... Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log SW Time I End Time Our (hr) Phow Op CodeActivity Code Time P -T -X Operation SW D Pm MKS) End Depth(flKa) 7/1/2017 7/1/2017 0.50 INTRMI CEMENT SVRG P Service rig, inspect top drive, //Blocks 0.0 0.0 18:15 18:45 7/1/2017 7/1/2017 2.50 INTRMI CEMENT OTHR P Continue to load pipe shed with 4" drill 0.0 0.0 18:45 21:15 pipe and 4" HWDP for effect. 7/1/2017 7/2/2017 2.75 INTRMI CEMENT PULD P M/U 20 stnds of 4" HWDP and stand 0.0 0.0 21:15 00:00 back in derrick, rabbiting pipe off skate. 7/2/2017 7/2/2017 18.50 INTRMI CEMENT PULD P Continue to make up stands via 0.0 0.0 00:00 18:30 mouse hole and stand back in derrick drifting on skate with 2.34" tldit. Sim Ops with freeze protecting 10 3/4";K 7 5/8" ANN with 96 BELS of Isotherm average of 2.8 BPM 300-920 PSI injection pressure. SICP = 700 PSI. 7/2/2017 7/2/2017 1.00 INTRMI CEMENT SHAH P Pick up BHA to rig floor and prep for 0.0 0.0 18:30 19:30 MU. 7/2/2017 7/2/2017 3.25 INTRMI CEMENT BHAH P PJSM, MU SLB BHA #4_4" 14.00 0.0 508.2 19:30 22:45 DPS, 10% Wear, 4" HWDP (2 joints), 4 3/4" Hydraulic Jars, 4" HWDP (3 joints), XO, Saver sub (Corrosion Ring), Float Sub (non -ported float - flapper # 0037), 30' NMDC, 6-5/8" NM Stab (non -ported float - plunger # 0066), 30' NMDC, 6" NM Slab (non - ported float - flapper # 1253), 10' Pony NMDC, 4 3/4" adnVISION w/ 5 3/4 Stabilizer, 4 314" SonicScope w/ 6" Stabilizers, 4 3/4" Impulse (MWD), 4 3/4" Periscope, PD Receiver Sub, PD 475 Orbit AA 6 3/4" Stabilized CC, 6 3/4" PDC Bit (X516 Axe Blade). RIH with one stnd DP to have pipe accross BOP while continuing to load shed. 7/2/2017 7/3/2017 1.25 INTRMI CEMENT OTHR P Load and strap remander of 270 jls 4" 508.2 508.2 22:45 00:00 DP and prep to RIH. 7/312017 7/3/2017 2.25 INTRMI CEMENT PULD P Count pipe in shed and confim totals. 508.2 2,330.0 00:00 02:15 Single in 4" DP from 508'- 2,330' MD. 7/3/2017 7/3/2017 0.25 INTRMI CEMENT DHEA P Fill DP and shallow hole test MWD 2,330.0 2,330.0 02:15 02:30 with 240 GPM 1,480 PSI, 26% F/O (Good). 7/3/2017 7/3/2017 1.25 INTRMI CEMENT PULD P Contine to RIH with 4" DP from 2,330' 2,330.0 3,386.0 02:30 03:45 - 3,386' MD. UP WT = 94K, DWN WT = 82K. 7/3/2017 7/3/2017 1.00 INTRMI CEMENT DLOG P Down liink Sonic t/Fast mode 8 Log 3,386.0 3,528.0 03:45 04:45 from 3,386' to 3,528' MD for free ring. 7/3/2017 7/3/2017 5.50 INTRMI CEMENT PULD P Continue to Trip in hole from 3,528' 3,528.0 - 8,932.0 04:45 10:15 MD - 8,932' MD filling pipe every 2,000' UP WT= 165K, DWN WT= 90K. 7/3/2017 7/3/2017 5.75 INTRMI CEMENT DLOG P Perform down link and log in hole from 8,932.0 11,863.0 10:15 16:00 8,932' MD - 11,863' MD tagging TOC. Filling pipe every 20 STNDS, tack back stands # 121 and 120 to 11,680' MD uUP WT=200K, DWN WT= 191K. Page 26/45 Report Printed: 7/31/2017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Ttme End Time Our thrl Phase Op code Activity Code Time P -T -X Operahon sten Daps, MKS) End Depth (WB) 7/3/2017 7/3/2017 0.50 INTRMI CEMENT CIRC P Break circulation filling pipe and 11,863.0 11,863.0 16:00 16:30 downlink Sonic scope at 250 GPM = 2,225PSI, 25% F/O, blow down top drive. 7/3/2017 7/3/2017 2.00 INTRMI CEMENTMPSP P Set 7-5/8" Baker Storm PKR for • 11,863.0 11,863.0 16:30 18:30 upcommiing BOP test. Rack back stand after setting. 7/3/2017 7/3/2017 1.00 INTRMI WHDBOP RURD P Purge lines install test plug and test to 11,863.0 11,863.0 18:30 19:30 500 PSI for 5 min. Drain stack, pull wear bushing, install test plug and ru testing equipment. re -purge lines. 7/3/2017 7/4/2017 4.50 INTRMI WHDBOP BOPE P Test BOPE. All test to 250/3,500 PSI. 11,863.0 11,863.0 19:30 00:00 charted test except Super choke and man operated choke valve to 250 / 2,500 PSI. tested with 3.5" and 4.5" testjoint. Koomey drawdown test start - 3,000 PSI, after functions = 1,700 PSI, 9 sec for 200 PSI / with 2 elect pumps, 65 sec total to obtain full system press with elec / air pumps. Test witnessed by Brian Bixby with AOGCC. 7/4/2017 7/4/2017 0.25 INTRMI WHDBOP BOPE P Finish Test of BOPE. Al test to 11,863.0 11,863.0 00:00 00:15 250/3,500 PSI. Tested with 3.5" and 4.5" lest joint. Test witnessed by Brian Bixby with AOGCC. Last test- Lower pipe rams w/ 3.5" test joint- bleed off @ 0012 hrs 7/4/2017. 7/4/2017 7/4/2017 0.50 INTRMI WHDBOP RURD P Rig down testing ewuipmenl. Blow 11,863.0 11,863.0 00:15 00:45 down lines and drain stack. 7/4/2017 7/4/2017 0.25 INTRMI WHDBOP RURD P Install FMC 9" ID upper wear ring. Run 11,863.0 11,863.0 00:45 01:00 in lock down screws. 7/4/2017 7/4/2017 1.50 INTRMI WHDBOP MPSP P Make up a stand of 4" drill pipe. Make 11,863.0 11,863.0 01:00 02:30 up Baker Oil tools retrieving tool. RIH , retrieve storm paker, pull out and lay down Baker storm packer. 7/4/2017 7/4/2017 0.50 INTRMI CEMENT TRIP P Run in the hole a stand to 11773', 11,863.0 11,863.0 02:30 03:00 wash and ream to 11860', pumping 200 gpm w/ 1790 psi 21 % flow out. Rotate 60 rpm w/ 11 k ftlbs of torque. Tag @ 11860'. PU wt 200k, SO wt 94k. 7/4/2017 7/4/2017 2.25 INTRMI CEMENT DRLG P Drill shoe track and cement f/ 11860' 11,863.0 11,966.0 03:00 05:15 to 11966', pumping 150-200 gpm w/ 1190-1680 psi. Rotate 80 rpm w/ 13k ft lbs of torque. Drill w/ 4-12k weight Ion bit. 7/4/2017 7/4/2017 0.50 INTRMI CEMENT DDRL P Drill 20' of new hole f/ 11866-11986'. 11,966.0 11,986.0 05:15 05:45 Pumping 240 gpm w/ 2160 psi, 21 % flow out. Rotate 80 rpm w/ 14k ft lbs of torque. Drill w/ 1 O weight on bit. ADT= .4 hrs. 7/4/2017 7/4/2017 2.50 INTRMI CEMENT CIRC P Stand back a stand. Pump a sweep, 11,986.0 11,986.0 05:45 08:15 while rotate and recip f/ 11949'to 11870'. Pumping 200 gpm w/ 1840 psi, 18% flow out, ECD 10.96 ppg. Rotate 60 rpm w/ 13k ft lbs of torque. Pumped 719 WIS. MW in 10.2 ppg, MW out 10.2 ppg. PU wt 206k, SO Wt 91 k. Rot wt 137k. Page 27/45 Report Printed: 7/31/2017 . Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tim End Time Our(hr) Phase Op C.d. Ad.ityCode TmeiP-T-% O parappn uDe pth Mart KE11 Fib Depth (IFf®) 7/4/2017 7/4/2017 0.25 INTRMi CEMENT OWFF P Observe well for flow-static. 11,986.0 11,986.0 08:15 08:30 7/4/2017 7/4/2017 1.00 INTRMI CEMENT FIT P Rig up for FIT test. Flood lines. 11,986.0 11,986.0 08:30 09:30 Pumped 1.6 bbls, document every 2 strokes. Shoe @ 11957' MD (6367.9' TVD) applied 1020 psi. FIT 13.3 ppg. Bleed back 1.4 bbls. 7/4/2017 7/4/2017 1.00 PROD1 DRILL MPDA P Pull trip nipple and install Managed 11,986.0 11,986.0 09:30 10:30 Pressure Drilling bearing assembly. 7/4/2017 7/4/2017 2.00 PRODt DRILL DISP P Displace well f! 10.2 ppg mud to 9.5 11,986.0 11,986.0 10:30 12:30 ppg FloPro. Pumping 200 gpm w/ 1675 psi, 20% flow out. Rotate 60 rpm w/ 7 ft lbs of torque. ECD 10.84 ppg OA=380 psi 7/4/2017 7/4/2017 1.25 PROD1 DRILL MPDA P Calibrate MPD chokes. Obtain SPR's. 11,986.0 11,986.0 12:30 13:45 Clean shakers and troughs in pit room. SPR 11 945'MD 6367' TVD. MW = 9.5 PPG 13:10 hrs Pumpl ) 20 SPM 500 PSI 30 SPM 755 PSI Pump2 ) 20 SPM 500 PSI 30 SPM 760 PSI 7/4/2017 7/4/2017 4.25 PRODt DRILL DDRL P DDrill 6-3/4" production hole f/ 11986' 11,986.0 12,340.0 13:45 18:00 MD to 12340' MD 6,384' TVD, Pump @ 260 gpm= 2240 psi on wl 21 % FO, Rotate @ 140 rpm's w/9K Tq on, 6K Tq off. WOB= 1OK, ECD= 10.73 ppg EMW, Max gas= 3170 units.. P/U= 162K, S/O= 103, ROT= 126K, ADT= 3.30 Bit hrs= 3.70, Total Jar hrs= 3.70. 7/4/2017 7/5/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4" production hole f/ 12340' 12,340.0 12,817.0 18:00 00:00 MD to 12817' MD 6,398' TVD, Pump @ 260 gpm= 2360 psi on w/ 21 % FO, Rotate @ 140 rpm's w19K Tq on, 6K Tq off. WOB= 11 K, ECD= 10.98 ppg EMW, Max gas= 339 units.. PIU= 160K, S/O= 103K, ROT= 126K, ADT= 4.22, Bit hm= 7.92, Total Jar hrs= 7.92. SPR 12719' MD 6395' TVD. MW= 9.5 PPG 22:45 hrs Pumps ) 20 SPM 650 PSI 30 SPM 900 PSI Pump2) 20 SPM 670 PSI 30 SPM. 920 PSI OA=540 psi 37 bbis lost to formation last 24 hrs. Page 28145 Report Printed: 7/31/2017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stat Time End Time Die (h,) Phase op Code ActivityCode Time P -T -X opetafipn Stasi Depth inKB) Erb Depth(fiKB) 7/5/2017 7/5/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4" production hole f/ 12817' 12,817.0 13,457.0 00:00 06:00 MD to 13457' MD 6,401' TVD, Pump @ 260 gpm= 2490 psi on w/ 22% FO, Rotate @ 140 rpm's w/10K Tq on, 8K Tq off. WOB= 8K, ECD= 11.15 ppg EMW, Max gas= 715 units.. P/U= 170K, S/O= 96K, ROT= 129K, ADT= 4.36, Bit hrs= 12.28, Total Jar hrs= 12.28. Holding 295 psi back pressure on connections. SPR 13286' MD 6403' TVD. MW= 9.5 PPG 04:20 hrs Pump1 ) 20 SPM 700 PSI 30 SPM 940 PSI Pump2) 20 SPM 690 PSI 30 SPM 940 PSI 7/5/2017 7/5/2017 6.00 PRODt DRILL DDRL P DDrill 6-3/4" production hole f/ 13457' 13,457.0 14,045.0 06:00 12:00 MD to 14045' MD 6,407' TVD, Pump @ 260 gpm= 2570 psi on w/ 21 % FO, Rotate @ 140 rpm's w/10K Tq on, AK Tq off. WOB= 9K, ECD= 11.1 ppg EMW, Max gas= 2100 units.. P/U= 164K, S/0= t00K, ROT= 128K, ADT= 3.98, Bit hrs= 16.26, Total Jar hrs= 16.26. Holding 295 psi back pressure on connections. SPR 13948' MD 6404' TVD. MW = 9.5 PPG 10:45 hrs Pumps ) 20 SPM 720 PSI 30 SPM 990 PSI Pump2) 20 SPM 720 PSI 30 SPM 1000 PSI OA=540 psi. 7/5/2017 7/5/2017 6.00 PROD? DRILL DDRL P DDrill 6-3/4" production hole f/ 14045' 14,045.0 14,649.0 12:00 18:00 MD to 14649' MD 6,445' TVD, Pump @ 270 gpm= 2680 psi on w/ 21 % FO, Rotate @ 140 rpm's will OK Tq on, 8K Tq off. WOB= 9K, ECD= 11.1 ppg EMW, Max gas= 2100 units.. P/U= 178K, S/0= 94K, ROT= 126K, ADT= 4.31, Bit hrs= 20.57, Total Jar hrs= 20.57. Holding 295 psi back pressure on connections. Page 29146 Report Printed: 713112017 0 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tme Time Dur(hr) Phase Code ctiL Activity Code Time P -T -X Operation Start Depth (ftKB) EM Depth (W[3) 7I5I2017 7/6/202017 6.0.0 0 PROD1 DRILL DDRL P DDrill 6-3/4" production hole f/ 14649' 14,649.0 15,278.0 18:00 00:00 MD to 15278' MD 6,447' TVD, Pump @ 260 gpm= 2485 psi on w/ 21 % F0, Rotate @ 140 rpm's w/11 K Tq on, 9K Tq off. WOB= 7K, ECD= 11.05 ppg EMW, Max gas= 1892 units.. P/U= 188K, S/0= 93K, ROT= 128K, ADT= 4.28, Bit hrs= 24.60, Total Jar hrs= 24.60. Holding 295 psi back pressure on connections. SPR 14708' MD 6449' TVD. MW = 9.5 PPG 18:35 hrs Pump1 ) 20 SPM 680 PSI 30 SPM 920 PSI Pump2) 20 SPM 680 PSI 30 SPM 940 PSI SPR 15278' MD 6448' TVD. MW = 9.5 PPG 23:45 hrs Pump1 ) 20 SPM 650 PSI 30 SPM 900 PSI Pump2 ) 20 SPM 660 PSI 30 SPM 900 PSI OA=535 psi 93 bbls lost to formation last 24 hrs. 7/6/2017 7/6/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4" production hole f/ 15278' 15,278.0 15,909.0 00:00 06:00 MD to 15909' MD 6,460' TVD, Pump @ 260 gpm= 2490 psi on w/ 20% FO, Rotate @ 140 rpm's w/11 K Tq on, 9.5K Tq off. WOB= 1 OK, ECD= 11.01 ppg EMW, Max gas= 2000 units.. P/U= 193K, S/0= 86K, ROT= 130K, ADT= 4.13, Bit hrs= 28.73, Total Jar hrs= 28.73. Holding 295 psi back pressure on connections. SPR 15846' MD 6461' TVD. MW = 9.5 PPG 05:00 hrs Pump1 ) 20 SPM 680 PSI 30 SPM 940 PSI Pump2) 20 SPM 680 PSI 30 SPM 930 PSI Page 30145 Report Printed: 7/31/2017 Operations Summary (with Timelog Depths) ow 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sten Time End Tune Dur (hr) Phase Op cotle Activity Code Time P -T -X Operebon n Depth $1(nKB)) EW Depth (itK8) 7/6/2017 7/6/2017 6.00 PROD1 DRILL DDRL P DDrill 5-314" production hole f/ 15909' 15,909.0 16,588.0 06:00 12:00 MD to 16588' MD 6,446' ND, Pump Q 260 gpm= 2560 psi on w/ 21% FO, Rotate Q 140 rpm's w/12K Tq on, 10K Tq off. WOB= 9K, ECD= 11.2 ppg EMW, Max gas= 1500 units.. P/U= 195K, S/0= 86K, ROT= 129K, ADT= 4.06, Bit hrs= 32.79, Total Jar hrs= 32.79. Holding 295 psi back pressure on connections. SPR 16414' MD 6448' TVD. MW = 9.5 PPG 10:30 hrs Pumpl ) 20 SPM 710 PSI 30 SPM 960 PSI Pump2 ) 20 SPM 690 PSI 30 SPM 950 PSI OA=550 psi 7/6/2017 7/6/2017 6.00 PRODt DRILL DDRL P DDrill 6-3/4" production hole f/ 16588' 16,588.0 17,268.0 12:00 18:00 MD to 17268' MD 6,460' TVD, Pump 260 gpm= 2645 psi on w/ 20% FO, Rotate @ 140 rpm's w/1 3K Tq on, 10K Tq off. WOB= 10K, ECD= 11.36 ppg EMW, Max gas= 1255 units.. PIU= 201 K, S/0= 82K, ROT= 127K, ADT= 4.39, Bit hrs= 37.18, Total Jar hrs= 37.18. Holding 295 psi back pressure on connections. SPR 17173' MD 6457' TVD. MW = 9.5 PPG 17:15 hrs Pumpl ) 20 SPM 730 PSI 30 SPM 980 PSI Pump2) 20 SPM 710 PSI 30 SPM 980 PSI 7/6/2017 7/7/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4" production hole f/ 17268' 17,268.0 17,915.0 18:00 00:00 MD to 17915' MD 6473' ND, Pump 268 gpm= 2890 psi on w/ 21 % FO, Rotate @ 140 rpm's w/14K Tq on, 11 K Tq off. WOB= 9K, ECD= 11.56 ppg EMW, Max gas= 4180 units.. P/U= 203K, S/0= 72K, ROT= 130K, ADT= 3.75, Bit hrs= 40.93, Total Jar hrs= 40.93. Holding 295 psi back pressure on connections. SPR 17836' MD 6470' ND. MW = 9.5 PPG 23:00 hrs Pumpl ) 20 SPM 810 PSI 30 SPM 1080 PSI Pump2) 20 SPM 810 PSI 30 SPM 1060 PSI OA=520 psi 87 bbls lost to formation last 24 hrs. Page 31145 Report Printed: 7/3112017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time EM Time Cur(hr) Phase Op Code Activity Code Time P -T -X Operation St on room End! Oeplh (We) 7/7/2017 7/7/2017 6.00 PRODI DRILL DDRL P DDrill 6-3/4" production hole f/ 17915' 17,915.0 18,563.0 00:00 06:00 MD to 18563' MD 6492' TVD, Pump @ 260 gpm= 2780 psi on w/ 20% FO, Rotate @ 140 rpm's w/14K Tq on, 42K Tq off. WOB= 9K, ECD= 11.48 ppg EMW, Max gas= 4350 units.. PIU= 220K, S/O= 65K, ROT= 130K, ADT= 3.95, Bit hm= 44.88, Total Jar hm= 44.88. Holding 295 psi back pressure on connections. SPR 18500' MD 6491' TVD. MW = 9.5 PPG 05:15 hrs Pumpl ) 20 SPM 810 PSI 30 SPM 1100 PSI Pump2 ) 20 SPM 810 PSI 30 SPM 1100 PSI 7/7/2017 7/7/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4" production hole f/ 18563' 18,563.0 19,039.0 06:00 12:00 MD to 19039' MD 6491' TVD, Pump @ 266 gpm= 2810 psi on w/ 20% FO, Rotate @ 140 rpm's w/14K Tq on, 12K Tq off. WOB= 7K, ECD= 11.48 ppg EMW, Max gas= 185 units.. PIU= 226K, S/O= N/A, ROT= 125K, ADT= 4.49, Bit hrs= 49.37, Total Jar hrs= 49.37. Holding 295 psi back pressure on connections. OA=500 psi 7/7/2017 71712017 5.75 PROD1 DRILL DDRL P DDrill 6-3/4" production hole f/ 19039' 19,039.0 19,448.0 12:00 17:45 MD to 19448' MD 6479' TVD, Pump @ 266 gpm= 2910 psi on w/ 20% FO, Rotate @ 140 rpm's w/13K Tq on, 11.5K Tq off. WOB= 8K, ECD= 11.49 ppg EMW, Max gas= 1117 units.. P/U= 220K, BID= N/A, ROT= 125K, ADT= 4.20, Bit hrs= 53.57, Total Jar hrs= 53.57. Holding 295 psi back pressure on connections. SPR 19259' MD 6486' TVD. MW = 9.5 PPG 14:50 hrs Pumpl ) 20 SPM 810 PSI 30 SPM 1100 PSI Pump2) 20 SPM 830 PSI 30 SPM 1100 PSI 7/7/2017 7/7/2017 3.50 PROD1 DRILL BKRM P BROOH f/19448' MD t/18599' MD. 19,448.0 18,599.0 17:45 21:15 264 gpm, 2820 psi, 20% FO, 140 rpm, 12K tq. Collars slid down on the following NRP's while coming out: Stand 198 - bottom joint - bottom collar, Stand 197 - bottom joint - bottom collar, Stand 196 - bottom joint - bottom collar. Page 32145 Report Printed: 7131/2017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Tran,Our (hr) Phase Op Code Activity Cotle Time P -T -X opembon alert Depth (ftKB) End DOM (WE) 7/7/2017 7/8/2017 2.75 PROD1 DRILL CIRC P CBU x2. 264 gpm, 2790 psi. 140 rpm, 18,599.0 18,409.0 21:15 00:00 12K tq. Rack back one stand DP after first BU f/18599' MD 1118409' MD 112 bbls lost to formation last 24 his 7/8/2017 7/8/2017 0.50 PROD1 DRILL CIRC P Complete CBU. 264 gpm, 2790 psi, 16,409.0 18,470.0 00:00 00:30 19% FO, 140 rpm, 12K tq. 7/8/2017 7/8/2017 1.50 PROD1 DRILL MPDA P Change out RCD bearing easy. Trap 18,470.0 18,470.0 00:30 02:00 300 psi w/annular preventer. Remove super slider from middle joint. Strip out and replace bearing assy. Attempt to strip bearing assy to RCD head. Unable to strip. Rotate at 5 rpm and install bearing assy. Replace super slider. 7/8/2017 7/8/2017 3.50 PROD1 DRILL REAM P Wash and ream in hole (/18470' MD 18,470.0 19,448.0 02:00 05:30 1119448' MD. 100 rpm, 12K tq, 210 gpm, 2600 psi, 7/8/2017 7/8/2017 6.50 PROD1 DRILL DDRL P DDrill 6-3/4" production hole f/ 19448' 19,448.0 19,855.0 05:30 12:00 MD to 19855' MD 6472' TVD, Pump @ 268 gpm= 3045 psi on w/ 20% FO, Rotate @ 140 rpm's w/1 2K Tq on, 12K Tq off. WOB= 6-1 OK, ECD= 11.66 ppg EMW, Max gas= 55 units. P/U= 220K, S/0= N/A, ROT= 125K, ADT, 4.13, Bit hrs= 57.7, Total Jar hrs= 57.7. Holding 295 psi back pressure on connections. SPR 19822' MD 6467' TVD. MW = 9.5 PPG 11:00 hrs Pumpl ) 20 SPM 880 PSI 30 SPM 1220 PSI OA=500 psi 7/8/2017 7/8/2017 6.00 PROD? DRILL DDRL P DDrill 6-3/4" production hole f/ 19855' 19,855.0 20,206.0 12:00 18:00 MD to 20206' MD 6469' TVD, Pump @ 266 gpm= 2970 psi on w/ 21 % FO, Rotate @ 140 rpm's w/1 3K Tq on, 11 K Tq off. WOB= 8K, ECD= 11.60 ppg EMW, Max gas= 113 units. P/U= 222K, S/0= N/A, ROT= 126K, ADT= 4.18, Bit hrs= 61.88, Total Jar hrs= 61.18. Holding 295 psi back pressure on connections. SPR 19921' MD 6473' TVD. MW = 9.5 PPG 12:45 hrs Pumpl ) 20 SPM 890 PSI 30 SPM 1220 PSI Pump2) 20 SPM 890 PSI 30 SPM 1200 PSI Page 33145 ReportPrinted: 7/31/2017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sten Time End Time Dur (hr) Phase Op Code Activity Coda Torre P -T -X Opembon Start Depm (ftKB) End Depth (ftKS) 7/872017 7!9/2017 6.00 PRODi DRILL—DDRL P DDrill 6-3/4" production hole it 20206' 20,206.0 20,673.0 18:00 00:00 MD to 20673' MD 6442' TVD, Pump @ 276 gpm= 3080 psi on w! 21 % FO, Rotate @ 140 rpm's w11 3K Tq on, 11K Tq off. WOB= 8K, ECD= 11.61 ppg EMW, Max gas= 1024 units. P/U= 219K, S/0= N/A, ROT= 125K, ADT= 4.7, Bit hrs= 66.58, Total Jar hrs= 66.58. Holding 295 psi back pressure on connections. SPR 20585' MD 6449' TVD. MW = 9.5 PPG 22:45 hrs Pumpl ) 20 SPM 840 PSI 30 SPM 1120 PSI Pump2) 20 SPM 840 PSI 30 SPM 1080 PSI OA=480 psi. 68 bbls lost to formation last 24 hrs 7/92017 7/9/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4" production hole f/ 20673' 20,673.0 21,133.0 00:00 06:00 MD to 21133' MD 6437' TVD, Pump 268 gpm= 3000 psi on w/ 21 % FO, Rotate @ 140 rpm's w/13K Tq on, 12K Tq off. WOB= 8-12K, ECD= 11.60 ppg EMW, Max gas= 555 units. P/U= 214K, S/0= N/A, ROT= 125K, ADT= 4.82, Bit hrs= 71.40, Total Jar hrs= 71.40. Holding 295 psi back pressure on connections. S 7/9/2017 7/9/2017 6.00 PROW DRILL DDRL P DDrill 6-3/4" production hole f/ 21133' 21,133.0 21,562.0 06:00 1200 MD to 21562' MD 6434' TVD, Pump 266 gpm= 3050 psi on w/ 20% F0, Rotate @ 120 rpm's w/14K Tq on, 13K Tq off. WOB= 8-11 K, ECD= 11.70 ppg EMW, Max gas= 1670 units. P/U= 222K, S(0= N/A, ROT= 127K, ADT= 4.5, Bit hrs= 75.90, Total Jar hrs= 75.90. Holding 295 psi back pressure on connections. SPR 21152' MD 6437' TVD. MW = 9.5 PPG 06:23 hrs Pumpl ) 20 SPM 875 PSI 30 SPM 1230 PSI Pump2) 20 SPM 875 PSI 30 SPM 1210 PSI SPR 21526' MD 6437' TVD. MW= 9.5 PPG 11:35 hrs Pumpl ) 20 SPM 895 PSI 30 SPM 1240 PSI Pump2) 20 SPM 895 PSI 30 SPM 1220 PSI Page 34/45 Report Printed: 7131!2017 4 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time EM Time Dur (h,) Phase op Code Activity Cada Trine P -RX �� Start Depth (ftKB) EM Depth (W3) 7/9/2017 7/9/2017 5.75 PROD1 DRILL DDRL P DDrill 6-3/4" production hole V 21562' 21,562.0 22,004.0 12:00 17:45 MD to 22004' MD 6436' TVD, Pump @ 275 gpm= 3290 psi on w/ 20% FO, Rotate @ 140 rpm's w/14K Tq on, 13K Tq off. WOB= 14K, ECD= 11.63 ppg EMW, Max gas= 2518 units. P/U= 228K, S/O= N/A, ROT= 124K, ADT= 3.52, Bit hrs= 79.42, Total Jar hrs= 79.42. Holding 295 psi back pressure on connections. Faulted out of zone into the Kalubik formation at 21,935' MD 6436'TVD. SPR 22004' MD 6436' TVD. MW= 9.5 PPG 17:50 hrs Pumpl ) 20 SPM 910 PSI 30 SPM 1240 PSI Pump2) 20 SPM 910 PSI 30 SPM 1240 PSI OA=500 psi 7/9/2017 7/9/2017 1.25 PROD1 DRILL BKRM T BROOH f/22004' MD V21780' MD. 22,004.0 21,780.0 17:45 19:00 280 gpm, 3065 psi, 20% FO, 140 rpm, 13K tq. 7/9/2017 7/9/2017 1.50 PRODi DRILL MPDA T Change out RCD bearing easy. Trap 21,780.0 21,780.0 19:00 20:30 300 psi w/annular preventer. Remove super slider from middle joint. Strip out and replace bearing assy. Rotate at 5 rpm and install bearing assy. Replace super slider. 7/9/2017 7/9/2017 1.25 PROD1 DRILL REAM T Wash and ream f/21780' MD V22004' 21,780.0 22,004.0 20:30 21:45 MD. 266 gpm, 3160 psi, 20% FO, 100 rpm, 12K tq. 7/9/2017 7/10/2017 2.25 PROD1 DRILL DDRL P DDrill 6-3/4" production hole f/ 22004' 22,004.0 22,023.0 21:45 00:00 MD to 22023' MD 6436' TVD, Pump @ 289 gpm= 3465 psi on w/ 20% FO, Rotate @ 100 rpm's w/1 1.5K Tq on, 11K Tq off. WOB= 7K, ECD=11.52 ppg EMW, Max gas= 13 units. P/U= 228K, S/O= WA, ROT= 124K, ADT= 2, Bit hrs= 81.42, Total Jar hrs= 81'42. Holding 295 psi back pressure on connections. OA=500 psi. 112 bbls lost to formation last 24 hrs 7/10/2017 7/10/2017 3.50 PROD1 DRILL DDRL P DDrill 6-3/4" production hole f/ 22023' 22,023.0 22,055.0 00:00 03:30 MD to 22055' MD 6436' TVD, Pump @ 289 gpm= 3400 psi on w/ 20% FO, Rotate @ 100 rpm's w111.5K Tq on, 12K Tq off. WOB= 7K, ECD= 11.52 ppg EMW, Max gas= 13 units. P/U= 228K, S/O= N/A, ROT= 124K, ADT= 3.49, Bit hrs= 84.91, Total Jar hrs= 84.92. Holding 295 psi back pressure on connections. Page 35145 Report Printed: 7/31/2017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stmt Time End Time Dur (hr) Phew Cp Code Activity Cade Time P -T -X Operation start Depen (RKB) End Depth(ftKB) 7/10/2017 7/10/2017 1.00 PROD1 CASING BKRM P BROOH f/22055' MD t/21965' MD. 22,055.0 21,935.0 03:30 04:30 263 gpm, 3060 psi, 21 % FO, 100 rpm, 13K tq. Observe packoff at 21965' MD. Drop below packoff. BROOH with reduced parameters f/21965' MD t/21935' MD. 84 gpm, 1050 psi, 14% FO. 20 rpm, 13K tq. 7/10/2017 7/10/2017 2.00 PROD1 CASING BKRM -F— Stage up to 120 rpm and 268 gpm. 21,935.0 21,627.0 04:30 06:30 BROOH f/21935' MD U21627' MD pt 100 fph. Commence weighting up mud system to 10 Pips. 7/10/2017 7/10/2017 7.50 PROD1 CASING CIRC P Circulate and condition mud system. 21,627.0 21,724.0 06:30 14:00 Weight u 10 g p to peg. Rotate and reciprocate f/21627' MD U21724' MD. Rotate at 110 rpm, 12.31K tq, PU=136K SO=113K. 204 gpm, 2091 psi. SPR 21713' MD 6436' TVD. MW = 10 PPG 13:40 hrs Pumps ) 20 SPM 940 PSI 30 SPM 1300 PSI Pump2) 20 SPM 920 PSI 30 SPM 1260 PSI 7/10/2017 7/10/2017 4.75 PROD1 CASING BKRM P BROOH (21724' MD t/20815' 21,724.0 20,832.0 14:00 18:45 MD.226 gem, 2430 psi, 20% FO, 100- 120 rpm,13k tq, ECD=11.74. Maintain 130 psi back pressure during connections. Pack off at 20815' MD. Attempt to work through with same parameters. Packing off at same depth each time. 7/10/2017 7/11/2017 5.25 PROD1 CASING BKRM P BROOH f/20832' MD t/20290' MD 20,832.0 20,290.0 18:45 00:00 w/reduced parameters. 84 gpm, 17% FO, 25 rpm, 14K tq, 200 fph holding 130 psi back pressure on connections. OA=380 psi 199 bbls lost to formation last 24 hrs 7/11/2017 7/11/2017 2.00 PROD1 CASING BKRM P Continue to backream out from 20,290 20,290.0 20,019.0 00:00 02:00 -ft MD to 20,019 -ft MD, at 84 gpm at 900 psi. 17% F/O, 25 rpm w/ 14K To holding 130 psi on annulus during connections 7/11/2017 7/112617 2.00 PROD1 CASING CIRC P CBU. Reciprocate f/20019' MD 20,019.0 20,014.0 02:00 04:00 1/20114' MD, 80 rpm, 12K tq, 253 gpm, 2870 psi. 135K rot up wt, 117 rot do wt. 7/11/2017 7/11/2017 2.00 PROD? CASING OWFF T OWFF. Shut in well and observe 50 20,014.0 20,014.0 04:00 06:00 psi build. Open well and observe flow back. Observe decrease in flow f/4.6 bbl/hr to 1 bbl/hr.over 1 hr duration. 4.6 bbl total bled back. Shut in well. 16 psi in 10 min's. Repeat bleed process for 30 min. Observe decrease in flow f/507 bbl/hr to 2.1 bbl/hr. Page 36145 Report Printed: 7/3V2017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time log Siad Time End Too Our @r) Phase op Code Ad ty Code Time P -T -X OperD Start DepMDePM (flK0 End 13) 7111/2017 7/11!2017 6.00 PROD1 CASING BKRM P BROOH f120114' MD 019111' MD. t 20,014.0 19,111.0 19,11ftl.0 06:00 12:00 80 rpm, 1 OK tq, 210 gpm, 2143 psi, 134K rot up wt. 550 ft/hr. Observe increase in 1q, pump pressure and hoist wt. f/19172' MD V19125' MD. Slow string speed to 100 fph. 7/11/2017 7/11/2017 6.00 PROD1 CASING PMPO P Pump OOH f/1911 VMD 018880' MD. 19,111.0 18,880.0 12:00 18:00 2 bpm, 880 psi. Ream each stand pulled at 20 bpm, 20 rpm, 11-13K tq. PU=205K Rot=125K. Unable to BROOH due to continous packoft. 7/11/2017 7/11/2017 4.25 PROD1 CASING PMPO P Pump OOH f/18880' MD 0118690' 18,880.0 18,690.0 18:00 22:15 MD. 2 bpm, 860 psi. Ream each stand pulled at 20 bpm, 20 rpm, 11-13K tq. PU=205K Rot=125K. Unable to BROOH due to continous packoffs. 7/11/2017 7112/2017 1.75 PROD1 CASING BKRM P BROOH f/18690' MD 1118610' MD.2 18,690.0 18,610.0 22:15 00:00 bpm, 760 psi, 20 rpm, 11-13K tq, PU=205K Rot=125K. OA=300 psi 162 bbls lost to formation last 24 hrs 7112/2017 7/12/2017 4.50 PROD1 CASING BKRM P BROOH f/18610' MD 018407' MD. 2 18,610.0 18,407.0 00:00 04:30 bpm, 760 psi, 10 to 20 rpm, 11-13K Tq, PU=205K Rot=144K. Adjusted to pulling speed to 200-ft1hr and increased PR to 24 spm (101 gpm) at 980 psi at 20 rpm w/ 12.5k TQ ROT UP wt=141K 7/12/2017 7/12/2017 1.50 PROD1 CASING BKRM P BROOH f/18610' MD 018407' MD. 2 18,407.0 18,219.0 04:30 06:00 bpm, 760 psi, 10 to 20 rpm, 11-13K Tq, PU=205K Rol=144K. Adjusted to pulling speed to 200-ft/hr and increased PR to 24 spm (101 gpm) at 980 psi at 20 rpm w! 12.5k TQ ROT UP wt=141K 7/12/2017 7112/2017 6.00 PROD1 CASING BKRM P BROOH f/18,219' MD V17,230' MD. 18,219.0 17,230.0 06:00 12:00 210 gpm, 1980 psi, staging up to 80 to 100 rpm, 11.5K Tq, Rot UP wl =130K while pulling at 275-ft/hr then increasing parameters as hole allows and preventing pack offs. OA=315 psi. 7/12/2017 7/12/2017 6.00 PROD1 CASING BKRM P BROOH f/17230' MD V15600' MD. 17,230.0 15,600.0 12:00 18:00 211 gpm, 1865 psi,120 rpm, 10K Tq, 500-550 fph.. 7112/2017 7/12/2017 3.50 PROD1 CASING BKRM P BROOH (/15600' MD 1114423' MD. 15,600.0 14,423.0 18:00 21:30 211 gpm, 1820 psi,120 rpm, 9K Tq, 600-650 fph.. Page 37/45 Report Printed: 7/31/2017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code AcOvItr Code Thee P -T -X Operation 3ted Depm I (WB) End Depth (M(B) 7/12/2017 7/13/2017 2.50 PROD1 CASING BKRM P Encounter packoff at 14423' MO. 14,423.0 14,330.0 21:30 00:00 Unable to work through with full parameters. Reduce parameters to 84-105 gpm, 20 rpm, 100-175 fph. BROOH f/14423' MD 1/14330' MD. OA=350 psi 170 bbls lost to formation last 24 hrs 7/13/2017 7/13/2017 7.50 PROD1 CASING BKRM P BROOH f/14330' MD 1/14065' MD 14,330.0 14,065.0 00:00 07:30 with varying parameters to mitigate packoffs. 10-20 rpm, 8K tq, 20 gpm=480 psi, 42 gpm=540 psi, 60 gpm=610 psi, 84 gpm=710 psi. 105 gpm=815 psi. Hoist speeds 20-150 fph. rotating hoist weight=132K, rotating slack weight= 115K. 7/1312017 7/13/2017 2.50 PROD1 CASING BKRM P BROOH f/14065' MD U13725' MD 14,065.0 13,725.0 07:30 10:00 staging up parameters to 186 gpm, 1460 psi, 70 rpm, 10K tq, 175 fph hoist speed. 7/13/2017 7/13/2017 0.25 PROD1 CASING MPDA T Monitor well. 13,725.0 13,725.0 10:00 10:15 7/13/2017 7/13/2017 0.50 PROD1 CASING MPDA T Change out RCD bearing easy. 13,725.0 13,725.0 10:15 10:45 7113/2017 7/13/2017 1.25 PROD1 CASING BKRM P BROOH f/13725' MD U13522' MO. 13,725.0 13,522.0 10:45 12:00 186 gpm, 1400 psi, 70 rpm, 8K tq, 500 fph. 7/13/2017 7/13/2017 2.00 PROD1 CASING BKRM P BROOH f113522' MD 1/13060' MD. 13,522.0 13,080.0 12:00 14:00 211 gpm, 1690 psi, 10070 rpm, 8.5K tq, 250450 fph. Encounter packoff at 13080' MD. 7/13/2017 7/13/2017 2.25 PROD1 CASING BKRM P Unable to clear packoff. Wash and 13,080.0 13,050.0 14:00 16:15 ream to 13165' MD. BROOH f/13165' MD t13050' MD. staging up flow rate f/126 gpm t/211 gpm and rotary f/30 rpm 1/90 rpm. Hoist speed f/35 fph U150 fph. 7/13/2017 7/13/2017 5.75 PROD1 CASING BKRM P BROOH (/13050' MD t/11952' MD. 13,050.0 11,952.0 16:15 22:00 211 gpm, 1600 psi, 80-100 rpm, 7.5K tq, 250 fph hoist speed. 7/13/2017 7/14/2017 2.00 PROD? CASING CIRC P Pump 30 bbl hi -vis sweep wl5 ppb 11,952.0 11,952.0 22:00 00:00 medium nut plug. CBU x2. Rotate and reciprocate f/ 11952' MD t111865' MD. 260 gpm, 2500 psi, 140 rpm. OA=400 psi 108 bola lost to formation last 24 hrs 7/14/2017 7/14/2017 1.00 PROD1 CASING CIRC P Con't to circulate. Rotate and 11,952.0 11,865.0 00:00 01:00 reciprocate f/ 11952' MD t/11865' 44D. 260 gpm, 2461 psi, 140 rpm, 7.5K tq. 7/14/2017 7/14/2017 1.25 PROD1 CASING SI -PC P Set back one stand OP. Slip and cul 11,865.0 11,775.0 01:00 02:15 91' drilling line. Sim-ops/Perform draw down test. Initial shut in pressure=92 psi. Shut in pressure decreased to 17 psi after 13 bleed cycles. Bled back 1 bbl total. Page 38/45 ReportPrinted: 7/31/2017 . " Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sten Time End Time Dur (hr) Phi Op Code Active Cotle ty Time P -T- X Operation Siad DepN (WIS) End Depm tftKB) 7/14/2017 7/14/2017 1.25 PRODt CASING MPDA P Remove RCD bearing assy. Install trip 11,775.0 11,775.0 02:15 03:30 nipple. Monitor well while installing trip nipple. Static. 7/14/2017 7114/2017 4.25 PROD? CASING PMPO P Pump OOH f/11775' MD t/9510' MD. 11,775.0 9,510.0 03:30 07:45 3.5 bpm, 950 psi, 14% FO, PU=150K, 3000 fph. 7/14/2017 7/14/2017 0.25 PROD1 CASING RGRP T Drilling line not spooling properly on 9,510.0 9,510.0 07:45 08:00 drawworks.Unspool and respool drilling line on drawworks. 7/14/2017 7/1412017 5.75 PROD1 CASING PMPO P Pump OOH 89510' MD V5610 MD. 9,510.0 5,610.0 08:00 13:45 3.5 bpm, 920 psi, 14% FO, PU=108K, 3000 fph. 7/14/2017 7/14/2017 1.75 PROD1 CASING OWFF P OWFF. Slight flow from well starting at 5,610.0 5,610.0 13:45 15:30 1.8 bph decreasing to 1.3 bph in 75 mins. Flow back total of 1.6 bbls. 7/14/2017 7114/2017 1.50 PROD1 CASING TRIP P POOH on elevators f/561 o' MD 5,610.0 5,021.0 15:30 17:00 1/5021' MD at 700 fph. PU=112K SO=92K. Observe improper displacement of 5.32 bbl gain. 7/14/2017 7114/2017 5.50 PROW CASING TRIP T RIH (/5021' MD V11930' MD. 5,021.0 11,930.0 17:00 22:30 PU=161K S0=1041K. Calc disp=39.2 bbls Act disp=42.7 bbls 7/1412017 7/15/2017 1.50 PROD1 CASING CIRC T CBU. 191 gpm, 1600 psi, 19% FO, 11,930.0 11,930.0 22:30 00:00 10.72 ppg ECD 2.6 bbls lost to formation last 24 hrs 711512017 7/15/2017 0.50 PRODt CASING CIRC T Continue to circulate at 11,930 -ft at 11,930.0 11,930.0 00:00 00:30 191 gpm at 1,540 psi w! 19% F10, ECD+10.72, Total stks pumped = 4,622. 7/15/2017 7/1512017 3.00 PROD1 CASING OWFF T Line up and monitor well on trip tank, 11,930.0 11,930.0 00:30 03:30 timing returns in 1 qt. viscosity cup. Initial fill = 11.56 seconds, observe steady flow decrease in rate to 38 seconds to fill 1 qt. 2.6 bbl gain in him of observation. 7/15/2017 7/15/2017 8.50 PRODi CASING PMPO T Pump out of the hole from 11,929 -ft at 11,930.0 6,250.0 03:30 12:00 149 gpm at 1,050 psi w/ 162K UPw wt. Increasing string speed to 2,000 ft/hr. At 6,500 -ft increased string speed to 2,500-ft/hr while circulating at 149 gpm at 780 psi w/ 116K UP wt. to 6,250 -ft. 4.3 bbl loss in 12 hrs. 7/15/2017 7/15/2017 1.25 PROW CASING PMPO T Continue to pump out of the hole from 6,250.0 5,021.0 12:00 13:15 6,250 -ft at 150 gpm at 750 psi w/ 14% F/O w/ 11 OK UPw wt. at 2,500-ft/hr to 5,353 -ft - observed improper hole fill. Slowed pulling speed to 2000-ftlhr. and Continue to pump out of the hole to 5,021 -ft at 150 gpm at 650 psi w/ 14% F/O, w/ 103K UP wt. 7/15/2017 7/15/2017 3.75 PROD1 CASING PMPO P Continue to pump out of the hole to 5,021.0 2,961.0 13:15 17:00 5,021 -ft at 150 gpm at 650 psi w! 14°k F/O, w/ 103K UP wt. 2000 fph to 2961'MD. Page 39145 Report Printed: 7/31/2017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Thna Eno Tlme Our (hr) Phase Op Cede Adivdy Code Time P.T-X Openmon Stan oepm (flK8) End Depth (WB) 7/15/2017 7/16/2017 7.00 PROD? CASING OWFF T OWFF,Well flowing slightly. Monitor 2,961.0 2,961.0 17:00 00:00 returns by timing returns in 1 qt. viscosity cup. Initial fill = 34.56 seconds/ .619 bph, observe steady flow decrease in rate to 70.53 seconds/.303 bph.. 1.64 bbl gain in 7 hrs of observation. Sim-ops/Pick up Volant centralizers to dg floor, Clean and clear rig floor, prepare to lay down DP, service dg. 2.6 bbls lost to formation last 24 hrs 7/16/2017 7/16/2017 12.00 PROD1 CASING OWFF T OWFF,Well flowing slightly. Monitot 2,961.0 2,961.0 00:00 12:00 returns by liming returns in 1 qt. viscosity cup. Initial fill = 78.59 seconds/.27 bph, observe steady flow decrease in rate to 106.25 seconds/.2 bph.. .95 bbl gain in 12 hrs of observation. 7/16/2017 7/16/2017 1.50 PROD1 WHDBOP MPSP P Rig up and set 7 5/8" Baker Storm 2,961.0 0.0 12:00 13:30 Packer. TOP=98.75' MD COE=106.23' MD. Test and chart packer to 1000 psi/10 min. Rack back stand. 7/16/2017 7/16/2017 1.00 PROD1 WHDBOP WWWH P Pull marring. Make up stack washer. 0.0 0.0 13:30 14:30 Flush ROPE. 7/16/2017 7/16/2017 0.50 PROD1 WHDBOP RURD P Make up 4 1/2" test jt. and set test 0.0 0.0 14:30 15:00 plug. Rig up to test BOPE. 7/16/2017 7/16/2017 5.50 PROD1 WHDBOP BOPE P Test BOPE. All test to 250/3,500 PSI. 0.0 0.0 15:00 20:30 charted test except Super choke and man operated choke valve to 250 / 2,000 PSI. tested with 3.5" and 4.5" test joint. Annular tested w/3 1/2" test jt 250/2500 psi -w/4 1/2 test it 250/3500 psi. Koomey drawdown test start - 3,000 PSI, after functions = 1,750 PSI, 13 sec for 200 PSI / with 2 elect pumps, 64 sec total to obtain full system press with elec / air pumps. Nitrogen bottles=2100 psi avg. Test PVT and gas alarms. Test witness waived by Lou Laubenstein with AOGCC. 7/16/2017 7/16/2017 0.50 PRODt WHDBOP RURD P Pull test plug, set 9" ID wearring. Blow 0.0 0.0 20:30 21:00 down test equipment. 7/16/2017 7/16/2017 0.75 PROD1 WHDBOP MPSP P Make up a stand of 4" drill pipe. Make 0.0 0.0 21:00 21:45 up Baker Oil tools retrieving tool. RIH , retrieve storm packer, pull out and lay down Baker storm packer. 7/16/2017 7/16/2017 1.75 PROD1 CASING PULD P POOH f/2966 t/2683' MD laying down 2,966.0 2,683.0 21:45 23:30 4" OR Lay down 10 jts. 7/16/2017 7/17/2017 0.50 PROD1 CASING SVRG P Service dg. 2,683.0 2,683.0 23:30 0000 Page 40145 ReportPrinted: 7/31/2017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Our (hi Phase Op Code Achwi, Code Time P -T -X Operafion Start Depth We) End Depth (ftKB) 7/17/2017 7/17/2017 1.50 PROD1 CASING PULD P POOH Laying down drill pipe from 2,683.0 2,315.0 00:00 01:30 2,683 -ft to 2,315 -ft (Bit Depth) monitor well and continue pulling at 200-ft/hr, the next 2 jts at 500-11/hr and 5 jts at 1,000 -Whir while monitoring annulus and trip tank. 7/17/2017 7/17/2017 0.75 PROD1 CASING CIRC P Pump surface to surface at 128 gpm 2,315.0 2,315.0 01:30 02:15 at 489 psi - 990 Total STKS. 7/17/2017 7/17/2017 2.75 PROD1 CASING PULD P POOH laying down remaining 61 jts of 2,315.0 413.0 02:15 05:00 1 4" DP from 2,315-111 to 413 -ft. (6.75" Directional Ddg BHA) at 2,500-11/hr 7/17/2017 7/17/2017 1.50 PROD1 CASING OWFF T Monitor well for flow via vise cup, 1st 413.0 413.0 05:00 06:30 collection was in 123 seconds - 7.3 gph, 2nd collection = 239 seconds - 3.7 gph. 3rd collection = 242 seconds - 3.69 gph, 4th collection = 223 seconds = 4 gph, 5th collection - 207 seconds = 4.3 gph, 6th collection- 203 seconds = 4.4 gph 7/1712017 7/17/2017 0.50 PROD? CASING PULD P Lay down 2jts 4"HWDP. 413.0 352.0 06:30 07:00 7/17/2017 7/17/2017 0.50 PROW CASING CIRC P Line up and circulate 10.5 ppg FloPro 352.0 352.0 07:00 07:30 mud from 352' MD to surface. 4 bpm, 750 psi. 310 strokes pumped 7/17/2017 7/17/2017 2.50 PRODi CASING OWFF T Monitor well for flow via vise cup, t at 352.0 352.0 07:30 10:00 collection was in 125 seconds - 7.1 gph, 2nd collection = 214 seconds - 4.2 gph. 3rd collection = 467 seconds - 1.9 gph, 4th collection = 426 seconds = 2.1 gph, 5th collection - 438 seconds = 2 gph, 6th collection- 617 seconds = 1.47 bph-7th collection -845 seconds=1.26 gph. 7/1712017 7/17/2017 2.50 PROD1 CASING BHAH P Lay down BHA. 352.0 0.0 10:00 12:30 7/17/2017 7/17/2017 1.00 PROD? CASING BHAH P Clean and clear rig floor. 0.0 0.0 12:30 13:30 7/17/2017 7/1712017 0.50 COMPZN CASING RURD P Rig up to run 4 1/2" liner. 0.0 0.0 13:30 14:00 7/17/2017 7/18/2017 10.00 COMPZN CASING PUTB P Pick up and RIH w/4 1/2", 12.6#, L-80, 0.0 6,012.0 14:00 00:00 HYD 563 perforated/blank production liner to 6012' MD as per detail. Torque connections to 4800 R/Ibs . PU=92K 5O=82K 7118/2017 7/18/2017 5.50 COMPZN CASING PUTS P Pick up and RIH w/4 1/2", 12.6#, L-60, 6,012.0 10,084.0 00:00 05:30 HYD 563 perforated/blank production liner from 6012' MD to 10084' MD as per detail. Torque connections to 4800 fUlbs . PU=127K SO=96K Ran 224-41/2", 12.6#, L-80 HYD 563 blank jts, 9-41/2", 12.6#, L-80 HYD 563 perforated jts., 17- 5.99" OD Baker swell packers, 16- Baker Frac Sleeves, Baker liner hanger/liner top packer, 253- 6.13" OD Hydroform centralizers, 238 -Stop rings No remakes, no rejects. Page 41146 Report Printed: 7131/2017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time EM Time Our (hr) Phase Op Code Activity CodeStart Time P -T -X Opemtlon Depth (ftK6) EM Depth(ftKB) 7/18/2017 7/18/2017 0.50 COMPZN CASING OTHR P PU and MU liner hanger assy. RIH 10,084.0 10,211.0 05:30 06:00 one stand to 10211' MD. 7/18/2017 7/18/2017 1.50 COMPZN CASING CIRC P Circulate one liner volume. 128 gpm, 10,211.0 10,211.0 06:00 07:30 558 psi. 7/18/2017 7/18/2017 1.50 COMPZN CASING RUNL P RIH w/liner on DP from 10211' MD to 10,211.0 11,921.0 07:30 09:00 11921' MD 7/18/2017 7/18/2017 1.50 COMPZN CASING CIRC P CBU at 11921' MD. 128 gpm, 650-570 11,921.0 11,921.0 09:00 10:30 psi, Obtain parameters. PU=146K, SO=104K, Rot=116K. 6K tq @ 20 rpm. 7/18/2017 7/18/2017 1.00 COMPZN CASING RUNL P RIH w/liner on DP from 11921' MD to 11,921.0 12,682.0 10:30 11:30 12682' MD.Work through tight hole at 11972' MD. PU=117K SO=101 K 7/18/2017 7/18/2017 11.00 COMPZN CASING RUNL P Cony to RIH w/liner on DP from 12,682.0 20,075.0 11:30 22:30 12682' MD to 20075' MD. PU=200K SO=50K 7/18/2017 7/18/2017 0.50 COMPZN CASING RUNL T Unable to work past tight hole at 20,075.0 20,075.0 22:30 23:00 20075' MD. Establish circulation at 1 bpm, 530 psi. Increase to 1.5 bpm, 650 psi. Attempt unsuccessfully to wash by tight hole. Cease pumping and work through tight hole by tagging up at a faster slack off rate. 7/18/2017 7/18/2017 0.50 COMPZN CASING RUNL P Con't to RIH Winer on DP from 20,075.0 20,126.0 23:00 23:30 20075' MD to 20126' MD. PU=191 K SO=70K 29.6 bbls lost to formation last 24 hrs 7/19/2017 7/19/2017 7.25 COMPZN CASING RUNL P Con't to RIH wAiner on DP from 20,126.0 20,391.0 00:00 07:15 20126' MD to 20391' MD. PU=198K SO=70K 7/19/2017 7/19/2017 4.75 COMPZN CASING RUNL P Cont to RIH w/liner on DP from 20,391.0 20,820.0 07:15 12:00 20391' MD to 20820' MD. Rotate at 20 rpm w/torque limiter set at 1OK. PU=198K Rot SO=92 Rot=125K w/8K tq. Establish circ at 22 gpm/550 psi. 7/19/2017 7/19/2017 6.50 COMPZN CASING RUNL P Con't to RIH w/liner on DP from 20,820.0 21,037.0 12:00 18:30 20820' MD to 21037' MD. Rotate at 10 rpm w/torque limiter set at 10K. PU=191K SO=70K Rot --96K. Circ at 22 gpm/550 psi. Observe pressure increase to 717 psi. Cease pumping. 7/19/2017 7/20/2017 5.50 COMPZN CASING RUNL P Con't to RIH w/liner on DP from 21,037.0 21,537.0 18:30 00:00 21037 MD to 21537' MD. Rotate at 20 rpm wttorque limiter set at 16K. PU=200K SO=95K Rot=146K. 23.8 bbls lost to formation last 24 hrs OA=180 psi 7/20/2017 7/20/2017 8.00 COMPZN CASING RUNL P Con't to RIH wAiner on DP from 21,537.0 21,914.0 00:00 08:00 21537' MD to 21914' MD. Rotate at 20 rpm w/torque limiter set at 1 O PU=185K 120=95K.. Page 42145 Report Printed: 713112017 Operations Summary (with Timelog Depths) 3 2K-30 Rig: DOYON 142 Jbb: DRILLING ORIGINAL Time Log Slate T,. EM Tune our (hr) Phase op Cada Acv Ity Code NM P -T -X Opereuon Start Depth (ftKB) EM Depen MKB) 7/20/2017 7/20/2017 1.75 COMPZN CASING CIRC P Circulate drill pipe volume (120 bbls) 21,914.0 21,914.0 08:00 09:45 staging pump rate up to 1.8 bpm, 820 psi. PU=206K SO=94K 7/2012017 7/20/2017 1.25 COMPZN CASING PACK P Drop 1.625" ball. Pump on seat at 143 21,914.0 21,914.0 09:45 11:00 gpm, 1386 psi. Reduce pump rate to 87 gpm, 970 psi at 800 strokes. Ball on seat at 918 strokes. Increase pressure to 1500 psi and then to 1900 psi to set hanger..Set down string weight to ensure hanger set. Pressure up to 4000 psi to release running tool. Bleed off and pick up to clear rotating dogs. Rotate at 15 rpm and set down 50K to set packer.. 7/20/2017 7120/2017 0.75 COMPZN CASING PRTS P Close annular preventer. Test liner top 21,914.0 21,914.0 11:00 11:45 packer to 3500 psi/5 min. 7/20/2017 7/20/2017 0.25 COMPZN CASING PACK P Release from liner. Set back one 21,914.0 11,722.0 11:45 12:00 stand DP. 7/20/2017 7/20/2017 2.00 COMPZN WELLPR DISP P Clean and prep pits for displacement. 11,722.0 11,722.0 12:00 14:00 Reciprocate f111722' MD 1/11627' MO. Pump 35 bbls hi -vis 10.5 ppg brine spacer. Displace wellbore from 10 ppg FloPro mud to 10.5 ppg NaCl/KCL brine. Pump at 10 bpm,' 3532 psi, 31 % FO. PU=191 K S0=1 36K Total strokes pumped - =5618 7120/2017 7/20/2017 0.50 COMPZN WELLPR OWFF P OWFF. Static. 11,722.0 11,722.0 14:00 14:30 7/20/2017 72012017 0.75 COMPZN WELLPR CRIH P Spot 50 bbls corrosion inhibitor at 11,722.0 11,722.0 14:30 15:15 11722' MD. 8 bpm, 2233 psi, 23% FO. Total strokes pumped=1536. OWFF. Static. 7/20/2017 7/20/2017 0.50 COMPZN WELLPR PULD P Lay down 7Its 4" XT39 DP fit 1722' 11,722.0 11,502.0 15:15 15:45 MD t/11502' MD.PU=191 K SO=136K 720/2017 7/20/2017 2.25 COMPZN WELLPR PULD P Lay down 66 Its 4" XT39 HWDP 11,502.0 9,477.0 15:45 18:00 f111502' MD t/9477' MD.PU=186K S0=1 30K 7/20/2017 7121/2017 6.00 COMPZN WELLPR PULD P Lay down 198 jts 4" XT39 DP f/9477' 9,477.0 3,318.0 18:00 00:00 MD U3318' MD.PU=153K SO=107K 33 bbls lost to formation last 24 hrs 7/21/2017 7/21/2017 3.25 COMPZN WELLPR PULD P Lay down 105 jts 4" XT39 DP f/3318' 3,318.0 0.0 00:00 03:15 MD t/surface' MD.PU=153K SO=107K 7/212017 7/21/2017 0.75 COMPZN WELLPR PULD P Break out and lay down liner running 0.0 0.0 03:15 04:00 tool. Confirm shear of dog sub. 7/21/2017 7/21/2017 1.00 COMPZN RPCOMP WWWH P Pull wearring. Make up stack washer 0.0 0.0 04:00 05:00 and Flush BOPE. 7/21/2017 7212017 3.00 COMPZN RPCOMP RURD P Rig up casing handling equipment and 0.0 0.0 05:00 08:00 HES TEC wire spooler. 7/21/2017 7/2112017 2.00 COMPZN RPCOMP PUTS P Make up Baker Premier packer assy 0.0 125.0 08:00 10:00 and guage carrier. Install RokGuage DHG and TEC wire and test connection to 5000 psi. Page 43/45 Report Printed: 7/31/2017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start T,. End Time our (hr) ( ) Phase 0 Code p Act, Code ry Time P -T- X Oparetion Start Depth rt De End Depth ($Ka) 7/21/2017 7/21/2017 4.75 COMPZN RPCOMP PUTS P Pick up and RIH w/3 1/2", 9.3#, EUEm 125.0 3,179.0 10:00 14:45 tubing as per detail to 3179' MD. Install GriPro wire clamp every joint and fill every 10 joints. MU torque=2240 fl/lbs. 7/21/2017 7/21/2017 0.75 COMPZN RPCOMP DHEO P Rig up and test Cal SV to 500 psi. 3,179.0 3,179.0 14:45 15:30 (Good) 7/21/2017 7/21/2017 2.50 COMPZN RPCOMP PUTS P Pick up and RIH w/31/2", 9.3#, EUEm 3,179.0 5,017.0 15:30 18:00 tubing as per detail to 5017' MD. Install Gr Pro wire damp every joint.. 7/21/2017 7/22/2017 6.00 COMPZN RPCOMP PUTB P Pick up and RIH w/3 1/2", 9.3#, EUEm 5,017.0 9,059.0 18:00 00:00 tubing as per detail to 9059' MD. Install Gr Pro wire damp every joint. 13.3 bbls lost to formation last 24 hrs 7/22/2017 7/22/2017 6.00 COMPZN RPCOMP PUTS P Pick up and RIH w/3 1/2', 9.3#, EUEm 9,059.0 11,725.0 00:00 06:00 tubing as per detail to 11 725'MD. Install GriPro wire clamp every joint. PUW=115K SOW=82K , 7/22/2017 7/22/2017 1.25 COMPZN RPCOMP HOSO P Pick up its 376, 377, 378, 379 and no- 11,725.0 11,787.0 06:00 07:15 goat 11827' WLEG depth. Lay down above jts. Make up space out pups (2.28',2.29',4.25',10.30'),4 1/2" jt, Spaced out to be 3.00' above fully located. 7/22/2017 7/22/2017 1.75 COMPZN RPCOMP THGR P Make up hanger and landing jt. 11,787.0 11,824.0 07:15 09:00 Terminale TEC wire and test Swedge- Lok fittings to 5000 psi/5 mins. Drain BOPE. RIH and land hanger. 7/22/2017 7/22/2017 0.50 COMPZN RPCOMP RURD P RILDS. Rig down tubing handling 11,824.0 11,824.0 09:00 09:30 equipment. Rig up pressure test equip. 7/22/2017 7/22/2017 2.25 COMPZN RPCOMP PRTS P Test tubing to 5000 psi/30 mins 11,824.0 11,824.0 09:30 11:45 charted. Bleed tubing pressure to 2500 psi. Test IA to 4200 psi/30 mins charted. Bleed IA and tubing to 0 psi. Pressure up on IA to 2350 psi to open SOV. All tests good. 7/22/2017 7/22/2017 0.25 COMPZN RPCOMP RURD P Rig down test equip. 11,824.0 11,824.0 11:45 12:00 OA=140 psi. 7/22/2017 7/22/2017 0.50 COMPZN RPCOMP OWFF P OWFF. Static. 11,824.0 11,824.0 12:00 12:30 7/22/2017 7/22/2017 0.25 COMPZN RPCOMP RURD P Lay down landing jt. 11,824.0 0.0 12:30 12:45 7/22/2017 7/22/2017 0.25 COMPZN WHDBOP MPSP P Rig up and install HP type BPV. Test 0.0 0.0 12:45 13:00 from below to 2500 psi/5 mins charted. Good 7/22/2017 7/22/2017 1.50 COMPZN WHDBOP RURD P Clean and dear dg floor of GBR 0.0 0.0 13:00 14:30 tubing equipment. Sim-ops/Blow down cellar circulation lines. 7/22/2017 7/22/2017 4.50 COMPZN WHDBOP NUND P Pull mousehole. Remove MPD air 0.0 0.0 14:30 19:00 valve, RCD and Katch Kan. Remove choke and kill lines. Nipple down BOPE. Set back annular and double gate. Pick mud cross, single gate and risers. Stage on BOP deck. Sim- ops/Flush pit lines w/safe surf W. Page 44145 Report Printed: 7/31/2017 Operations Summary (with Timelog Depths) 2K-30 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log stad Time End Time Our (hr) Phase Op Code AdMty Code Time P -T -X Operation Starr Oeplh MKS) EM Depth (WS) 7/22/2017 7/22/2017 2.25 COMPZN WHDBOP NUND P Terminate TEC wire through tubing 0.0 0.0 19:00 21:15 spool. Prep tubing hanger for tree adapter flange. Install SBMF seal and test dart. Sim-ops/Break connections on adapter flange and risers from single gate. Break ram door bolts. Blow down pit and pump complexes. 7/22/2017 7/22/2017 0.75 COMPZN WHDBOP NUND P Nipple up tree adapter flange. 0.0 0.0 21:15 22:00 7/22/2017 7/22/2017 0.75 COMPZN WHDBOP PRTS P Test void to 250/5000 psi -15 mins 0.0 0.0 22:00 22:45 each. Witnessed by Co Man. 7/22/2017 7/23/2017 1.25 COMPZN WHDBOP NUND P Nipple up tree. 0.0 0.0 22:45 00:00 7/23/2017 7/23/2017 1.00 COMPZN WHDBOP NUND P Continue to NU tree. Install wing valve 0.0 0.0 00:00 01:00 and flange. 7123/2017 7/23/2017 1.00 COMPZN WHDBOP PRTS P RU test equip. Flood tree w/diesel and 0.0 0.0 01:00 02:00 purge air. Test tree to 250 psi/15 mins. Unable to achieve high pressure test " due to test dart leaking. Test witnessed by Co Man. 7/23/2017 7123/2017 0.75 COMPZN WHDBOP PRTS T Pick up t -bar and make up retrieval 0.0 0.0 02:00 02:45 tool. Pull test dart and change out O- ring. Reset test dart. 712312017 7/23/2017 1.50 COMPZN WELLPR PRTS P Fill tree w/diesel. Rig up test 0.0 0.0 02:45 04:15 equipment. Test tree to 10,000 psi/75 min's. Test witnessed by Co Man. 7/2312017 723/2017 0.75 COMPZN WELLPR MPSP P Pull test dart and HP BPV. Install H 0.0 0.0 04:15 05:00 BPV. 7/23/2017 7123/2017 7.00 COMPZN MOVE PULD P PJSM-Lay down 162 its 4" DP from 0.0 0.0 05:00 12:00 derrick. Sim-ops/Install gauges on tree and secure well. Rig on gen power at 09:50 hrs. 7/23/2017 723/2017 6.50 COMPZN MOVE PULD P PJSM- Lay down 183 its 4" DP from 0.0 0.0 12:00 18:30 derrick. Sim-ops/Prep support modules for rig move. 7/23/2017 7/24/2017 5.50 DEMOB MOVE RURD P Prep rig for move. Rig down 0.0 0.0 18:30 00:00 interconnects, prepare sub for skidding rig floor. Prep cellar for move. Rig down hoses to rock washer. Pick up hoses outside dg. Sim-ops/Clean handling equipment for NO testing. Remove drag chain, Rig down steam return lines for hot well. Clean pump room. Remove elevator links from top drive. Remove slip dies. KDTH laying matting boards on road between 2K Pad and 2H Pad. Release rig at 00:00 hrs 7-24-17. Page 45/45 Report Printed: 7/31/2017 NADConversion Kuparuk River Unit Kuparuk 2K Pad 2K-30 2K-30 NAD 27 Definitive Survey Report 01 August, 2017 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-30 Project Kuparuk River Unit TVD Reference: Rig: 39.21+115.70 @ 154.91usft Site: Kuparuk 21K Pad MD Reference: Rig: 39.21+115.70 @ 154.91 usft Well: 2K-30 North Reference: True Wellborn: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30 Database: OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zane: Alaska Zone 04 Using geodetic scale factor Well 2K-30 Date Audit Notes: From Well Position +N/S 0.00 usft Northing: 5,938,165.20 usft Latitude: 70° 14'32.241 N +E/ -W 0.00 usft Easting: 498,310.15 usft Longitude: 150'0'49.131 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 115.70 usft fellbore 2K-30 lagnetics Model Name Sample Date Declination Dip Angle Field Strength (1 P) uT) BGGM2017 6/25/2017 17.45 80.84 57 481.61 Design 2K-30 Date Audit Notes: From To Map Version: 1.0 Phase: ACTUAL Tie On Depth: 39.21 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 1,625.28 21K-30 Srvy 1 - SLB _GWD70 (2K-30) (usft) (usft) (usft) (") 1,723.38 39.21 0.00 0.00 190.00 Survey Program Date From To Map Map (usft) (usft) Survey (Wellbore). Tool Name Description Survey Date 98.42 1,625.28 21K-30 Srvy 1 - SLB _GWD70 (2K-30) GYD-GC-SS Gyrodata gyro single shots 6/16/2017 8:17: 1,723.38 3,237.982K-30 Srvy 2- SLB _MWD+GMAG(2K-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/17/2017 8:47:- 3,332.11 11,900.272K-30 Srvy 3- SLB _MWD+GMAG(2K-3 MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 6/22/201711:04: 11,995.32 21,992.592K-30 Srvy 4-SLB_MWD+GMAG(2K-3 MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 7/4/2017 1:43:0, Survey &12017 10.03:40AM Page 2 • COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD NDSS +N/S +E/ -W Northing Easting DLS Section (usft) (11 (") (usft) (usft) (usft) (usft) N (ft) ('1100') (ft) Survey Tool Name 39.21 0.00 0.00 39.21 -115.70 0,00 0.00 5,938,165.20 498,310.15 0.00 0.00 UNDEFINED 9842 0.70 335.02 9642 56.49 0.33 -0,15 5,938,165.53 498,310.00 1.18 -0.30 GYD-GC-SS(1) 115.00 0.64 341.59 115.00 -39.91 0.51 -0.22 5,938,165.71 498,309.93 0.54 -0.47 NOT an AcWal Survey 20" x 24" 130.17 0.59 34763 130.17 -24.74 0.67 -0.26 5,938,165.87 498,309.89 0.54 -0.61 GYD-GC-SS(1) 153.49 055 308.56 153.49 -1.42 0.85 -0.37 5,938,166.05 498,309.78 164 -0.78 GYD-GC-SS(1) 198.31 1.29 281.60 198.30 43.39 1.09 -1.04 5,938,16629 498,309.11 1.87 -0.89 GYD-GCSS(1) 245.08 1.15 279.09 245.O6 90.15 1.27 -2.02 5,938,166.47 498,308.13 0.32 -090 GYD-GC-SS(1) 34422 1.67 272.02 344.17 189.26 1.48 4.44 5,938,166.68 498,305.71 0.55 -0.68 GYDGC-SS(1) 372.32 1.55 256.14 37226 217.35 1.41 5.22 5,938,166.62 498,304.93 1.45 -0.49 GYD-GC-8S(1) 402.14 2.12 258.67 402.06 247.15 122 8.16 5,938,166.42 498,303.99 191 -0.14 GYD-GC-SS(1) &12017 10.03:40AM Page 2 • COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2KS0 Project Kuparuk River Unit TVD Reference: Rig: 39.21+115.70 @ 154.91usft Site: Kuparuk 2K Pad MD Reference: Rig: 39.21+115.70 @ 154.91us% Well: 2K-30 North Reference: True Wellbore: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30 Database: OAKEDMP2 Survey Lisp Lisp Vertical MD Inc Ari TVD TVD$S +N1 -S +E1 -W Northing Easting DLS Section (watt) 0 (") Wait) (usft) (usft) Wait) (1t) (ft) (.11001 (ft) Survey Tool Name 434.02 2.85 255.73 433.91 279.00 0.91 -7.50 5,938,166.11 498,302.65 2.32 0.41 GYD-GC-SS(1) 464.45 3.44 255.71 464.30 309.39 0.50 -9.12 5,938,165]0 498,301.03 1.94 1.09 GYD-GC-SS(1) 495.60 4.21 254.52 495.38 34047 304 -11.13 5,938,165.17 498,299.02 248 1.97 GYD-GCSS(1) 527.99 4.96 253.90 527,66 372.75 374 -1362 5,938,164.46 498,296.53 2.32 3.10 GYD-GCSS(1) 558.20 5.46 253.85 557.75 402.84 -1.50 -16.26 5,938,163.70 498,293.89 1.66 4.30 GYD-GCSS(1) 620.31 6.33 25750 619.53 464.62 5.07 -22.44 5,938,162.14 498,287.71 1.52 6.92 GYD-GC-SS(1) 714.48 6.32 255.63 713.13 558.22 5.48 -32.53 5,938,159.73 498,27763 0.22 11.4 GYD-GC-SS(1) 808.17 9.20 252.38 805.95 651.04 3.02 -04.66 5,938,155.19 498,26549 3.11 16.64 GYD-GC-S$(1) 902.25 8.96 248.05 898.85 743.94 -14.4 38.63 5,938,151.18 498,251.53 0.77 24.01 GYD-GC-SS(1) 997.69 10.76 242.54 992.88 837.97 -20.93 -73.43 5,938,144.29 498,236.73 2.13 33.36 GYD-GC-SS(1) 1,093.02 11,82 243.60 1,086.36 931.45 -29.37 -90.07 5,938,135.85 498,220.08 1.13 44.57 GYD-GCSS(1) 1,187.76 14.22 241.29 1,178.66 1,023.75 59.28 -108.97 5,938,125.95 498,201.18 2.59 57.60 GYD-GCSS(1) 1,281.83 16.11 241.20 1,269.45 1,114.54 -51.12 -130.54 5,938,114.12 498,179.61 2.01 73.01 GYD-GCS8(1) 1,376.52 19.18 240.72 1,359.68 1,204.77 -65.06 -155.63 5,938,100.19 498,154.52 3.25 91.09 GYD-GC-SS(1) 1,470.30 22.00 239.77 1,447.46 1,292.55 -81.44 -184.25 5,938,083.81 498,125.90 3.03 112.19 GYD-GC-SS(1) 1,531.27 22.06 240.25 1,503.98 1,349.07 -92.87 -20 05 5,938,072.39 498,106.10 0.31 126.89 GYD-GC-SS(1) 1,625.28 22.40 238.95 1,591.00 1,436.09 -110.87 -234.73 5,938,054.40 498,075.42 0.64 149.94 GYD4C-SS(1) 1,723.38 24.30 234.72 1,681.7 1,526.16 -132.17 -267.22 5,938,033.10 498,042.92 2.58 176.56 MWD+IFR-AK-CAZSC(2) 1,813.51 25.24 23302 1,762.90 1,607.99 -154.44 -297.71 5,938,010.84 498,01243 1.31 20379 MWD+1FR-AK-CAZSC(2) 1,90847 27.74 228.86 1,847.63 1,692.72 -181.08 -330.44 5,937,984.21 497,979.71 329 235.71 MWD+IFR-AK-CAZ-SC(2) 2,003.63 30.98 226.22 1,930.82 1,775.91 -212.71 -364.92 5,937,952.60 497,945.22 3.65 272.84 MWD+IFR-AK-CAZ-SC(2) 2,098.08 32.65 224.98 2,011.7 1,856.16 -247.55 4(10.48 5,937,917.76 497,909.66 1.90 313.33 MWD+IFR-AK-CAZ-SC(2) 2,193.26 34.05 224.15 2,090.58 1,935.67 -284.83 437.19 5,937,880.49 497,872.94 1.55 356.42 MWD+IFR-AK-CAZ-SC(2) 2,28760 3557 221.21 2,168.04 2,013.13 -324.43 -473.67 5,937,840.91 497,836.46 240 401.75 MWD+IFR-AK-CAZSC(2) 2,381.90 37.89 221.10 2,243.61 2,088.70 56689 -510.78 5,937,798A6 497,799.34 2.46 450.01 MWD+IFR-AK-CAZSC(2) 2,477.26 40.26 220.08 2,317.64 2,162.73 412.54 549.87 5,937,752.82 497,760.24 2.58 501.76 MWD+IFR-AKCAZ-SC(2) 2,572.39 43.66 215.72 2,388.38 2,23347 -462.75 -588.86 5,937,702.63 497,721.25 4.71 557.97 MWD+IFR-AK-CAZ-SC(2) 2,667.07 45.97 215.15 2,455.54 2,300.63 517.12 527.54 5,937,648.27 497,682.56 2.48 618.23 MWD+IFR-AK-CAZ-SC(2) 2,76174 47.18 214.25 2,520.62 2,385.71 -573.65 -66667 5,937,59116 497,643.41 1.45 680.70 MWD+IFR-AK-CAZ-SC(2) 2,856.76 49.14 214.12 2,584.00 2,429.09 532.20 -706.45 5,937,533.22 497,603.63 2.07 745.27 MWD+1FR-AK-CAZ-SC(2) 2,951.87 52.10 213.94 2,644.34 2,489.43 593.12 -747.58 5,937,472.31 497,562.49 3.12 812.41 MWD+IFR-AK-CAZ-SC(2) 3,046.36 53.91 213.75 2,701.19 2,546.28 -755.80 -789.61 5,937,409.65 497,520.45 1.92 881.43 MWD+IFR-AK-CA7-SC(2) 3,141,48 57.61 213.81 2,754.71 2,599.80 -821.15 -833.32 5,937,344.32 497,476.73 3.89 953.38 MWD+IFR-AK-CAZ-SC(2) 3,237.96 59.61 213.23 2,80496 2,650.05 -889.81 378.80 5,937,275.67 497,431.24 2.14 1,02889 MWD+IFR-AK-CAZ-SC(2) 3,309.00 61.41 212.71 2,839.92 2,685.01 -94169 -912.45 5,937,223.81 497,397.58 2.62 1,085.83 NDT an Actual Survey 10-314" z 13-112" 3,332.11 62.00 212.54 2,8R 88 2,695.97 -958.83 -923.42 5,937,205.67 497,386.61 2.62 1,104.61 MWD+IFR-AK-CAZSC(3) 3,399.75 62.97 212.86 2,882.13 2,727.22 -1,009.31 -955.82 5,937,156.21 497,354.19 1.49 1,159.95 MWD+IFR-AK-CAZSC(3) 3,450]4 63.75 213.36 2,904.99 2,7W.08 -1,047.48 -980.72 5,937,118.04 497,329.29 1.76 1,201.87 MWD+IFR-AKCAZ-SC(3) 3,493.42 69.22 214.03 2,923.71 2,768.80 -1,079.40 -1,002.00 5,937,086.14 497,306.01 1.79 1.236.99 MWD+IFR-AKCAZ-SC(3) 3,530.56 64.18 214.45 2,939.87 2,784.96 -1,107.04 -1.20.81 5,937,058.50 497,289.19 1.02 1,267.48 MWD+IFR-AK-CAZ-SC(3) 8/12017 10: 03.40AM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-30 Project: Kuparuk River Unit TVD Reference: Rig: 39.21+115.70 Q 154.91 usft Site: Kuparuk 2K Pao MD Reference: Rig: 39.21+115.70 Q 154.91 usft Well: 2K-30 North Reference: True Wellbore: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS -NIS +E/ -W Northing Basting DLS Section (usft) (1) (') (usft) (usft) (usft) (usft) (ft) (ft) 1711001 (ft) Survey Toot Name 3,56223 63.77 21504 2,95377 2,79886 -1,130.42 -1,037.03 5,937,035.12 497,272.97 2.12 1,293.33 MWD+IFR-AK-CAZ-SC(3) 3,588.44 63.71 21542 2,965.37 2,81946 -1,149.62 -1,050.59 5,937,015.93 497,259.41 1.32 1,314.59 MWD+IFR-AK-CA2-SC(3) 3,682.88 63.25 217.42 3,007.54 2,85263 -1,217.62 -1,100.76 5,936,947.95 497,209.23 1.96 1,390.26 MM+IFR-AK-CAZ-SC(3) 3,777.58 6329 219.85 3,050.14 2,895.23 -1,283.68 -1,153.56 5,936,881.91 497,156.42 2.29 1,469.49 MWD+IFR-AK-CAZ-SC(3) 3,871.86 63.39 221.03 3,092.44 2,937.53 -1,347.80 -0,208.21 5,936,817.80 497,101.76 1.12 1,537.13 MWD+IFR-AK-CAZ-SC(3) 3,966.40 6323 221.02 3,134.90 2,979.99 -1,411.53 -1,263.65 5,936,754.10 497,046.31 0.17 1,609.51 MWD+IFR-AK-CAZ-SC(3) 4,061.18 63.13 220.11 3,177.67 3,022.76 -1,475.78 -1,318.66 5,936,689.86 496,991.29 0.86 1,682.34 MWD+IFR-AK(CAZ-SC(3) 4,156.24 63.14 219.29 3,220.63 3,065.72 -1,541.03 -1,372.83 5,936,62463 496,937.12 0.77 1,75800 MWD+IFR-AK-CAZSC(3) 4,251.42 63.14 217.57 3,263.63 3,108.72 -1,60254 -1,42860 5,936,558.14 496,884.33 161 1,830.67 MWD+IFR-AK-CAZSC(3) 4,345.63 63.04 216.70 3,306.27 3,151.35 -1,674.51 -1,476.32 5,935,491.19 496,833.61 0.83 1,905.43 MWD+IFR-AK-CAZ-SC(3) 4,440.03 63.08 215.49 3,349.04 3,194.13 -1,742.51 -1,525.89 5,936,423.20 496,784.02 1.14 1,981.01 MWD+IFR-AK-CAZ-SC(3) 4,534.89 63.17 214.38 3,391.92 3,237.01 -1,811.88 -1,574.35 5,935,353.86 496,735.55 1.05 2,057.73 MWD+IFR-AK-CAZ-SC(3) 4,629.80 63.20 215.09 3,434.74 3,279.83 -1,88149 -1,622.61 5,936,284.26 496,687.28 067 2,134.67 MWD+IFR-AK-CAZ-SC(3) 4,724.61 63.73 215.15 3,477.09 3,322.18 -1,950.87 -1,671.41 5,936,214.90 496,638.47 0.56 2,211.47 MWD+IFR-AK-CAZ-SC(3) 4,818.94 63.71 214.31 3,518.86 3,363.95 -2,020.38 -1,719.59 5,936,145.41 496,590.28 0.80 2,288.29 MWD+IFR-AK-CAZ-SC(3) 4,914.01 63.65 215.03 3,561.01 3,406A0 -2,090.46 -1,768.06 5,936,075.34 496,541.79 068 2,365.72 MWD+IFR-AK-CAZ-SC(3) 5,00872 63.58 215.74 3,603.10 3,448.19 -2,159.63 -1,817.19 5,936,006.19 496,492.65 0.68 2,442.38 MWD+IFR-AK-CAZ-SC(3) 5,10344 63.59 216.77 3,645.24 3,490.33 -2,228.04 -1,86236 5,935,937.80 496,442.48 0.97 2,51845 MWD+IFR-AK-CAZ-SC(3) 5,198.28 63.60 217.55 3,687.42 3,532.51 -2,295.74 -1,918.67 5,935,870.12 496,391.16 0.74 2,594.03 MWD+IFR-AK-CAZ-SC(3) 5,29260 63.52 218.03 3,729.42 3,574.51 -2,362.48 -1,97042 5,935,803.40 496,339.40 0.46 2,658.74 MWD+IFR-AK-CAZ-SC(3) 5,387.77 63.74 217.29 3,771.69 3,616.78 -2,429.98 -2,022.52 5,935,735.92 496,28229 0.73 2,744.27 MWDHFR-AK-CAZ-SC(3) 5,482.16 64.07 217.53 3,813.21 3,658.30 -2,497.31 -2,074.01 5,935,668.61 496,235.78 0.42 2,819.52 MWD+IFR-AK-CAZ-SC (3) 5,576.36 64.20 217.64 3,854.30 3,699.39 -2,564.48 -2,125.72 5,935,60145 49,184.07 0.17 2,894.65 MWD+IFR-AK-CAZ-SC(3) 5,671.14 64.16 218.56 3,895.58 3,74067 -2,631.62 -2,178.36 5,935,534.33 496,131.42 0.87 2,969.91 MWD+IFR-AK-CAZSC(3) 5,765.74 64.13 218.59 3,936.84 3,761.93 -2,698.17 -2,231.44 5,935,467.80 496,078.33 0.04 3,044.67 MWD+IFR-AK-CAZSC(3) 5,859.69 64.13 218.41 3,97283 3,822.92 -2,764.33 -2,284.07 5,93,401.66 496,025.69 0.17 3,118.96 MWD+IFR-AK-CAZSC(3) 5,954.87 64.13 218.46 4,019.36 3,864.45 -2,831.41 -2,337.30 5,935,334.59 495,972.45 0.05 3,194.27 MWD+IFR-AK-CAZSC(3) 6,049.76 64.19 217.64 4,060]2 3,905.81 -2,898.67 -2,389.94 5,935,267.36 495,919.80 078 3,269.64 MWD+IFR-AK-CAZSC(3) 6,144.80 64.10 217.74 4,102.17 3,997.26 -2,966.35 -2,442.23 5,935,19970 495,867.50 0.13 3,345.37 MWD+IFR-AK-CAZ-SC(3) 6,23923 64.17 217.77 4,143.36 3,968.45 -3,033.53 -2,494.26 5,935,132.54 495,815.46 0.08 3,420.56 MWD+IFR-AK-CAZ-SC(3) 6,333.84 64A4 218.60 4,184.61 4,029.70 -3,100.45 -2,546.89 5,935,06563 495,762.82 0.79 3,495.61 MWD+IFR-AK-CAZ-SC(3) 6,427.61 64.14 218.31 4,225.51 4,070.60 -3,166.53 -2,599.37 5,934,999.57 495,710.33 0.2B 3,569.80 MWD+IFR-AK-CAZ-SC (3) 6,523.01 64.13 218.14 4,267.13 4,112.22 -3,233.97 -2,652.48 5,934,932.15 495,657.21 0.16 3,69544 MWD+IFR-AK-CAZSC(3) 6,617.65 64.17 218.21 4,308.39 4,153,48 -3,300.92 -2,705.12 5,934,855.21 495,604.56 0.08 3,720.51 MWD+IFR-AK-CAZSC(3) 6,712.12 64.14 217.55 4,349.57 4,194.66 -3,368.03 -2,757.33 5,934,798.13 495,552.34 0.63 3,795.67 MWD+IFR-AK-CA7SC(3) 6,806.02 64.13 217.14 4,390.54 4,235.63 -3,435.20 -2,808.58 5,93,730.97 495,501.08 0.39 3,870.72 MWD+IFR-AK-CAZSC(3) 6,901.12 64.15 216.98 4,432.02 4,277.11 -3,503.49 -2,WD.16 5,934,662.70 495,449.50 0.15 3,946.93 MWD+IFR-AK-CAZSC(3) 6,996.45 63.65 216.54 4,473.96 4,319.05 -3,572.06 -2,911.39 5,934,594.13 495,398.25 867 4,023.37 MWD+IFR-AK-CAZSC(3) 7,090.43 63.63 215.99 4,51569 4,36078 -3,639.97 -2,961.20 5,934,526.26 495,348.43 0.52 4,098.88 MWD+IFR-AK-CAZSC(3) 7,185.98 63.67 217.13 4,558.10 4,403.19 -3,708.74 -3,012.20 5,934,457.50 495,297.42 1.07 4,175.46 MWD+IFR-AK-CAZSC(3) 8712017 10:03.40AM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-30 Project: Kuparuk River Unit TVD Reference: Rig: 39.21+115.70 @ 154.91 usft Site: Kuparuk 2K Pad MD Reference: Rig: 39.21+115.70 @ 154.91 usft Well: 2K-30 Norm Reference: True Wellbore: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +EI -W Northing Easting OLS Section (usft) (°) 0 (usft) (watt) (usft) (usft) (ft) 00 (7140) (te) Survey Tool Name 7,281.17 63.56 217.27 4,600.40 4,445.49 -3,776.67 -3,063.76 5,934,38960 495,245.85 0.18 4,251.31 MWD+IFR-AK-CAZ-SC(3) 7,37586 63.46 216.67 4,64264 4,487.73 -3,844.38 -3,114.73 5,934,321.91 495,194.87 0.58 4,326.84 MWD+IFR-AK-CAZ-SC(3) 7,470.85 63.60 216.56 4,684.98 4,530.07 3,912.63 5,165.44 5,934,253.67 495,144.15 0.18 4,402.86 MWD+IFR-AK-CAZ-SC(3) 7,565.07 63.63 216.04 4,726.85 4,571.94 -3,980.65 -3,215.41 5,934,185.67 495,094.17 0.50 4,478.53 MWD+IFR-AK-CAZSC(3) 7,659.80 63.66 216.56 4,768.90 4,613.99 4,049.06 -3,265.66 5,934,117.27 495,043.91 0.49 4,554.63 MWD+IFR-AK-CAZSC(3) 7,754.18 63.56 216.71 4,810.85 4,655.94 4.116.91 -3,316.11 5,934,4945 494,993.45 0.18 4,630.20 MWD+IFR-AK-CAZ-SC(3) 7,84945 63.63 217.86 4,853.22 4,698.31 -0,184.8(1 -3,367.80 5,933,981.58 494,941.75 1.08 4,706.03 MND+IFR-AK-CAZ-SC(3) 7,943.88 63.79 218.57 4,89504 4,740.13 -0,251.31 -3,420.18 5,933,915.08 494,889.36 0.70 4,780.63 MWD+IFR-AK-CAZ-SC(3) 8,038.65 63.75 21917 4,936.93 4,782.02 4.317.50 3,473.52 5,933,848.91 494,836.01 0.57 4,855.08 MWD+IFR-AK-CAZ-SC(3) 8,134.59 63.76 219.35 4,979.36 4,82445 3,384.13 -3,527.98 5,933,782.30 494,781.54 0.17 4,930.15 MWD+IFR-AK-CAZSC(3) 8,227.86 63.79 219.89 5,020.57 4,865.66 4,448.58 -3,581.33 5,933,717.87 494,728.18 0.52 5,002.89 MND+IFR-AK-CAZSC (3) 8,320.13 63.75 219.75 5,Wi.W 4,906.44 4,512.15 -3,634.34 5,933,654.32 494,675.16 0.14 5,074.70 MMAFR-AK-CAZSC(3) 8,417.50 64.13 219.05 5,104.13 4,949.22 4,579.74 3,689.86 5,933,586.74 494,619.64 0.75 5,150.90 MWD+IFR-AK-CAZ-SC(3) 8,51181 64.16 219.31 5,145.26 4,990.35 4,645.53 5,743.47 5,933,520.98 494,566.01 0.25 5,225.00 MWD+IFR-AK-CAZ-SC(3) 8,607.16 64.26 21266 5,186]4 5,031.83 4.712.73 4796.90 5,933,453.79 494,512.58 1.56 5,300.46 MWD+IFR-AK-CAZ-$C(3) 8,701.77 64.23 216.93 5,227.86 5,072.95 3,780.52 -3,848.53 5,933,386.03 494,460.93 0.70 5,376.18 MWD+IFR-AK-CAZ-SC(3) 8,796.53 64.20 216.46 5,269.08 5,114.17 4,848.93 -3,899.52 5,933,31763 494,409.94 0.45 5,452.41 MWD+IFR-AK-CAZSC(3) 8,890.47 63.81 217.42 5,310.25 5,15434 -0,916.42 5,950.26 5,933,250.16 494,359.19 1.01 5,527.68 MND+IFR-AK-CAZ-SC(3) 8,985.13 63.75 217.33 5,352.07 5,197.16 4,983.90 4,01.81 5,933,182.69 494,307.63 0.11 5,607.09 MWD+IFR-AK-CAZ-SC(3) 9,OBO.57 63.59 217.72 5,394.40 5,23949 5,051.74 4,053.91 5,933,114.87 49,255.51 0.40 5,678.95 MWD+IFR-AK-CAZ-SC(3) 9,17559 63.60 217.13 5,436.71 5,281.80 -5,119.40 -0,105.68 5,933,4223 494,203.73 0.56 5,754.57 MWD+IFR-AK-CAZ-SC(3) 9,269.40 63.69 21813 5,478.31 5,323.40 -5.186.78 -0,15578 5,932,979.87 49,153.62 0.96 5,829.63 MWD+IFR-AK-CAZ-SC(3) 9,364.65 63.69 216.59 5,520.53 5,365.62 5,255.55 -0,206.41 5,932,911.12 494,102.98 0.43 5,9W.14 MWD+IFR-AK-CAZSC(3) 9,458.68 63.65 215.67 5,562.23 5,407.32 -5,323.81 4.256.09 5,932,843.08 494,053.29 0.88 5,981.80 MWD+IFR-AK-CAZSC (3) 9,554.10 63.62 215.69 5,604.61 5,449.70 -5,393.06 4.305.96 5,932,773.65 494,003.41 0.04 6,058.85 MND+IFR-AK-CAZSC(3) 9,648.82 63.79 216.86 5,646.57 5,491.66 -5,461.52 4,35620 5,932,705.21 493,%3.16 1.12 6,134.99 MND+IFR-AK-CAZSC(3) 9,742.94 63.57 217.15 5,688.30 5,533.39 -5,528.89 4,406.98 5,932,637,86 493,902.38 0.36 6,210.15 MND+IFR-AK-CAZ-SC (3) 9,837.50 63.69 217.14 5,730.30 5,575.39 5,596.42 4,458.13 5,932,570.34 493,851.21 0.13 6,285.54 MWD+IFR-AK-CAZ-SC(3) 9,932.26 63.76 217.29 5,77225 5,617.34 5,664.08 4.509.52 5,932,502.69 493,799.81 0.16 6,361.10 MWD+IFR-AK-CAZ-SC(3) 10,026.87 63.72 217.63 5,814.11 5,659.20 -5,731,43 4,561.13 5,932,435.36 493,748.19 0.33 6,416.39 MND+IFR-AK-CAZ-SC (3) 10,121.55 64.25 217.96 5,855.63 5,7W.72 -5,798.67 4.613.27 5,932,368.15 493,696.04 0.64 6,511.66 MWD+IFR-AK-CAZ-SC(3) 10,215.59 64.22 218.16 5,896.51 5,741.60 5,865.35 4,665.48 5,932,30148 493,643.82 0.19 6,586.40 MWD+IFR-AK-CAZSC(3) 10,310.48 64.10 218.12 5,937.87 5,782.% 5,932.52 4,718.23 5,932,234.33 493,591.07 0.13 6,661.70 MWD+IFR-AK-CAZ-SC(3) 10,405.54 64.17 217.91 5,979.34 5,824.43 5,999.91 4770.91 5,932,166.96 493,538.38 0.21 6,737.22 MWD+IFR-AK-CAZ-SC(3) 10,500.06 64.08 217.49 6,020.59 5,865.68 -6,067.20 4,822.91 5,932,099.69 493,486.36 0.41 6,812.52 MWD+IFR-AK-CAZ-SC (3) 10,594.59 64.04 217.08 6,061.94 5,907.03 6,134.83 4,874.41 5,932,032.07 493,434.66 0.39 6,888.06 MND+IFR-AK-CAZ-SC (3) 10,689.57 65.39 213.97 6,102.52 5,947.61 5,204.72 4.924.29 5,931,%220 493,384.96 3.28 6,965.65 MND+IFR-AK-CAZSC(3) 10,784.33 67.70 210.06 6,140.24 5,985.33 6,278.42 4,970.34 5,931,888.52 493,338.90 4.50 7,046.13 TW0+1FR-AK-CAZSC(3) 10,878.91 70.56 207.52 6,173.94 6,019.03 0,355.87 5,012.87 5,931,811.09 493,296.35 3.93 7,129.78 MND+IFR-AK-CAZ-SC(3) 10,973.90 71.99 206.17 6,204.43 6,049.52 0,436.13 5,053.49 5,931,730.85 493,255.72 2.02 7,215.88 MWD+IFR-AK-CAZ-SC(3) 8/1/2017 10.03:40AM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-30 Project: Kuparuk River Unit TVD Reference: Rig: 39.21+115.70 @ 154.91 usft Site: Kuparuk 2K Pad MD Reference: Rig: 39.21+115.70 @ 154.9lusft Well: 2K-30 North Reference: True Wellbore: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Aa1 TVD TVDSS +WS +E/ -W Northing Easting DLS Section (usft} (') (1) (usft) (usft) (usft) (usft) (ft) (ft) (moo.) (ft) Survey Teol Name 11,068.38 73.05 205.76 6,232.81 6,077.90 -6,517.15 -5,092.95 5,931,64984 493,216.25 1.20 7,302.52 MWD+IFR.AK-CAZ-SC(3) 11,162.71 74.48 204.43 6,259.19 6,104.28 -6,599.17 -5,131.35 5,931,567.84 493,177.83 2.03 7,389.96 MWD+IFR-AK-CAZ-SC(3) 11,257.76 76.17 202.10 6,283.27 6,128.36 -6,68363 5,167.66 5,931983.39 493,141.51 2.96 7,47945 MWD+IFR-AK-CAZSC(3) 11,352.90 77,W 199.83 6,304.86 6,149.95 -6770.15 5,200.81 5,931,396.89 493,108.35 2.77 7,570.41 MWD+IFR-AK-CAZSC(3) 11,447.14 7972 196.48 6,323.39 6,168.48 -6,857.94 5,229.58 5,931,309.12 493,079.56 4.15 7,661.85 MWDOFR-AK-CAZSC(3) 11,54132 82.41 192.78. 6,338.02 6,183.11 x,947.93 -5,253.06 5,931,219.14 493,056.06 4.82 7,754.56 MWD+IFR-AK-CAZ-SC(3) 11,635.23 8560 18967 6,347.83 6,192.92 -7,039.52 -5,271.23 5,931,127.56 493,037.87 4.73 7,847.92 MWD+1FR-AK-CAZ-SC(3) 11,731.71 86.76 188.64 6,354.26 6,199.35 -7,134.56 5,286.55 5,931,032.54 493,022.53 161 7,944.17 MWD+IFR-AK-CAZ-SC(3) 11,825.93 86.63 188.89 6,359.69 6,20478 -7,227.52 5,300.88 5,930,939.59 493,008.18 0.30 8,038.21 MWD+IFR-AK-CAZSC(3) 11,900.27 86.30 189.80 6,364.28 6,209.37 -7,30074 5,312.93 5,930,866.39 492,996.12 1.30 8,112.40 MWD+IFR-AK-CAZ-SC(3) 11,957.00 86.35 189.36 6,367.91 6,213.00 -7,356.56 -5,322.35 5,930,810.57 492,986.68 0.77 8,169.01 NOT an Actual Survey 75/8"X 8.7/8 by 11^ 11,995.32 86.39 189.07 6,370.33 6,215.42 -7,394.31 5,328.48 5,930,772.83 492,980.55 0.77 8,207.25 MWD+IFR-AK-CAZ-SC(4) 12,090.15 8274 188.70 6,375.19 6,220.28 -7,487.88 5,343.10 5,930,679.27 492,965.90 148 8,301.94 MWD+IFR-AKCAZSC(4) 12,183.50 88.12 187.11 6,378.56 6,223.65 -7,5W.28 5,355.93 5,930,586.88 492,953.05 1.75 8,395.16 MWD+IFR-AKCAZSC(4) 12,237.93 87.98 186.81 6,380.41 6,225.50 -7,634.27 -5,362.53 5,930,532.89 492,946.45 0.61 8,449.48 MWD+IFR-AKCAZSC(4) 12,279.32 88.08 188.14 6,381.84 6,226.93 -7,675.29 5,367.91 5,930,491.89 492,941.06 3.22 8,490.81 MWD+IFR-AK-CAZ-SC(4) 12,325.04 87.98 189.58 6,38341 6,228.50 -7,720.43 -5,374.94 5,930,446.74 492,934.01 3.16 8,536.49 MM+IFR-AK-CAZ-SC(4) 12,373.86 88.22 189.52 6,385.03 6,230.12 -7,768.55 5,383.04 5,930,398.63 492,925.91 0.51 8,585.28 MWD+IFR-AK-CAZ-SC (4) 12,422.85 87.87 190.50 6,366.70 6,231.79 -7,816.76 5,391.55 5,930,350.43 492,917.39 2.12 6634.24 MWD+IFR-AK-CAZ-SC(4) 12,469.52 88.15 190.37 6,38832 6,233.41 -7,862.64 -5,400.00 5,930,304.56 492,908.93 0.66 8,600.88 MWD+IFR-AK-CAZ-SC(4) 12,564.19 88.60 191.05 6,391.00 6,236.09 -7,955.62 5,417.58 5,930,211.59 492,891.32 0.86 8,775.51 MWD+IFR-AKCAZ-SC(4) 12,658.55 88.56 191.20 6,393.34 6,238.43 -8,048.18 -5,435.79 5,930,119.05 492,873.10 0.16 8,869.82 MWD+IFR-AKCAZSC(4) 12,753.14 88.24 192.20 6,395.98 6,241.07 -8,140.76 -5,454.96 5,930,02647 492,853.91 1.11 8,964.33 MWD+IFR-AKCAZSC(4) 12,846.93 89.08 19229 6,398.18 6,243.27 -6232.39 -5,474.85 5,929,934.86 492,834.01 0.90 9,058.02 MWD+IFR-AK-CAZ-$C(4) 12,941.92 89.08 192.27 6,399.70 6,244.79 5,325.20 -5,495.05 5,929,84207 492,813.79 0.02 9,152.92 MWD+IFR-AK-CAZ-SC(4) 13,036.43 8.46 192.62 6,400.91 6,246.00 -8,417.48 -5,515.41 5,929,749.80 492,793.40 0.55 9,247,34 MWD+IFR-AK-CAZ-SC(4) 13,131.31 8946 193.24 6,401.80 6,246.89 -8,509.95 5,53664 5,929,657.34 492,772.16 0.65 9,342.09 MWD+IFR-AK-CAZ-SC(4) 13,225.89 90.07 193.14 6,402.19 6,24728 5,602.03 -5,558.22 5,929,565.27 492,750.56 0.65 9,436.52 MWD+IFR-AK-CAZSC(4) 13,320.11 90.45 193.34 6,401.76 6,24585 5,693.75 -5,57960 5,929,473.57 492,728.96 0.46 9,530.59 MWD+IFR-AK-WSC(4) 13,41577 90.55 19224 6,4W.93 6,246.02 5,787.03 5,600.98 5,929,380.31 492,707.76 1.15 9,626.13 MWD+IFR-AK-W-SC(4) 13,511.00 89.94 192.27 6,400.52 6,245.61 -8,wileg -5,621.19 5,929,287.26 492,687.53 0.64 9,721.29 MWD+IFR-AK-CAZ-SC(4) 13,604.89 89.49 191.47 6,400.99 6,246.08 5,971.97 -5,640.50 5,929,195.39 492,668.20 0.98 9,815.13 MWD+IFR-AK-CAZ-SC(4) 13,698.80 89.59 190.74 6401.74 6,246.83 -9,064.12 -5,658.59 5,929,103.26 492,650.09 0.78 9,909.02 MWD+IFR-AK-CAZ-SG(4) 13,793.58 89.32 189.78 6,402.64 6,247.73 -9157.38 -5,675.47 5,929,010.01 492,633.19 1.05 10,003.79 MWD+IFR-AKCAZSC(4) 13,888.15 88.77 191.02 6,404.22 6,249.31 -9,250.38 -5,692.54 5,928,91702 492,616.11 143 10,098.34 MWD+IFR-AKCAZSC(4) 13,983.70 88.43 19021 6,406.55 6,251.64 -9,344.26 5,710.13 5,928,823.15 492,598.49 0.92 10,19386 MWD+IFR-AKCAZSC(4) 14,078.43 87.88 19091 6409.60 6,254.69 -9,437.34 5,727.49 5,928,730.09 492,581.12 0.94 10,2W.53 MWD+IFR-AKCAZ-SC(4) 14,172.73 88.06 19052 6,412.94 6,258.03 -9,529.94 5,745.01 5,928,637.50 492,563.58 0.46 10,382.77 MWD+IFR-AK-CAZ-SC(4) 14,268.99 86.54 190.79 6,417.48 6,262.57 -9,624.43 -5,762.79 5,928,543.03 492,545.78 1.66 10,478.91 MWDAFR-AK-CAZ-SC(4) 14,364.20 85.53 191.36 6,424.06 6,269.15 -9,717.64 -5,781.03 5.928,44983 492,527.52 122 10,57387 MWD+IFR-AK-CAZ-SC(4) 6712017 10:03:40AM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-30 Project: Kupaluk River Unit TVD Reference: Rig: 39.21+115.70 @ 154.91usft Site: Kuparuk 2K Pad MD Reference: Rig: 39.21+115.70 @ 154.9lusft Well: 2K-30 North Reference: True Wellborn: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azl TVD TVDSS +N! -S +E/ -W Northing Easting DLS Section (waft) (1) 0 (usft) (usft) (usft) (uidt) (ft) (ft) (-/100') (ft) Survey Tool Name 14,459.03 85.71 190.92 6,431.30 6,276.39 -9,810.41 5,799.30 5,928,357.07 492,509.23 D.51) 10,668.41 MWD+IFR-AK-CAZ-SC(4) 14,55398 85.96 190.65 6,43820 6,283.29 -9,903.44 5,817.02 5,928,264.06 492,491.49 0.39 10,763.10 MWD+IFR-AK-CAZSC(4) 14,648.65 88]9 18868 6,442.53 6,2W.62 -9,99666 -5,832.89 5,928,170.85 492,47560 3.64 10,85766 MWO+IFR-AK-CAZSC(4) 14,743.38 89.35 187.18 6,444.07 6,289.16 -10,09046 -5,84596 5,928,077.06 492,462.51 1.69 10,952.30 MWD+IFR-AK-CA7SC(4) 14,838.07 89.32 187.69 6,445.17 6,290.26 40,184.35 5,658.21 5,927,983.18 492,450.24 0.54 11,046.89 MWD+IFR-AK-CAZ-SC(4) 14,933.24 89.59 188.60 6,446.08 6,291.17 -10,278.55 -5,871.69 5,927,888.99 492,43614 1.00 11,142.01 MWD+IFR-AK-CAZ-SC(4) 15,027.73 89.97 186.85 6,446.44 6,291.53 -10,372.18 -5,884.39 5,927,795.38 492,424.02 1.90 11,236.42 MWD+1FR-AK-CAZ-SC(4) 15,122.21 89.73 187.13 6,446.69 6,291.78 -10,46596 -5,895.89 5.927,701.61 492,412.50 0.39 11,330.77 MWD+IFR-AK-CAZSC(4) 15,217.07 8928 186.91 6,447.51 6,292.60 -10,560.10 5,907.49 5,927,607.48 492,400.89 0.53 11,425.50 MM+IFR-AK-CAZ-SC(4) 15,312.03 89.35 187.13 6,448.64 6,293.73 -10,654.34 -5,919.09 5,927,513.25 492,389.26 0.24 11,520.32 MWD+IFR-AK-CAZ-SC(4) 15,406.97 88.77 189.12 6,450.20 6,295.29 -10,748.31 -5,932.51 5,927,419.29 492,37583 2.18 11,615.19 MWD+1FR-AK-CAZ-SC(4) 15,500.56 88.50 190.7 6,452.35 6,297.44 -10,840.46 5,948.74 5,927,327.16 492,359.57 1.88 11,708.75 MWD+IFR-AK-CAZSC(4) 15,596.41 88.39 190.49 6,454.86 6,299.95 -10,934.61 -5,966.50 5,927,233.02 492,341,79 0.45 11,804.56 MWD+IFR-AK-CAZ-SC(4) 15,691.44 88.53 190.38 6,457.42 6,302.51 -11,028.04 -5,98371 5,927,139.61 492,324.57 0.19 11,899.56 MWD+IFR-AK-CAZSC(4) 15,785.53 88.72 191,19 6,459.68 6,304]7 -11,120.44 8,001.31 5,927,047.22 492,306.95 0.88 11,99361 MWD+IFR-AK-CAZSC(4) 15,880.86 90.45 191.58 6,460.37 6,305.46 -11,213.89 8,020.13 5,926,953.79 492,288.11 1.86 1208.91 MWD+IFR-AK-CAZ-SC(4) 15,975.92 91.68 191.63 6.458.60 6,303.69 -11,306.98 8,039.24 5,926,860.70 492,268.98 1.29 12,183.91 MWD+IFR-AK-CAZ-SC(4) 16,071.58 91.92 192.92 6,455.60 6,300.69 -11,400.41 8,059.57 5,926,767.29 492,24863 1.37 12,279.45 MWD+IFR-AK-0W-SC(4) 16,164.51 9221 192.40 6,45225 6,297.34 -11,491.02 5,079.93 5,926,676.69 492,228.26 0.64 12,372.21 MWD+IFR-AK-CAZ-SC(4) 16,259.29 90.74 192.13 6,449.81 6,294.90 -11,58360 8,100.05 5,926,584.12 492,208.11 1.58 12,466.89 MWD+1FR-AK-CAZ-SC(4) 16,353.36 91.17 191.73 6,448.24 6,293.33 -11,675.63 8,119.50 5,926,492.11 492,188.65 0.62 12,580.89 MWD+IFR-AK-CAZSC(4) 16,449.19 90.28 192.13 6,447.03 6,292.12 -11,769.38 8,139.30 5,926,398.37 492,168.82 1.02 12,656.66 MWD+IFR-AK-CA7-SC(4) 16,544.15 69.70 191.98 6,447.04 6,292.13 -11,862.25 8,159.14 5,926,305.52 492,148.97 0.63 12,751.55 MWD+IFR-AK-CAZSC(4) 16,639.14 89.39 190.58 6,447.80 6,292.89 -11,955.40 8,177,72 5,926,212.38 492,130.37 1.51 12,846.52 MWD+IFR-AK-CAZ-SC(4) 16,734.10 89.35 19014 6,448.84 6,293.93 -12,048.71 8,195.28 5,926,119.8 492,112.79 0.17 12,941.46 MW0+IFR-AK-CAZ-SC(4) 16,828.91 89.22 191.04 6,450.02 6,295.11 -12,141.81 8,213.19 5,926,02600 492,094.85 0.34 13,03625 MWD+IFR-AK-CAZSC(4) 16,923.25 88.84 189.41 6,451.62 6,296.71 -12,234.63 8,229.93 5,925,933.19 492,078.10 1.77 13,130.58 MWD+IFR-AK-CAZSC(4) 17,018.29 88.80 187.96 6,453.58 6,298.67 -12,328.56 8,244.28 5,925,839.27 492,063.73 1.53 13,225.57 MWD+IFR-AK-CAZ-SC(4) 17,113.24 88.67 187.09 6,455.68 6,300.77 -12,422.67 8,256.71 5,925,745.18 492,051.28 0.93 13,320.41 1AWD+IFR-AK-CAZ-SC(4) 17,208.22 88.70 186.52 6,45786 6,302.95 -12,516.95 8,267.96 5,925,650.90 492,040.01 060 13,415.21 MWD+IFR-AK-CAZ-SC(4) 17,302.95 68.32 184.68 6,460.32 6,305.41 -12,611.20 8,27721 5,925,556.67 492,030.75 1.98 13,50963 MWD+IFR-AK-CAZSC(4) 17,397.85 88.32 164.42 6,963.10 6,308.19 -12,705.76 8,284.73 5,925,462.12 492,02320 0.27 13,604.06 MWD+1FR-AK-CAZSC(4) 17,492.51 88.94 184.08 6,465.36 6,310.45 -12,800.13 8,291.74 5,925,367.76 492,016.17 0.75 13,698.21 MWD+IFR-AK-CAZ-SC(4) 17,587.37 88.94 183.96 6,467.12 6,312.21 -12,894.74 8,298.39 5,925,273.16 492,009.50 0.13 13,792.54 MWD+IFR-AK-CAZ-SC(4) 17.682,31 89.57 184.89 6,468.35 6,313.44 -12,989.39 8,305.72 5,925,178.53 492,002.15 1.18 13,887.02 MWD+IFR-AK-CAZ-SC(4) 17,776.61 88.76 185.75 6,469.73 6,314.82 -13,083.27 8,314.46 5,925,084.66 491,993.39 1.25 13,981.00 MWD+IFR-AK-CAZ-SC(4) 17,871.43 89.15 187.18 6,471.46 6,316.55 -13,177.47 8,325.13 5,924,990.47 491,982.70 1.56 14,075.62 MWD+IFR-AK-CAZ-SC(4) 17,956.66 89.15 191.49 6,472.87 6,317.96 -13,271.40 8,34057 5,924,896.55 491,967.23 4.53 14,170.81 MWD+IFR-AK-CAZSC(4) 18,050.97 87.98 194.41 6,475.23 6,320.32 -13,363.27 8,361.70 5,924,804.69 491,946.09 3.33 14,264.95 MWD+IFR-AK-CAZSC(4) 18,154.90 87.71 193.99 6,478.76 6,323.85 -13,454.27 8,384.73 5,924,713.71 491,923.05 0.53 14,358.56 MWD+IFR-AK-CAZSC(4) 81112017 10:03:40AM Page 7 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Comparry: NADConversion Local Co-ordinate Reference: Well 2K-30 Project Kupamk River Unit TVD Reference: Rig: 39.21+115.70 @ 154.91 usft Site: Kuparuk 2K Pad MD Reference: Rig: 39.21+115.70 @ 154.91usft Well: 2K-30 North Reference: True Wellbore: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +W -S +Ef-W Northing Eaagng OLS Section (usft) (1 (1) Wait) (usft) (uslt) (usft) (N) (it) (9100.) (R) Survey Tool Name 18,250.59 87.91 194.25 6,482.42 6,327.51 -13,547.00 -6,408.05 5,924,62099 491,899.70 0.34 14,453.94 MWD+IFR-AK-CAZ-SC(4) 18,344.87 88.32 194.42 6,485.52 6,330.61 -13,638.29 .6,431.38 5,924,529.71 491,876.35 0.47 14,547.90 MWD+IFR-AK-CAZ-SC(4) 18,437.84 88.39 193.72 6,488.19 6,333.28 -13,728.44 -6,453.97 5,924,439.58 491,853.74 0.76 14,640.59 MWD+IFR-AK-CAZ-SC(4) 18,535.15 88.83 18982 6,490.55 6,335.69 -13,823.66 3,473.81 5,924,344.38 491,833.89 4.03 14,737.81 MWD+IFR-AK-CAZ-SC(4) 18,629.99 90.40 188.47 6,491.19 6,336.28 -13,91728 3,488.89 5,924,250.76 491,818.79 2.18 14,832.63 MWD+IFR-AK-CAZSC(4) 18,723.51 89.94 187.28 6,490.91 6,336.00 -14,009.92 -6,501.70 5,924,158.14 491,805.96 1.36 14,926.08 MWD+IFR-AK-CAZ-SC(4) 18,819.59 90.04 186.01 6,490.93 6,336.02 -14,105.35 -6,512.82 5,924,W2.72 491,794.82 1.33 15,022.00 MWD+IFR-AK-CAZ-SC(4) 18,914.52 90.04 18442 6,490.86 6,335.95 -14,199.89 3521.45 5,923,968.20 491,786.17 1.67 15,116.59 MWD+1FR-AK-CAZ-SC(4) 19,009.16 9045 183.29 6,490.46 6,335.55 -14,294.31 3,527.81 5,923,873.78 491,779.79 1.27 15,210.69 MWD+IFR-AK-CAZSC(4) 19,104.10 91.27 182.18 6,489.03 6,334.12 -14,389.13 3,532.34 5,923,778.98 491,775.24 1.45 15,304.85 MWD+IFR-AK-CAZSC(4) 19,198.69 91.75 180.42 6,486.54 6,331.63 -14,483.66 3,534.48 5,923,684.46 491,773.07 1.93 15,398.32 MWD+IFR-AK-CAZ-SC(4) 19,293.16 91.79 18043 6,483.62 6,328.71 -14,578.08 3,535.18 5,923,590.04 491,772.35 0.04 15,491.43 MWD+IFR-AK-CAZ-SC(4) 19,383.02 92.44 179.93 6,450.31 6,325.40 -14,667.88 3,535.47 5,923,500.26 491,772.05 0.91 15,579.91 MWD+IFR-AK-CAZ-SC(4) 19,482.30 92.37 180.69 6,476.14 6,321.23 -14,767.07 3,536.00 5,923,401.08 491,771.49 0.77 15,677.69 MWD+IFR-AK-CAZ-SC(4) 19,577.95 91.40 183.30 6,472.99 6,318.08 -14,862.60 -6,539.33 5,923,305.56 491,768.14 2.91 15,772.34 MWD+IFR-AK-CAZSC(4) 19,672.50 91.61 185.56 6,470.51 6,315.60 -14,956.63 -6,546.63 5,923,211.34 491,760.82 2.40 15,866.41 MWD+IFR-AK-CAZ-SC(4) 19,767.26 89.50 182.23 6,6994 6,315.03 -15,051.34 3,553.07 5,923,116.83 491,754.37 4.41 15,950.61 MWD+IFR-AK-CAZ-SC(4) 19,861.02 89.97 180.09 6,470.72 6,315.81 -15,145.08 3,554.96 5,923,023.11 491,752.45 2.47 16,053.25 MWD+IFR-AK-CAZ-SC(4) 19,956.38 90.11 180.02 6,470.65 6,315.74 -15,240.44 3,555.05 5,922,927.76 491,752.33 0.16 16,147.17 MWD+IFR-AK-CAZSC(4) 20,051.06 89.71 181.49 6,470.80 6,315.89 -15,335.10 -6,556.30 5,922,833.10 491,751.07 1.61 16,240.62 MWD+IFR-AKCAZ-SC (4) 20,145.86 91.17 184.09 6,470.07 6,315.16 -15,429.78 -6,560.92 5,922,73694 491,746.43 3.15 16,334.66 MWD+IFR-AK-CAZ-SC(4) 20,240.65 92.58 185.27 6,46597 6,312.W -15,524.20 -6,568.64 5,922,644.03 491,738.68 1.94 16,428.98 MWD+IFR-AK-CAZ-SC(4) 20,335.01 92.89 184.28 6,462.47 6,307.56 -15,618.12 3,576.49 5,922,550.11 491,730.82 1.10 16,522.84 MWD+IFR-AKCAZSC(4) 20,430.24 93.33 184.24 6,457.30 6,302.39 -15,712.95 3,583.55 5,922,455.30 491,723.73 0.46 16,617.46 MWD+IFR-AK-WSC (4) 20,525.01 93.78 184.08 6,451.42 6,296.51 -15,807.29 3,590.42 5,922,360.97 491,716.85 0.50 16,711.55 'MWD+IFR-AK-CAZ-SC(4) 20,619.43 93.57 18355 6,445.37 6,290.46 -15,901.30 3,596.69 5,922,266.97 491,710.56 080 16,805.23 MWD+IFR-AK-CAZ-SC(4) 20,714.35 9240 183.12 6,440.43 6,286.52 -15,995.93 .6,602.20 5,922172.35 491,705.03 1.31 16,899.38 MWD+IFR-AK-CAZSC(4) 20,808.73 91.17 183.42 6,437.49 6,282.58 -16,090.11 -6,607.58 5,922078.18 491,69962 1.34 16,993.50 MWD+IFR-AK-CAZSC(4) 20,903.24 89.96 183.31 6,436.56 6,281.65 -16,184.45 3,613.13 5,921,983.85 491,694.50 1.29 17,086.93 MWD+IFR-AK-CAZ-SC(4) 20,996.63 69.79 181.13 6,436.76 6,281.85 -16,277.77 3,61674 5,921,890.55 491,690.42 2.34 17,179.46 MWD+IFR-AKCAZ-SC(4) 21,91.49 90.93 162.84 6,436.16 6,281.25 -16,372.56 3,620.03 5,921]95.76 491,687AI 2.17 17,273.38 MWD+IFR-AK-CAZ-SC(4) 21,186.22 91.22 183.12 6,434.39 6,279.48 -16,467.15 3,624.95 5,921,701,19 491,682.17 0.43 17,367.39 MWD+IFR-AK-CAZ-SC(4) 21,281.24 89.80 182.28 6,433.54 6,27663 -16,562.05 -6,629.43 5,921,65029 491,677.67 1.74 17,461.63 MWD+IFR-AK-CAZSC(4) 21,375.62 88.92 180.69 6,434.60 6,27969 -16,656.39 3,631.88 5,921,511.96 491,67520 1.93 17,554.96 MWD+IFR-AK-CAZSC(4) 21,470.97 W.68 183.38 6,434.93 6,280.02 -16,751,7 3,635.26 5,921,416.69 491,671.80 3.37 17,649.38 MWD+IFR-AKCAZ-SC(4) 21,566.14 69.87 184.43 6,434.47 6,279.56 -16,846.62 3,641.74 5,921,321.76 491,665.30 1.39 17,744.00 MWD+4FR-AK-W-SC(4) 21,660.49 89.10 183.35 6,435.32 6,250.41 -16,940.74 3,648.14 5,921,227.64 491,658.88 141 17,837.81 MWD+IFR-AKCAZ-SC(4) 21,755.38 90.00 18079 6,436.07 6,281.16 -17,035.56 3,651.57 5,921,132.84 491,655.43 2.86 17,93178 MWD+IFR-AK-CAZ-SC(4) 21,849.91 90.07 181.91 6,436.01 6,281.10 -17,130.06 3,653.50 5,921,038.34 491,653.18 1.19 18,025.24 MWD+IFR-AK-CAZSC(4) 21,914.00 89.94 181.56 6,436.00 6,281.09 -17,194.12 -6,655.74 5,920,974.29 491,65122 0.58 18,508.66 NOT an AcWal Survey 0.112" x 6 -Wil" 8/12017 10: 03: 40AM Page 8 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-30 Project: Kuparuk River Unit TVD Reference: Rig: 39.21+115.70 @ 154.91usft Site: Kuparuk 2K Pad MD Reference: Rig: 39.21+115.70 Q 154.91 usft Well: 2K-30 North Reference: True Wellbore: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30 Database: OAKEDMP2 Survey 21 Surface Coordinates p Declination & Convergence 21 GRS Survey Corrections I] Survey Tool Codes Brandon Temple nmk .g"m hyre"a SLB DE. 0342012.0UI lnzzW4 'W Dgaflyskredby EaZVW Client Representative: q4✓ [0 e:20vao 10:1800aevo Date. Map Map Vertical MD Inc AN TVD TVDSS +NIS +E/ -W Northing Eastin9 DLS Section (usft) (1) (1 (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Nene 21,944.43 89.88 181.40 6,436.05 6,281.14 -17,22454 6,656.53 5,920,943.87 491,650.43 0.58 18,118.76 MWD+IFR-AK-CAZ-SC(4) 21,992.59 89.13 179.58 6,436.47 6,281.56 -17,272.70 6,656.94 5,920,895.72 491,550.01 4.09 18,166.25 MWD+IFR-AK-0AZSC(4) 22,055.00 89.13 179.58 6,437.41 6,282.50 -17,335.10 6,656.48 5,920,833.33 491,650.45 0.00 18,227.62 PROJECTED to TD rinal Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. n Yes E] No 1 have checked to the best of my ability that the following data is correct 21 Surface Coordinates p Declination & Convergence 21 GRS Survey Corrections I] Survey Tool Codes Brandon Temple nmk .g"m hyre"a SLB DE. 0342012.0UI lnzzW4 'W Dgaflyskredby EaZVW Client Representative: q4✓ [0 e:20vao 10:1800aevo Date. 8/1117 8/1201710:03:40AM Page 9 COMPASS 5060.14 Build 85 I Cement Detail Report 2K-30 String: Surface Casing Cement Job: DRILLING ORIGINAL, 6/14/201713:00 Cement Details Description Cementing Start Date Cementing End DateWellbore Name Surface Casing Cement 6119/2017 17:00 6/19/2017 19:20 2K-30 Comment Make up FMC casing hanger and landing joint. Wash down f/ 3267'- 3309'w/ 2.5 bpm, 150 psi, SOW 115k. Land off on landing ring at 3309' MD. Circulate and condition mud, staging up pumps to 7 bpm, ICP 250 psi, FCP 169 psi, 27% F/O, PUW 180k, SOW 128k. Reciprocate pipe f/ 3309'- 3289' MD. MW in 9.65ppg, MW out 9.75ppg. Total 1455 bible pumped. Note: Pumped 65 bbl 11.0ppg 300 Vis red-dye marker w/ 5 Ib/bbl nutplug and 3 gallons red dye. Observed nut plug and slight indication of red dye at surface and at 73 bbis early to calculated gauge hole. Observed good red dye pill at surface at 35 bbis early to calculated gauge hole. Discuss with town and decision made to maintain plan to pump 250% excess through permafrost and 50% excess below permafrost. PJSM. Line up cementers, pump 5 bola Chemwash100 to flood lines. Pressure test lines to 500/3500 psi - good test. While reciprocating pipe from 3309'- 3294' MD, pump 35 bbis Chemwash100 at 5 bpm, 85 psi, 21% F/O. Batch up and pump 72 bbis 10.5ppg MudPush It spacer at 4.5 bpm, 122 psi, 21 % F/O. Drop bottom plug. Mix lead cement, wet @ 18:17 his. Pump 468.4 bbis 11.0ppg LiteCrete Lead slurry at 6 bpm, 320 psi, 21% F/O. First 50 bbis of lead cement were pumped neat then started adding 1 Wool CEM-Net LCM into remaining lead slurry. Observe bottom plug land on calculated volume and take 100 psi differential to shear. Land hanger and leave landed at end of lead cement due to hole getting sticky. Mix tail cement, wet @ 19:43 hrs. Pump 61.2 bbis 12.Oppg LiteCrete tail slurry at 4.5 bpm, 220 psi, 21% F/O. Drop top plug. Kick out with 10.1 bbis freshwater at 6 bpm, 357 psi, 24% F/O. Bleed off pressure and monitor for flow to check floats - observe floats not holding. Bled off total 8 bbis. Shut in and observed pressure build to 140 psi. Observed fluid level on backside drop total of -20' below rig floor. Discuss with town. Pressure up above final displacement pressure to 550 psi at 3 bpm and shut in, total 3 bbls pumped. Wait Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement Cement 10-3/4" Surface 39.0 3,309.0 Yes 220.0 Yes Yes casing Q Pump Init (bbllm... Q Pump Final (bbl/... Q Pump Avg (bbll... P Pump Final 1psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rp m) 6 3 6 490.0 1,040.0 Yes 15.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To IRKS) Drill Out Diameter (in) Comment Floats did not hold - had to shut in and WOC Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est sun (ftKB) Amount (sacks) Class Volume Pumped (bbl) CW100 40.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density porgal) Plastic Viscosity (Pa-s) Thickening Time (hr) CmprStr 1 (psi) 8.34 Additives Additive Type Concentration Cone Unit label Fluid Fluid TypeFluitl Description Estimated Top (ftKB) Est Btm IRKS) Amount (sacks) Class Volume Pumped (bbl) Mud Pushll 72.0 Yield (fN/sack) Mix H2O Ratio (gal/sa... Free Water (Yo) Density (migal) Plastic Viscosity (Pa-s) Thickening Time (hr) CmprStr 1 (psi) 10.50 Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement-- 39.0 2,809.0 1,377 LiteCrete 468.4 LiteCrete Yield (11/sack) Mix H2O Ratio (gal/se... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pais) Thickening Time (hr) CmprStr1 (psi) 1.91 6.83 11.00 6.22 Additives Additive Type Concentration Cone Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Cone Unit label D185 Dispersant 0.08 gal/sx Additive Type Concentration Cone Unit label CEM-Net LCM 1.0 lbs/bbl Additive Type Concentration Cone Unit label D177 Retarder 0.03 gal/sx Page 1/2 ReportPrinted: 8116/2017 Cement Detail Report 2K-30 String: Surface Casing Cement Job: DRILLING ORIGINAL, 6/14/201713:00 Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement-- 2,809.0 3,309.0 209 LiteCrete 61.2 LiteCrete Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa-s) Thickening Time (hr) CmprStr 1 (psi) 1.65 5.74 12.00 4.38 Additives Additive Type Concentration Conc Unit label D046 0.2 %BWOC Additive Type Concentration Conc Unit label D177 0.015 gal/sx Additive Type Concentration Conc Unit label D185 0.15 gal/sx Page 2/2 Report Printed: 8/16/2017 Cement Detail Report 2K-30 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 6/14/201713:00 Cement Details Description Cementing Start Date C0 -6n,131119 End Date Wellbore Name Intermediate Casing Cement 6/30/2017 13:43 0/2017 16:19 2K-30 Comment Make up hanger and landing joint. Wash down to 11,956' MD. 4 BPM @ 435 PSI. 16% F/O. 103K OWN WTprior to landing hanger. Circulate while stage pumps up to 5 BPM 530 PSI, 17% F/O. UP WT 330K. DWN WT = 115K/. Hold PJSM to R/U cement hose. Circulate while reciprocating from 11,956' MD to 11,916' MD at 7 BPM 430 PSI. 25%F/0. UP WT 330 K, DWN WT = 122K. 10.4 in lout. PJSM W/SLB for cement program. Total STKS pumped 11,943 (1203 bbls). SLB on line 2 BBLS of fresh water, PT lines to 250/4000 PSI. Test trips (GOOD) Batch up cement and pump 40.1 BBLS mud push 12.5 ppg @ 4.5 BPM, 320 PSI, 17% F/O. Drop BTM PLUG. Pump 137.4 BBLS of 15.8# Class G cement ( yield 1.16 cuf tsx, mix water 5.117 gal/sx, thickening time 4 hr 48 min) with reciprocations @ 5.2 BPM, 190 PSI, 26% F/O, FCP = 2.9 BPM. 75 PSI, 19% F/O. Drop top plug pump 10.1 BBLS water UP WT = 335K DWN WT = 122K. Displace cement with rig pump at 7.8 BPM 219 PSI, 28% F/O. 4568 STKS (460 bbls) reduce rate to 4 BPM. 530 PSI, 15% F/O. @ 5,200 STKS (523 bbls) UP WT = 335, DWN WT = 101K. Land hanger at 4,680 STKS (471 bbis). Bump plug @ 3 BPM 500 PSI FCP. 5,333 STK (537 bbls) W increase pressure to 1,045 PSI and hold for 5 min. Bleed off to check Floats. (GOOD) cement in place at 16:15 his 6/30/2017. Perform casing pressure test to 3,500 PSI and chart same. pumped 7.2 BBLS bled back same. RID B/D test system. Cement Stages Stage # 1 Description Objective Top Depth (ftKB)Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing cement intermediate to I 10,394.0 1 11,966.0 Ves Yes Yes Cement HRZ @ 10435' Q Pump Intl (bbl/niQ A5 Pump Final (bbll... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 3 5 503.0 1,050.0 Yes 17.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 11,863.0 I Drill Bit 11,966.0 63/4 Comment Make up hanger and landing joint. Wash down to 11,956' MD. 4 BPM @ 435 PSI. 16% F/O. 103K DWN WTprior to landing hanger. Circulate while stage pumps up to 5 BPM 530 PSI, 17% F/O. UP WT 330K. DWN WT = 115K/. Hold PJSM to R/U cement hose. Circulate while reciprocating from 11,956' MD to 11,916' MD at 7 BPM 430 PSI. 25% F/O. UP WT 330 K, DWN WT = 122K. 10.4 in /out. PJSM W/SLB for cement program. Total STKS pumped 11,943 (1203 bbls). SLB on line 2 BBLS of fresh water, PT lines to 250/4000 PSI. Test trips (GOOD) Batch up cement and pump 40.1 BBLS mud push 12.5 ppg @ 4.5 BPM, 320 PSI, 17% F/O. Drop BTM PLUG. Pump 137.4 BBLS of 15.8# Class G cement ( yield 1.16 cuft/sx, mix water 5.117 gal/sx, thickening time 4 hr 48 min) with reciprocations @ 5.2 BPM , 190 PSI, 26% F/O, FCP = 2.9 BPM. 75 PSI, 19% F/O. Drop top plug pump 10.1 BBLS water UP WT = 335K DWN WT = 122K. Displace cement with rig pump at 7.8 BPM 219 PSI, 28% F/O. 4568 STKS (460 bbis) reduce rate to 4 BPM. 530 PSI, 15% F/O. @ 5,200 STKS (523 bills) UP WT = 335, DWN WT = 101 K. Land hanger at 4,680 STKS (471 bbls). Bump plug @ 3 BPM 500 PSI FCP. 5,333 STK (537 bbis) W increase pressure to 1,045 PSI and hold for 5 min. Bleed off to check Floats. (GOOD) cement in place at 16:15 hrs 6/30/2017. Perform rasing pressure test to 3,500 PSI and chart same. pumped 7.2 BBLS bled back same. RID B/D test system. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB)Est etm (ftKB) Amount (sacks) Class Volume Pumped (bbl) MudPush II 9,925.0 10,394.0 40.1 Yield (ft /sack) Mix X20 Ratio (gausa... Free Water (%) Density (IWgal) Plastic Viscosity (Pa-s) Thickening Time (hr) CmprStr 1 (psi) 12.50 Additives Additive Type Concentration I Cone Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est BIM (ftKB) Amount (sacks) Class Volume Pumpetl (bbl) 15.8 ppg Cement 10,394.0 11,966.0 658 G 1 137.4 Yield (ft'/sack)Miz K20 Ratio (gal/sa... Free water (%) Density (IWgal) Plastic Viscosity (Pa•s) Thickening Time (hr) Cmpratr 1 (psi) 1.16 5.12 15.80 4.83 Additives Additive Type Concentration Cone Unit label D047 Antifoam 0.05 gat/sx Additive Type Concentration Cone Unit label D065 Dispersant 0.3 %BWOC Additive Type Concentration Cone Unit label D255 Fluid Loss 0.5 %BWOC Additive Type Concentration Cone Unit label D177 Retarder 0.015 gallsx Page tl1 Report Printed: 811012017 RECEIVED AUG 10 2017 ergerAOGCC Drilling & Measurements Product Delivery Transmittal #: 10AUG17-SP02 DATA LOGGED M.K.BENDEP Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Logging Date Color Log Prints: Well Name: 2K-30 Date Dispatched: 10 -Aug -17 SCOPE Service 2" MD Service Order #: 17AKA0008 Dispatched By: Stephanie Pacillo 2" TVD x Product Description Hardcopy Digital Copy Logging Date Color Log Prints: 4 Contents on CD 17 -Jul -17 SCOPE Service 2" MD x x 2" TVD x x 5 MD x x 5' TVD x x Digital Data N/A Contents on CD LAS/DLIS Data x Surveys 2 Contents on CD Directional Survey Nad27 x x Directional Survey Nad83 x x CD 1 Contents on CD Data: DLIS/ LAS x Graphics: PDF x Surveys: PDF/TXT x Please sign and email a copy to: Please sign and email a copy to: Tom.Osterkamo(o)conocoohillips.com AlaskaPTSPrintCenter(a)slb.com Attn: Tom Osterkamp Attn: Stephanie Pacillo Received By: 8 actz., 21 7072 28492 X17072 /-S 49 2 RECEIVED AUG 10 2017 FINAL AUG NADConversion Kuparuk River Unit Kuparuk 2K Pad 2K-30 2K-30 Definitive Survey Report 01 August, 2017 I I ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 2K-30 Project: Kuparuk River Unit TVD Reference: Rig: 39.21+115.70 @ 154.9lusft Site: Kuparuk 2K Pad MD Reference: Rig: 39.21+115.70 @ 154.91usft Well: 2K-30 North Reference: True Wellbore: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30 Database: OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2K-30 Audit Notes: To Well Position +N/ -S 0.00 usft Northing: 5,938,165.20 usft Latitude: 70" 14'32.241 N 39.21 +E/ -W 0.00 usft Easting: 498,310.15 usft Longitude: 150° 0'49.131 W Position Uncertainty (usft) 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 115.70 usft Wellbore 2K-30 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°I (°) (nT) BGGM2017 6/25/2017 17.45 80.84 57,481.61 Design 21K-30 Date Audit Notes: To Map Map Version: 1.0 Phase: ACTUAL Tie On Depth: 39.21 Vertical Section: Depth From (TVD) +NI -S +E/ -W Direction 1,723.38 (usft) (usft) (usft) (°i 3,332.11 39.21 0.00 0.00 190.00 Survey Program Date From To Map Map (usft) (waft) Survey (Wellbore) Tool Name Description Survey Date 98.42 1,625.28 21K-30 Srvy 1 - SLB _GW070 (2K-30) GYD-GC-SS Gyrodata gyro single shots 6/16/2017 8:17: 1,723.38 3,237.962K-30 Srvy 2-SLB_MWD+GMAG(21K-3 MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 6/17/2017 8:47: 3,332.11 11,900.272K-30 Srvy3- SLB _ MWD+GMAG(2K-3 W MD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 6/22/2017 11:04: 11,995.32 21,992.592K-30 Srvy4-SLB_MWD+GMAG(2K-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/4/2017 143:0 Survey 8112017 1O:O3.40AM Page 2 COMPASS 5000 14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) (°) (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 39.21 0.00 0.00 39.21 -115.70 0.00 0.00 5,938,165.20 498.310.15 0.00 0.00 UNDEFINED 98.42 070 336.02 98.42 -5649 0.33 -0.15 5,938,165.53 498,310.00 1.18 -0.30 GYD-GC-SS,I, 115.00 0.64 341.59 115.00 -39.91 0.51 -0.22 5,938,165.71 498,309.93 0.54 -047 NOT an Actual Survey 20" x 24" 130.17 0.59 347.63 130.17 -24.74 0.67 -026 5,938,165.7 498,309.89 0.54 -0.61 GYD-GC-SS(1) 15349 0.55 308.56 153.49 -1.42 0.85 -0.37 5,938,16605 498,309.78 1.64 -0.78 GYD-GC-SS(1) 198.31 129 28160 198.30 43.39 1.09 -1.04 5.M,1%,29 498,309.11 1.87 -0.89 GYD-GC-S$(1) 245.08 1.15 279.09 245.06 90.15 1.27 -202 5,938,166.47 49$308.13 0.32 -0.90 GYD-GC-SS(1) 344.22 1.67 272.02 344.17 189.26 1.48 4.44 5,938,166.68 498,305.71 0.55 -D.68 GYD-GC-SS(1) 372.32 1.55 258.14 372.26 217.35 1.41 -5.22 5,938,166.62 498,304.93 1.45 -049 GYD-GC-SS(1) 402.14 2.12 258.67 402.06 247.15 1.22 -6.16 5,938,166.42 498,303.99 1.91 -0.14 GYD-GC-SS(1) 8112017 1O:O3.40AM Page 2 COMPASS 5000 14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-30 Project: Kupamk River Unit TVD Reference: Rig: 39.21+115.70 @ 154.91 usfl Site: Kuparuk 2K Pad MD Reference: Rig: 39.21+115.70 @ 154.91usft Well: 2K-30 North Reference: True Wellbore: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30 Database: OAKEDMP2 Survey Map Map Vertical MD Inc AZi TVD TVDSS +NAS +E/ -W Northing Easting DLS Section (usfl) (') V) (usfl) (usft) (usft) (usfl) (ft) (ft) (°/100') (ft) Survey Tool Name 434.02 285 255.73 433.91 279.00 0.91 -7.50 5,938,166.11 498.302.65 2.32 0.41 GYD-GC-SS(1) 464.45 344 255.71 464.30 309.39 0.50 -9.12 5,938,165.70 498301.03 1.94 1.09 GYD-GC-SS(1) 495.60 421 254.52 495.38 34047 -0.04 -11.13 5,938,165.17 498,299.02 248 1.97 GYD-GC-SS (1) 527.99 4.96 253.90 52766 372.75 -0.74 -13.62 5,938,16446 498,29653 2.32 3.10 GYD-GC-SS(1) 55820 546 253.85 557.75 402.84 -1.50 -16.26 5,938,163.70 498,293.89 1.66 4.3D GYD-GC-SS(1) 620.31 6.33 257.50 619.53 464.62 -3.07 -2244 5.938.162.14 498,287.71 1,52 692 GYD-GC-SS (1) 714.48 6.32 255.63 713.13 55822 -5.48 -32.53 5,938,15973 498,277.63 0.22 11.04 GYD-GC-SS (1) 808.17 9.20 252.38 805.95 651.04 -9.02 -44.66 5,938,155.19 498,26549 3.11 16.64 GYD-GC-SS(1) 90225 8.96 248.05 898.85 743.94 -14.04 -5863 5,938,151.18 498,251.53 077 24.01 GYD-GC-SS(1) 997.69 10.76 242.54 992.88 837.97 -20.93 -73.43 5,938,144.29 496,236.73 2.13 33.36 GYD-GC-SS (1) 1,093.02 11.82 243.60 1,086.36 931.45 -29.37 -90.07 5,938.13585 498,220.08 1.13 44.57 GYD-GC-SS(1) 1,187]6 14.22 241.29 1,178.66 1,023.75 -3928 -108.97 5,938,125.95 498,201.18 2.59 57.60 GYD-GC-SS(1) 1,281.83 16.11 241.20 1.269.45 1,114.54 -51.12 -130.54 5,938,114.12 40,179.61 2.01 73,01 GYD-GC-SS(1) 1,376.52 19.18 240.72 1,35968 1,204.77 -85.06 -155.63 5.938,100 19 498.154.52 3.25 91.09 GYD-GC-SS (1) 1,470.30 22.00 239.77 1,447.46 1,292.55 -8144 484.25 5,938,083.81 498,125.90 3.03 112.19 GYD-GC-SS(1) 1,531.27 22.06 240.25 1.503.98 1349.07 -92.87 -204.05 5,938,072.39 498,106.10 0.31 126.89 GYD-GC-SS(1) 1.625.28 2240 238.95 1,591.00 1.436.09 -11087 -234.73 5.938.054.40 498.075.42 0.64 149.94 GYD-GC-SS (1) 1,723.38 24.30 234.72 1,681.07 1,526.16 -132.17 -267.22 5,938,033.10 498,04292 2.58 176.56 MWD+IFR-AK-CAZ-SC(2) 1,813.51 25.24 233.02 1.762.90 1,607.99 -154.44 -297.71 5,938,010.84 498,012.43 1.31 203.79 MWD+IFR-AK-CAZ-SC (2) 1,908.17 2734 228.86 1847.63 1,692.72 -181.08 -330.44 5,937,984.21 497,979.71 3.29 235.71 MWD+IFR-AK-CAZ-SC(2) 2,003.63 30.98 226.22 1,930.82 1,775.91 -212.71 -364.92 5,937,952.60 497,94522 3.65 272.84 MWD+IFR-AK-CAZ-SC(2) 2,098.08 32.65 224.98 2,011.07 1,856.16 -247.55 400.48 5,937,91776 497,909.65 1.90 313.33 MWO+IFR-AK-CAZ-SC(2) 2.193.26 34.05 224.15 2,090.58 1,935.67 -284.83 -437.19 5,937,88049 497,872.94 1.55 356.42 MWD+IFR-AK-CAZ-SC(2) 2,287.60 35.57 221.21 2,168.04 2,013.13 -32443 473.67 5.937,84091 497,836.46 240 40115 MWD+IFR-AK-CAZ-SC (2) 2,381.90 37.89 221,10 2,24361 2,08870 -366.89 -510.78 5,937,798.46 497,799.34 246 450.01 MWD+IFR-AK-CAZ-SC(2) 2,477.26 40.26 220.08 2,317.64 2,16273 -412.54 -549.87 5,937,752.82 497,760.24 2.58 501.76 MWD+IFR-AK-CAZ-SC(2) 2,572.39 43.65 21572 2,388.38 2,233.47 -16275 -588.86 5,937,70263 497,721.25 4.71 557.97 MWD+IFR-AK-CAZ-SC (2) 2,667.07 45.97 215.15 2,45554 2,3DD.63 -517.12 -627.54 5,937,64827 497.682.56 2.48 61823 MWD+IFR-AK-CAZ-SC (2) 2,761.74 47.18 214.25 2,520.62 2,365.71 -573.65 -666.67 5,937,591.76 497,643.41 145 680.70 MWD+IFR-AK-CAZ-SC(2) 2,856.76 49.14 214.12 2,584.00 2.429.09 632.20 -706.45 5,937,533.22 497,603.63 2.07 745.27 MWD+IFR-AK-CAZ-SC(2) 2,951.87 52.10 213.94 2,644.34 2,489.43 -693.12 -747.58 5937,47231 497,56249 3.12 81241 MWD+IFR-AK-CAZ-SC(2) 3,046.36 5391 213.75 2,701.19 2,546.28 -75580 -789.61 5,937,409.65 497,520.45 192 881.43 MWD+IFR-AK-CAZ-SC (2) 3,141.48 57.61 213.81 2,754.71 2,599.80 -821.15 -833.32 5,937,344.32 497,476.73 3.89 953.38 MWD+IFR-AK-CAZ-SC(2) 3,237.96 59.61 213.23 2,804.96 2,650.05 -869.81 -878.80 5,937.275.67 497,43124 2.14 1,028.89 MWD+IFR-AK-CAZ-SC(2) 3,309.00 6141 212.71 2,83992 2,685.01 -941.69 -91245 5,937,223.81 497,397.58 2.62 1,085.83 NOT ml Actual Survey 10-3/4" X 134/2' 3,332.11 62.00 212.54 2,850.88 2,69597 -958.83 -92342 5,937,206.67 497,386.61 262 1,104.61 MWD+IFR-AK-CAZ-SC(3) 3,399.75 62.97 212.86 2,882.13 2,727.22 -1,009.31 -955.82 5,937,15621 497,354.19 149 1,159.95 MWD+IFR-AK-CAZ-SC(3) 345034 63.75 213.36 2,904.99 2,750.08 -1.047.48 -980.72 5,937,118.04 49,329.29 1.76 1,201.87 MWD+IFR-AK-CAZ-SC (3) 3,49342 64.22 214.03 2,92331 2,768.80 -1,079.40 -1,OD200 5,937,086.14 497,308.01 1.79 1,236.99 MWD+IFR-AK-CAZ-SC(3) 3,530.56 64.18 214.45 2,939.87 2.784.96 -1,107.04 -1,020.81 5.93705850 497,289.19 1.02 126748 MWD+IFR-AK-CAZ-SC(3) 8/12017 10,03r40AM Page 3 COMPASS 5000 14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-30 Project: Kuparuk River Unit TVD Reference: Rig: 39.21+115.70 @ 154.91usft Site: Kuparuk 2K Pad MD Reference: Rig: 39.21+115.70 @ 154.91 usft Well: 2K-30 North Reference: True Wellbore: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30 Database: OAKEDMP2 Survey Map Map Vertical MD Inc AN TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (o) 0 (usft) (usft) (usft) (usft) (ft) (ft) (ollow) (ft) Survey Tool Name 3,562.23 6377 215.04 2,953.77 2,79886 -1,130.42 -1,037.03 5,937,035.12 497,272.97 2.12 1,293.33 MWD+1FR-AK-CAZ-SC(3) 3,58844 63.71 215.42 2965.37 2,81046 -1,14962 -1,050.59 5.937,015 93 497,25941 1.32 1,314.59 MWD+IFR-AK-CAZ-SC(3) 3,682.88 63.25 217.42 3.007.54 2,852.63 -1,217.62 -1,100.76 5,936,947.95 497,20923 1.96 1390.26 MWD+IFR-AK-CAZ-SC(3) 3,777.58 63.29 219.85 3,050.14 2.895.23 -1,28368 -1,153.56 5,936,88191 497,156.42 2.29 1,464.49 MWD+1FR-AK-CAZ-SC(3) 3,871.86 63.39 221.03 3,09244 2,937.53 -1,347.8D -1,208.21 5,936,817.80 497,101.76 1.12 1,537.13 MWD+IFR-AK-CAZ-SC(3) 3,966.40 63.23 221.02 3,134.90 2,979.99 -1411.53 -1,26365 5,9W,754.10 497,046.31 0.17 1,609.51 MWD+1FR-AK-CAZ-SC(3) 4,061.18 63.13 220.11 3,177.67 3,022.76 -1,475.78 -131866 5,938689.86 496,991.29 0.86 1,682.34 MWD+IFR-AK-CAZ-SC(3) 4,156.24 63.14 219.29 3,220.83 3,065.72 -1,541.03 -1,372.83 5,936,624.63 496,937.12 077 1756.00 MWD+IFR-AK-CAZ-SC(3) 4,251.42 63.14 217.57 3,263.63 3,10872 -1,607.54 -1,425.60 5.936,558 14 496,88433 1.61 1,83067 MWD+IFR-AK-CAZ-SC(3) 4,34563 63.04 216.70 3,3W.27 3,151.36 -1674.51 -1,476.32 5,936,491.19 496,833.61 083 1,90543 MWD+IFR-AK-CAZ.SC(3) 4,440.03 63.08 215.49 3,349.04 3,194.13 -1,742.51 -1,525.89 5,936,42320 496,784.02 1.14 1,981.01 MWD+IFR-AK-CAZ-SC(3) 4,534.89 63.17 214.38 3,391.92 3,237.01 -1,811.88 -1,574.35 5,936,353.86 496,735.56 1.05 2,057.73 MWD+1FR-AK-CAZ-SC (3) 4,629.80 6320 215.09 3,43474 3,279.83 -1,881.49 -1,62261 5,938284.26 496,687.28 0.67 2,134.67 MWD+IFR-AK-CAZ-SC(3) 472461 63.73 215.15 3.477.09 3,322.18 4,95087 -1,67141 5,936,214.90 496,638.47 0.56 2,211.47 MWD+IFR-AK-CAZ-SC(3) 4,818.94 63.71 214.31 3,518.86 3,363.95 -2,020.38 -1,719.59 5,936,14541 496,590.28 0.80 2,288.29 MWD+IFR-AK-CAZ-SC(3) 4,914.01 63.65 215.03 3,561.01 3,403.10 -2.090.46 -1768.06 5.9W,075 34 496,54179 0.68 2,365.72 MWD+IFR-AK-CAZ-SC(3) 5.00872 63.58 21574 3.603.10 3448.19 -2,15963 -1,817.19 5,936,006.19 496,492.65 0.68 2,442.38 MWD+IFR-AK-CAZ-SC(3) 5,103.44 63,59 216.77 3.645.24 3,490.33 -2,228.04 -1,867.36 5,93893780 496,44248 0.97 2,51845 MWD+IFR-AK-CAZ-SC(3) 5,19828 63.60 217.55 3,687.42 3,532.51 -2,29574 -1,918.67 5,935,870.12 498391.16 074 2,594.03 MWD+1FR-AK-CAZ-SC(3) 5,292.60 63.52 218.03 3,72942 3,574.51 -2,362.48 -1,970.42 5,935,803.40 496,33940 0.46 2,66874 MWD+1FR-AK-CAZ-SC(3) 5,387.77 63.74 217.29 3,771.69 3,61678 -2,429.98 -2,022.52 5,935,735.92 496,287.29 0.73 2,744.27 MWD+IFR-AK-CAZ-SC(3) 5,482.16 6467 217.53 3.813.21 3,658.30 -2,497.31 -2,074.01 5,935,66861 496,235.78 042 2,819.52 MWD+1FR-AK.CAZ-SC(3) 5,576.36 64.20 217.64 3,854.30 3,699.39 -2,564.48 -2,125.72 5,935,601.45 496,184.07 0.17 2,894.65 MWD+1FR-AK-CAZ-SC(3) 5,671.14 64.16 218.56 3,895.58 3,740.67 -2,631.62 -2.178.36 5.935,534.33 496.13142 0.87 2,969.91 MWD+IFR-AK-CAZ-SC(3) 5,765.74 64.13 218.59 3,936.84 3.781.93 -2,698.17 -2,23144 5,93846780 496,078.33 0.04 3,044.67 MWD+IFR-AK-CAZ-SC(3) 5,85969 64.13 218.41 3,977.83 3,822.92 -2,764.33 -2,284.07 5,935,401.66 496,025.69 0.17 3,118.96 MWD+IFR-AK-CAZ-SC(3) 5,954.87 64.13 21846 4,019.36 3,864.45 -2,831.41 -2,337.30 5,935,334.59 495.972.45 005 3,194.27 MM+IFR-AK-CAZ-SC(3) 6,049.76 64.19 217.64 4,05072 3,90581 -2,898.67 -2,389.94 5,935,267.36 495,919.80 0.78 3,269.64 MWD+IFR-AK-CAZ-SC(3) 6,144.80 64.10 21774 4,102.17 3,94726 -2,968.35 -2,44223 5,935,199.70 495.867,50 0.13 3,345.37 MWD+IFR-AK-CAZ-SC(3) 6,239.23 64.17 217.77 4,143.36 3,988.45 -3,033.53 -2,494.26 5,935,132.54 495,815.46 0.08 3,420.56 MWD+IFR-AK-CAZ-SC(3) 6,333.84 64.14 218.60 4,184.61 4,029.70 .3,100.45 -2,546.89 5,935,06563 495,762.82 0.79 349561 MWD+IFR-AK-CAZ-SC(3) 6,427.61 64.14 218.31 4,225.51 4,070.60 -3,166.53 -2,599.37 5,934999.57 495,710.33 028 3,559.80 MWD+IFR-AK-CAZ.SC(3) 6,523.01 64.13 218.14 4,267.13 4,11222 -3,233.97 -2,65248 5,934,932.15 495,657.21 0.16 3,645.44 MWD+IFR-AK-CAZ-SC(3) 6,617.65 64.17 218.21 4,308.39 4,153.48 -3,300.92 -2,705.12 5,934,865.21 495,604.56 0.08 3,720.51 MWD+IFR-AK-CAZ-SC (3) 6,712.12 64.14 217.55 4,349.57 4,194.66 -3.368.03 -2,757.33 5.9U,798 13 495,552.34 0.63 3,79567 MWD+IFR-AK-CAZ-SC(3) 6,887.02 64.13 217.14 4,390.54 4,23563 -3,435.20 -2,808.58 5,934730.97 495,501.08 0.39 3,870.72 MWD+1FR-AK-CAZ-SC(3) 6,901.12 64.15 216.98 4,43202 4,277.11 -3,50349 -2,860.16 5,934,662.70 495,449.50 0.15 3,946.93 MWD+IFR-AK-CAZ-SC(3) 6,996.45 6365 216.54 4,473.96 4,319.05 -3.572.08 -2,911.39 5,934,594.13 495,398.25 0.67 4,023.37 MWD+1FR-AK-CAZ-SC(3) 7,090.43 63.63 215.99 4,515.69 4,360.78 .3,639.97 .2,961.20 5,934,526.26 495,348.43 0.52 4,098.88 MWD+IFR-AK-CAZ-SC(3) 7,185.98 63.67 217.13 4,558.10 4,403.19 -3,708.74 -3,012.20 5,934,457.50 495,297.42 1.07 4,17546 MWD+IFR-AK-CAZ-SC(3) S/l/2017 10.03:40AM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 2K-30 Project: Kuparuk River Unit TVD Reference: Rig: 39.21+115.70 @ 154.91 usft Site: Kuparuk 2K Pad MD Reference: Rig: 39.21+115.70 @ 154.91 usft Well: 2K-30 North Reference: True Wellbore: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30 Database: OAKEDMP2 Survey Map Map Vertical MD Inc AN TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (1 (1) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,281.17 63.56 217.27 4,600.40 4,445.49 -3,77667 -3,063.76 5934,389.60 495,245.85 0.18 4,251.31 MWD+IFR-AK-CAZ-SC(3) 7,375.86 6345 216.67 4,642.64 4,487.73 -3,844.38 -3,114.73 5,934,321.91 495,19487 0.58 4326.84 MWD+IFR-AK-CAZ-SC(3) 7,47085 63.60 216.56 4,684.98 4,530.07 8912.63 -3,155.44 5,934,253.67 495,144.15 0.18 4,402.86 MWD+IFR-AK-CAZ-SC(3) 7,56507 63.63 21604 4726.85 4,57194 -3,980.65 -3,21541 5,934,18567 495,094.17 0.50 4,478.53 MWD+IFR-AK-CAZ-SC(3) 7,659.80 63.66 216.56 4,768.90 4,613.99 4049.08 -3,265.66 5,934,117.27 495,043.91 0.49 4,554.63 MWD+IFR-AK-CAZ-SC (3) 7,754.18 63.56 216.71 4,810.85 4,655.94 4,116.91 -3,316.11 5,934,04945 494,993.45 0.18 4,630.20 MWD+IFR-AK-CAZ-SC(3) 7,84945 6363 217.86 4,85322 4,698.31 -4,184.80 -3,367.80 5,933,981.58 494.941.75 1.08 4,706.03 MWD+IFR-AK-CAZ-SC(3) 7,943.88 63.79 218.57 4,895.04 4,740.13 4,251.31 -3,420.18 5,933,915.08 494,889.36 0.70 4,780.63 MWD+IFR-AK-CAZ-SC(3) 8,03865 63.75 219.17 4,936.93 4,78202 4,317.50 -3,473.52 5,933,848.91 494,836.01 0.57 4,855.08 MWD+IFR-AK-CAZ-SC(3) 8.134.59 63.76 219.35 4,97936 4,824.45 -4,384.13 -3,527.98 5,933,78230 494,781.54 0.17 4,930.15 MWD+IFR-AK-CAZ-SC(3) 8,227.86 6379 219.89 5,020.57 4,865.66 -4,448.58 -3,581.33 5,933,717.87 494,728.18 0.52 5,002.89 MWD+IFR-AK-CAZ-SC(3) 8,320.13 6375 219.75 5,081.35 4,906.44 -4,512.15 -3,634.34 5,933,654.32 494,675.16 0.14 5,074.70 MWD+IFR-AK-CAZ-SC(3) 6,41].50 64.13 219.05 5,104.13 4,949.22 -4,579.74 -3,689.86 5,933,586.74 494,619.64 075 5,150.90 MWD+IFR-AK-CAZ-SC(3) 8,511.81 64.16 219.31 5,145.26 4,990.35 -4,645.53 -3,74347 5,933,520.98 494,566.01 0.25 5.225.00 MWD+IFR-AK-CAZ-SC(3) 8,607.16 64.26 21766 5.18674 5,031.83 -4,712.73 -3,796.90 5,933,45379 494,512.58 1.56 5,300.46 MWD+1FR-AK-CAZ-SC(3) 8,701.77 64.23 216.93 5,227.86 5,072.95 4,780.52 -3,848.53 5.933,386.03 494,460.93 070 5,376.18 MWD+IFR-AK-CAZ-SC(3) 8,796.53 64.20 216.46 5,269.08 5,114.17 -4,848.93 -3,899.52 5,933,317.63 494,409.94 0.45 5,452.41 MWD+IFR-AK-CAZ-SC(3) 8,890.47 63.81 217.42 5,310.25 5,155.34 .4,916.42 -3,950.26 5,933,250.16 494,359.19 1.01 5,527.68 MWD+IFR-AK-CAZ-SC(3) 8,985.13 63.75 217.33 5,352.07 5,197.16 -4,983.90 -4,00181 5,933,182.69 494,307.63 0.11 5,603.09 MWD+IFR-AK-CAZ-SC(3) 9,080.57 63.59 21772 5,394.40 5,239.49 -5,051.74 -4,053.91 5,933,114.87 494,255.51 0.40 5,678.95 MWD+IFR-AK-CAZ-SC(3) 9,17569 63.60 217.13 5,436.71 5,281.80 -5,119.40 4105.68 5,933,047.23 494,203.73 0.56 5,754.57 MWD+1FR-AK-CAZ-SC(3) 9.2694D 6369 216.13 5,478.31 5,323.40 -5,186.78 -4,155.78 5,932,979.87 494,153.82 0.96 5,829,63 MWD+IFR-AK-CAZ-SC(3) 9,364.66 63.69 216.59 5,520.53 5,36562 -5,255.55 -4,20641 5,932,911.12 494,102.98 0.43 5,906.14 MWD+IFR-AK-CAZ-SC(3) 9,458.68 63.65 215.67 5,562.23 5,407.32 -5,323.61 4,256.09 5,932,84308 494,053.29 0.88 5,981.80 MWD+IFR-AK-CAZ-SC(3) 9,554.10 63.62 215.69 5,604.61 5,44970 -5,39306 4,305.96 5,932,773.65 494,003.41 0.04 8,058.85 MWD+IFR-AK-CAZ-SC(3) 9,648.82 63.79 216.86 5,646.57 5,491.66 -5461.52 -4,356.20 5,932,705.21 493,953.16 1.12 6,134.99 MWD+IFR-AK-CAZ-SC(3) 9.742.94 63.57 217.15 5,688.30 5,533.39 -5,528.89 4,406.98 5,932,637,86 493,902.38 0.36 6,210.15 MWD+IFR-AK-CAZ-SC(3) 9,837.50 63.69 217.14 5,730.30 5,575.39 -5,596.42 4,458.13 5,932,57034 493,85121 0.13 6,285.54 MWD+IFR-AK-CAZ-SC(3) 9,932.26 63.76 217.29 5,77225 5,617.34 -5,664.08 4,50952 5,932,50269 493,799.81 0.16 6,361.10 MWD+1FR-AK-CAZ-SC(3) 10,026.87 6372 217.63 5,814.11 5,659.20 .5,731.43 -4,561.13 5,932,435.36 493,748.19 0.33 6,436.39 MWD+IFR-AK-CAZ-SC(3) 10,121.55 64.25 217.96 5,855.63 5,700,72 -5,79867 -4,61327 5.932,368.15 493,69604 0.64 6,511.66 MWD+IFR-AK-CAZ-SC(3) 10,215.59 64.22 218.16 5,896.51 5,74160 -5.865.35 4,66548 5,932,301.48 493,643.82 0.19 6,586.40 MWD+IFR-AK-CAZ-SC(3) 10,310.48 64.10 218.12 5,937.87 5,782.% -5,93252 -4,718.23 5932.234.33 493,591.07 0.13 6,661.70 MWD+IFR-AK-CAZ-SC(3) 10,405.54 64.17 217.91 5,979.34 5,824.43 -5,999.91 -4,770.91 5,932,166.96 493,538.38 021 6,737.22 MWD+IFR-AK-CAZ-SC(3) 10,500.06 64.08 21]49 6,020.59 5,865.68 -6,057.20 -4,822.91 5,932,09969 493486.36 041 6,812.52 MWD+1FR-AK-CAZ-SC(3) 10,594.59 64.04 21708 6,061.94 5,907.03 b,134.83 4,874.41 5,932,032.07 493,434.66 0.39 6,888.06 MWD+IFR-AK-CAZ-SC(3) 10.689.57 65.39 213.97 6,102.52 5.947.61 -6.204.72 -4,924.29 5,931,962.20 493,384.96 3.28 6,965.55 MWD+IFR-AK-CAZ-SC(3) 10,78433 6770 210.06 6.140.24 5,985.33 -6,278.42 -4,970.34 5,931,888.52 493.338.90 4.50 7,046.13 MWD+1FR-AK-CAZ-SC(3) 10,878.91 70.56 207.52 6,173.94 6,019.03 -8,355.87 -5,012.87 5,931,811.09 493,296.35 3.93 7,129.78 MWD+IFR-AK-CAZ-SC(3) 40,973.90 71.99 206.17 6,204.43 6,049.52 -6,436.13 -5,05349 5,931,730.85 493,255.72 2.02 7,215.88 MWD+1FR-AK-CAZ-SC(3) 8712017 10:03 40AM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-30 Project: Kupamk River Unit TVD Reference: Rig: 39.21+115.70 @ 154.9lusit Site: Kuparuk 2K Pad MD Reference: Rig: 39.21+115.70 @ 154.91usft Well: 2K-30 North Reference: True Wellbore: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/.S +E/ -W Northing Easting DLS Section (usft) (') (1) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11.068.38 73.05 205.76 6232.81 6.077.90 $,517.15 -5,092.95 5,931,649.84 493,21625 1.20 7,302.52 MWD+IFR-AK-CAZ-SC(3) 11162.71 74.48 204.43 6,259.19 6,104.28 -6599.17 -5,131,35 5.931,56]84 493,177.83 2.03 7,389.96 MWD+IFR-AK-CAZ-SC(3) 11,257.76 76.17 202.10 6,283.27 6,128.36 6,683.63 -5,167.66 5,931.483 39 493,141.51 2.96 7,479.45 MWD+1FR-AK-CAZ-SC(3) 11352.90 7]60 19983 6,304.86 6,149.95 6,770.15 -5,20081 5,931,396.89 493,108.35 2.77 7,57041 MWD+IFR-AK-CAZ-SC(3) 11.447.14 79,72 196.48 6,323.39 6,168.48 -6,857.94 -5,229.58 5,931,309.12 493,079.56 4.15 7,661.85 MWD+IFR-AK-CAZ-SC(3) 11,541.32 82.41 192.78 6,338.02 6,183.11 -6,94]93 -5,253.06 5,931,219.14 493,056.06 482 7,754.56 MWD+IFR-AK-CAZ-SC(3) 11,635.23 85.60 189.67 6,347.83 6,192.92 -7,039.52 -5,271.23 5,931,12756 493,037.87 473 7.847.92 MWD+1FR-AK-CAZ-SC (3) 11,731.71 86.76 188.64 6,354.26 6,199.35 -0,134.56 -5,286.55 5,931,032.54 493,022.53 1.61 7,944.17 MWD+IFR-AK-CAZ-SC(3) 11,825.93 86.63 188.89 6,35969 6,20478 -7,227.52 -5,300.88 5,930,939.59 493,008.18 0.30 8,038.21 MWD+IFR-AK-CAZ-SC(3) 11,90027 86.30 189.80 6,364.28 6,209.37 -7,300]4 -5,312.93 5,930.866.39 492,996.12 1.30 8.112.40 MW0+1FR-AK-CAZ-SC (3) 11957.00 86.35 189.36 6,367.91 6,213.00 -7,356.56 -5,322.35 5,930,810.57 492,986.68 0.77 8,169.0` NOT aO ACtual Survey 7-616" z 9-719 by 11" 11,995.32 86.39 18907 6,370.33 6,21542 -7,394.31 -5,328.48 5,930,772.83 492,980.55 0.77 8,207.25 MW0+1FR-AK-CAZ-SC(4) 12,090.15 8774 188.70 6,375.19 6,220.28 -7487.88 -5,343.10 5,930,67927 492,965.90 148 8,301.94 MWD+IFR-AI(-CAZ-SC(4) 12,183.50 88.12 187.11 6,378.56 6,223.65 -7,58028 -5,355.93 5,9m,586 88 492,953.05 1.75 8,395.16 MWD+IFR-AK-CAZ-SC(4) 12,237.93 87.98 186.81 6,38041 6,225.50 -7,634.27 -5,362.53 5.930,53289 492,946.45 0.61 8,449.48 MWD+IFR-AK-CAZ-SC(4) 12.279.32 8808 188.14 6,381.84 6,226.93 -7,675.29 -5,367.91 5,930,49189 492,941.06 322 8,49081 MWD+IFR-AK-CAZ-SC (4) 12,325.04 87.98 189.58 6.383.41 6,228.50 -7,72043 -5,374.94 5.93,446]4 492.934.01 3.16 8,535.49 MWD+IFR-AK-CAZ-SC(4) 12,37386 88.22 189.52 6.385.03 6,230.12 -7.768.55 -5,383.04 5,930,39863 492,925.91 0.51 8.5B528 MWD+IFR-AK-CAZ-SC(4) 12,422.85 87.87 190.50 6,3W.70 6,23179 -7,816.76 -5,391.55 5,930,35043 492,917.39 2.12 8,634.24 MWD+IFR-AK-CAZ-SC(4) 12469.52 88.15 190.37 6,388.32 6,233.41 -7,862.64 -5,400.00 5,930,304.56 492,908.93 066 8,680.88 MWD+IFR-AK-CAZ-SC(4) 12,564.19 8860 191.05 6,391.00 6,236.09 -7,955.62 -5,417.58 5,930,211.59 492,89132 0.86 8,775.51 MWD+IFR-AK-CAZSC(4) 12,658.55 88.56 191.20 6,393.34 6,238.43 -8,04818 -5,435.79 5,930,119.05 492,873.10 0.16 8,869.82 MWD+1FR-AK-CAZ-SC(4) 12,753.14 88.24 192.20 6,395.98 6,241.07 -8,140.76 -5,454.96 5,930,02647 492,853.91 1.11 8964.33 MWD+IFR-AK-CAZ-SC(4) 12,84693 89.08 192.29 6,398.18 6,243.27 -8,232.39 -5,474.85 5.929,934.86 492,834.01 0.90 9,058.02 MWD+1FR4K-CAZ-SC(4) 12,94192 89.08 192.27 6,39970 6,244.79 -8,325.20 -5,495.05 5,929,842.07 492.813.79 0.02 9,152.92 MWD+IFR-AK-CAZ-SC(4) 13.036.43 8996 192.62 6400.91 6,246.00 -8,417.48 -5,515.41 5,929,749.80 492,793.40 0.55 9,247.34 MWD+1FR-AK-CAZ-SC (4) 13,131.31 89.46 193.24 6,404,80 6,246.89 -8,509.95 -5,536.64 5,929,657.34 492,772.16 0.65 9,342.09 MWD+IFR-AK-CAZ-SC (4) 13,225.89 9007 193.14 6,402.19 6,247.28 -8,602.03 -5,558.22 5,929,55527 492,750.58 0.65 9,436.52 MWD+IFR-AK-CAZ.SC(4) 13,320.11 90.45 193.34 6,401.76 6,246.85 -8,693]5 -5,579.80 5,929,473.57 492,728.% 0.46 9.530.59 MWD+IFR-AK-CAZ-SC (4) 13,415.77 90.55 192.24 6,40093 6,246.02 -8,787.03 -5,600.98 5,929,380.31 492,707.76 1.15 9,626.13 MWD+1FR-AK-CAZ-SC (4) 13,511.00 89.94 192.27 6,400.52 6,24561 -8,880.09 -5,621.19 5,929,287.26 492,687.53 0.64 9,721.29 MWD+1FR-AK-CAZ-SC(4) 13.604.89 89.49 191.47 6,400.99 6,24808 .8,971.97 -5,640.50 5,929,195.39 492,668.20 0.98 9,815.13 MWD+IFR-AK-CAZ.SC(4) 13,698.80 89.59 190.74 6,401.74 6,246.83 -9,064.12 -5,658.59 5,929,103.26 492,650.09 0.78 9,90902 MWD+1FR-AK-CAZ-SC (4) 13,793.58 89.32 189.78 6,402.64 6,24773 -9,157.38 -5,675.47 5,929,010.01 492,633.19 1.05 10,003.79 MWD+IFR-AK-CAZ-SC(4) 13,888.15 88.77 191.02 6,404.22 6,249.31 -9,250.38 -5,692.54 5,928,917.02 492,616.11 1.43 10,MB.34 MW1)+1FR-AK-CAZ-SC(4) 13,983.70 88.43 190.21 6,406.55 6,251.64 -9,344.26 -5,710.13 5,928,823.15 492,598.49 0.92 10,193.86 MWD+1FR-AK-CAZ-SC (4) 14,07843 87.88 190.91 6,40960 6,254.69 -9,437.34 -5,727.49 5,928.7M 09 492,581.12 0.94 10,286.53 MWD+IFR-AK-CAZ-SC(4) 14,172.73 88.08 190.52 6,412.94 6,258.03 -9,529.94 -5,745.01 5,928,637.50 492,563.58 0.46 10,382.77 MWD+IFR-AK-CAZ-SC(4) 14,268.99 86.54 190.79 6,417.48 6,262.57 -9,624.43 -5,762.79 5,928,543.03 492,545.78 1 60 10,478.91 MWD+IFR-AK-CAZ-SC (4) 14,364.20 85.53 191.36 6,424.06 6,269.15 -9,717.64 -5,781.03 5,928,449.83 492,527.52 1.22 10,573.87 MWD+IFR-AK-CAZ-SC (4) 8/12017 10.03.40AM Page 6 COMPASS 5000.14 Build 85 I ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-30 Project: Kupamk River Unit TVD Reference: Rig: 39.21+115.70 @ 154.91 usft Site: Kuparuk 2K Pad MD Reference: Rig: 39.21+115.70 @ 154.91usft Well: 21K-30 North Reference: True Wellborn: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD NDSS +Nl-S +El -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 14,459.03 8531 190.92 6,43130 6,276.39 -9810.41 -5.799.30 5,928,357.07 492,509.23 0.50 10,668.41 MWD+IFR-AK-CAZ-SC(4) 14,553.98 85.96 190.65 6,438.20 6,283.29 -9,903.44 -5,817.02 5,928,26406 492,49149 0.39 10.763.10 MWD+IFR-AK-CAZ-8C(4) 14,64866 88.79 188.68 6,442.53 6,287.62 -9,99866 -5,832.89 5,928,170.85 492,475.60 3.64 10,857.66 MWD+IFR-AK-CAZ-SC (4) 14,743.38 89.35 187.18 6,444.07 6,289,16 -10,090.46 -5,845.96 5,928,077.06 492,462.51 1.69 10,952.30 MWD+IFR-AK-CAZ-SC(4) 14,838.07 89.32 187.69 6,445.17 6,290.26 -10,184.35 -5,858.21 5,927,983.18 492,45024 0.54 11,046.89 MWD+IFR-AK-CAZ-SC(4) 14,933.24 89.59 188.60 6,446.08 6291.17 -10,278.55 -5,871.69 5,927,888.99 492,436.74 1.00 11,142.01 MWD+1FR-AK-CAZ-SC (4) 15,02733 89.97 186.85 6,446.44 6,291.53 -10,372.18 -5,884.39 5,927,795.38 492,424.02 1.90 1123642 MWD+IFR-AK-CAZ-SC(4) 15,122.21 89.73 187.13 6,446.69 6,291.78 -10,465.96 -5,895.89 5,927,70161 492,412.50 0.39 11,330.77 MWD+IFR-AK-CAZ-5C (4) 15,217.07 89.28 186.91 6447.51 6,292.60 -10,560.10 -5,907.49 5,927,60748 492,400.89 0.53 11,425.50 MW1)+IFR-AK-CAZ-SC(4) 15.312.03 89.35 187.13 6,44864 6,293.73 -10,654.34 -5,919.09 5,927,513.25 492,389.26 0.24 11,520.32 MWD+IFR-AK-CAZ-8C(4) 15,406.97 88.77 189.12 6,450.20 6,295.29 -10,748.31 -5,932.51 5,927,41929 492.375.83 2.18 11,615.19 MWD+IFR-AK-CAZ-SC(4) 15,500.56 88.60 190.87 6,452.35 6,297.44 -10,840.46 -5,94834 5,927,327.16 492,359.57 1.88 11,708.75 MWD+IFR-AK-CAZ-SC (4) 15,596.41 88.39 190.49 6454.86 6,29995 -10,934.61 -5,966.50 5,927,233.02 492,341.79 0.45 11,804% MWD+IFR-AK-CAZ-SC (4) 15.691.44 8853 190.38 6,457.42 6,302.51 -11,028.A -5,983.71 5,927,139.61 492.324.57 0.19 11,899.56 MWD+1FR-AK-CAZ-SC(4) 15,785.53 8872 191.19 6,459.68 6,304.77 -11,120.44 -6,001.31 5,927,04722 492,306.95 0.88 11.993.61 MWD+IFR-AK-CAZ-SC(4) 15,880.86 90.45 191.58 6,460.37 6,305.46 -11,213.89 -6,020.13 5.926,95379 492,288.11 1.86 12,088.91 MWD+IFR-AK-CAZ-SC(4) 15,975.92 91.68 191.63 6,458.60 6,30369 -11,306.98 -6,D39.24 5,926,860.70 492,268.98 1.29 12,183.91 MWD+IFR-AK-CAZ-SC(4) 16,071.58 91.92 192.92 6,455.60 6,30069 -11,40041 -6,059.57 5,926,767.29 492,24863 1.37 12,279.45 MWD+IFR-AK-CAZ-SC(4) 16,164.51 92.21 192.40 6,45225 6,297.34 -11491.02 -6,079.93 5,926,676.69 492,22026 0.64 12,372.21 MWD+IFR-AK-CAZ-SC(4) 16,25929 90.74 192.13 6,449.81 6.294.90 -11,583.60 -6.100.05 5,926,584.12 492,208.11 1.58 12,466.89 MWD+IFR-AK-CAZ-SC (4) 16,353.36 91.17 19173 6,446.24 6.293.33 -11,67563 -6,119.50 5,926,492.11 492,188.65 0.62 12,560.89 MWD+IFR-AK-CAZ-SC(4) 16,449.19 90.28 192.13 6,447.03 6,292,12 -11369.38 -6,139.30 5,926,398.37 492,168.82 1.02 12,656.66 MWD+IFR-AK-CAZ-SC(4) 16,544.15 89.70 191.98 6,447.04 6,292.13 -11,862.25 -6.159.14 5,926,305.52 492,148,97 0.63 12,751.55 MWD+IFR-AK-CAZ-SC(4) 16,639.14 89.39 190.58 6,447.80 6,292.89 -11,955.40 -6,177.72 5,926 212 38 492.130.37 1.51 12,846.52 MWD+IFR-AK-CAZ-SC(4) 16,734.10 89.35 190.74 6,448.84 6,293.93 -12,048.71 -6,195.28 5,926119.08 492,112.79 0.17 12,94146 MWD+IFR-AK-CAZ-SC(4) 16,828.91 89.22 191.04 6,450.02 6,295.11 -12.141.81 -6,213.19 5,926,026.00 492,094.86 0.34 13,036.25 MWD+IFR-AK-CAZ-SC (4) 16,92325 88.84 189.41 6,451.62 6,296.71 -12,234.63 -6.229.93 5,925,933.19 492,078.10 1.77 13,130.58 MWD+IFR-AK-CAZ-SC(4) 17,018.29 88.80 187.96 6,45358 6,298.67 -12,328.56 -6,244.28 5,925,639.27 492,063.73 1.53 13225.57 MWD+IFR-AK-CAZ-SC(4) 17,113.24 6867 187.09 6,455.68 6,30037 -12,422.67 -6,256.71 5,925,745.18 492,051.28 093 13,320.41 MWD+IFR-AK-CAZ-SC(4) 17,208.22 8870 186.52 6,457.86 6,302.95 -12,516.95 -6,267.96 5,925,650.90 492,040.01 0.60 13,415.21 MWD.lFR-AK-CAZ-5C(4) 17,302.95 88.32 18468 6,460.32 6,305.41 -12,611.20 -6,277.21 6925,556.67 492,030.75 1.98 13,509.63 MWD+IFR-AK-CAZ-SC(4) 17,397.85 88.32 184.42 6,463.10 6,308.19 -12,705.76 -6,284.73 5,925,462.12 492,023.20 027 13,604.06 MWD+IFR-AK-CAZ-SC(4) 17,492.51 88.94 184.08 6,465.36 6,310.45 -12,800.13 -6.291.74 5,925,367.76 492,016.17 035 13,69821 MWD+IFR-AKCAZ-SC(4) 17,587.37 88.94 183.% 6,467.12 6,312.21 -12,894.74 -6,298.39 5,925,273.16 492.009.50 0.13 13.792.54 MWD+IFR-AK-CAZ-SC (4) 17,682.31 69.57 184.89 6,468.35 6,31344 -12,989.39 -6,305.72 5,925,178.53 492,002.15 1.18 13,887.02 MWD+IFR-AK-CAZ-SC(4) 17,77661 88.76 185.75 6,469.73 6,314.82 -13,08327 -6,314.46 5,925,084.66 491,993.39 125 13,981.00 MWD+IFR-AK-CAZ-SC(4) 17,87143 89.15 187.18 6,47146 6,316.55 -13,177.47 -6,325.13 5,924,99047 491,982.70 1.56 14,075.62 MWD+IFR-AK-CAZ-SC(4) 17,966.66 89.15 191.49 6,472.87 6,317.96 -13,271.40 -6,340.57 5,924,896.55 491,967.23 4.53 14,170.81 MWD+IFR-AK-CAZSC(4) 18,060.97 87.98 194.41 6,475.23 6.320.32 -13,363.27 -6,361.70 5,924,8N 69 491,946.09 3.33 14,264.95 MWD+IFR-AK-CAZ-SC(4) 18,154.90 87.71 193.99 6,478.76 6,323.85 -13,454.27 -6,384.73 5,924,713.71 491,923.05 0.53 14,358.56 MWD+IFR-AK-CAZ-SC(4) 8/12017 10.03:40AM Page 7 COMPASS 5000.14 Build 85 i ( ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-30 Project: Kuparuk River Unit TVD Reference: Rig: 39.21+115.70 @ 154,91usft Site: Kuparuk 2K Pad MD Reference: Rig: 39.21+115.70 @ 154.91usft Well: 21K-30 North Reference: True Wellbore: 2K30 Survey Calculation Method: Minimum Curvature Design: 2K30 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N7 -S +E/ -W Northing Sealing DLS Section (usft) (') (') (usft) (usft) (usft) (usft) (ft) (ft) ('/100•) (ft) Survey Tool Name 18,250.59 87.91 194.25 6,482.42 6,327,51 -13,547.00 -6,408.05 5,924,620.99 491,899.70 0.34 14453.94 MWD+IFR-AK-CAZ-SC(4) 18,344.87 88.32 194.42 6.485.52 6,330.61 -13.638.29 6,431,38 5,924,52971 491.876.35 0.47 14,547.90 MWD+IFR-AK-CAZ-SC(4) 16,437.84 88.39 19372 6488.19 6,333.28 -13,728.44 -6.453.97 5.924.439.58 491,853.74 0.76 14,640.59 MWD+IFR-AK-CAZ-SC(4) 18.535.15 86.83 189.82 6,490.55 6,33564 -13,823.66 -6,473.81 5,924,344.38 491,833.89 4.03 14,737.81 M01D+IFR-AK-CAZ-SC(4) 18,629.99 9040 188.47 6.491.19 8,336.28 -13,917.28 -6,488.89 5,924,250.76 491,818.79 2.18 14,832.63 MWD+IFR-AK-CAZ-SC(4) 18,723.51 69.94 187.28 6,490.91 6,336.00 -14,009.92 -6,501.70 5,924,158.14 491,805.96 1.36 14,926.08 MWD+IFR-AK-CAZ-SC(4) 18,819.59 90.04 186.01 6,490.93 6,336.02 -14,105.35 -6.512.82 5,924,062.72 491,79482 1.33 15,022.00 MWD+IFR-AK-CAZ-SC(4) 18.914.52 90.04 184.42 6,490.86 6,335.95 -14,199.89 6,521 45 5,923,95820 491,786.17 1.67 15,116.59 MWD+IFR-AK-CAZ-SC (4) 19,009.16 9045 183.29 6,490.46 6,335.55 -14,294.31 6,527.81 5,923,87378 491.]]979 1.27 15,210.69 MWD+IFR-AK-CAZ-SC(4) 19,104.10 91.27 182.18 6,48903 6,334.12 -14,389.13 -6,53234 5,923.77898 491,775.24 145 15,304.85 MWD+IFR-AK-CAZ-SC(4) 19,198.69 9175 180.42 8,488.54 6,331.63 -14,483.66 -6,534.48 5,923,68446 491,773.07 1.93 15,398.32 MWD+IFR-AK-CAZ-SC(4) 19.293.16 91.79 180.43 6,483.62 6,328.71 -14.578.08 -6,535.18 5.923.59004 491.772.35 0.04 15,491.43 MWD+IFR-AK-CAZ-SC(4) 19,383.02 92.44 179.93 6,480.31 6,325.40 -14,667.88 -6,53547 5,923,500.26 491,7]205 0.91 15,579.91 MWD+IFR-AK-CAZ-SC(4) 19,482.30 92.37 18069 6,476.14 6,321.23 -14,]6].07 -6.536.00 5,923,401.08 491,771.49 077 15,677.69 MWD+IFR-AK-CAZ.SC(4) 19,5]7.95 91.40 183.30 6,47299 6,318.08 -14,862.60 -6539.33 5,923,305.56 491,768.14 2.91 15,]]2.34 MWD+IFR-AK-CAZ-SC (4) 19,672.50 91.61 185.56 6.470.51 6,315.60 -14,956.83 -6,54663 5,923,211.34 491360.82 2.40 15,866.41 MWD+IFR-AK-CAZ-SC(4) 19.767.26 89.08 182.23 6,469.94 6,315.03 -15,051.34 -6.65307 5,923,116.83 491,754.37 4.41 15,96061 MWD+IFR-AK-CAZ-SC(4) 19,861.02 8997 180.09 6.470.72 6,315.81 -15,145.08 -6,554.96 5,923,023.11 491]52.45 2.47 16,053.25 MWD+1FR-AK-CAZ-SC(4) 19,956.38 90.11 180.02 6,470.65 6,315.74 -15,24044 b555.05 5,922.927.76 491,752.33 0.16 16.147.17 MWD+IFR-AK-CAZ-SC(4) 20,051.06 89.71 181.49 6,470.80 6,31589 -15,335.10 -6,556.30 5,922,833.10 491,751.07 161 16.240.62 MWD+IFR-AK-CAZ-SC(4) 20,145.86 91.17 184.09 6,470.07 6,315.16 -15,429.78 6,560.92 5,922,738.44 491,746.43 3.15 16,334.% MWD+1FR-AK-CAZ-SC (4) 20,24065 92.58 185.27 6,466.97 6,312.08 -15,524.20 6,568.64 5,922,644.03 491,73868 1.94 16,42898 MWD+IFR-AK-CAZ-SC(4) 20,335.01 92.89 184.28 6462.47 6,307.56 -15,618.12 -6,576.49 5,922,550.11 491,730.82 1.10 16,522.84 MWD+IFR-AK-CAZ-SC(4) 20,430.24 93.33 184.24 6,45].30 6,302.39 -15,712.95 -6,583.55 5,922,45530 491,723.73 0.45 16,61]46 MW0+IFR-AK-CAZ-3C(4) 20,525.01 93.78 184.08 6,451.42 6,296.51 -15,807.29 -6.590.42 5,922,36097 491,716.85 0.50 16,711.55 MWD+IFR-AK-CAZ-SC(4) 20,619.43 93.57 183.55 6,445.37 6,290.46 -15,90130 6,59669 5,922,266.97 491,710.56 060 16,805.23 MWD+IFR-AK-CAZ-SC(4) 20,714.35 9240 183.12 6,440.43 6,285.52 -15,995.93 -6,60220 5,922,172.35 491,705.03 1.31 16,899.38 MWD+IFR-AK-CAZ-SC(4) 20,808.73 91.17 18342 6,437.49 6,282.58 -16,090.11 -6,607.58 5,922,078.18 491.699.62 1.34 16,993.06 MWD+IFR-AK-CAZ-SC(4) 20,903.24 89.98 183.31 6,436.56 6,281.65 -16,184.45 -6613.13 5,921,98385 491,694.06 1.29 17.086.93 MWD+IFR-AK-CAZ-SC(4) 20,99663 89.79 181.13 6,436.76 6,281.85 -15,277.77 6,61674 5,921,890.55 491,69042 2.34 17,17946 MWD+IFR-AK-CAZ-SC(4) 21,091.49 90.93 182.84 6.436.16 6,281.25 -16,372.56 -6,620.03 5,921,795.76 491,687.11 2.47 17,273.38 MWD+1FR-AK-CAZ-SC(4) 21,186.22 91.22 183.12 6,434.39 6.279.48 -16,467.15 -6,624.95 5,921,701.19 491,682.17 0.43 17,367.39 MWD+IFR-AK-CAZ-SC (4) 21,281.24 89.80 182.28 6,433.54 6,278.63 -16,562.05 -6,629.43 5,921,60.29 491,677.67 174 17,461.63 MWD+1FR-AK-CAZ-SC(4) 21,37562 88.92 18069 6,434.60 6,279.69 -18656.39 6,631.88 5,921,511.96 491,675.20 1.93 17,554.96 MWD+IFR-AK-CAZ-SC(4) 21,470.97 90.68 183.38 6,434.93 6,280.02 -16,751.67 -6,635.26 5,921,41669 491,671.80 3.37 17649.38 MWD+IFR-AK-CAZ-SC(4) 21,566.14 89.87 184.43 6.434.47 6,279.56 -16,846.62 6,641]4 5,921,321.76 491,665.30 1.39 17,74400 MWD+IFR-AK-CAZ-SC(4) 21,66049 89.10 183.35 6,435.32 6,280.41 -16.940.74 -6.648.14 5,921,227.64 491,658.88 1.41 17,837.81 MWD+IFR-AK-CAZ-SC(4) 21,755.38 90.0 180.79 6,436.07 6,281.16 -17,035.56 -6.651.57 5,921,132.84 491,655.43 2.86 17,931.78 MWD+IFR-AK-CAZ-SC(4) 21,849.91 90.07 181.91 6,436.01 6,281.10 -17,130.0 -6,653.80 5,921,38.34 491.653.18 1.19 18,025.24 MWD+IFR-AK-CAZ-SC(4) 21,914.00 89.94 181.56 6,436.00 6,281.09 -17,194.12 -6,655.74 5,920,974.29 491,651.22 0.58 18,088.66 NOT an AdON Survey 4-1/2" x 6,374" 8/12017 10..03,40AM Page 8 COMPASS 5000.14 Build 66 I ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-30 Project: Kuparuk River Unit TVD Reference: Rig: 39.21+115,70 @ 154.91 usft Site: Kupamk 2K Pad MO Reference: Rig: 39.21+115.70 @ 154,91usft Well: 2K-30 North Reference: True Wellbore: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30 Database: OAKEDMP2 Survey [D Surface Coordinates (] Declinatial & Convergence C GRS Survey Corrections pi Survey Tool Codes Dga.lyseW MIaMo Brandon Temple 0 SLB DE: 1 Da% QIW Dignsslg dbyA Vcx Client Representative: wa:209ma 10,1600mm Date: Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) 11 11 (usft) (usft) (usft) (usft) (ft) (ft) (-/100-) (it) Survey Tool Name 21,944.43 89.88 18140 6.436.05 6,281.14 -17.22454 -6,656.53 5,920,943.87 491650.43 0.58 18,118.76 MWD+IFR-AK-CAZ-SC(4) 21,992.59 89.13 17958 6,436.47 6,281.56 -17,272]0 6,655.94 5,920,89532 491,650.01 4.09 18,166.25 MWD+IFR-AK-CAZ-SC(4) 22,055.00 89.13 179.58 6,437.41 6,282.50 -17,335.10 -6,656.48 5,920,833.33 491,65045 900 18,227.62 PROJECTED tD TD rinal Definitive Survey Verified and Sinned -of, All targets and/or well position objectives have been achieved. 0 Yes ❑ No I have checked to the best of my ability that the following data Is correct [D Surface Coordinates (] Declinatial & Convergence C GRS Survey Corrections pi Survey Tool Codes Dga.lyseW MIaMo Brandon Temple 0 SLB DE: 1 Da% QIW Dignsslg dbyA Vcx Client Representative: wa:209ma 10,1600mm Date: 811117 8712017 10.03:40AM Page 9 COMPASS 5000.14 Build 85 21 7072 28 49 2 RECEIVED AUG 10 2017 FINAL A®GCC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K-30 2K-30 Definitive Survey Report 31 July, 2017 ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well TD: 2K-30 Project: Kuparuk River Unit TVD Reference: Rig: 39.21+115.70 @ 154.91 usft Site: Kuparuk 2K Pad MD Reference: Rig: 39.21+115.70 @ 154.91usft Well: TO 2K-30 North Reference: True Wellbore: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30 Database: OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States 39.21 Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 MWD+IFR AK CAZ SCC Using Well Reference Point Map Zone: Alaska Zone 4 25867 Using geodetic scale factor Well TD: 2K-30 5,937,916.35 1,63B,341.92 Well Position +N/ -S 0.00 usft Northing: 5,937,915.25 usft Latitude: 70° 14'31.136 N 1,638,340.94 +E/ -W 0.00 usft Easting: 1,638,342.95 usft Longitude: 150° V0.293 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 115.70 usft Wellbore 2K-30 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I P) (nT) BGGM2016 6/25/2017 17.43 80.86 57,527.84 Design 2K-30 Date 7/31/2017 Azi (usft) (I Audit Notes: To 0.00 0.00 98.42 Version: 1.0 Phase: ACTUAL Tie On Depth: 39.21 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 1,723.38 (usft) (usft) (usft) (") 3,332.11 39.21 0.00 0.00 190.00 Survey Program Date 7/31/2017 Azi (usft) (I From To 0.00 0.00 98.42 (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 98.42 1,625.28 2K-30 Srvy 1 - SLB_GWD70 (2K-30) GYD-GC-SS G rodata y gyro single shots 6/16/2017 8:17: 1,723.38 3,237.962K-30 Srvy 2- SLB _MWD+GMAG(2K-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/17/2017 8:47: 3,332.11 11,900.272K-30 Srvy 3-SLB_MWD+GMAG(2K-3 MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 6/22/2017 11:04: 11,995.32 21,992.592K-30 Srvy 4-SLB_MWD+GMAG(2K-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/4/2017 1:43:1 Survey MD Inc Azi (usft) (I (% 39.21 0.00 0.00 98.42 0.70 33602 11500 664 341.59 20" x 24" 217.35 130.17 0.59 34763 15349 0.55 308.56 198.31 1.29 281.60 245.08 1.15 279.09 344.22 167 272.02 372.32 1.55 258.14 402.14 2.12 25867 TVD TVDSS +N/ -S (usft) (usft) (usft) 39.21 -115.70 0.00 98.42 -56.49 0.33 115.00 -39.91 0.51 130.17 -2474 0.67 153.49 -1.42 0.85 198.30 43.39 1.09 245.06 90.15 1.27 344.17 189.26 1.48 372.26 217.35 1.41 40206 247.15 122 7/312017 11:06.11AM Page 2 COMPASS 5000 14 Build 85 Map Map Vertical +E/ -W Northing Easting OLS Section (usft) (ft) (ft) r°Ileo') IN Survey Tool Name 0.00 5.937,915.25 1,638.342.95 0.00 0.00 UNDEFINED -0.15 5,937,91559 1,638,342.80 1.18 -0.30 GYD-GC-SS (1) -0.22 5,937,915.77 1,638,34273 0.54 -0.47 NpTBpAclualSUNly -0.26 5,937,91592 1,638,342.69 0.54 -0.61 GYD-GC-SS(1) -0.37 5,937,916.11 1,638.342.58 1.64 -0.78 GYD-GC-$S(1) 4.04 5,937,916.35 1,63B,341.92 187 -0.89 GYD-GC-SS(1) -202 5937916.53 1,638,340.94 0.32 -0.90 GYD-GC-SS(1) 4.44 5.937,916.73 1,638,338.51 0.55 -0.68 GYD-GC-SS(1) -5.22 5,937,91667 1,638,337]3 145 -0.49 GYD-GC-SS(1) -6.16 5,937,916.48 1,638,336.79 1.91 -0.14 GYD-GC-SS(1) 7/312017 11:06.11AM Page 2 COMPASS 5000 14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: TD: 2K-30 Wellbore: 2K-30 Design: 2K-30 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: Well TD: 2K-30 TVD Reference: Rig: 39,21+115.70@ 154.91 usft MD Reference: Rig: 39.21+115.70 @ 154.91 usft North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) V) (I (usft) (usft) (usft) (usft) (ft) (ft) (-M00-) (ft) Survey Tool Name 434,02 2.85 255.73 433.91 279 OD 0.91 -7.50 5,937,916.17 1,638,335.45 2.32 0.41 GYD-GC-SS(1) 464.45 3.44 255.71 464.30 309.39 0.50 -9.12 5,937,915.76 1,638,333.83 1.94 1.09 GYD-GC-SS(1) 495.60 4.21 254.52 49538 340.47 -0.04 -11.13 5,937.915.22 1,638,331.82 2.48 1.97 GYD-GC-SS(1) 527.99 4.95 253.90 527.66 372.75 -0.74 -1362 5,937,914.52 1,638,329.33 2.32 3.10 GYD-GC-SS(1) 55820 5.46 253.85 55735 402.84 -1.50 -16.26 5,937,913.76 1,638,32670 166 4.30 GYD-GC-SS(1) 620.31 6.33 257.50 619.53 464.62 -3.07 -22.44 5,937,912.20 1,638,320.51 1.52 6.92 GYD-GC-SS (1) 714.48 6.32 255.63 713.13 55822 -5.48 -32.53 5,937,909.79 1,638,31043 0.22 1104 GYD-GC-SS(1) 808.17 920 252.38 805.95 651.04 -9.02 -44.66 5,937,906.24 1,638,298.29 3.11 1664 GYD-GC-SS(1) 90225 8.95 248.05 898.85 743.94 44.04 -58.63 5,937,901.23 1,638,28433 0.77 2401 GYD-GC-SS(1) 997.69 10.76 242.54 992.88 B37.97 -20.93 -7343 5,937,894.35 1,638,269.53 2.13 33.36 GYD-GC-SS (1) 1,093.02 11.82 243.60 1,086.36 93145 -29.37 -90.07 5,937,885.91 1,638,252.88 1.13 44.57 GYD-GC-S$(1) 1,187.76 14.22 241.29 1,178.66 1,023.75 -3928 -10897 5,937,876.01 1,638,23398 2.59 5760 GYD-GC-SS(1) 1,281.83 16.11 241.20 1,259.45 1,114.54 -51.12 -130.54 5,937,864.18 1,638,212.41 2.01 73.01 GYD-GC-SS(1) 1,376.52 19.18 240.72 1,35968 1,204.77 -65.06 -155.63 5.937,850.25 1,638,187.32 3.25 91.09 GYD-GC-55(1) 1,470.30 22.00 239.77 1,447.46 1,292.55 -8144 -184.25 5.937,83388 1,638,15870 3.03 112.19 GYD-GC-SS(1) 1,531.27 22.06 240.25 1,503.98 1,349.07 -92.87 -204.05 5,937,822.45 1638,138.89 0.31 126.89 GYD-GC-SS(1) 1,625.28 22.40 238.95 1,591.00 1,436.09 -110.87 -234.73 5,937,80446 1,638,108.22 0.64 149.94 GYD-GC-SS(1) 1,723.38 24.30 234.72 1,681.07 1,526.16 -132.17 -267.22 5,937,783.17 1,638,075.72 2.58 176.56 MWD+IFR-AK-CAZ-SC(2) 1,813.51 25.24 233.02 1,762.90 1,607.99 -154.44 -29771 5,937,760.91 1,638,04522 1.31 203.79 MWD+1FR-AK-CAZ-SC(2) 1,908.17 27.74 228.86 1.847.63 1,692.72 -181.08 -330.44 5,937,734.28 1,638,01250 3.29 23571 MWD+IFR-AK-CAZ-$C(2) 2,003.63 30.98 226.22 1,930.82 1,775.91 -212.71 -364.92 5,937.702.67 1,637,97801 3.65 272.84 MWD+IFR-AK-CAZ-SC (2) 2,098.08 32.65 224.98 2,011.07 1,856.16 -247.55 400.48 5,937,667.84 1,637,942.44 1.90 313.33 MWD+IFR-AK-CAZ-SC(2) 2,193.26 34.05 224.15 2,090.58 1,935.67 -284.83 437.19 5,937,630.57 1,637,905.73 1.55 356.42 MWD+IFR-AK-CAZ-SC(2) 2,287.60 35.57 221.21 2,168.04 2,013.13 -324.43 -473.67 5,937,590.99 1,637,869.24 2.40 401.75 MWD+IFR-AK-CAZ-SC(2) 2,381.90 37.89 221.10 2,24361 2,088.70 -356.89 -510.78 5,937,548.54 1,637,832.12 2.46 450.01 MWD+1FR-AK-CAZ-SC(2) 2,477.26 4026 220.08 2,317.64 2,162.73 412.54 -549.87 5,937,502.91 1,637,793.02 2.58 501.76 MWD+IFR-AK-CAZ-SC(2) 2,572.39 4366 215.72 2,388.38 2,233.47 -462.75 -588.86 5,937,45272 1,637,754.03 471 557.97 MWD+IFR-AK-CAZ-SC(2) 2,667.07 45.97 215.15 2,455.54 2,300.63 -517.12 -627.54 5,937,398.36 1,637,715.33 2.48 61823 MWD+IFR-AK-CAZ-SC(2) 2.761.74 47.18 214.25 2,52062 2,365.71 -573.65 66667 5,937,341.85 1,637,676.19 145 680.70 MWD+IFR-AK-CAZ-SC(2) 2,85676 49.14 214.12 2,584.00 2,429.09 -63220 -706.45 5,937,28331 1,637,636.40 2.07 745.27 MWD+IFR-AK-CAZ-SC(2) 2951.87 52.10 213.94 2,644.34 2,489.43 -693.12 -747.58 5,937,222.41 1,637,595.25 3.12 812.41 MWD+IFR-AK-CAZ-SC(2) 3,046.36 53.91 213.75 2,701.19 2,546.28 -755.60 -78961 5,937,159.75 1,637,55321 1.92 881.43 MWD+IFR-AK-CAZ-SC(2) 3,14148 57.61 213.81 2,754.71 2,599.80 -821.15 -833.32 5,937,09442 1,637,509.48 3.89 953.38 MWD+IFR-AK-CAZ-SC(2) 3,237.96 59.61 213.23 2,804.96 2,650. D5 -889.81 -878.80 5,937,025.77 1,637,464.00 2.14 1,028.89 MWD+IFR-AK-CAZ-SC(2) 3,309.00 61.41 212.71 2,839.92 2,685.01 -941.69 -912.45 5,936,973.91 1,637,430.34 2.62 1,085.83 NOT an Aphid Survey 10.3/4" x 134/2' 3,332.11 6260 212.54 2,85068 2,695.97 -958.83 -923.42 5.936,956.78 1,637,419.36 2.62 1,104.61 MWD+IFR-AK-CAZ-SC (3) 3.3W,75 62.97 212.86 2,882.13 2,727.22 -1,009.31 -955.82 5,936,9013.31 1,637,386.94 1.49 1,159.95 MWD+IFR-AK-CAZ-SC(3) 3,450.74 63.75 213.36 2,904.99 2.750.08 -1,047.48 -980.72 5,936,868.15 1,637,362.04 1.76 1,201.87 MWD+IFR-AK-CAZ-SC(3) 3,493.42 6422 214.03 2,923.71 2,768.80 -1,079.40 -1,002.00 5,936,836.24 1,637,340.75 1.79 1,236.99 MWD+IFR-AK-CAZ-SC(3) 3,530.56 64.18 21445 2,939.87 2,784.96 -1,107.04 -1,020.81 5,936,80861 1,637,321.93 1.02 1,26748 MWD+IFR-AK-CAZ-SC(3) 713112017 11:06: f IAM Page 3 COMPASS 5000.14 Build 85 Company: Project: Site: Well: Wellbore: Design: Survey ConocoPhillips(Alaska) Inc.-Kup2 Kuparuk River Unit Kuparuk 2K Pad TD: 2K-30 2K-30 2K-30 ConocciPhillips Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well TO 2K-30 Rig: 39.21+115.70 @ 154.91 usft Rig: 39.21+115.70 Q 154.91 usft True Minimum Curvature OAKEDMP2 Map Map MD Inc Azl TVD TVDSS +N/ -S +E/ -W Northing Easting (usft) (1 (1) (usft) (usft) (usft) Wait) (ft) (ft) 3,562.23 6377 21504 2,953.77 2,796.86 -1,130.42 -1,037.03 5,936,785.23 1,637,305.71 3,568.44 63.71 21542 2.965.37 2,810.46 -1,149.62 -1,050.59 5,936,766.04 1,637,292.15 3,682.88 63.25 217.42 3807.54 2,852.63 -1,217.62 -1,100.76 5,936,698.06 1,637,241.97 3,777.58 6329 219.85 3,050.14 2,895.23 -1,283.68 -1,153.56 5,936,632.02 1,637,189.16 3,871.86 63.39 22103 3,092.44 2,93753 -1,347.80 -1,208.21 5,936,567.92 1,637,134.49 3,966.40 63.23 221.02 3,134.90 2,979.99 -1411.53 -1,26365 5,936,50422 1,637,07904 4,061.18 63.13 220.11 3,177.67 3,022.76 -1,475.78 -1,318.66 5,936,439.98 1,637,024.02 4,156.24 63.14 219.29 3,220.63 3,065.72 -1,541.03 -1,372.83 5,936,374.76 1,630969.84 4.251.42 63.14 217.57 3,263.63 3,108.72 -1,607.54 -1,425.60 5,936,308.27 1,63091705 4,34563 63.04 216.70 3.30627 3,151.36 -1674.51 -1,476.32 5,936,241.32 1,636,866.32 4,44003 63.08 215.49 3,349.04 3,194.13 -1,742.51 -1,525.89 5,936,173.34 1,636,81873 4,53489 63.17 214.38 3,391.92 3,237.01 -1,811,88 -1,574.35 5.936,10399 1,636,76826 4,629.80 63.20 215.09 3.434.74 3,279.83 -1.881.49 -1,622.61 5,936,03440 1,636.719.99 4,724.61 63.73 215.15 3,477.09 3.322.18 -1,950.87 -1,671.41 5,935965.04 1,636,671.18 4,818.94 63.71 214.31 3,518.86 3,363.95 -2,020.38 -1,719.59 5,935,895.55 1,636,62298 4,914.01 63.65 215.03 3,561.01 3,406.10 -2,09046 -1,768.06 5,935,825.49 1,636,574.49 5,00872 63.58 21574 3,603.10 3.448.19 -2,159.63 -1,817.19 5,935,756.34 1,635,525.34 5,103.44 63.59 21637 3,645.24 3,49033 -2,228.04 -1,867.36 5,935,687.95 1,636,475.16 5,198.28 63.60 217.55 3,687.42 3532.51 -2,295.74 -1,918.67 5,935,620.28 1,636,423.84 5,292.60 63.52 218.03 3,729.42 3,574,51 -2,362.48 -1,970.42 5,935,553.56 1,630372.08 5,387.77 63.74 217.29 3,771.69 3,61678 -2,429.98 -2,022.52 5,935,486.08 1.636,319.97 5,482.16 64.07 217.53 3,813.21 3,658.30 -2,497.31 -2.074.01 5,935,41837 1,636,26846 5,576.36 64.20 217.64 3,854.30 3,699.39 -2,564.48 -2,125.72 5,935.35162 1,636,216.74 5671.14 64.16 218.56 3,895.58 3,740.67 -2.631.62 -2,178.36 5,935,28,.50 1,630164.09 5,765.74 64.13 218.59 3,936.84 3,781.93 -2,696.17 -2,231.44 5.935,217,97 1,636,110.99 5,859.69 64.13 21841 3,977.83 3,822.92 -2,764.33 -2,284.07 5,935,15183 1,636,05835 5,954.87 64.13 218.46 4,019.36 3,864.45 -2,83141 -2,33730 5,935,084.77 1.6W,005 10 6,04936 64.19 217.64 4,06072 3,905.81 -2,898.67 -2,389.94 5,935,017.54 1,635,952.45 6,144.80 64.10 217.74 4,102.17 3.947.26 -2,966.35 -2,44223 5,934,94968 1,635,9W 15 6,239.23 64.17 217.77 4,14336 3,98845 -3,033.53 -2,494.26 5,934,882.72 1,635,848.11 6,333,84 64.14 218.60 4,184.61 4,02970 -3,10045 -2,546.89 5,931,815.81 1,635,795.46 6,427,61 64.14 218.31 4,225.51 4,070.60 -3,166.53 -2,599.37 5,934,74936 1,635,742.97 6,523.01 64.13 218.14 4,267.13 4,112.22 -3,233.97 -2,65248 5,934,682.34 1,635,689.84 6,617.65 64.17 21821 4,308.39 4,153.48 -3,300.92 -2,705.12 5,934,615.41 1,635,637.19 6,712.12 64.14 217.55 4,349.57 4,194.66 -3,368.03 -2,757.33 5,934.548.32 1,635,584.97 6,897.02 64.13 217.14 4,390.54 4,235.63 -3,435.20 -2,808.58 5,9U,481 17 1,635.533.70 6,901.12 64.15 216.98 4,43202 4,277.11 -3,50349 -2,860.16 5,93,41290 1,635,482.12 6,996.45 6365 216.54 4,473.96 4.319.05 -3,572.08 -2,911.39 5,934,344.34 1,635,430.87 7,090.43 63.63 215.99 4,515.69 4,360.78 -3,639.97 -2,961.20 5,934,276.46 1,635,381.05 7,185.98 63.67 217.13 4,558.10 4,403.19 -3,70874 -3,012.20 5,93,207.71 1,635,330.03 7M2017 11:06: 1fAM Page 4 COMPASS 5000.14 Build 85 Vertical DLS Section (.1100') (ft) Survey Toot Name 2.12 1,293.33 MWD+IFR-AK-CAZ-SC(3) 1.32 1,314.59 MWD+IFR-AK-CAZ-SC (3) 1.96 1,390.26 MWDHFR-AK-CAZ-SC(3) 2.29 1,464.49 MWD+IFR-AK-CAZ-SC (3) 1.12 1,537.13 MWD+IFR-AK-CAZ-SC (3) 0.17 1,609.51 MWD+IFR-AK-CAZ-SC(3) 0.86 1,682.34 MWD+IFR-AK-CAZ-SC(3) 0.77 1.756.00 MWD+IFR-AK-CAZ-SC(3) 1.61 1,83067 MWDHFR-AK-CAZ-SC(3) 0.83 1,90543 MWD+IFR-AK-CAZ-SC(3) 1.14 1981.01 MWD+IFR-AK-CAZ-SC(3) 1.05 2,05773 MWD+IFR-AK-CAZ-SC(3) 0.67 2,13467 MWD+IFR-AK-CAZ-SC(3) 0.56 2,211.47 MWD+IFR-AK-CAZ-SC(3) 0.80 2,288.29 MWD+IFR-AK-CAZ-SC (3) 0.68 2,365.72 MWD+IFR-AK-CAZ-SC (3) 068 2,442.38 MWD+IFR-AK-CAZ-SC(3) 0.97 2,518.45 MWD+IFR-AK-CAZ-SC(3) 0.74 2,594.03 MWD+IFR-AK-CAZ-SC(3) 0.46 2,66874 MWD+IFR-AK-CAZ-SC 13) 073 2,744.27 MWD+IFR-AK-CAZ-SC(3) 0.42 2,819.52 MWD+IFR-AK-CAZ-SC(3) 0.17 2,894.65 MWD+IFR-AK-CAZ-SC(3) 0.87 2,969.91 MWD+IFR-AK-CAZ-SC(3) 0.04 3,044.67 MWD+IFR-AK-CAZ-SC(3) 0.17 3,118.96 MWD+IFR-AK-CAZ-SC(3) 0.05 3,194.27 MWDHFR-AK-CAZ-SC(3) 078 3,269.64 MWD+IFR-AK-CAZ-SC(3) 0.13 3,345.37 MWD+IFR-AK-CAZ-SC (3) 0.08 3420.56 MWD+IFR-AK-CAZ-SC(3) 079 3,495.61 MWD+IFR-AK-CAZ-SC(3) 0.28 3,569.80 MWD+IFR-AK-CAZ-SC(3) 0.16 3,64544 MWD+IFR-AK-CAZ-SC(3) 0.08 3,720.51 MWD+IFR-AK-CAZ-SC(3) 0.63 3,795.67 MWD+IFR-AK-CAZ-SC(3) 0.39 3,870.72 MWD+IFR-AK-CAZ-SC(3) 0.15 3,946.93 MWD+IFR-AK-CAZ.SC(31 0.67 4,023.37 MWDHFR-AK-CAZ-SC(3) 0.52 4,09888 MWD+IFR-AK-CAZ-SC(3) 107 4,175.46 MWD+IFR-AK-CAZ-SC(3) 7M2017 11:06: 1fAM Page 4 COMPASS 5000.14 Build 85 Company: ConowPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 21K Pad Wait: TD: 2K-30 Wellbore: 2K-30 Design: 2K-30 Survey Conocolohillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well TD: 2K-30 Rig: 39.21+115.70 @ 154.91 usft Rig: 39.21+115.70 @ 154.91 usft True Minimum Curvature OAKEDMP2 7/312017 11:06.11AM Page 5 COMPASS 5000,14 Build 95 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (") V) (usft) (usft) (usft) (usftl (ft) (ft) ('/100') (ft) Survey Tool Name 7,281.17 63.56 21727 4,600.40 4,445.49 -3,776.67 -3,06376 5,934,13981 1,635,278.46 0.18 4,251.31 MWD+IFR-AK-CAZ-SC(3) 7,375.86 63.46 216.67 4,642.64 4,487.73 -3.844.38 -3,114.73 5,934,072.12 1,635,227.48 0.58 4,326.84 MW0+IFR-AK-CAZ-SC(3) 7,470.85 6360 216.56 4,684.96 4,530.07 -3,912.63 -3,16544 5,934,003.89 1,635,176.75 0.18 4,402.86 MWD+IFR-AK-CAZ-SC(3) 7,565.07 6363 216.04 4,726.85 4,571.94 -3,98065 -3.215.41 5,933,935.86 1,635,126.77 0.50 4,478.53 MWD+IFR-AK-CAZ-SC(3) 7,659.80 63.66 216.56 4,768.90 4,613.99 -4.049.06 -3,265.66 5,933,867.49 1,635,076.50 0.49 4,55463 MWD+iFR-AK-CAZ-SC (3) 7754.18 63.56 216.71 4,810.85 4,65594 -4,116.91 -3,316.11 5,933,79867 1,635.026.04 0.18 4,630.20 MWD+IFR-AK-CAZ-SC(3) 7.849.45 6363 217.86 4,853.22 4,698.31 4184.80 -3,367.80 5,933,731.80 1,634,974.34 1.08 4,706.03 MWDNFR-AK-CAZ-SC(3) 7.94388 63.79 218.57 4.89504 4.740.13 -4,251.31 -3,420.18 5,933,665.31 1.634,921.95 0,70 4,78063 MWD+IFR-AK-CAZ-SC(3) 8,03865 6375 219.17 4,936.93 4,782.02 -4,317 50 -3,473.52 5.933.599.14 1,634,868.59 0.57 4,855.08 MWD+IFR-AK-CAZ-SC(3) 8134.59 6376 219.35 4,979.36 4.824.45 -0,384.13 -3,527.98 5,933,532.54 1,6U,814 12 0.17 4,930.15 MWD+IFR-AK-CAZ-SC(3) 8,227.86 63.79 219.89 5,020.57 4,86566 -4,448.58 -3,581.33 5,933,468.11 1,634.760.75 0.52 5,002.89 MWD+1FR-AK-CAZ-5C (3) 8,320.13 63.75 21975 5,061.35 4,906.44 -4,512.15 -3,634.34 5,933,40455 1,634,707,74 0.14 5,074.70 MWD+IFR-AK-CAZ-SC(3) 6,417.50 64.13 219.05 5,104.13 4,949.22 -4,57934 -3,689.86 5,933,336.99 1,634,652.20 015 5,150.90 MWD+IFR-AK-CAZ-K(3) 8,511.81 64.16 219.31 5,14526 4,990.35 4,645.53 -3,743.47 5,933,271.22 1,63,598.57 0.25 5,225.00 MWD+IFR-AK-CAZ-SC(3) 8,607.16 64.26 217.66 5,18874 5,031.83 -4,712.73 -3,796.90 5,933.2D4 04 1,634,545.14 156 5,300.46 MM+IFR-AK-CAZ-SC(3) 8,701.77 64.23 216.93 5,227.86 5,072.95 4780.52 -3,848.53 5,933,136.28 1,63,493.49 0.70 5,376.18 MWD+IFR-AK-CAZ-SC(3) 6,796.53 6420 216.46 5,269.08 5,114.17 -4,848.93 -3.899.52 5,933,067.88 1,63,44249 0.45 5,452.41 MWD+IFR-AK-CAZ-SC(3) 8,890.47 6381 217.42 5,310.25 5,155.34 -4,916.42 -3,950.26 5,933,00042 1,634.39114 1.01 5,52768 MWD+IFR-AK-CAZ-SC(3) 8,985.13 63.75 217.33 5,352.07 5,197.16 -4,983.90 -,001.81 5,932,932.95 1,634,340.17 0.11 5,603.09 MWD+IFR-AK-CAZ-SC(3) 9,080.57 63.59 217.72 5,394.40 5,239.49 -5,051.74 -4,053.91 5,932,865.13 1,634,288.06 040 5,678.95 MWD+IFR-AK-CAZ-SC(3) 9,175.69 63.60 21713 5,436.71 5,281.80 -5,119.40 4,105.68 5.932,79]50 1,634,23627 0.56 5,754.57 MWD+IFR-AK-CAZ-SC(3) 9,26940 63.69 216.13 5,478.31 5,323.40 -5,186.78 -0,155.78 5,932,730.13 1634,186.16 0.96 5,829.63 MWD+IFR-AK-CAZ-SC(3) 9,354.66 Wall 216.59 5,520.53 5,365.62 -5,255.55 -4,206.41 5,932,661.39 1,63,135.52 043 5,906.14 MWD+IFR-AK-CAZ.SC(3) 9,458.68 63.65 21567 5,56223 5,407:32 -5,323.61 -4,256.09 5,932,593.35 1,63,08582 0.88 5.981.80 MWD+IFR-AK-CAZ-SC(3) 9,554.10 63.62 215.69 5,604.61 5,449.70 -5,393.06 4,305.96 5,932,523.92 1,634,035.94 0.04 6,058.85 MWD+IFR-AK-CAZ-SC 13) 9,648.82 63.79 216.66 5,648.57 5,491.66 -5,461.52 -4,356.20 5,932,45548 1,633,98568 1.12 6,134.99 MWD+IFR-AK-CAZ-SC(3) 9,742.94 63.57 217.15 5,688.30 5,533.39 -5,528.89 -4,406.98 5,932,388.13 1,633,934.89 0.36 6,210.15 MWDNFR-AK-CAZ-SC(3) 9,837.50 63.69 217.14 5,730.30 5,575.39 -5,596.42 4,458.13 5,932,320.62 1,633,883.72 0.13 6,285.54 MWD+1FR-AK-CAZ-SC (3) 9,932.26 63.76 217.29 5,77225 5,617.34 -5,664.08 -4,509.52 5,932,252.98 1,633,832.32 0.16 6,361.1D MWD+IFR-AK-CAZ-SC(3) 10,026.87 63.72 217.63 5,814.11 5,659.20 -5,73143 -4,561.13 5,932,185.65 1,633,780.70 0.33 6,436.39 MWD+IFR-AK-CAZ-SC(3) 10,121.55 6425 217.96 5,855.63 5,700.72 -5,798.67 4,613.27 5,932,11844 1,633)28.55 0.64 6,51166 MWD+IFR-AK-CAZ-SC(3) 10,215.59 64.22 218.16 5,896.51 5,741.60 -5,865.35 4,66548 5,932,051.77 1,633,676.32 0.19 6,586.40 MWD+IFR-AK-CAZ-SC(3) 10,310.48 64.10 218.12 5,937.87 5,782.96 -5,932.52 -4,718.23 5,931,984.63 1,633,623.57 0.13 6,661.70 MWD+IFR-AK-CAZ-SC(3) 10,405.54 64.17 217.91 5,979.34 5,824.43 -5.999.91 4,770.91 5,931,91726 1,633,570.87 0.21 6,737.22 MWD+IFR-AK-CAZ-SC(3) 10,500.05 64.08 21749 6,020.59 5,86568 -6,067.20 4,822.91 5.931,849.99 1,633,518.85 041 6,812.52 MWD+IFR-AK-CAZ-SC(3) 10.594.59 64.04 217.08 6,061.94 5,907.03 -6,13483 -4,874.41 5,931,782.38 1,633,467.34 0.39 6,888.06 MWD+IFR-AK-CAZ-SC(3) 10,689.57 65.39 213.97 6,102.52 5,947.61 -6,204.72 -4,924.29 5,931,712.51 1,833,417.45 3.28 6,965.55 MWD+IFR-AK-CAZ-SC(3) 10,784.33 0610 210.06 6,140.24 5,985.33 -6,278.42 -4,970.34 5,931,638.83 1,633,371.38 4.50 7,046.13 MWD+IFR-AK-CAZ-SC (3) 10.878.91 70.56 207.52 6,173.94 6,019.03 -6,355.87 -5,012.87 5,931,561.40 1,633,328.83 3.93 7,129.78 MWD+IFR-AK-CAZ-SC(3) 10,973.90 71.99 206.17 6,20443 6,049.52 -6,436.13 -5,053.49 5,931,481.16 1,633,288.19 2.02 7,215.88 MWD+IFR-AK-CAZ-SC(3) 7/312017 11:06.11AM Page 5 COMPASS 5000,14 Build 95 Company: Project: Site: Well: Wellbore: Design: Survey ConocoPhillips(Alaska) Inc.-Kup2 Kuparuk River Unit Kuparuk 2K Pad TD: 2K-30 2K-30 2K-30 MD Inc Azi (usft) P) P) 11,068.38 73.05 205.76 11,162 71 74.48 204.43 11.257.76 76.17 202.10 11352.90 77.60 199.83 11,447.14 7972 196.48 11641.32 82.41 19278 11,635.23 8560 189.67 11,731.71 W76 18864 11,825.93 86.63 188.89 11.900.27 86.30 18980 11,957.00 86.35 189.36 7-6/8" x 9-718 by 11" 11,995.32 86.39 189.07 12,090.15 8714 188.70 12,183.50 88.12 187.11 12,237.93 87.98 186.81 12,279.32 88.08 188.14 12,325.04 87.98 189.58 12,373.86 88.22 189.52 12.422.85 87.87 190.50 12,469.52 88.15 190.37 12,564.19 88.60 19105 12,658.55 88.56 191.20 12,753.14 8824 192.20 12,846.93 89.08 19229 12,941.92 89.08 192.27 13,036.43 8946 192.62 13,131.31 89.46 193.24 13,225.89 90.07 193.14 13, 320.11 90.45 193.34 13,41577 90.55 192.24 13,511.00 89.94 192.27 13,604.89 69.49 19147 13,698.80 89.59 190.74 13,793.58 89.32 189.78 13,888.15 88.77 191.02 13,983.70 88.43 190.21 14,07943 87.88 190.91 14,172.73 88.06 190.52 14,268.99 86.54 190.79 14,364.20 85.53 191.36 TVD (usft) 6,232.81 6,259.19 6,283.27 6,304.86 6,323.39 6,338.02 6,34783 6,35426 6,359.69 6.364.28 6,36791 6,370.33 6,375.19 6,378.56 6,38041 6,381 84 6,383.41 6,385.03 6,386.70 6,368.32 6,391.00 6,393.34 6,395.98 6,398.18 6,399.70 6,400.91 6,401.80 6,402.19 6,401 76 6,400.93 6,400.52 6,400.99 6,401.74 6,402.64 6,404.22 6,406.55 6,409.60 6,412.94 6,417.48 6,424.06 TVDSS (usft) 6,077.90 6,104.28 6,12936 6,149.95 6,168.48 6,183.11 6,192.92 6,199.35 6,204 78 6.209.37 6,213.00 6,215.42 6,220.28 6,22365 6,225.50 6,226.93 6,228.50 6,230.12 6,231.79 6,23141 6,236.09 6,238.43 6,241.07 6,243.27 6,244.79 6,246.00 6,246.89 6,247.28 5,246.85 6,248.02 6,245.61 6,246.08 6,246.83 6,247.73 6,249.31 6,251.64 6,254.69 6,258.03 6,262.57 6,269.15 ConocoPhillips Definitive Survey Report +N/ -S (usft) -6,517.15 -6,599.17 -6,683.63 -6,770.15 -6,857.94 -6,94].93 -7,039.52 -7,134.56 -7,227.52 -7.300.74 -7,356.56 -7.394.31 -7,48] 88 -7,580.28 -7,634.27 -7,675.29 -7,720.43 -7,768.55 -7,816.76 -7,86264 -7,955.62 -8,048.18 -8,140.76 -8,232.39 -8,325.20 -6,417.46 -8,509.95 -8,60203 -8,693.75 -8,787.03 -8,880.D9 -8,971.97 -9,064.12 -9,157.38 -9,250.38 -9,344.26 -9,437.34 -9,529.94 -9,624.43 -9,71764 Local Co-ordinate Reference: Well TD: 2K-30 TVD Reference: Rig: 39,21+115.70 Qc 154.91 usft MD Reference: Rig: 39.21+115.70 @ 154.91usft North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 Map Map +E/ -W Northing Easting (usft) (ft) (ft) (°/ -5,092.95 5,931,400.16 1,633,248.72 -5,131.35 5,931,318.16 1,633,210.30 -5,167.66 5,931,23371 1,633,17397 -5,200.81 5,931,147.21 1,633.140.80 -5,229.58 5,931,05944 1,633,112.01 -5,253.06 5,930,969.46 1,633,08850 -5,27123 5.930,877.89 1,633,070.31 -5,286.55 5,930,782.86 1,633,054.97 -5,300.88 5.930,68991 1,633,040.61 -5,312.93 5,930.616.71 1.633.028.55 5,322.35 5,930.560.90 1,633,019.11 -5,32848 5,930,523.15 1,633,012.97 -5,343.10 5,930,42960 1,632,998.32 -5,355.93 5,930,33721 1,632,98547 -5,362.53 5,930,283.22 1,632,978.86 -5.367.91 5,930,242 21 1,632,973 47 -5,374.94 5,930,197.07 1,632,966.42 -5,383.04 5.930,148.96 1,632,958.31 -5,391.55 5,930,100.76 1632,949.79 -5,400.00 5,930,054.89 1,632,941.33 -5,417.58 5,929,961.92 1,632,923.72 -5,435.79 5,929,869:38 1,632,905.50 -5,454.% 5,929,77861 1.632,886.30 -5474.85 5,929,685.19 1632,866.39 -5,495.05 5,929,592.40 1,632,846.16 -5,51541 5,929,500.13 1,632,825 78 -5,536.64 5,929,407.68 1,632,804.52 -5,558.22 5,929,315.61 1,632,782.92 -5,579.80 5,929,223.91 1,632,761.32 -5,600.98 5,929,130.65 1,632,740.12 -5,621.19 5,929,037.60 1,632,719.88 -5.640.50 5,928,945.74 1,632,700.55 -5,658.59 5,928,85360 1,632,682.43 -5,675.47 5,928,760.36 1,632,665.53 -5,692.54 5,928,667.37 1,632,64844 -5,710.13 5,928,57350 1.632,630 82 -5,727.49 5,928,480.44 1,632,613.44 -5,745.01 5,928,387.85 1,632,595.90 -5,762.79 5,928,293.37 1,632,57809 -5,781.03 5.928200.18 1632,559.83 OLS Vertical Section 100') (ft) Survey Tool Name 1.20 7,302.52 MWD+IFR-AK-CAZ-SC(3) 2.03 7,389.96 MWD+IFR-AK-CAZ-SC(3) 2.96 7,479.45 MWD+IFR-AK-CAZ-SC (3) 2.77 7,57041 MWD+IFR-AK-CAZ-SC (3) 4.15 7,661.85 MWD+IFR-AK-CAZ-SC(3) 4.82 7,754.56 MWD+IFR-AK-CAZ-SC(3) 413 7,84].92 MWD+IFR-AK-CAZ-SC(3) 1,61 7,944.17 MWD+IFR-AK-CAZ-SC(3) 0.30 8,038.21 MWD+IFR-AK-CAZ-SC(3) 1,30 8,112.40 MWD+IFR-AK-CAZ-SC (3) 0.77 8,169.0180 /tChli)$IIN6y 017 8,207.25 MWD+IFR-AK-CAZ-SC(4) 1.48 8,301.94 MWD+IFR-AK-CAZ-SC(4) 115 8,395.16 MWD+IFR-AK-CAZ-SC(4) 0.61 8,449.48 MWD+IFR-AK-CAZ-SC(4) 3.22 8,490.81 MWD+IFR-AK-CAZ-SC (4) 3.16 8,536.49 MWD+IFR-AK-CAZ-SC(4) 0.51 8,58528 MWD+IFR-AK-CAZ-SC(4) 2.12 8,634.24 MWD+IFR-AK-CAZ-SC(4) 0.66 8,680.88 MWD+IFR-AK-CAZ-SG(4) Des 8,775.51 MWD+IFR-AK-CAZ-SC(4) 0.16 8,869.82 MWD+IFR-AK-CAZ-SC (4) 1.11 8,964.33 MWD+IFR-AK-CAZ-SC(4) 0.90 9,058.02 MWD+IFR-AK-CAZSC(4) 0.02 9,152.92 MWD+IFR-AK-CAZ-SC(4) 055 9,247.34 MWD+IFR-AK-CAZ-SC(4) 0.65 9,342.09 MWDNFR-AK-CAZ-SC(4) 0.65 9436.52 MWD+IFR-AK-CAZ-SC(4) 0.46 9,530.59 MWD+IFR-AK-CAZ-SG (4) 1.15 9,626.13 MWD+IFR-AK-CAZ-SC(4) 0.64 9,721.29 MWD+IFR-AK-CAZ-SC (4) 0.98 9,815.13 MWD+IFR-AK-CAZ-SC(4) 018 9,909.02 MWD+IFR-AK-CAZ-SC(4) 105 10,0379 MWD+IFR-AK-CAZ-SC(4) 1.43 10,098.34 MWD+IFR-AK-CAZ-SC(4) 0.92 10.193.86 MWD+IFR-AK-CAZ-SC(4) 0.94 10,288.53 MWD+IFR-AK-CAZ-SC (4) 0.46 10,38277 MWD+IFR-AK-CAZ-SC(4) 1.60 10,478.91 MWD+IFR-AK-CAZ-SC(4) 1.22 10,573.87 MWD+IFR-AK-CAZ-SC (4) 71312017 11:06.11AM Page 6 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: TD: 2K-30 Wellbore: 2K-30 Design: 2K-30 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: Well To 21K-30 TVD Reference: Rig: 39.21+115.70 @ 154.9lusft MD Reference: Rig: 39.21+115.70 @ 154.9lusft North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 Map Map MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting (usft) 0 V) Wait) (usft) (usft) (usft) (ft) (ft) 14,459.03 8571 190.92 6,431.30 6,276.39 -9,810.41 -5,799.30 5,928,10742 1,632,541.53 14,553.98 85.96 19065 6,438.20 6,283.29 -9,90344 -5,81702 5,928,014.41 1,632,52379 14,648.66 88.79 188.68 6,442.53 6,28762 -9,99666 -5.832.89 5,927,921:20 1,632,507.89 14,743 38 89.35 187.18 6,444.07 6,289.16 -10,090.46 -5,845.96 5,927,827.41 1,632,494.80 14,838.07 89.32 187.69 6.445.17 6,290.26 -10,184.35 -5858.21 5,927,73354 1,632,482.52 14,93324 89.59 188.60 6,446.08 6,291.17 -10278.55 -5,871.69 5,927,639.35 1,632,46902 15,027.73 89.97 186.85 6,446.44 6,291.53 -10,372.18 -5,884.39 5,927,545.73 1,632,456.29 15,122.21 89.73 187.13 6,446.69 6,29138 -10,465.96 -5,895.89 5,927,451.97 1,632,44477 15,217.07 89.28 186.91 6,447.51 6,292.60 -10,560.10 -5,90749 5,927,357.83 1,632.433.15 15,31203 89.35 187.13 6,44864 6,293.73 -10654.34 -5,919.09 5,927,263.60 1,63242152 15,406.97 88.77 189.12 6,450.20 6,29529 -10,748.31 -5,932.51 5.927,169.65 1,632,408.08 15,500.56 8860 190.87 6,452.35 6,297.44 -10,84046 -5,948.74 5,927,077.52 1,632,391.82 15,59641 88.39 190.49 6,454.86 6,299.95 -10.93461 -5,966.50 5,926,983.38 1,632,374.04 15,691.44 88.53 190.38 6,45742 6,302.51 -11,02804 -5,983.71 5,926,889.97 1,632,356.81 15,785.53 88.72 191.19 6,45968 6,30477 -11,12044 6,001.31 5,926,797.58 1,632,339,18 15,880.86 90.45 191.58 6,460.37 6,305.46 -11,213.89 6,020.13 5,926,704.15 1,632,320.34 15,97592 9168 19163 6,458.60 6,303.69 -11,306.98 -6,039.24 5,926,611.05 1,632,301.20 16,071.58 91.92 19292 6,455.60 6,300.69 -11,40041 -6,059.57 5,926,517.65 1,632.280.85 16,164.51 9221 192.40 6,452.25 6,297.34 -11,49102 -6,079.93 5,926,427.06 1,632,26047 16,259.29 90.74 192.13 6,449.81 6,294.90 -11,58360 6,100.05 5,926,334.49 1632,24032 16,353.36 91.17 191.73 6,448.24 6,293.33 -11,675.63 6,119.50 5,926,24248 1,632,220.86 16,449.19 90.26 192.13 6,447.03 6,292.12 -11769.38 -6,13930 5,926.14674 1,632.201.02 16,544.15 89.70 191.98 6,447.04 6,292.13 -11,86225 -6,159.14 5,926,055.89 1632,181.17 16,639.14 89.39 190.58 6447.80 6,292.89 -11955.40 6,17772 5,925,962.75 1,632,162.57 16,734.10 89.35 1W,74 6,448.84 6,293.93 -12,048.71 6,195.28 5,925,869.45 1,632,144.98 16,82891 89.22 191.04 6,450.02 6,295.11 -12,141.81 -6,213.19 5,925,77637 1,632,127.04 16,923.25 88.84 189.41 6451.62 6,296.71 -12,23463 -6.229.93 5,925.683.56 1,632,11028 17,01829 88.80 187.96 6.453.58 6,298.67 -12,328.58 -6,244.28 5,925,589.65 1,632,09590 17,113.24 8867 187.09 6,45588 6,300.77 -12,422.67 -6,256.71 5,925,495.55 1,63208345 17,208.22 88.70 186.52 6,457.86 6,302.95 -12,516.95 6,267.96 5.925,401.28 1,632072.17 17,302.95 88.32 184.68 6,460.32 6,305.41 -12,61120 6,277.21 5,925,30705 1,632,062.91 17,397.85 88.32 184.42 6,463.10 6,308.19 -12,70576 -6,284.73 5,925,21250 1,632,055.35 17,492.51 88.94 184.08 6,465.36 6,310.45 -12,800.13 -6,29174 5,925,118.14 1,632.048.32 17,587.37 88.94 183.96 6,467.12 6,312.21 -12,89414 6,298.39 5,925,023.54 1,632,04164 17,682.31 89.57 184.89 6,468.35 6,31344 -12.969.39 6,305]2 5,924,928.90 1,632,034.29 17,776.61 88.76 185.75 6.469.73 6,314.82 -13,083.27 6,31446 5,924,83503 1,632,025.53 17,87143 89.15 187.18 6,471.46 6,316.55 -13,177.47 -6,325.13 5,924,74085 1,632,014.83 17,966.66 89.15 191.49 6,472.87 6,317.96 -13,271.40 -6,340.57 5,924,646.92 1,631,999.36 18.060.97 87.98 194.41 6,475.23 6,320.32 -13,363.27 -6,361.70 5,924,555.07 1,631,978.21 18,15490 87.71 19399 6,47876 6,323.85 -13,45427 6,384.73 5,924,46409 1,631,955.16 Vertical DLS Section (°1100') (ft) Survey Tool Name 0.50 10,668.41 MWD+IFR-AK-CAZ-SC(4) 0.39 10,763.10 MWD+IFR-AK-CAZ-SC (4) 364 10,857.66 Mv0+IFR-AK-CAZ-SC(4) 169 10,95230 MWD+IFR-AK-CAZ-SC(4) 0.54 11,046.89 MWD+IFR-AK-CAZ-SC(4) 1.00 11,142.01 MWD+IFR-AK-CAZ-$C (4) 1.90 11,23642 MWD+IFR-AK-CAZ-SC(4) 0.39 11,33017 MWD+IFR-AK-CAZ-SC(4) 0.53 11,425.50 MWD+IFR-AK-CAZ-SC(4) 0.24 11,520.32 MWD+IFR-AK-CAZ-SC(4) 2.18 11,615.19 MWD+IFR-AK-CAZ-SC (4) 1.88 11,708.75 MWD+IFR-AK-CAZ-$C(4) 045 11804.56 MWD+IFR-AK-CAZ-SC(4) 0.19 11,699.56 MWD+IFR-AK-CAZ-SC (4) 0.88 11,993.61 MWD+IFR-AK-CAZ-SC (4) 1.86 12,088.91 MWD+IFR-AK-CAZ-SC (4) 1.29 12,183.91 MWD+IFR-AK-CAZ-SC(4) 1.37 12,279.45 MWD+IFR-AK-CAZ-SC(4) 0.64 12.372.21 MWD+IFR-AK-CAZ-SC(4) 1.58 12,466.89 MWD+IFR-AK-CAZ-SC (4) 062 12,560.89 MWD+IFR-AK-CAZ-SC 14) 1.02 12,656.66 MWD+IFR-AK-CAZ-SC(4) 0.63 12.751.55 MWD+IFR-AK-CAZ-SC(4) 1.51 12,846.52 MWD+IFR-AK-CAZ-SC (4) 0.17 12,94146 MWD+IFR-AK-CAZ-SC (4) 0.34 13,036.25 MWD+IFR-AK-CAZ-SC 14) 1.77 13,130.58 MWD+IFR-AK-CAZ-SC(4) 1.53 13.225.57 MWD+IFR-AK-CAZ-SC(4) 0.93 13,320.41 MWD+IFR-AK-CAZ-SC (4) 0.60 13,415.21 MWD+IFR-AK-CAZ-SC(4) 1.98 13,509.63 MWD+IFR-AK-CAZ-SC(4) 0.27 13,604.06 MWD+IFR-AK-CAZ-SC(4) 0,75 13,698.21 MWD+IFR-AK-CAZ-SC(4) 0.13 13,792.54 MWD+IFR-AK-CAZ-SC (4) 1.18 13,887.02 MWD+IFR-AK-CAZ-SC(4) 1.25 13,981.00 MWD+IFR-AK-CAZ-SC(4) 1.56 14,075.62 MWD+IFR-AK-CAZ-SC(4) 4.53 14,170,81 MWD+IFR-AK-CAZ-SC (4) 3.33 14,264.95 MWD+IFR-AK-CAZ-SC (4) 0.53 14,358.56 MWD+IFR-AK-CAZ-SC (4) 7/312017 11:06: 1fAM Page 7 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: TD: 2K-30 Wellborn: 2K-30 Design: 2K-30 Survey ConocoPhillips Definitive Survey Report Local Go -ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well TD: 2K-30 Rig: 39.21+115.70 @ 154.91 usft Rig: 39.21+115.70 @ 154.91 usft True Minimum Curvature OAKEDMP2 Map Map Vertical MD Inc Azi TVD TVDSS +NAS +E1 -W Northing Easting DLS Section (usft) 11 (1 (usft) (usft) (usft) (usft) (ft) (ft) (°I100-) (ft) Survey Tool Name 18,250.59 87.91 194.25 6,482.42 6.327.51 -13,547.00 -6,408.05 5,924,371.37 1,631,931.81 0.34 14,453.94 MWD+IFR-AK-CAZ-SC(4) 18,344.87 88.32 194.42 6,485.52 6,330.61 -13,638.29 -6,431.38 5,924,280.09 1,631,908.46 0.47 14,547.90 MWD+IFR-AK-CAZ-8C(4) 18.437.84 88.39 193.72 6,486.19 6,333.28 -13,728.44 6,453.97 5,924,189.97 1,631,88585 0,76 14,640.59 MWD+IFR-AK-CAZ-SC(4) 18.535.15 88.83 189.82 6,490.55 6,335.64 -13,823.66 -6,473.81 5,924,09476 1.631,86596 403 14,737.81 MWD+IFR-AK-CAZ-SC(4) 18,629.99 90.40 18847 6.491.19 6,336.28 -13,917.28 -6,488.89 5,924,001.15 1,631,85089 2.18 14,832.63 MWD+IFR-AK-CAZ-SC(4) 18,723.51 89.94 18728 6490.91 6,336.00 -14,009.92 -6,501.70 5,923,908.53 1,631,838.05 1.35 14,926.08 MWD+IFR-AK-CAZ-SC(4) 18,819.59 90,w 186.01 6,490.93 6,336.02 -14,105.35 -6512.82 5,923,813.11 1,631,626.91 1.33 15,022.00 MWD+IFR-AK-CAZ-SC(4) 18.914.52 90.04 184.42 6,49086 6.335.95 -14,199.89 -6,521.45 5,923,718.58 1,631,81825 1.67 15,116.59 MWD+IFR-AK-CAZ-SC(4) 19,009.16 90.45 18329 6,49D.46 6,335.55 -14,294.31 -6,527.81 5,923,624.17 1,631,811.86 1.27 15,210.69 MWD+IFR-AK-CAZ-SC(4) 19,104.10 91.27 182.18 6.489.03 6,334.12 -14,389.13 6,532.34 5,923,529.36 1631,807.31 1.45 15,30485 MWD+IFR-AK-CAZ-SC(4) 19,198.69 91.75 18042 6.486.54 6,331.63 -14,483.66 6,534.48 5,923,43485 1,631,805.14 1.93 15,398.32 MWD+IFR-AK-CAZ-SC(4) 19,293.16 91.79 180.43 6,483.62 6,328.71 -14,578.08 -6.535.18 5,923,340.43 1,631,80441 0.04 15,49143 MWD+IFR-AK-CAZ-SC(4) 19,383.02 92.44 179.93 6,480.31 6,325.40 -14,667.88 -6,535.47 5,923,250.64 1,631,804.10 0.91 15,579.91 MWD+IFR-AK-CAZ-SC(4) 19.482.30 92.37 180.69 6,476.14 6,321.23 -14,767.07 -6,536.00 5.923,151.46 1,63180354 0.77 15,677.69 MWD+IFR-AK-CAZ-SC(4) 19,577.95 91.40 183.30 6,472.99 6,318.08 -14,862.60 6,539.33 5.923,055.94 1,631,800.19 2.91 15,772.34 MWD+IFR-AK-CAZ-SC (4) 19,672.50 9161 18856 6,470.51 6,315.60 -14,956.83 -654663 5,922.961.73 1,631,792.86 240 15,86641 MM+IFR-AK-CAZ-SC(4) 19,767.26 $9.08 182.23 6,46994 6.315.03 -15,051.34 6,553.07 5,922,867.22 1,631]8640 4.41 15,96061 MWD+IFR-AK-CAZ-SC(4) 19,86102 8997 180.09 6,470.72 6,315.81 -15.145.08 -6,554.96 5922773.50 1.631,7846B 247 16,053.25 MWD+IFR-AK-CAZ-SC(4) 19,956.38 90.11 180.02 6,47065 6,315.74 -15,240.44 -6,555.05 5.922 678,15 1,631,784.36 0.16 16,147.17 MWD+IFR-AK-CAZ-SC(4) 20,051.06 89.71 18149 6,470.80 6,315.89 -15,335.10 6,556.30 5,922,583.49 1,631,783.09 161 16,240.62 MWD+IFR-AK-CAZ-SC (4) 20,145.86 91.17 184.09 6,470.07 6,315.16 -15,429.78 6,560.92 5,922,48882 1,631,778.45 3.15 16,334.66 MWD+IFR-AK-CAZ-SC(4) 20,240.65 92.58 185.27 6.466.97 6,312.05 -15,524.20 6,568.64 5,922,394.42 1,631,770.69 1.94 16,428.98 MW0+IFR-AK-CAZ-SC(4) 20,33601 92.89 184.28 6,462.47 6,30756 -15,618.12 -6,576.49 5,922,300.50 1,631,762.82 1.10 16,522.84 MWD+IFR-AK-CAZ-SC(4) 20,430.24 93.33 184.24 6,457.30 6,302.39 -15.712.95 -6,583.55 5.922 205.69 1,631,755.73 0.46 16,617.46 MWD+IFR-AK-CAZ-SC (4) 20,525.01 93.78 18408 6,451.42 6,296.51 -15,807.29 -6,590.42 5,922,111.36 1.631.748.85 0.50 16,711,55 MWD+IFR-AK-CAZ-SC(4) 20,619.43 93.57 183.55 6,445.37 6,290.46 -15,901.30 6,596.69 5,922,017.36 1,631,742.55 0.60 16,805.23 MWD+1FR-AK-CAZ-SC 14) 20,714.35 92.40 183.12 6,440.43 6,285.52 -15,995.93 6,602.20 5,921,92274 1,631,737.01 1.31 16,89938 MWD+IFR-AK-CAZ-SC(4) 20,808.73 91.17 18342 6,437.49 6,282.58 -16,090.11 -6,607.58 5,921,82857 1,631,731.61 1.34 16,993.06 MWD+IFR-AK-CAZ-SC(4) 20,903.24 89.% 183.31 6,436.56 6,281.65 46,184.45 -6,613.13 5,921,734.24 163172603 1.29 17,086.93 MWD+IFR-AK-CAZ-SC(4) 20,99663 89.79 181.13 6436.76 6,281.85 -16,27777 -6,616.74 5,921,640.94 1,631,722.39 2.34 17179.46 MWD+IFR-AK-CAZ-$C(4) 21,09149 90.93 182.84 6,435.16 6,281.25 -16.372.56 6,620.03 5,921,546.15 1,631.719.08 2.17 17,273.38 MWD+IFR-AK-CAZ-SC 14) 21.186.22 91.22 183.12 6,434.39 6,279.48 -16,467.15 6,624.95 5,921.451.56 1,631,714 13 043 17,367.39 MWD+IFR-AK-CAZ-SC(4) 21,281.24 8980 18228 6,433.54 6,278.63 -16,562.05 6,629.43 5,921,356.68 1,631,709.63 174 17,46163 MWD+IFR-AK-CAZ-SC(4) 21,37562 88.92 180.69 6,43460 6,279.69 -16,656.39 -6,631.88 5,921,262.35 1,631,707.16 1.93 17,55496 MWD+IFR-AK-CAZ-SG(4) 21,470.97 90.68 183.38 6,434.93 6,28002 -16.751.67 -6,635.26 5,921,167.09 1,631,703.75 3.37 17,649.38 MWD+IFR-AK-CAZ-SC(4) 21,566.14 8987 18443 6,434.47 6,27956 -16,846.62 -6,64134 5,921,072.15 1,631,697.24 1.39 17,744.00 MWD+IFR-AK-CAZ-SC(4) 21660.49 89.10 183.35 6,435.32 6,280.41 -16,94074 6,648.14 5,920,97804 1,631,690.81 1.41 17,837.81 MWD+IFR-AK-CAZ-SC(4) 21,755.38 90.00 180.79 6,436.07 6,281.16 -17,035.56 6,651.57 5,920,883.23 1,631,687.36 2.86 17,931.78 MWD+IFR-AK-CAZ-SC (4) 21,849.91 90.07 181.91 6,436.01 6,281.10 -17,130.06 6,653.80 5,920,788.74 1,631,685.11 1.19 18,025.24 MWD+�IFR-AK-CAZ�SC(4) 21,914.00 89.94 181.56 8,436.00 6,281.09 -17,194,12 -6,655.74 5,92Q72468 1,631,683.15 0.58 18,088.66 Yf1T sn G1 reel Snm...l 713112017 11:06, IIAM Page 8 COMPASS 5000.14 Budd 85 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: To 2K-30 Wellborn: 2K-30 Design: 2K-30 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well TD: 2K-30 Rig: 39.21+115.70 @ 154.9lusft Rig: 39.21+115.70 @ 154.91 usft True Minimum Curvature OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (') (usft) (usft) (usft) (usft) (ft) (ft) (-/100-) (ft) Survey Tool Name 21,944.43 89.88 181.40 6,436.05 6,281.14 -17,224.54 -6,656.53 5,920,894.27 1,631,682.35 0.58 18,118.76 MWD+IFR-AK-CAZ-SC (4) 21,992.59 89.13 179.58 6,436.47 6,281.56 -17,272,70 6,656.94 5.920,646 12 1,631,681.93 4.09 18,166.25 MWD+IFR-AK-CAZ-SC (4) 22,055.00 89.13 179.58 6,437.41 6,282.50 -17,335.10 6,656.48 5,920,583.72 1,631,682.37 0.00 18,227.62 PROJECTED to TD rinal Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. 71 Yes ❑ No I have checked to the best of my ability that the following data is correct: 0 Surface Coordnates p Declination & Convergence O GRS Survey Corrections EJ Survey Tool Codes mj,l yam b1reaem SLB DE: Brandon Temple w�¢ei7aaai Wmaa-mm Dyb1"1,r*dby AmbVom tnra:mv9ea 10:t8W Clint Representative: ✓^ aeoo Date: 8!1!17 7/312017 11:06: 11AM Page 9 COMPASS 5000.14 Build 85 THE STATE °fALASKA GOVERNOR BILL WALKER Adam Klem Completions Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2K-30 Permit to Drill Number: 217-072 Sundry Number: 317-309 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 www.aogcc.alaska.gov Enclosed is the approved application for 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, LU�7� Hollis S. French S Chair DATED this 1 qday of August, 2017. RBDMS L�, AUG - 9 2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED JUL 0 70117 nAOGCC' 7 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate Repair Well Elp Operations shuttlown❑ 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: COnocoPhilll s Alaska Inc. Exploratory ❑ Development p Stratigraphic ❑ Service ❑ 217-072 ' 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20758-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No El fi-b KRU 2K-30 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25588, ADL 25605, ADL 25604, ADL 25607 1 Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 25,291 est 6350 est 8500 Casing Length Size MD TVD Burst Collapse Structural Conductor. 140' 20" 179' 179' Surface 3,270' 103/4 3,309' 2,849' Intermediate 11,918 75/8 11,957' 6,368' Liner 8,155' 412 2,591' 6,368' Perforation Depth MD (ft): IPerforation Depth TVD (ft): ITubing Size: Tubing Grade: Tubing MD (ft): See attached schematic See attached schematic 3.5" L-80 11,567' est Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER = BAKER PREMIER PACKER 11,537' MD and 6,330' TVD est SSSV = NONE N/A 12. Attachments: Proposal Summary 0 Wellbore schematic 0 13. Well Class after proposed work: Detailed Operations Program EI BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development EI Service ❑ 14. Estimated Date for 815/2017 15. Well Status after proposed work: Commencing Operations: OIL RIfWIND ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG I GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: Mr'yr p •1W GIN] ElpShutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Adam Klem Contact Name: Adam Klem Authorized Title: Completions Engineer Contact Email: Adam. Klem@conocophillips.com Contact Phone: (907) 263-4529 Authorized Signature: / Date: b' 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: r, n Post Initial Injection MIT Req'd? Yes E]No � RBDMS b\,46b ' 9 2017 ,( Spacing Exception Required? Yes ❑ No Subsequent Form Required: It — -4t APPROVED BY Approved by: J COMMISSIONER THE COMMISSION Date: Z1, t F /i- 4^p�\v\ lForm 10.403 Revised 4/2017 "V V lOJ�\f L, m�� 7/(5/ 20'-7 Submit Form and ' `///�t�t�t pyli(al�o i valid for 12 months from the date of approval. Attachments in Duplicate 2K-30 (Gulper) ConocoPhillips Grassroots Horizontal A -Sand Producer Proposed Wellbore Schematic(wp12) Lest Ecked: a .'tm, IepplN 154%' 12,WI61M Idem 7/6/17 I" Conducor W -179' Surface Casino 10-31,V'45.5# L-80 Hydrll 563 3,270'MD/3,309'TVD(61' INC) GLM W SOV 3-112" 9.3#L-801 UE SRDMOD Feet: -9755MD 7-5J8" 29.7# L-80 Hyd563 Casing 11,957' MD / 6,368' ND (85e INC) 13.5" Surface Hole Top West Sell: 2321' MD12199' TVD Bae West Sell: 3315' MD12742'TVD 9-7/8" x 11" Intermediate Hole CX: 8464' MD 15110' TVD C.35:97M'MD 15676' TVD X%'2.7 "D Nipple Nalubik: 10738' MDIM05'TVD A4: Production Liner. E 4-1/Z'12.6# L-80 Hydril 563 25,291' MD est / 6,485' TVD est 00 , TD: 25.291' MD / 6 d85' TVD feel Production Hole 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). ConocoPhillips Alaska, Inc. Paul K. Wharton Staff Landman P.O. Box 100360 — Suite ATO 1482 Anchorage, Alaska 99510-0360 Phone (907) 263-4076 Paul.K.Wharton@mnocophillips.com To: Operator and Owners (shown on Exhibit 2) Re: Notice pursuant to 20 AAC 25.283 (1) 2K-30 Well Kuparuk River Unit, Alaska ADL 25588, KRU Tract 76; ADL 25605 KRU Tract 88, ADL 25604, KRU Tract 89; and ADL 255607, KRU Tract 96 Dear Sirs: ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Kuparuk River Unit ("KRU") working interest owners, 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 2K-30 Well (the "Well'). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about June 29, 2017. This Notice is being provided pursuant to 20 AAC 25.283. The Well has been drilled as a directional well as shown on the attached plat (Exhibit 1). 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 ("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 to you. If you require any additional information, please contact the undersigned. Very truly yours, 9.«,e- /v. (�v�jor c�iN Paul Wharton Staff Landman cc: Adam Klem Rebecca Swensen 2K-30 Hydraulic Fracturing Notice Lett, June 29, 2017 Page 2 Exhibit 1 ConocoPhillips Alaska 2K -3O N 2K-03 2K-J3L1 2 \A2K-05 2K-01 Lease Plat DL02558>� 0 1,300 2,600 5200 I Feet 2K-06 _ 6/28/2017 ADL025589 — ''x-19AL1 2K30 ADL025667 2K-28ABB LK Y42K�12�21K-15 4K-26 �n-rases —2K"19 1 ! 1 ,K-18 �KJ 2K -22A \ - ' 1 2K -15L1-0 2K-23 2-K -28AL1 2K -21A � 12K-22 2K -- 2K-21 2K-29 i 2K-22AL1-01 kr 2NI22ALl "- ADL025604 ADL025605 ADL025668 KUPARUK RIV sui 24-, O1ON008E O1ONOO9E i o v Q Well Surface Location 2K-32 — 2K-30 Open Interval — 2K-30 Trajectory Q1/2 mile Trajectory Radius • Frac Points O 1/2 mile Frac Point Radius ADL392952 ADL025607 Well Within Trajectory Radius O CPAI Lease [ Unit Boundary Sections 2K-30 Hydraulic Fracturing Notice Let,. June 29, 2017 Page 3 Exhibit 2 Mineral Owners: Operator: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1220 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Erik Keskula, Manager, NS Development Non -Operators: BP Exploration (Alaska) Inc. P.O. Box 196612 900 E. Benson Boulevard (Zip 99508) Anchorage, AK 99519-6612 Attention: Mr. John Dittrich Chevron U.S.A. Inc. 1400 Smith Street Room 40116 Houston, TX 77002 310 K Street, Suite 406 Attention: Mr. Dave White ExxonMobil Alaska Production Inc. 3700 Centerpoint, Suite 600 P. O. Box 196601 (Zip for PO Box 99519) Anchorage, AK 99503 (Street zip) Attention: Mr. Jamie Long Surface Owners: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 Attention: Director TO TH. ._ASKA OIL AND GAS CONSERVATION CO,. .,SSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Paul K. Wharton Request of ConocoPhillips Alaska, Inc. for ) Hydraulic fracturing for the 2K-30 Well ) under the Provisions of 20AAC 25.280 ) STATE OF ALASKA THIRD JUDICIAL DISTRICT ) Paul K. Wharton, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Paul K. Wharton, and I have personal knowledge of the matters set forth herein. 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 or about June 29, 2017, 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 29th day of June, 2017. Paul K. Wharton STATE OF ALASKA ) THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 291h day of June, 2017, by Paul K. Wharton. Notary Public, Sfate oflad ska My Commission Expires: STATE OF ALASI A n NOTARY PUBLIC REBECCA SWENSEN Ny Coirninion Ez Au . 27, Y040. Section 2 — Plat 20 AAC 25.283 (a)(2) Plat 1: 2K-30 Landowners 4A A /3 t'U' Sk"-1LL1 5r r22 eLl 2:f --',Ly ;2"-,_ 'v,' ConocoPhillips Alaska 2K-30 N 2K -69L1 JK-na %K -0i \�DL02558� -_ z 01ON009E Lease Plat A _ 1 IIk-22K '' n 0 300 2,600 5,200 2K-30 Trajectory 1/2 mile Trajectory Radius • Frac Points 9ADL392952 1/2 mile Frac Point Radius ADL025607 1 --- Well Within Trajectory Radius Feet CPA[ Lease 0 Unit Boundary y - Sections 6/26/2017 Vit: 'IxJ ADL025589 2K-30 ADLO25667 2K-2sr:e.e.l i'=9"- �k:.-:1•] 1 --KK�2i..-`�'g-lg .1- 2k: '2�2ALi-Ol 5r r22 eLl 2:f --',Ly ;2"-,_ ADL025668 KUPARUK RIVER UNIT ' -- -� 24 01ON008E 01ON009E _ 1 IIk-22K '' n �5: / 1 2k: '2�2ALi-Ol 5r r22 eLl 2:f --',Ly ADL025604 ADL025605 ADL025668 KUPARUK RIVER UNIT ' -- -� 24 01ON008E 01ON009E _ 1 Q Well Surface Location )g -gig 2K-30 Open I nterval 2K-30 Trajectory 1/2 mile Trajectory Radius • Frac Points 9ADL392952 1/2 mile Frac Point Radius ADL025607 1 --- Well Within Trajectory Radius CPA[ Lease 0 Unit Boundary y - Sections Table 1: Wells within .5 miles API Well Name Status Type 501032010200 2K-01 ACTIVE PROD 501032010100 2K-02 PA PROD 501032010000 2K-03 ACTIVE INJ 501032009900 2K-04 ACTIVE PROD 501032009800 2K-05 ACTIVE INJ 501032011000 2K-06 ACTIVE INJ 501032010700 2K-07 ACTIVE PROD 501032011100 2K-08 PA PROD 501032011172 2K -08A PA EXPEND 501032011101 2K -08A PA PROD 501032011170 2K -08A PA EXPEND 501032011171 2K -08A PA EXPEND 501032011173 2K -08B PA EXPEND 501032011174 2K -08B PA EXPEND 501032011175 2K -08B PA EXPEND 501032011102 2K -08B PA PROD 501032010800 2K-09 ACTIVE PROD 501032010860 2K-091-1 ACTIVE PROD 501032010861 2K -09L1-01 ACTIVE PROD 501032010600 2K-10 ACTIVE INJ 501032011400 2K-11 PA PROD 501032011401 2K -11A ACTIVE PROD 501032011470 2K -11A PA EXPEND 501032011460 2K-11AL1 ACTIVE PROD 501032010900 2K-12 ACTIVE INJ 501032011600 2K-13 PA PROD 501032011601 2K -13A ACTIVE INJ 501032011660 2K-13AL1 ACTIVE INJ 501032011661 2K-13AL2 ACTIVE INJ 501032011200 2K-14 PA PROD 501032011201 2K -14A ACTIVE PROD 501032011260 2K-14AL1 ACTIVE PROD 501032011300 2K-15 ACTIVE PROD 501032011360 2K-151-1 ACTIVE PROD 501032011361 2K-151-1-01 ACTIVE PROD 501032011362 2K-151-1-02 ACTIVE PROD 501032011500 2K-16 PA PROD 501032012100 2K-17 PA PROD 501032011700 2K-18 ACTIVE INJ 501032011800 2K-19 PA PROD 501032011801 2K -19A ACTIVE PROD 501032011860 2K-19AL1 ACTIVE PROD 501032012000 2K-20 ACTIVE INJ 501032012300 2K-21 PA PROD 501032012301 2K -21A ACTIVE PROD 501032011900 2K-22 PA PROD 501032011901 2K -22A ACTIVE PROD 501032011960 2K-22AL1 ACTIVE PROD 501032011961 2K-22AL1-01 ACTIVE PROD 501032012500 2K-23 ACTIVE INJ 501032012200 2K-24 ACTIVE INJ 501032012400 2K-25 ACTIVE PROD 501032012460 2K -25L1 ACTIVE PROD 501032012461 2K-251-1-01 ACTIVE PROD 501032012600 2K-26 ACTIVE PROD 501032038800 2K-27 ACTIVE PROD 501032038500 2K-28 PA INJ 501032038501 2K -28A ACTIVE INJ 501032038570 2K -28A PA EXPEND 501032038560 2K-28AL1 ACTIVE INJ 501032038571 2K-28AL1 PA EXPEND 501032038572 2K-28AL1 PA EXPEND 501032068700 2K-29 ACTIVE PROD 501032075700 2K-32 ACTIVE PROD 501032068800 2K-34 ACTIVE PROD 501032068870 2K-34 PA EXPEND 501032068860 2K -34L1 ACTIVE PROD 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. None as per Aquifer Exemption Title 40 CFR 147.102(b)(3), 'That portions of the aquifers on the North Slope described by a%mile area beyond and lying directly below the Kuparuk River Unit oil and gas producing field". 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 was 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: The 10-3/4" casing cement pump report on 6/19/2017 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 11 ppg LitCrete lead cement and 12 LiteCrete ppg tail cement. Took cement returns to surface. The plug bumped at 1,045 psi. The floats did not hold, so pressure was held while WOC. The 7-5/8" casing cement pump report on 6/30/2017 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg cement. The plug bumped at 1,045 psi. The floats were checked and they held. Summary All casing was cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well will be 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. Loepp, Victoria T (DOA) From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Monday, July 31, 2017 8:36 AM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]RE: 2K-30 top of cement Sonic/frac sundry My apologies, I had not seen those conditions of approval 1. The interpreted TOC is 9,587' MD. We are seeing very good cement from 12,250'MD (base of log) to 9,875'MD where it becomes a little rattier but still shows sign of competent cement. From 9,875' to 9,587'MD the cement is a little ratty, but still seems to be competent cement up to the TOC at 9,587'MD. This places the cement well above the top of the HRZ, indicating adequate reservoir and confining zone isolation as required. 2. 1 believe the cement and FIT results were already provided. Do you need me to re send them in? I believe that covers the COA as specified in the 10-401. Is there anything else you need from me? Thanks, Adam Klem From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, July 28, 2017 10:15 AM To: Klem, Adam <Adam.Klem @conocophillips.com> Subject: [EXTERNAL]RE: 2K-30 top of cement Sonic/frac sundry Adam, Please see conditions of approval for running the sonic on the approved PTD. Would like to see your interpretation, final WBS and other info included in the conditions. Thanx, Victoria From: Klem, Adam[mailto:Adam.Klem@conocophillips.com] Sent: Tuesday, July 18, 2017 6:59 AM To: Loepp, Victoria T (DOA) <victoria.loeploPalaska.eov> Subject: 2K-30 top of cement Sonic Victoria, Here is the Sonic log on 2K-30 to go along with the frac sundry. Let me know if you need anything else. Adam Klem SECTION 7 — PRESSURE TEST INFORMATION AND PLANS TO PRESSURE -TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 6/22/2017 the 10 & 3/4" casing was pressure tested to 3500 psi. On 6/30/2017 the 7 & 5/8" casing was pressure tested to 3500 psi. The 7 & 5/8" casing will be pressure tested to 4,200 psi prior to frac. AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 7,000 Annulus pressure during frac 3,800 Annulus PRV setpoint during frac 3,900 7 5/8" Annulus pressure test 4,200 3 1/2" Tubing pressure Test 5,500 Nitrogen PRV 8,200 Highest pump trip 1 8,000 SECTION 8 — PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Wei ht Grade API Burst API Colla se 10 & %11 45.5 L-80 2,090 psi 3,580 psi 7 & 5/8" 29.7 L-80 6,890 DSi 4,790 Dsi 3.5" 9.3 L-80 10,160 psi 10,540 psi Table 2: Pressure Ratings Stimulation Surface Rig -Up 10K Frac Tree NNenimensional information mikTt£i1 On thf, d.m ir4 am osomated moawllmmn Mly. ConocoPhillips 0.115ite2S- l OX Frx Tree CAMERON SECTION 9 — DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The fracturing zone, the Kuparuk A sand interval, is approximately 115' TVT at the heel, with the top of the Kuparuk A at 6,157' TVDSS (11,389' MD) and 125' TVT at the toe of the well, with the top Kuparuk A estimated at 6,310' TVDSS. The Kuparuk A interval is composed of multiple packages of very fine grained, quartz rich sandstone, separated by laterally continuous shale interbeds. The estimated fracture pressure for the Kuparuk A is 13.1 ppg. The overlying confining zone has an overall thickness of 298' TVT (850' MD) and consists of HRZ and Kalubik mudstones. Top HRZ was encountered at 5,837' TVDSS (10,435' MD). The estimated fracture pressure for the overlying confining layer is 16 ppg. The underlying confining zone consists of the Miluveach interval, a marine shale, approximately 500' thick. The estimated fracture pressure for the Miluveach is 15.5 ppg. The top of the Miluveach is located at approximately 6,275' TVDSS at the heel (the Miluveach interval was not penetrated in the 2K-30 wellbore). 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: 2K-32: The 7 & 5/8" casing cement pump report on 5/21/17 shows that the job was pumped with full losses. The cement job was pumped with 15.8 ppg cement, displaced with 10.4 ppg mud. The plug bumped at 1,200 psi and the floats were checked and they held. The cement was logged showing a TOC of 10,223' MD. 2K-21: 2S-13PB1 was plugged and abandoned per state regulations. 2K -21A: The 7" casing was temporarily suspended in 6/2017. The TOC was tagged at 9,459' MD. i ) } \| ` - }ƒ 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 there are 4 mapped faults that transect the Kuparuk A interval and enter the confining zone within one half mile radius of the wellbore trajectory for 2K-30. The east -west trending faults that intersect the planned well trajectory all terminate below the C50 interval, which consists of silts and shales in this area with an estimated fracture pressure of >16 ppg. The C50 interval is 1780' TVDSS above the Kuparuk A interval in the 2K-30 heel location. Four faults intersect the 2K-30 wellbore and all terminate within the confining layer. No losses were observed at any of the fault crossings during drilling of the 2K-32 analogue well to the west of the 2K-30 planned well. Fracture gradients within the confining zone (Kalubik and HRZ) will not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. Thickness and fracture pressure for the confining layer is discussed in Section 9. 2K-30 Faults MD SSTVD Throw Fault #1(A4/AS) 13925 6225 30 (DTS) Fault #2 (A4/A4) 15825 6300 10 (DTN) Fault #3 (A4/A4) 17300 6310 10(DTS) Fault #4 (A4/A4) 19800 6310 20(DTS) Two mapped fault within the half mile radius intersect the offset 2K-32 wellbore in the Kuparuk A sands. This corresponds to faults 1 & 4 in the 2K-30 wellbore. This fault terminates in the confining layer. No losses were observed at any faults during drilling of the 2K-32 lateral section. The 2K-32 lateral is greater than 1500' from the 2K-30 wellbore. 2K-32 Fault MD SSTVD Throw Fault #1 (A4/A5) 16600 6225 30(DTS) Fault#4(A4/A4) 22950 6275 25(DTS) The effective fracture length is estimated to be 760'. All of the fractures will be longitudinal, running parallel to the 2K-30 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. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults will not interfere with containment. Plat 2: Fault Analysis ConocoPhillips Alaska 21K30 N Fault Analysis Plat % ADL025588 0 1,300 2,600 5,200 FM 6/26/2017 ADL025589 //2K-30 ADL025667 10 2K-224 13 ADL025604 ADL025605 ADL025668 KUPARUK hS - — 23 N f 010N008E 010N009E Q Well Surface Location — Faults Within Confining Zone 2K-32 — 2K-30 Open Interval — 2K-30 Trajectory i =1 1/2 mile Trajectory Radius • Frac Points 1/2 mile Frac Point Radius ADL025607 f ADL392952 Well Within Frac Point Radius O CPAI Lease Unit Boundary p " Sections SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) 2K-30 will be completed in 2017 as horizontal producer in the Kuparuk sand formation. The well will be completed with 3.5" tubing and a 4.5" liner with ball actuated sliding sleeves. After the 15' stage we will shift a sleeve to close off that section of the lateral. We will then pump the 2nd stage and drop a ball (progressively getting larger) after each remaining stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. Proposed Procedure: Halliburton Pumping Services: (Kuparuk Sand Frac) 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 20 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. 29,201 bbls are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU HES Frac Equipment. 7. PT Surface lines to 9,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 500 bbl breakdown stage (35# linear gel) according to the attached excel HES pump schedule. Bring pumps up to maximum rate of 25 BPM as quick as possible, pressure permitting. Increase annulus pressure to 3,600 psi. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule with a maximum expected treating pressure of 7,000 psi. CUSTOMER C-Ph,thpi API 50103207SR UD Pbl E1) 15 &000 ... 190 .a. 215 LEASE 2e-30 SALES ORDE a-uV 1.00 BHST (Y) D.90 0.90 uaWeuRrpry _ 3500 35.00 0.15 0.15 FORMATIM eupar.Y A Santls DATE 35NH borG 35#HborG Max Pre55ure Wanli 20/40 Wan1120/40 3.50 4,00 Uould Additives Dry Atldiflves Treatment mtrnnl Stage Fluitl un...n.. n...w..r:..., SGCe n....:_.:__ Prop Proppant Conc ... r Slurry Clean gate Volume r.__. ..... Clean Volume Slurry Volume Prop Sfa6e T -On Time __ IMerval Lo-Surt300D M06] Q-22 0C CL -31 Tlme S.- 6uXer tlm GonlMbr un - Yx LW-idO WG -36 BE -6 Op[iFlo 111 Opti Flo ll SP Fr en exegm Gal &e4tla beater BrtaYx BneFer 2-1 3541 m G Pad 100 esh 0.35 25 25001 2-2 3541,rG Pad SSA -1 Silica Flour 1 0.035 my 2-3 35#H 0rG Pro aM laden Fluid Want! 20/413 3.00 25 5,000 £¢y 24 3S#Ha1,ArG PYODDaM laden Fuld Wanh 20/40 200 25 2Soo c 2gAA Y3 YS l� Ei yo 2-5 35pN bore pro MLaden Fluid Wen1120/4D 3.00 15 &000 ... 190 .a. 215 .quuu 24,00040 u:v:aa 0:25:59 a-uV 1.00 1.50 150 D.90 0.90 0.45 0:45 3500 35.00 0.15 0.15 200 2.OD 025 0.25 26 2-7 35NH borG 35#HborG P..Paint Laden Fuld Pm an[Ad. Fluid Wanli 20/40 Wan1120/40 3.50 4,00 25 35 8000 ],WO 190 16] 219 195 2000050 3000053 Oa:19 0:00]9 1.00 1.00 1.50 1.50 0,90 090 OAS 0.45 35M 35.00 0.15 0.15 200 2.00 025 0,25 2-0 35bH bore rer&Oro Ball 1.93S- 2S 630 15 15 36 0000:36 100 1.50 0.90 OAS 35.00 0.15 2.00 025 3-1 35pH bore pad 100 mesb 0.25 25 25000 595 602 6,250 5 VM 1:02:50 1.00 1.50 0.90 0.95 35.W 0.15 2.00 025 34 35pH MrG pad SSA-15ilica Flour 0.035 B]50038:45 100 1.50 0.90 OAS 35.00 0.15 2.00 0.25 3d 35pH bare Pro am laden Fluid Wank 20/40 1.00 35 5000 319 124 5,000 9 0:30:45 1.00 1.50 0.90 0.45 35.00 0.15 2000 0.25 3i 35pH orG pro aM Laden Fluid Wadi 2040 2.00 25 ]Spp 3J9 194 15,W00 0:33:46 1.00 1.50 0.90 0.45 35.00 0.15 2.00 0.25 3-5 35pH bore Prop Mladen Fluid Wan1i 20/40 3.OD 25 8,000 190 235 24,000 0 0:25:59 1.00 ].50 0.90 0.45 35.00 0.15 200 0.25 3b 359N bore Proppedladen Fluid WanIi 20/40 3.50 25 8,000 190 239 28,000 50 0:1):19 100 ].50 0.90 0.45 35.00 0.15 2.00 025 3-0 35pN bore Pro ant Laden Fluid wan020/40 4W 25 >000 16] 195 29000 53 0:00:29 1.00 1.50 090 0.45 35.00 0.15 2.Op 025 3-0 350 HyborG eer&Dro Ball 2000' 25 630 15 15 0:00:36 0:00:36 1.W 1.50 0.90 0.45 35.00 0.15 200 0,25 41 L2 35bH bore SSEH bore Pad Pad 100 mesb 55A -]Silica Flour 0.25 0.035 25 25000 595 602 6250 8]5 0:24:05 1:02:50 0:38V5 100 1.00 1.50 1,50 0.90 090 0.45 0.45 35. as 35.W 0.15 OAS 2.00 200 035 0.15 4-3 44 35pM bore 350H horG pro an[laden Fluid Pro an[Uden Fluid Wan1120/40 Wan1i 2040 1.00 2000 25 2$ 5000 7,500 119 ll9 124 194 SOW 15000 0:04:59 00]48 0:30:45 0:33A6 1.00 100 1,50 1.50 0090 0.90 0.45 OAS 35.00 35.00 0.15 0.15 200 2.00 0.25 025 4-5 35OH bore Pro am Laden Fuld W.11 20140 300 25 0000 390 215 24000 0:218:40 0:25:59 1.00 .1.50 0.90 0.95 35.00 0.15 2000 035 46 35pM tiprG pro aM laden Flub Wan1120/40 3.50 25 0000 390 239 28,000 0:08:50 0:]]:19 1.00 ].50 0.90 OAs 35.00 0.15 2.00 035 4) 354 H o G Pro am Laden n Flpia wand MLO 4600 25 ]000 i6] 195 10000 0:0]:53 0:0&29 1.00 1.50 0.90 OAS 35.00 0.15 2.00 0.25 4d SEE N orG Spacer & P0a113.063" 25 630 35 35 00036 0:00:36 5.00 1.50 0.90 0.45 3500 025 2.00 025 5-1 5-2 5-3 sd 35#HborG 35pH bore 35pH bore a[6 uvnn.n Pad Pad Pre ant Laden Fluid o...n..a_r I. a._ n..0 I 100 mesh SS43 Vllta Ftpm Wan1120/4O ur__n -.. I 0,25 0.035 1.00 ..a. 25 25 - 25,000 $000 -...... 595 119. 602 124 6,250 0]5 SOOU 034:05 0:04:59 1:0350 0:30:45 0:30:45 lOp 1.Op 101) 1.50 1.50 S.SO 0.90 0.90 090 045 0.45 0.45 1 3500 35.00 3SnD 0,15 0.]5 0.15 2.00 2.00 200 0.25 0.25 0.25 ConoeoPhillips - 2K-30 Planned Design I CUSTOMER conompbillipz AN 50103 10758 BFO /16/000 74 "- J-5 354 H bor G LEASE 2K 30 SAL i50RDE 35RH bore BHST/°F) t65 HALuauaao 350 Hirbor G 8-1 FORMATION gupamk A Sadds DATE Max Pressure 100 mezM1 35# H borG UuWdAddithes OryAdififf- &6 B-7 359X 60x6 35pH bore 6250 Prop Slurry Clean Clezn Slurry Pmp Stage Interval Lo-Surt3.0 MO -6] CL -RUC Cb31 1VF400 WGd6 BE -6 OpBFlmlll OptiFlodl 5P Tr^dtnl'- 5[mger u^d 0.25 Cpn; I Pale Vo Yme I VOIYme VOIYYIG. Total Tlm! ilralG n eF ^^ ^_Stage 'prappant 0:38:45 1.50 0.90 WrtamM BUNn Crmsllnkar [rmfllNn iI maaPmlatt GN BIttIM Bnak<r mhr BnaYar W Z - ^r e Q n G x « s84 c S� Y `n -2 35MH borG 7-3 354 H borG 74 350 HyborG J-5 354 H bor G 7-6 350 H borG )J 35RH bore 7-0 35RH borG -9 350 Hirbor G 8-1 35N llG e-3 359 Hss a G 35Norb 100 mezM1 35# H borG 65 35#H bore &6 B-7 359X 60x6 35pH bore a Ill e-eF35NHy�rG bwG aFePB Dr Bali 2.313- 25 630 1.II 15 ..� 15 .omw u:v:m 0:00:36 u:ua:a 0:.:36 a.. loo 1Au Iso u.W 0.90 0.95 OAS 35.00 35:00 0.35 0.15 2000 100 0.25 015 9-3sG Pad 100 mezM1 0.25 25 25,000 595 602 6250 0:24:05 1:02:50 100 1.50 0.90 0.45 35.00 0.15 2.00 0.25 9-3are Pad SSA-15iliaa Flour 0.035 875 0:38:45 1.00 1.50 0.90 0.45 3500 GAS 2.00 025 9-3arG pro and Laden Fluid WanIi 20/40 1.00 25 5,000 119 124 5,000 O:o4:59 0:38:45 1.00 ].50 0.90 OA5 35.00 0.15 20094or G Pro nt laden Fluid Wane 2014D 2.00 25 ),SW 1)9 194 15.0 0:0):48 03346 100 3.50 0.90 OAS35.00 0.15 2.00 0.25 9 -Sore Prop nt Latlen FlGld WanIi 20/40 3.. 25 fl0. 19D 215 24000 0:00:40 0:25:59 100 151) DRO OAS 35.00 0.15 2OI15%bore Pro pan[laden Fluid WanIi20/40 3.50 25 BWO 190 219 26,000 0:00:50 0:17:19 1.00 1.50 OAA 0.45 3500 0.15 2.. 0.25 9-7borG Propant Laden Fluid WanIi 20/40 4.. 25 ],.0 16] 195 28,000 0:07:53 0:08:29 100 1.50 0.90 OAS 35.05 0.35 2.. 0.25 9-8bore 10-3ore 5 acer& OroBall 2.375" Pad 100 mesh 0.25 25 25 630 2500D 15 595 15 602 6,250 0:0:36 0:34:05 0:.:36 1:02:50 1,M 1.. 1.50 1.50 0.90 0.90 0.45 OAS 35.. 35.. 0.15 0.15 2.. 2.00 0.25 0.25 10-2 35MH G pad SSA -1 Silia'a FIOYr p.a35 875 0:36A5 1.. 1.50 0.90 0.45 35.00 0.15 2.00 0.25 10-3 3Wdl G Ra nt laden Fluid Wadi 20/40 300 Is 5,000 119 124 5.0 0:04:59 0:38:45 100 1.50 0.90 0.45 35.00 0.15 2.00 0.25 104 10-5 359H rG 35Mdisbar G Pm ant Laden Fluid Pro ant laden Fluid wants 20/40 Wants 20/40 2.00 3.00 25 25 )500 8000 1]9 190 194 215 15ACO 24,000 0:0):48 0:08:40 0:33A6 0:25:59 1.00 1.00 150 150 0.90 0.90 0.45 0A5 35.00 35.00 0.15 D.15 2.00 0.25 106 3541-OrG Pro rrc Latlen Fluid Wants 2040 3.50 25 BOW 190 219 28.000 0:08:50 0:1]:]9 L. 1.50 0.90 pA5 35.00 0.15 1DJ 10.8 350 bOrG 35MH bore "Earn Laden Fluid cer8 Oro Ba112.418" WanIi 20/40 4.00 7 5 195 15 38,000 00]:53 0 00:36 0:08:29 0:00:36 3.00 3.. 0.45 0.45 35.. 331-1 350 H bor G Patl ]00 mesh 015 5 602 fi250 0:2005 1:02:50 100 0.45 311-2 35pH bore Pro an[Latlen Fluid WanIi 20/40 l.. A25 f 9 124 5000 0:09:59 0:38:45 1.. rl,5003D 0.45 311-3 3S#HborG Pm ant Laden Fluid Wan020/40 2.00 9 199 15,000 0:07:48 0:33:46 1.00 I1J 35pH bore Pm an[Laden Fluid WanIi 20/40 3.00 0 215 24,00110:08:40 11:25:59 1. 0.45 35.00 0.15 3.00 015 1L5 35RH bmG Pro ant Laden Fluid WanIi 20/40 3.50 0 219 28,000 008:50lidPro 11-] anLLaden Flusd R nnnnall. Wanli 20/40 400 ] .. ConocoPhillips - 2K-30 Planned Design 2 CUSTOMER I ....1hillips AN 50-10330]58 RFD (Ib/golf "- .. __ 630 _... 15 LEASE 2Xd0 SALES ORDE 1.11:41 D:W:36 BHST('F) 165 R4Lu®umv - _ ... 0.90 0.A5 DAIS FORMATION Cuparuk A Sands DATE 035 0.25 Max Pressure 359HborG 350H arG LlquidAddiN✓as Dry AddiN✓es Trea[m[nt Interval $bge fVld N..mFo• ne..•:nr:n.. $bge n....:..0 Prop PlDppdM Cone n .. • • Slurry I Clean Rate VOIVMe •._-. - . Clean Slurry VVIV Te VOIVTe Prop Stage TMa Tlme Interval Co -Surf 3000 MO -67 CL -22 UC CL.31 LVf-200 em Time SuI-, Buller ."All pmdlnker rmmP:mett WG -36 BE -6 Optiflo-III Optirla, SP a 4el alpdtle maker mker Bmkar 14-6 35NH 6arG cer&Ora 6.112625' _- _ __ __ 25 .. __ 630 _... 15 ... 15 ,„. ..✓•.aa 000:36 1.11:41 D:W:36 - 1.00 aeu 1.50 ... 0.90 0.A5 DAIS 35.00 3500 015 0.15 2.00 2.00 035 0.25 15-1 15-2 359HborG 350H arG Pad Pad 100 mesh SSA -1 SIica Flour 0.25 0035 25 25,OW 595 602 6,250 875 0:24:05 1:02:50 0:38:45 I.00 1.00 1.50 1.50 0.90 090 045 045 3500 3500 0.15 0.15 ]00 200 0.25 035 15-3 35YHborG pm nt Laden Fluld WanIi 20/40 1.OD 25 5,000 119 124 5,000 0:04:59 0:38:45 100 1.50 0.90 0.45 35.00 0.15 2.00 0.25 15-4 354 H bor G Pm n[ Laden Fluid WanIi 20/40 2.00 25 7,5 ll9 190 15 000 0:01:48 0:33A6 1.00 2.50 0.90 0.45 35.00 0.15 2.00 0.$5 15-5 35p borG Po,,.t laden Fluid Warn 20/40 300 25 8,080 190 23s 24,000 0:08:40 0:25:59 1.00 1.50 0.90 OAS 35.Op 0.15 2.M p.25 15-6 15-> 35-8 35p HVborG 35p H bore 35IX N hor G Propent Pro Spacer laden Fluid ant Laden fluid & Drop6.112.625" WanIi 20/W Wanll 20/40 3.50 400 25 25 25 8,000 7,000 630 190 16J 15 219 195 15 2R000 20000 0:00:50 0:0):53 0:00:36 0:17:19 0 08:29 0.0:36 1.00 1.00 1.00 1.50 1.50 1.50 0.90 0.90 0.90 0.45 0.45 OAS 3500 35.W 3500 0.15 0.15 0.15 2.00 2.Oo 2.p0 0.25 0.25 035 16-1 35NH bore pad 100 mesM1 0.25 25 25000 595 602 625U 0:24:05 1:02:50 1.00 1.SO 0.90 0.45 35.00 0.15 2.00 0.25 16-2 35NH bwG 35IXH hwG Pro Pad ant laden Fluid SSA -I Silica Flour WanIi 20/40 0.035 3.00 25 5000 319 124 875 5000 0:04:59 0:38:45 0:38:45 1.00 100 1.50 1.50 0.90 0.90 O45 DA5 BOO MOD 0.15 p.15 2.00 2.00 0.25 0.25 16d 164 16-5 166 35dHbarG 35NHborG 35p bore Pro Pro Proponent ant Laden Fluid ani Laden Fluid latlen Fluitl Wanii 20/40 WanIi 20/40 WanIi 2040 2.00 300 3.50 25 25 25 ]500 000 8000 179 190 190 194 215 239 15,W0 24,000 28000 0:07:40 0:08:40 O:ORSO 033:46 0:25:59 D:1J:19 3.00 1.00 1,B 1.50 150 1.50 0.90 COO 09p 0.45 0.45 pA5 35.00 35.00 35.00 0.15 0.15 0.15 200 2.00 2.00 0.25 0.25 0.25 16J 16-B I)-1 lh2 35NH bore 35NH bore 35NH bore 359H borG pro [Letlen Fluid cer&pro 8.112.6]5" Patl Pad Wanli 20/40 loo meaF SSA"! Silica Flour 4.00 035 OD35 25 25 25 7,000 630 25000 167 ]5 595 195 15 602 20000 6,250 WS 00753 O:OD'36 0:24:05 00029 0:00:36 1:02:50 1 0:30:45 1:00 1.00 1.00 1.00 L50 1.50 1 1.50 1.50 o.9p 0.90 0.90 0.90 OAS 045 045 0.45 35.Op 35.00 3500 35.00 0.]5 0.35 0.15 0.15 2.00 2.00 2.00 2,00 0.25 035 0.25 0.25 ll -3 35NH rG Portent Laden Fluid Wan112040 ].00 25 SODD 119 124 5000 0:04:59 0:H AS 1.00 1.50 0.90 0.45 35.00 0.15 2.00 0.25 174 3" 11dr G Pro ant Laden Fluid WanIi 20/40 2.00 25 ) S00 ll9 194 15,000 0:07:40 0:33:46 1.00 1 1.50 0.90 0.45 35.00 p.15 200 035 17.5 35NH orG Pro aM laden Fluid WanIi 20/40 3.00 25 B4OW 390 215 24,000 0:110:40 0:25:59 1.00 1.50 0.90 0.45 35.00 0.15 2.00 0.25 115 1]-J 35NH bore I'd NVi,.•f. Pro nt Laden Fluid ........A.. n..0 WanIi 2040 u:�-:: in . 3.50 n nn 25 �. 8000 -...... 190 219 28000 0:0850 - 0:1):19 1.00 1.58 0.90 045 3500 0.15 2.00 0.25 ConoeoPhillips - 2K-30 Planned Design 3 CUSTOMER ConomPhdlipa LEASE 2K-30 FORMATION Kuparuk A Sands Stage Fluid Stage Proppant AN 50.10340759 SALESORDE DATE BM (Ibl l) WEST ff) Me. Prenure 165 A'.... '— W G-36 816 UAWdAddWives OpLine I SP (B ) OryAdditives (Pm) Pmp Con[ (PPB) I slurry flrte (bpm) I dean Volum (9o)) I Omm Volum bbl a Slpm/ Volum DBI a Pmp Tot d Qbs) Stage Tim (hM1:mma) Interval Time (hh:mma) Lo-Surf300D Suden (9P)na M06] CL -22 OC Buller ewaallnLer PU l ➢V CL -33 pmuS (pq LV1-200 [epmea rro(9ot) WG -36 bel (➢Pt1 BEi ale[Me (P➢U Op[iFlo-III nater (PPO OptiFlo-II Brtaker ➢U Sp roster (➢ U Proppant Type Total()bs) 21D0 7.4 Initial Design Material Volume 0.1 0.1 1 LD -Sud 300D MO -6] CL -22 OC CL -31 LVR200 WG -36 BE -6 Op[IFIo-III LIAM II SP Wanli 20/40 119001000 SSA-] Silica FIWr 16,625 (901 /goU (BU (poi (9aU lbs lbs lbs lbs /6s 1,223.4 1,004.6 1,D83.0 541.8 3,Op0.D 4,020.3 183.5 2,446.9 305.9 125.2 100 mesh 116750 Max AddRIV8 flag Min Addbive Rat. lo -Surf 3000 M0,67] CL -22 UC CL -31 1 ' 0 W G-36 816 OptiFlo-III OpLine I SP (B ) (9➢m) (9Pm) (Pm) (➢m PBm PPm As. ppm PPm 1.1 1.6 1.1 1.1 ],050.0 36.8 0.2 2.1 0.3 0.5 0.2 0.2 0.2 1 0.3 1 21D0 7.4 DO DA 0.1 0.1 ConocoPhillips - 21K-30 Planned Design 4 Hydraulic Fracturing Fluid Product Component Information Disclosure Fracture Date 201746-22 State: Alaska County: Nankeen Ba API Number: 8010320758 CONOCOPHILLIPS Operator Name: NORTH SLOPE Well Nam and Number: 2K-30 Longitude: 0 Latitude: 0 Longn-at Projection: Indian/Faderel: none Production Type: True Vertical Depth (TVD): 0 Total Water Volume (galr: 1 221,412 Hydraulic Fracturing Fluid Composition: Chemical Maximum Abstract Maximum Ingredient Ingredient Trade Name Supplier Purpose Ingredients Service Concentration in Additive Concentration in In re g dbnst Mass Comments Company First. Name Last Name Email Ph. Number (CAS (% by mass)- HF Fluid I% by mass)** Sea Water Oerator Bese Fluitl Water ]732-18-5 96.00% 7..93075 10030152 Density =8.540 BE -6 Halliburton MIG IOCIDE Biocide Listed Beim Listed Below 0 NA CL -22 UC Halliburton Crosslinker Listed Beim Listed Below 0 NA CRO Halliburton Crosslinker Listed Belau Ustetl Below 0 NA LOSURF-300D LOSURF-300D Halliburton Non-ionic dListed Below Listed Below 0 NA MO -67 Hallipudon H Controll Additive Listed Below Listetl Set. 0 NA OPTIFLO-III RELDEI-AYED EASE Halliburton Breaker Listetl Below Listed Below 0 NA BREAKER SAND -COMMON WHITE -100 Halliburton MESH, SSA -2, PropPant Listed Below Listed Below 0 NA 2500 LB SACK SP BREAKER Hallibudon Breaker Listed Below Ustetl Below 0 NA WG -36 GELLING Hallibudon Gelling gAgent Listed Below Listed Below 0 NA 0 00011 Halliburton Breaker Ustetl Below Listed Below 0 NA Silica Flour Halliburton Pro ant Ustetl Below Listetl Below D NA LV7-200 Penreco Additive Listed Below Listetl Below 0 NA Xinmi Wanli 20/40 Went! Industry Proppant Listetl Below Listed Below Developmen 0 NA n Co. Litl Ingredients Listed Above 1,2,4Trimetr (benzene 95.836 1.00% 0.00065% 93 2-Bromo-2-nitro-1,3- ro ane liol 52-51-7 100.00% 0.00159% 225 Denise Tuck, Halliburton, 3000 Acrylate polymer Proprietary 1.008 0.00090% 128 N. Sam Houston Denisa.Tuck Denise.TuckHalroarton.co Halliburton Pkwy E., Houston, Denise Tuck 281-8]1-6226 TX ]]032,281- re 871.6226 Ammonium persultate ]]27-544) 100.008 0.019258 2-72-3 Corundum 1302-74-5 55.00% 7.38998% 10450m Crystalline silica, quaft 1480660-7 100.00% 11.879658 1679904 Cured acrylic resin Proprietary 30.008 0.005198 735 Denise Tuck@ Hallibudon Denise TUG Halliburton.co 261-971-62M in arwl EthGear 64.17-5 60.00% 0. 5523 u m 9000-30.0 100.008 J02028 0.30282% 42822 Heavyarome8c elroleum naphtha 64742-94-5 30.00% 0.01953% 2762 Hydro also Distillate, Li hL.C9-16 64742-474 100.00% 0.146608 207M Mullins 1302.95-8 45.00% 6.04635% 855000 Naphthalene 91-2041 5.008 0.003258 461 Oxylatetl phenolic resin Proprietary 30.00% 0.02604% 3683 Denise Tuck Halliburton Denise Tuck HalliburtZ 281-B71-6226 m Poly(oxy-1,2-athanetliyl),alpha-(4- nonylphenyl}omega-hytlroxy-, 127087-87-0 branched 5.00% 0.00325% 461 Potassium formate 590-244 60.00% 0.05399% 7636 Potassium hydroxide 1310-58-3 S.00E 0.002098 l296 Potassium mataborate 13709-94-9 60.00% 0.02509% 3548 Sodium esurboxymethyl cellulose WN-32-4 .008 0.000908 128 Sodium chloride 764714-5 .00% 2.957709 418243 Sodium collate 2836-32-0 .00% 0.00090% 128 Sodium hydroxide 1310-73-2 0.04067% 5751 Sodium eisulfate 7776-27-1 .00% 0a0 a%a%Sodium sulfate 7757-8241 130.00% .10% 0.00000%Ulexim, calcined 92908-333 .00% 005399% 7636 Water 7732-18-5 .00% 0.18765% 28538 ' Total Water Volume sources may include fresh water, produced water, and/or recycled water "Information is based on the maximum potential for concentration and mus the total may be over 100% – Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided. All component information listed was obtained from the supplier's Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the suppp' —' o Provided it. The Occupational Safety and Health Administration's (OSHA) regulations govern me criteria for the disclosure of this information. Please note that Federal Law protects "propdelary",'trade secret", and "confidential business information" and the criteria for how information is reported on an MSDS is subject to 29 CFR 1910.1 200i and Appendix D. 2K-30 Kuparuk Sand Multi -stage Frac Model Sharkstooth 2K-30 1-19 100,000 lb 61444 61564 780 120 0.154 20/40 Wan Ii 100,000 Ib Stages 1-19 Stage # Elapsed Stage Fluid Clean Stage Cum Clean Proppant Slurry Cum Sbirry Cum Slurry,BBL Clean Fluid Tme.mm;ss Tme.mm:ss VoI.GAL Vol.GAL Conc.PPA Proppant.LB Rate.BBL/M Rate.BBLJNI 0:00 24:05 HyborG_35 225_Ycon .5 25000.00 25000.00 V/hite Frac 100 Mesh 0.25 6250.00 25.00 602.00 24.72 1.24:05 4:58 HyborG_35# 225 Vimn_.5 5000.00 30000.00 WANLI LITE 20/40 1.00 11250.00 25.00 726,34 23.93 29:03 7:47 HyborG_35a225Ycon_, 5 7500.00 37500.00 WANLI LITE 20/40 2,00 26250.01 25.00 920,81 22.96 36:50 8:38 HyborG_35#225_Vicon_.5 8000.00 45500.00 WAN LI LITE 20/40 3.00 50250.01 25.00 1136.71 22,06 45:28 8:48 HyborG_35# 225 1Acon_.5 8000.00 53500.00 WANLI LITE 20/40 3.50 78250.01 25.00 1356.85 21,63 54:16 7:51 HyborG_35#_225 Vicon_.5 7000.00 60500.00 WANLI LITE 20/40 4.00 106250.00 25.00 1553.19 21.22 L02:08 6:40 HyborG_3S#_225ywon_, 5 7000.00 67500.00 WANLI LITE 20/40 0.00 106250.00 25.00 1719.85 25.00 Toth 1:08:-F3 r--_.._......._ ...................................___...... 67500 _............... _........ _.._ ................._._.._......_. .00 106250.00 1719.85 1001000 lb Wa n l i Stage Proppant Concentration (Ib/ft') o.00 0.80 SECTION 13 — POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through a third party flowback vendor until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to appropriate disposal well until they are clean enough for production.) Loepp, Victoria T (DOA) From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Monday, July 31, 2017 8:36 AM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]RE: 2K-30 top of cement Sonic/frac sundry My apologies, I had not seen those conditions of approval 1. The interpreted TOC is 9,587' MD. We are seeing very good cement from 12,250'MD (base of log) to 9,875'MD where it becomes a little rattier but still shows sign of competent cement. From 9,875' to 9,587'MD the cement is a little ratty, but still seems to be competent cement up to the TOC at 9,587'MD. This places the cement well above the top of the HRZ, indicating adequate reservoir and confining zone isolation as required. 2. 1 believe the cement and FIT results were already provided. Do you need me to re send them in? 1 believe that covers the COA as specified in the 10-401. Is there anything else you need from me? Thanks, Adam Klem From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, July 28, 2017 10:15 AM To: Klem, Adam <Adam.Klem@conocophillips.com> Subject: [EXTERNAL]RE: 2K-30 top of cement Sonic/frac sundry Adam, Please see conditions of approval for running the sonic on the approved PTD. Would like to see your interpretation, final WBS and other info included in the conditions. Thanx, Victoria From: Klem, Adam[mailto:Adam.Klem@conocophillips.com] Sent: Tuesday, July 18, 2017 6:59 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> Subject: 2K-30 top of cement Sonic Victoria, Here is the Sonic log on 2K-30 to go along with the frac sundry. Let me know if you need anything else. Adam Klem Bettis, Patricia K (DOA) From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Thursday, July 27, 2017 6:43 PM To: Bettis, Patricia K (DOA) Subject: Re: [EXTERNAL]KRU 2K-30 (PTD 217-072): Hydraulic Frac Sundry Application Patricia, We had seepage losses throughout the length of the lateral. Adam From: Bettis, Patricia K (DOA) <patricia.bettis@alaska.gov> Sent: Thursday, July 27, 2017 3:17:16 PM To: Klem, Adam Subject: [EXTERNAL]KRU 2K-30 (PTD 217-072): Hydraulic Frac Sundry Application Good afternoon Adam, Did ConocoPhillips experience any loss circulation while drilling production interval of the well? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at (907) 793-1238 or patricia.bettis@alaska.eov. P 7-0 2/ 7-- o Ta Loepp, Victoria T (DOA) From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Monday, July 31, 2017 8:36 AM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]RE: 2K-30 top of cement Sonic/frac sundry Follow Up Flag: Follow up Flag Status: Flagged My apologies, I had not seen those conditions of approval. 1. The interpreted TOC is 9,587' MD. We are seeing very good cement from 12,250'MD (base of log) to 9,875'MD where it becomes a little rattier but still shows sign of competent cement. From 9,875' to 9,587'MD the cement is a little ratty, but still seems to be competent cement up to the TOC at 9,587'MD. This places the cement well above the top of the HRZ, indicating adequate reservoir and confining zone isolation as required. 2. 1 believe the cement and FIT results were already provided. Do you need me to re send them in? I believe that covers the COA as specified in the 10-401. Is there anything else you need from me? Thanks, Adam Klem From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, July 28, 2017 10:15 AM To: Klem, Adam <Adam.Klem@conocophillips.com> Subject: [EXTERNAL]RE: 2K-30 top of cement Sonic/frac sundry Adam, Please see conditions of approval for running the sonic on the approved PTD. Would like to see your interpretation, final WBS and other info included in the conditions. Thanx, Victoria From: Klem, Adam[mailto:Adam.Klem@conocophillips.com] Sent: Tuesday, July 18, 2017 6:59 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Subject: 2K-30 top of cement Sonic Victoria, Here is the Sonic log on 2K-30 to go along with the frac sundry. Let me know if you need anything else. Adam Klem cum erger *Techlog Processed Interpretation $ '9 2 SonicScope• • of Cement Evaluation Recorded Mode Data: 9300 >1 12250 ft MD Scale 1:240 A, ��� �. C V w Q Q * A Mark of Schlun-berger 6 a COMPANY: ConocoPhillipsAlaska, Inc. a .5 6 WELL: 200 b N Fic:LD: Kuparuk River Unit .,,,ATE: Alaska _- COUNTRY United States ofAmerica .'9 Date Logged: 25 Jun 2017 99 Date Processed: 17 July 2017 . Surface Location : Longitude: -150.01675 Latitude: 70.241983 e 3 v Elevations: KB: Off DF: 154.91 ft GL: O ft o �a API Number: 50-103.20758-00.00 0 us lam Company: Conoco Phillips Alaska, Inc Well: 2K-30 Field: Kuparuk River Unit State: Alaska Country: USA Schlumberger � Sonic Scope TOC Evaluation THE STATE °'ALASKA GOVERNOR BILI. WALKER G.L. Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2K-30 ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-072 revised Alaska Oil and Gas Conservation Commission 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fox: 907.276.7542 www.00gcc.alaska.gov Surface Location: 139' FNL, 94' FEL, Sec. 11, TION, R08E, UM Bottomhole Location: 4830' FNL, 2134' FEL, Sec. 27, T10N, R08E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. / Commissioner DATED this Z y day of June, 2017. STATE OF ALASKA AL�ot(A OIL AND GAS CONSERVATION COMMk>oiON REVISION PERMIT TO DRILL 20 AAC 25.005 RECEIVE® JUN 14 2017 A M_nr % 1a. Type of Work: Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp Elic. Specify if weis pro os for: Drill ❑Q , Lateral ❑ 11b. Slratigraphic Test ❑ Development - Oil Ell Service- Winl ❑ Single Zone ❑� , Coalbed Gas ❑ Gas Hydrates ❑ Reddll ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket 0Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 Q KRU 2K-30 . 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 25291 TVD: 6485 Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 139' FNL, 94' FEL, Sec 11, T1 ON, R008E, UM ADL 25588, 25605, 25604, 25607 Kuparuk River Oil Pool - Top of Productive Horizon: 8. DNR Approval Number: 13, Approximate Spud Date: 1970' FNL, 116' FEL, Sec 15, T1 ON, R008E, UM 2674, 2675, 2677 2678 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4830' FNL, 2134' FEL, Sec 27, T10N, R008E, UM 10240 2133' from ADL 392952 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 154.7 r 15. Distance to Nearest Well Open Surface: x- 498310 y- 5938165 Zone- 4 GL / BF Elevation above MSL (ft): 115.7 to Same Pool: KRU 2K -21A: 705' 16. Deviated wells: Kickoff depth: 300 feet . 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91.3 degrees Downhole: 3142 • Surface: 2507 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling I Length MD TVD MD TVD (including stage data) 42" 20" 62.5# H-40 Welded 140' 39' 39' 179' 179' Driven 13.5" 10.75" 45.5# L-80 Hydril 563 3,274' 39' 39' 3313' 2845' 1436 sx 11# / 202 sx 12# DeepCRETE 11" 7.625" 29.7# L-80 Hydril 563 11,679' 39' 39' 11718' 6350' 552 sx 15.8 Class G 6.75" 4.5" 12.6# L-80 Hydril 563 13,723' 11568' 6334' 25291' 6485' Liner with Swell Packer/Frac Sleeves 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? YesO No ❑ 20. Attachments: Property Plat ❑ BOP SketchDrilling Diverter Sketch B Program Time v. Depth Plot Seabed Report 8 Drilling Fluid Program Shallow Hazard Analysis B 20 AAC 25.050 requirementse 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. - .-� Contact Name: Jacob Voss Authorized Name: G.L. Alvord Contact Email: 'Bke.VOSS Q'CO .Com Authorized Title: Drilling Manager e Contact Phone: 907-265-6935 / 0I q Authorized Signature: Date: Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number:Z(7-072- rewvse& 50-(03-207$e4-Oo-GG Date: (o -I-(`( requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methan5ll gas hydrates, or gas contained in shales:17- Other: 0 p , t-- t 9 rtss vre �-O 35-110 O $4 y Samples mq'd: Yes ❑ No /-/3Mud log req'd: Yes❑ NcZ -t- V V l er r p f c ve, k7 t< r La HzS measures: Yes No El Directional svy req'd: Yes Nr❑-,/ •�r%y t� S (iYG 2 576 0 PSI 4 Spacingexception req'd: Yes ❑ No V Inclination -only svy req'd: Yes❑ NgFir' I I 1� , Post initial injection MIT req'd: Yes❑ Nc n a c h t d // C OY2 CJI OYtS I rOVLL J 1 -StS al for rV nnlizt thG�f WD 6-6l'71C ✓ APPROVED BY W Z � I Approved by: ll COMMISSIONER THE COMMISSION Date: J A�r ' '� L7/ �n 1 /'� f A , Submit Form and F m 10-V,112 v 5/201 '*1�`6 11�e'rvY� i�lY�.l 2 months from the date of approval per 20 AAC 25.005(g) Attachments in Duplicate KRU 2K-30(PTD 217-072) Conditions of Approval: Approval is granted to run the LWD-Sonic on upcoming well KRU 2K-30 with the following provisions: 1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as soon as they become available. The evaluation is to include/highlight the intervals of competent cement (and lengths) that CPAI is using to meet the objective requirements for annular isolation, reservoir isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation is not acceptable. 2. LWD sonic logs must show free pipe and Top of Cement, just as the a -line log does. CPAI must start the log at a depth to insure the free pipe above the TOC is captured as well as the TOC. Starting the log below the actual TOC based on calculations predicting a different TOC will not be acceptable. 3. CPAI will provide a cement job summary report and evaluation along with the cement log and evaluation to the AOGCC when they become available 4. CPAI will provide the results of the FIT when available. 5. Depending on the cement job results indicated by the cement job report, the logs and the FIT, remedial measures or additional logging may be required. Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone(907)265-6935 Email: jake.vossCa�conocophillips.com June 13t11, 2016 Alaska Oil and Gas Conservation Commission 333 West Th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED JUN 14 2011 Application for Permit to Drill, Well 2K-30 `11 ConocoPhillips Re: Application for Permit to Drill Well 2K-30, A Kuparuk A4 Sand Producer Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a permit to drill an onshore grassroots producer well from the 2K pad. The expected spud date for this well is June 15th, 2017. It is planned to use rig Doyon 142. / 2K-30 is planned to be a horizontal well in the Kuparuk A4 sand. The surface section will be drilled with 13-1/2" bit and run 10-3/4" casing to +/-3,313' MD / 2,845' TVD. The intermediate section will be drilled with 9-7/8" x 11" bit/Under Reamer and run 7-5/8" casing to 11,717'MD / 6,350'TVD. The production hole will be drilled with 6-3/4" bit and run 4- 1/2" liner with frac sleeves/swell packers to +/- 25,291'MD / 6,485'TVD. The upper completion will be run with 3-1/2" tubing. This well will be frac'd post rig. This revision covers the change in TD due to additional lateral footage and adjustment of heel location for lateral orientation. ✓ Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Jake Voss at 265-6935 (fake.vossgconocoohillips.com) or Chip Alvord at 265-6120. Sincerely, Chip Alvord Drilling Manager Application for Permit to Drill Document Kuparuk Well 2K-30 Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as 2K-30 _ Drilling -� &Welts ConocoPhillips Location Summary Reauirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except jor an item already on file ,wtth the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the .surface. at the top of each objective formation. and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration: (C) the proposed depth of the it at the top of each objective formation and at total depth: Location at Surface 139' FNL, 94' FEL, Sec 11, TION, ROME, UM NGS Coordinates Northings: 5,938,165' Eastings: 498,310' RKBElevation 154.TAMSL Pad Elevation 115.7'AMSL Location at Top of 1970' FNL, 116' FEL, Sec 15, TION, R008E, UM Productive Interval Ku aruk A4 Sand NGSCoordinates Measured De th, RKB 1 11,717' Northings: 5,931,057' Eastings: 493, 013 1Total Vertical Death. RKB: 1 6350' Location at Total De th 4830' FNL, 2134' FEL, Sec 27, TION, ROME, UM NGS Coordinates Northings: 5,917,642' Eastings: 491,002' MeasuredDe th,RICB: 25,291' Total Vertical De th, RKB: 6,485' Total Vertical Depth, SS. 6,330' (D) other information required by 10 AAC 25.050(b); Requirements of 20 AAC 25.050(b) ja well is to be intentionally deviated, the application fora Permit to Drill (Form 10-401) must (1) include a plat, drown to a suitable scale, showing the path of the proposed wellbore, including all adjacent it ellbores within 200 feet of any portion of the proposed well: Please see Attachment: Directional Plan And (2) for all hells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells. to the extent that those nuns are known or discoverable in public records, and shot, that each named operator has been furnished a copy of the application by certified mail. m - (B) state that the applicant is the only affected mvner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application far a Permit to Drill must be accompanied by each of the following items, except for all item already on file with the commission and ident fed in the application.: (3) a diagram and description of the blo,out prevention equipment (ROPE) as required by 20 AAC 25.035, 10 AAC 25.036, or 10 AAC 15.037, as appltcable: Please reference BOP schematics on file for Doyon 142. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the, inline mg items. except for an item already on file with the commission and idem fed in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may he encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The maximum potential surface pressure (MPSP) while drilling 2K-30 is calculated using an estimated maximum reservoir pressure of 3,142 psi (10.0 ppg;rbased on 2K-21 development well on 4/25/17), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A4 sand at 6,350' TVD (WPI 1): A Sand Estimated. BHP = 3,142psi A Sand estimated depth (WP09) = 6,350' TVD Gas Gradient — 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 635 psi (6,350' TVD * 0.10 psi/ft) MPSP = BHP — gas column = 2,507psi (3,142 psi — 635 psi) (B) data on potential gas cones: The well bore is not expected to penetrate any shallow gas zones. And (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation cones, and cones that have a propensityfor differential sticking; See attached 2K-30 Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the follmring items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 15.0300; A procedure is on file with the commission for performing LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill most be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre -perforated liner. or screen to be installed Casing and Cement Program 18. Casing Program Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Flole Casing Weight Grade Coupling I Length MD ND MD ND (including stage data) 42" 20" 62.5# H-40 Welded 140' 39' 39' 179' 179' Riven 13.5" 10.75" 45.5# L-80 Hydril 563 3,274' 39' 39' 3313' 2845' 1436 sx 11#/ 202 sx 12# DeepCR 11" 7.625" 29.7# L-80 Hydril 563 11,679' 39' 39' 11718' 6350' 552 sx 15.8 Gass G 6.75" 4.5" 12.6# L-80 Fy ril 563 13,723' 11568' 6334' 25291' 6485' Liner w fth Swell Packer/Frac Sleeves 2K-3O_wp12 Cementing Schematic 9-7/8" x 11" Hole Kalubik 10,738' MD / 6,105' TVD Kuparuk A4 11,714' MD / 6,350' TVD , ................ . 6-3/4" Hole 20" Conductor to 140' 10-3/4" 45.5# L-80 HYD563 3,313 MD / 2,845' TVD @ 61' inc. .............................................. Top of Cement (top HRZ) .... 10,425' MD / 5,970'TV. D. 7-5/8" 29.7# L-80 HYD563 Casing 11,717' MD / 6,350' TVD @ 85- 4-1/2" Liner 11.6# L80 IBT 25,291 MD / 6,485' TVD 10-3/4" Surface casing run to 3,313' MD / 2,845' TVD Cement from 3313' MD to 2813'(500' of tail) with DeepCRETE @ 12 ppg, and from 2813' to surface with 11 ppg DeepCrete. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (1531' MD), zero excess in 20" conductor. 21K-30 Cement Calculations Surface Cement: Surface to 3,313' MID Hole Size ft(TOC) ft (Bottom) OD ID ppf Conductor Depth: 42 39 179 20 18.5 94 Surface Casing Depth: 13.5 39 3313 10.75 9.95 45.5 Intermediate Casing Depth: 11 10425 1 11717 7.625 6.875 29.7 = 3.673256 Length 500 ft 114 bbls 500 x Surface Cement: Surface to 3,313' MID Lead 1.84 ft3/ sx of 11.0 ppg DeepCRETE Capacities OH 0.177045 Tail 1.64 ft3/ sx of 12.0 DeepCRETE Permafrost (PF) depth 1531 ft 40% 13-1/2" x 103/4" 0.064783 XS% Above PF 250% 7-5/8" ST 20" x 10-3/4" 0.220213 XS% Below PF 50% Rathole Cement 2 x 10-3/4" 0.096175 Tail Cement Shoe Track 80 x 0.0459157 x 1 = 3.673256 Length 500 ft 114 bbls 500 x 0.06478288 x 1.5 48.6 Shoe Track 80 ft 554 sx 80 x 0.09617496 x 1 7.7 Open Hole 10 x 0.17704488 x 1.5 2.7 Total 59 bbl 331 ft3 202 sx Lead Top Tail Cement to Permafrost 1282 ft 1282 x 0.06478288 x 1.5 124.6 bbl Permafrost to 20" Casing 1352 ft 1352 x 0.06478288 x 3.5 306.6 bbl Conductor Length 80 ft 179 x 0.22021323 39.4 bbl Total: 471 bbl 2642 ft3 1436 sx 7-5/8" Intermediate casing run to 11,717' MD / 6,350' TVD Intermediate slurry designed to be at the top of HRZ at 10,425' MD/ 5,970' TVD which is 1288' MD / 380' TVD above the Kuparuk Oil Pool. Assume 40% excess annular volume. Intermediate 01 Cement: Cement from 11,717' MD to 10,425' MD SI urrv: Capacities: 15.8ppg Class G yieldi ng 1.16ftA3/sk 11"x7-5/8" 0.061064 XS%for open hole and annulus: 40% 11" OH 0.117544 7-5/8" ST 0.045916 Annulus Cement 1292 x 0.06106409 x 1.4 = 110.4527 bbls Rathole Cement 2 x 0.1175442 x 1.4 = 0.329124 bbls Shoe Track 80 x 0.0459157 x 1 = 3.673256 bbls Total 114 bbls 643 ft3 554 sx Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill most be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and descdptlon of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC25.035(17)(2); Please reference diverter schematic on file for Doyon 142. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill nuts! be accompanied by each of the following items, except for an item already on file with the commission and identified in the application.: (8) a drilling fluid program, including a diagram and description of the ddlling fluid system, as required by 20 AAC 25.033,• Mud Program Summary Diagram of Doyon 142 Mud System is on file with AOGCC. r/ Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (e)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) Surface Intermediate Production 13-1/2" Hole 9-7/8" x 11" Hole 6-3/4" Hole 10-3/4" Casing 7-5/8" Casing 4-1/2" Liner Mud System Spud (WBM) LSND FlowPro (WBM Density 8.6-10 9.2-10.8 9.5-11.0 PV 30-50 10-20 10-20 YP 40-80 16-24 16-24 Funnel Viscosity 200-300 N/A N/A Initial Gel 30-50 10-12 5 - 8 10 minute Gel 30-50 1 10-18 5-12 API Filtrate NC < 6 < 6 HTHP Fluid Loss at 160 F N/A < 10 < 10 H 9.0-10.0 9.0-10.0 9.5-10.0 Diagram of Doyon 142 Mud System is on file with AOGCC. r/ Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (e)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application jor a Permit to Drill must be accompanied by each of the following items. except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to attachment for proposed well schematic 1. Move in / rig up Doyon Rig 142. Install Annular with 16" diverter line and function test. 2. Spud and directionally drill 13.5" hole to casing point at +/- 3313' MD / 2,845' TVD as per directional plan (wp12). Survey with MWD, Gamma, GWD - / NOTE: Due to 2K-30 being a development well, Resistivity will not be used in surface hole similar to 2K-32. 3. Run and cement 10-3/4", 45.5#, L80, Hyd-563 casing to surface. Displace cement with mud. Evacuate top 2 feet of cement from annulus for sealant job (post rig.) 4. In the event cement returns are not seen at surface, perform a top job. Notify AOGCC if this occurs. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP'S to 3500 psi (annular preventer to 3500 psi) high and 250 psi low. Notify AOGCC 24 hrs before test. ✓ 6. PU 9-7/8" PDC bit and directional drilling assembly, with MWD/LWD (Gamma, resistivity). RIH and clean out to 100' above shoe. Test surface casing to 3500 psi for 30 minutes. 7. Drill out shoe track and 20' of new hole. Perform leak off test to a minimum of 13.0 ppg, maximum of 15 ppg EMW leak off, recording results. 8. Open 9-5/8" x 11" Under Reamer and directionally drill to the top of the C-37. 9. Perform Wiper trip to surface shoe and CBU until shakers are clean. 10. Install RCD bearing at this time for use of MPD if necessary. 11. Run back in hole to C-37. 12. Directionally drill to intermediate TD of 11,717 MD / 6,350' TVD, wellsite geologist will call intermediate TD. Circulate and rotate at maximum rates until shakers are clean, minimum of 3 bottoms up. 13. POOH on elevators. Closely monitor drag and address any problem areas by dropping below and circulating/rotating to clean up. 14. Lay down intermediate BHA and rack back 5" DP 15. Run 7-5/8", 29.7# L80, Hydril 563 casing from surface to TD at 11,717' MD. 16. Pump cementjob as per Schlumberger proposal. Top of cement to be -10,425' MD (top of HRZ formation OR approximately 1288 MD / 380' TVD above Kuparuk Pool), 17. Flush 10-3/4" x 7-5/8" annulus with water, followed by diesel to freeze protect. 18. Lay down 5" DP. 19. PU 4" DP, 6-3/4" bit, and drilling assembly with MWD/LWD (Gamma, resistivity, Periscope, and neutron density, SonicScope - Top of cement for Frac Sundry) 20. RIH and clean out cement to 100' above shoe. Test intermediate casing to 3500 psi for 30 minutes and chart. 21. Drill out shoe track and 20' of new hole. Perform formation integrity test to minimum of 13.0 ppg, maximum of 14.0 ppg EMW leak off, recording results. 22. Install RCD and swap mud over to 9.5 ppg FlowPro mud system 23. Directionally drill 6-3/4" hole geosteering through the Kuparuk A4 sand to TD -25,291' MD as per directional plan (wp 12). Hold back pressure on connections with MPD as needed. 24. Circulate hole clean and BROOH to shoe. Circulate hole clean and swap to KWF brine. POOH 25. Lay down production BHA. 26. PU and run 4-1/2", 11.6# liner. The top of liner will be placed at —11,568 MD, allowing for 150' of overlap in the 7-5/8" casing. 27. Set liner hanger. Slackoff and set liner top packer. 28. Monitor well for flow for 15 minutes 29. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes, chart results. 30. Flow check well for 30 minutes and POOH 31. Run 3-1/2" upper completion. 32. Nipple down BOPE, nipple up tree and test. 33. Freeze protect well with diesel and install BPV. 34. RDMO Please Note — This well will be frae'd. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application jar a Permit to Drill music be accompanied by each of the following items. except for an item already on file with the commission and identified in the application: (14) a general description of how the operatorplans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorisation under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (DS 1 B). All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Well Schematic Attachment 2 Diverter Layout Diagram Attachment 3 Directional Plan Attachment 4 Drilling Hazards Summary ir. *?, 7S x5,' BakerZ F.� PadrerMia: Lack titer Hanger i. 2K-30 (Gulper) Grassroots Horizontal A -Sand Producer Proposed Wellbore Schematic(wp12) 0.W too,, by joint is 45.12 W IBTM 20' Conductor to -140' 3-%" x T' GaMCO KBMG GLM surface CaSinu 10-3/4" 45.5# L-80 Hydril 563 3,313'MD/2,845'TVD(61- INC) GLM W/SOV Tubing 3-112- 9.3 # L-80 EUE 8RD-MOD Fa ue: — 9755' MD 3%" 2.75 D Nipple ConocoPhillips Last Edited: Voss 6/13/1 13.5" Surface Hole Top West Sak: 2321' MDI 21"' TVD Base West Sak: 3315' MD12742' TVD 9-7/8" x 11" Intermediate Hole C-37: 8460 MO 151 10'TVD C-35:9755' MD 1567W TVD HRZ: 10425 MD/ 5970' TVD Kaluaik: 1073V MD/ 6105' TVD Ktgwuk A4:11713' MD 16350' TVD I ....... ....... NIEL--------- f.......... 1-w__. ...... M....p..... _. TD: 25 291' MD 16.485' TVD IntermediateCasinO Production Liner: 6-3/4" Production Hol 7-5/8" 29.7# L-80 Hyd563 Casing 4112" 12.6# L-80 Hydril 563 11,717' MD / 6,350' ND (85" INC) 25,291' MD / 6,485' ND Trm�bm. a SCALE 100 0 50 100 SITE )> TITLE: DRILL 511E 2K Inc. DRANK BY: MRET MN] DATE: 03-29-2017 BEV: 1 2..'2 5 4 1. 271 SITE )> TITLE: DRILL 511E 2K Inc. DRANK BY: MRET MN] DATE: 03-29-2017 BEV: 1 2K-30 Drilling Hazards Summary 13-1/2" Hole / 10-3/4" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, Additions of Lecithin. Anti -collision High Due to the P&A of 2K-16, 2K-30 is 511 away from 2K -16's existing High ECD and swabbing with higher Low surface location. The well fails anti -collision and requires a TCA. Run M W's required Gyro While Drilling as needed for magnetic interference and to mitigate AC issues. Gravel / Sand Sloughing Low Increase mud weight / viscosity, High viscosity sweeps. Monitor fill on connections. Hole Swabbing / Tight Hole on Trips Moderate Circulate hole clean prior to trip. Proper hole fill (use of trip sheets), Pumping out of hole as needed. Lost circulation Moderate Prevent by keeping hole clean. If losses occur - reduce pump rates and Hole cleaning Low mud theology, use LCM Unsuccessful cementjob Moderate Use lower density cement slurry. Due to subsidence— offsite 2K wells Anti -collision High have had to perform top 'obs. Use LCM in slurry as needed. 9-7/8" x 11" Hole/ 7-5/8" Casing Interval Event Risk Level Mitigation Strategy Shale stability Moderate For the unstable HRZ and Kalubik shales with high inclination control MW's required with higher MW and proper tripping practices to avoid surging or swabbing. Minimize pressure cycling by stripping out using MPD to Abnormal Reservoir Pressure Moderate eliminate swab. High ECD and swabbing with higher Low Condition mud prior to trips. Monitor ECD's with PWD tool while M W's required drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Lost circulation Low Use PWD and TAD to monitor hole cleaning. Reduced pump rates, adjust mud rheology, add LCM. Use GKA LCM decision tree. Keep ECD below known frac gradient of -12.0 -12.5 ppg. In event that overburden cannot be strengthened to —12 ppg FG, top setting is back Stuck pipe Moderate up plan for 2K-30. Hole cleaning Low Use PWD and TAD to monitor hole cleaning. Control the ROP and use Hole swabbing on trips Moderate the best hole cleanin practice. Anti -collision High Due to the landing area of 2K-30 with regards to 2K -21A, the well path fails anti -collision. This is due to tool error uncertainty; however, when 2K-30 passes over the top of 2K-21 A, it will be above the Kupamk A4 reservoir and with logging data we will be geologically certain that we will not hit 2K -21A. 2K-30 passes over 2K -21A while it is drilling the Kalubik formation around 11,000' to 11,100' MD. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is higher than expected. BHP of 2K -21A was taken in April at 10.0 ppg EMW. Well has been on production to help aid in drawdown while offset injectors are off. 6-3/4" Hole / 4-1/2" Liner Interval Event Risk Level Mitigation Stra!tgy High ECD and swabbing with higher Moderate Condition mud prior to trips. Monitor ECU's with PWD tool while MW's required drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is hi her than expected. Lost Circulation Moderate Use PWD and TAD to monitor hole cleaning. Reduced pump rates, adjust mud rheology, add LCM. Use GKA LC decision tree. Use of MPD will allow lower mud weights to reduce ECD while shutting on connections to prevent my potential influx. Stuck pipe Moderate Good hole cleaning, stabilized BHA, proper mud weight to minimize differential stuck, PWD monitor ECD. Hole swabbing on trips Moderate Monitor proper hole till while tripping, good hole cleaning. Backream out to intermediate shoe, then utilize MPD to strip out and eliminate swab. 2K-30wpl27DD02 Plan Summary S-Top WS-Rase 'm C P_SST e fm C-80co � n ,50 1 C-37 HR 1N �-40 A1C-35 0 i 0- -0 0 6000 12000 MOOD 24000 2D' x aT 10 &4" x 13-1 Measured Depth o _ _ 21Y x 42' Geodetic Dann, Depth Reference: Plan: 39 + 115.7 @ 154+0ush (DO M42) ppp��00 Rig: Doyonl42 10 &4' x 13-t c o - y A on F 0 2500 5000 7500 10000 12500 1!M0CB 97500 20000 22500 0 39 300 Horizontal Departure 30p - a90 - 93030 4% 670 ��.. ,. 670 - 860 660 - 1040 60 1040 - 1230 35 60 1216 - 1410 1410 - 1600 n +59 - 2590 �' I zs93 3seo v 30 -- _-- -., 3560 - a55 o 2]0 m 4510 - 5550 552 - G 0 C 8540 - ]520 1.j 7520 - 8510 'xj05 es0 - es5 9500 - 1147 0 3500 7000 10500 14000 17500 21000 240 120 11470 - 134 SURVEY PROGRAM Surface Location 13,150 - t epth From Depth To Survey/Plan Tool North / Y: Isar - 17 - 39.2 1200.00 2K-3IMP12 (Plan: 2K-30) GYD-GC-SS East/ X: 210 190 1745 1.5 12X.00 2200.00 2K-30ep12(Plzn: 2K30) MWD Pad Elevation: 11570 193M 213 25r)0.00 3313.4 2K30M12(PIan: 2K-30) MWD+IFR-AK-CAZSC lea 21340 239 3313.04 4813.04 2K30ap12(Plan: 2K-30) MWD CASING DETAILS 23320 - 25251 3313.04 11]1].54 2K-30M12 (Plan: 2K-30) MWD+IFR-AK4AZSC TVD MD Name 111111 11717.54 1321].54 2K-305 12(Plan: 2K-30) MWD 116.20 116.20 20'x42" Ma9nelic*WM: BGGM-16 T 11717.54 25291.41 2K-30.p12(Plan: 2K-30) MMD+IFR-AK-CAZSC 2844.70 3313.04 III 3/4"x13-1/a WI is Model Date: 25,rm-17 634970 11]1].54 7-Wx9-7B"by II- Ma9na1ic Oec9ne8an: 17.43° 6484.]0 25291.41 41/2"x63/4" Toco ena Mapnebc Dir iontoaTme De ion,Mdl7.Q-East SECTION DETAILS ec MD Inc Azi WD +N/-S +E/-W Oleg TFace VSect Target Annotation 1 39.W 0.03 0.03 39.00 0.03 0.00 0.W 0.00 0.00 2 3X.00 0. W 0. W 300.0 0.00 0.00 0.00 0.0 0.00 KOP: Start 1.511 W' DLS, 255'T5 for W0 1504.7 3 82.00 7.50 255.2 798.57 -6.46 -31.56 1.50 255.00 13.81 Siad 211W DLS, -25'75 for 877.61' 4 147/.61 20.59 238.64 1454.70 -82.25 -176.71 2.00 -25.00 111.68 Hold for 1W,82' Bsse 1 ermal,on 5 1584.43 20.59 238.64 1554.70 -101.80 -208.79 0.00 0.00 136.51 ShK 2.5112' DIS, 35°T5 for 1728.61' 6 3313.04 W.99 211.96 2 1.7. .941,15 -X1.60 2.50 -35.00 1083+0 Hold for 28 21987 7 3333.04 60.99 211.96 2854.40 -956.29 -910.86 0.00 0.00 1099.93 Start 2.51100' DIS, W.99' TF, for 229.1 a' Ws_Top 8 %62.19 63.88 21].54 2960.49 -1123.01 -1026.67 2.50 60.99 1284.23 Hold for 702324' 9 105116.03 63.88 21754 W52.44 -6123.93 -4869.19 0.00 0.00 6876,12 Start 311W DIS,-539' T5for 1131.51' 2741.7 10 11717.54 86.W 190.65 6349.70 -7110.42 -5295.53 3.03 -53.90 7921.96 2K-3001.Heel 022417 JM Hold for 20 WS ease 11 11737.54 8600 190.65 6351.10 -7130.2 -5299.21 0.00 0.00 7941.91 Stmt 311 W' DIS. 0-TF, for 106.48 1211844.01 Sale 190.65 6355.56 -]234.5] -5318.87 3.00 0.00 8W.27 Hold for 171626' 13 13560.87 89.19 190.65 63]9.]0 2921+0 -5636.06 0.00 0.00 9764.85 21K30 02. Prefautt in A4 06W17 JM SW 311 W' DU3. 179.12' TF, for 47.23' 14 13608.10 87.70 190.67 632.95 -8968.0* -5641+9 3.00 179.12 9812.05 Hold for 870.44' 15 14478.53 87+8 190.67 6414+0 -9822.83 -525.83 0.00 0.0010681.78 2K30 03. Post cult m A4 M817 JM Shot 0.131100' DIS. -54.45'75 for 4129.33' CAMP SST 16 18607.87 90.81 186.43 6465.53 13904.57 -6419.40 0.13 ,54.4514806.05 Hold for 1117.18 17 19724.99 90.81 186.43 6449]0 -15014.56 -6544.48 0.00 0. W 15922.89 2K-W 60. PrefauB in A4 060817 JM Start 311W DM, 103.5]' T5 for 104.2' 18 19829.07 90.24 189.50 6448.75-1511].62 -6558.89 3.00 100.571226.89 Hold for 971,12' 19 2020.49 90.24 189.50 6444+0-16075.71 -6719.20 0.00 0.001298.26 2K3005. Postfault in C 0608 17 JM Start 371 W' DLS, -11 an' TF, for 72.67' 4sen7 0.50 20 208]3.16 89.48 187.45 6444.88 -16147.58 -6729.91 3.00 -110.261]070.90 Hold for 4418.25' 48¢ 4,.) 21 25291.41 89AB 187.45 6484.70 -2(1528.32 -7303.04 0.00 0.0021484.2 2K-W OB.Toe W0817 JM TD: 25291.41' MD, "BBT WD St O�S'/0 2K-16 Minor Risked at 56037 ]5.] 1 in 100. 0.35 Minor Risked zSE 2K-21A Minor Risked � rcuP_A4 at 1 in 500. x�,.�.,,...... ........... Prepared by: ......................... - ....... Checked 6Y: ""'""°'°°""""0"" Aaept� by: Efl( Stark Approved by: B. Temple �¢��f�, �e¢ intent Osara 4^�=� 11'1 E. 468313 ;..:)ak2 a�...,�,m�, �d..,d �•".,,,.. 6 V. Osara Stark J. Voss Spider View 13 2M-32L1PB1 LCL1 2S-14-2M32L1PB2 � 2M-34 2 -7M -9A11 2M-35 [2M2S-1108L1 2S -09A 2S-04 2S-07 2S-05' 2$-09 /Kuparuk 2S Pa f 2S-02 25-12 2S-03PB1 L 2S-01 1 `2508 / 25-10 Prelim: Kuparuk Cairn Pad2 2S -o3 J `2S06 Easting (3500 usNin) 2M-09 -.00HIM. Kuparuk 2K 2K-32 2K-07 2K-15—- 2K-26 2-8 K *1'\ 1 1 K'@i) 2K-18 IC4l 2K-23 K 0 2K -22A 2K -28A 1 2K-25 2K-21 2K-22 2K-24 `—'2K�30WP12 Fasting (3500 us(Uin) 2K-22AL1-01 2K-22AL1 Plan View 2K-30wp12 Plan View 4000- 000k10 '10 �h b 0 -,-2 X42" t5-4000 o -- ry 2 2y a 7-5/8" x 9 18" b 1200 00 ±,-8000 r 73000 _ K 22 z 14000 s 15000 a12000 16000 17000 18000 19000 -16000 20000 21000 22000 23000 24000 2K-30wp 12 -20000 4 1/2" x 6-3/4"- _ -20000 -16000 -12000 -8000 -4000 0 4000 8000 12000 16000 West( -)/East(+) (4000 usft/in) Section View 2K-30wp12 1 Section View 0 2500 5000 7500 10000 12500 15000 17500 20000 Vertical Section at 190.00°(2500 usft/in) 20" x 42" Base Permafrost 0 __ - WS_Top c Oe___--- ? 1oo& _ WS -Base CAMP_SST o"-- aper a 2500 aC-BN-----103/4"x13-1/2 �- o .-- - — - --o0 C-50 00 ®o 7-5/8" x 9-7/8" b 11" Y 4 1/2" x 6-3/4" C-40� o00 0 r- 5000 - = C 37 o 0 P� 00 0� 0 0 0 0 0 0 0 - -C35HRZ o0 ,• o oN o m �o N 0 0 om m a vr�.n HRZ_BASE o o 7500 , - K_1 0 0 0 0 J(UP_C KUP_A5 KUP_A4 2K-30 02. Prefault in A4 060817 M "• 2K-30 04. Prefault in A4 060817 2K-30 06.Toe 060817 10000 2K-30 01.Heel 022417 JI 12K-30 03. Postfault in A4 060817 M 2K-30 05. Postfault in C 060817 0 2500 5000 7500 10000 12500 15000 17500 20000 Vertical Section at 190.00°(2500 usft/in) Plan Report ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad Plan: 2K-30 Plan: 2K-30 Plan: 2K-30wpl2 Report 13 June, 2017 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: Plan: 2K-30 Wellbore: Plan: 2K-30 Design: 2K-30wpl2 Schlumberger Report Local Co-ordinate Reference: Well Plan: 2K-30 TVD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) MD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kupamk 2K Pad Site Position: From: Map Position Uncertainty: Well Plan: 2K-30 Well Position +N/ -S +E/ -W Position Uncertainty Northing: Easting: 0.00 usft Slot Radius: 0.00 usft Northing: 0.00 usft Easting: 0.00 usft Wellhead Elevation: Wellbore Plan: 2K-30 Magnetics Model Name Sample Date Declination (") BGGM2016 6125/2017 Design 2K-30wpl2 39.00 +EI -W Audit Notes: (usft) (°) Version: Phase: PLAN Vertical Section: Depth From (TVD) +N/ -S 2,500.00 (usft) (usft) MWD+IFR AK CAZ SCC 39.00 0.00 Survey Tool Program Date 6/8/2017 From To Latitude: Longitude: 0" Grid Convergence: -0.02 Latitude: Longitude: 0.00 usft Ground Level: 115.70 usft Dip Angle (°) 1743 Field Strength (nT) 80.86 57,528 Tie On Depth: 39.00 +EI -W Direction (usft) (°) 0.00 190.00 (usft) (usft) Survey (Wellbore) Tool Name Description 39.00 1,200.00 2K-30wpl2 (Plan: 2K-30) GYD-GC-SS Gyrodata gyro single shots 1,200.00 2,200.00 2K-30wpl2 (Plan: 2K-30) MWD MWD - Standard 2,500.00 3,313.04 2K-30wpl2 (Plan: 2K-30) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3,313.04 4,813.04 2K-30wpl2 (Plan: 2K-30) MWD MWD -Standard 3,313.04 11,717.54 2K-30wpl2 (Plan: 2K-30) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11,717.54 13,217.54 2K-30wpl2 (Plan: 2K-30) MWD MWD - Standard 11,717.54 25,291.41 2K-30wp12 (Plan: 2K-30) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (°) (") (usft) (usft) (°/100usft) (°) (usft) 39.00 0.00 0.00 39.00 -115.70 0.00 0.00 0.00 100.00 0.00 0.00 100.00 -54.70 0.00 0.00 0.04 116.20 0.00 0.00 116.20 -38.50 0.00 0.00 0.19 20" x 42" 200.00 0.00 0.00 200.00 45.30 0.00 0.00 0.19 300.00 0.00 0.00 300.00 145.30 0.00 0.00 0.33 KOP: Start 1.5°/100' DLS, 255° TF, for 500'- KOP: Start 1.5°1100' DLS, 2550 TF, for 500' 6/132017 9:21:26AM Page 2 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well Plan: 2K-30 Project: Kuparuk River Unit TVD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyonl42) Site: Kuparuk 2K Pad MD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) Well: Plan: 2K-30 North Reference: True Wellbore: Plan: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30wpl2 Database: OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (°) (°) (usft) (usft) (°/I00usft) (°) (usft) 400.00 1.50 255.00 399.99 245.29 1.50 255.00 0.44 500.00 3.00 255.00 499.91 345.21 1.50 0.00 0.53 600.00 4.50 255.00 599.69 444.99 1.50 0.00 0.65 700.00 6.00 255.00 699.27 544.57 1.50 0.00 0.78 800.00 7.50 255.00 798.57 643.87 1.50 0.00 0.92 Start 2°1100' DLS, -25° TF, for 677.61' 900.00 9.35 249.79 897.49 742.79 2.00 -25.00 1.07 1,000.00 11.25 246.31 995.88 841.18 2.00 -19.85 1.23 1,100.00 13.18 243.83 1,093.61 938.91 2.00 -16.42 1.40 1,200.00 15.13 241.98 1,190.57 1,035.87 2.00 -14.00 1.58 1,300.00 17.09 240.54 1,286.63 1,131.93 2.00 -12.20 1.70 1,400.00 19.06 239.39 1,381.70 1,227.00 2.00 -10.82 1.82 1,477.61 20.59 238.64 1,454.70 1,300.00 2.00 -9.73 2.02 Hold for 106.82' - Hold for 106.82' 1,500.00 20.59 238.64 1,475.66 1,320.96 0.00 0.00 2.09 1,531.02 20.59 238.64 1,504.70 1,350.00 0.00 0.00 2.40 Base Permafrost 1,584.43 20.59 238.64 1,554.70 1,400.00 0.00 0.00 2.40 Start 2.5°/100' DLS, -35° TF, for 1728.61' 1,600.00 20.91 238.02 1,569.26 1,414.56 2.50 -35.00 2.46 1,700.00 23.01 234.40 1,662.00 1,507.30 2.50 -34.42 2.88 1,800.00 25.19 231.37 1,753.28 1,598.58 2.50 -31.06 3.39 1,900.00 27.41 228.80 1,842.93 1,688.23 2.50 -28.29 3.97 2,000.00 29.68 226.59 1,930.77 1,776.07 2.50 -25.99 4.62 2,100.00 31.98 224.66 2,016.64 1,861.94 2.50 -24.04 5.33 2,200.00 34.30 222.97 2,100.37 1,945.67 2.50 -22.39 6.10 2,300.00 36.64 221.47 2,181.81 2,027.11 2.50 -20.98 6.93 2,321.12 37.14 221.18 2,198.70 2,044.00 2.50 -19.75 7.81 WS Top 2,400.00 39.00 220.13 2,260.79 2,106.09 2.50 -19.52 7.81 2,500.00 41.38 218.92 2,337.18 2,182.48 2.50 -18.69 8.33 2,600.00 43.76 217.82 2,410.82 2,256.12 2.50 -17.77 8.49 2,700.00 46.16 216.81 2,481.57 2,326.87 2.50 -16.96 8.67 2,800.00 48.56 215.87 2,549.30 2,394.60 2.50 -16.24 8.88 2,900.00 50.98 215.01 2,613.88 2,459.18 2.50 -15.61 9.12 3,000.00 53.39 214.20 2,675.19 2,520.49 2.50 -15.05 9.38 3,100.00 55.82 213.44 2,733.11 2,578.41 2.50 -14.55 9.67 3,115.36 56.19 213.33 2,741.70 2,587.00 2.50 -14.11 9.98 WS Base 3,200.00 58.24 212.72 2,787.53 2,632.83 2.50 -14.05 9.98 3,300.00 60.67 212.04 2,838.34 2,683.64 2.50 -13.72 10.32 3,313.04 60.99 211.96 2,844.70 2,690.00 2.50 -13.38 10.39 Hold for 20'- 10 3/4" x 13-1/2 3,333.04 60.99 211.96 2,854.40 2,699.70 0.00 0.00 10.55 Start 2.5°/100' DLS, 60.99° TF, for 229.14' 6/132017 921:26AM Page 3 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: Plan: 2K-30 Wellbore: Plan: 2K-30 Design: 2K-30wp12 Planned Survey Schlumberger Report Local Co-ordinate Reference: Well Plan: 2K-30 TVD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyonl42) MD Reference: Plan: 39 + 115.7 @ 154.70usft (Dcyonl42) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 MD Inc Azl (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (°) (°) (usft) (usft) (°PI Dousft) (") (usft) 3,400.00 61.81 213.62 2,886.45 2,731.75 2.50 60.99 11.17 3,500.00 63.08 216.05 2,932.72 2,778.02 2.50 60.19 12.17 3,562.19 63.88 217.54 2,960.49 2,805.79 2.50 59.06 12.83 Hold for 7023.84' 3,600.00 63.88 217.54 2,977.13 2,822.43 0.00 0.00 13.21 3,700.00 63.88 217.54 3,021.15 2,866.45 0.00 0.00 14.25 3,800.00 63.88 217.54 3,065.17 2,910.47 0.00 0.00 15.34 3,900.00 63.88 217.54 3,109.20 2,954.50 0.00 0.00 16.46 4,000.00 63.88 217.54 3,153.22 2,998.52 0.00 0.00 17.62 4,100.00 63.88 217.54 3,197.24 3,042.54 0.00 0.00 18.81 4,123.77 63.88 217.54 3,207.70 3,053.00 0.00 0.00 20.01 C-80 4,200.00 63.88 217.54 3,241.26 3,086.56 0.00 0.00 20.01 4,287.33 63.88 217.54 3,279.70 3,125.00 0.00 0.00 21.24 CAMP SST 4,300.00 63.88 217.54 3,285.28 3,130.58 0.00 0.00 21.24 4,400.00 63.88 217.54 3,329.30 3,174.60 0.00 0.00 22.48 4,500.00 63.88 217.54 3,373.32 3,218.62 0.00 0.00 23.73 4,600.00 63.88 217.54 3,417.34 3,262.64 0.00 0.00 24.99 4,700.00 63.88 217.54 3,461.36 3,306.66 0.00 0.00 26.27 4,800.00 63.88 217.54 3,505.38 3,350.68 0.00 0.00 27.55 4,900.00 63.88 217.54 3,549.40 3,394.70 0.00 0.00 16.09 5,000.00 63.88 217.54 3,593.42 3,438.72 0.00 0.00 16.52 5,100.00 63.88 217.54 3,637.45 3,482.75 0.00 0.00 16.96 5,200.00 63.88 217.54 3,681.47 3,526.77 0.00 0.00 17.41 5,300.00 63.88 217.54 3,725.49 3,570.79 0.00 0.00 17.86 5,400.00 63.88 217.54 3,769.51 3,614.81 0.00 0.00 18.31 5,500.00 63.88 217.54 3,813.53 3,658.83 0.00 0.00 18.77 5,600.00 63.88 217.54 3,857.55 3,702.85 0.00 0.00 19.24 5,700.00 63.88 217.54 3,901.57 3,746.87 0.00 0.00 19.71 5,800.00 63.88 217.54 3,945.59 3,790.89 0.00 0.00 20.18 5,900.00 63.88 217.54 3,989.61 3,834.91 0.00 0.00 20.65 6,000.00 63.88 217.54 4,033.63 3,878.93 0.00 0.00 21.13 6,100.00 63.88 217.54 4,077.65 3,922.95 0.00 0.00 21.61 6,200.00 63.88 217.54 4,121.67 3,966.97 0.00 0.00 22.09 6,300.00 63.88 217.54 4,165.69 4,010.99 0.00 0.00 22.58 6,400.00 63.88 217.54 4,209.72 4,055.02 0.00 0.00 23.07 6,500.00 63.88 217.54 4,253.74 4,099.04 0.00 0.00 23.56 6,600.00 63.88 217.54 4,297.76 4,143.06 0.00 0.00 24.05 6,700.00 63.88 217.54 4,341.78 4,187.08 0.00 0.00 24.54 6,800.00 63.88 217.54 4,385.80 4,231.10 0.00 0.00 25.04 6,900.00 63.88 217.54 4,429.82 4,275.12 0.00 0.00 25.53 7,000.00 63.88 217.54 4,473.84 4,319.14 0.00 0.00 26.03 7,100.00 63.88 217.54 4,517.86 4,363.16 0.00 0.00 26.53 7,200.00 63.88 217.54 4,561.88 4,407.18 0.00 0.00 27.04 61132017 9:21:26AM Page 4 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: Plan: 2K-30 Wellbore: Plan: 2K-30 Design: 2K-30wp12 Planned Survey MD Inc Azi (azimuth) (usft) Plan: 39 + 115.7 @ 154.70usft (Doyon142) North Reference: 7,251.83 63.88 217.54 C-50 Minimum Curvature 7,300.00 63.88 217.54 7,400.00 63.88 217.54 7,500.00 63.88 217.54 7,600.00 63.88 217.54 7,700.00 63.88 217.54 7,800.00 63.88 217.54 7,900.00 63.88 217.54 7,933.33 63.88 217.54 C-40 4,451.20 0.00 8,000.00 63.88 217.54 8,100.00 63.88 217.54 8,200.00 63.88 217.54 8,300.00 63.88 217.54 8,400.00 63.88 217.54 8,444.45 63.88 217.54 C-37 0.00 0.00 8,500.00 63.88 217.54 8,600.00 63.88 217.54 8,700.00 63.88 217.54 8,800.00 63.88 217.54 8,900.00 63.88 217.54 9,000.00 63.88 217.54 9,100.00 63.88 217.54 9,200.00 63.88 217.54 9,300.00 63.88 217.54 9,400.00 63.88 217.54 9,500.00 63.88 217.54 9,600.00 63.88 217.54 9,700.00 63.88 217.54 9,730.21 63.88 217.54 C-35 0.00 0.00 9,800.00 63.88 217.54 9,900.00 63.88 217.54 10,000.00 63.88 217.54 10,100.00 63.88 217.54 10,200.00 63.88 217.54 10,300.00 63.88 217.54 10,398.07 63.88 217.54 HRZ 5,155.54 0.00 10,400.00 63.88 217.54 10,500.00 63.88 217.54 10,586.03 63.88 217.54 Start 3°1100' DLS, -53.9° TF, for 1131.51' Schlumberger Report Local Coordinate Reference: Well Plan: 2K-30 TVD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) MD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 TVD TVDSS DLeg TFace Lat. Error (usft) Neff) (°I100usft) (°) (usft) 4,584.70 4,430.00 0.00 0.00 27.54 4,605.90 4,451.20 0.00 0.00 27.54 4,649.92 4,495.22 0.00 0.00 28.04 4,693.94 4,539.24 0.00 0.00 28.55 4,737.97 4,583.27 0.00 0.00 29.06 4,781.99 4,627.29 0.00 0.00 29.56 4,826.01 4,671.31 0.00 0.00 30.07 4,870.03 4,715.33 0.00 0.00 30.58 4,884.70 4,730.00 0.00 0.00 31.09 4,914.05 4,759.35 0.00 0.00 31.09 4,958.07 4,803.37 0.00 0.00 31.61 5,002.09 4,847.39 0.00 0.00 32.12 5,046.11 4,891.41 0.00 0.00 32.63 5,090.13 4,935.43 0.00 0.00 33.15 5,109.70 4,955.00 0.00 0.00 33.66 5,134.15 4,979.45 0.00 0.00 33.66 5,178.17 5,023.47 0.00 0.00 34.18 5,222.19 5,067.49 0.00 0.00 34.69 5,266.22 5,111.52 0.00 0.00 35.21 5,310.24 5,155.54 0.00 0.00 35.73 5,354.26 5,199.56 0.00 0.00 36.25 5,398.28 5,243.58 0.00 0.00 36.76 5,442.30 5,287.60 0.00 0.00 37.28 5,486.32 5,331.62 0.00 0.00 37.80 5,530.34 5,375.64 0.00 0.00 38.32 5,574.36 5,419.66 0.00 0.00 38.84 5,618.38 5,463.68 0.00 0.00 39.37 5,662.40 5,507.70 0.00 0.00 39.89 5,675.70 5,521.00 0.00 0.00 40.41 5,706.42 5,551.72 0.00 0.00 40.41 5,750.44 5,595.74 0.00 0.00 40.93 5,794.46 5,639.76 0.00 0.00 41.45 5,838.49 5,683.79 0.00 0.00 41.98 5,882.51 5,727.81 0.00 0.00 42.50 5,926.53 5,771.83 0.00 0.00 43.02 5,969.70 5,815.00 0.00 0.00 43.55 5,970.55 5,815.85 0.00 0.00 43.55 6,014.57 5,859.87 0.00 0.00 44.07 6,052.44 5,897.74 0.00 0.00 44.53 6/132017 9:21:26AM Page 5 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2K-30 Project: Kuparuk River Unit TVD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyonl42) Site: Kuparuk 2K Pad MD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyonl42) Well: Plan: 2K-30 North Reference: True Wellbore: Plan: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30wpl2 Database: OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (°) (°) (usft) (usft) (°NOOusft) (°) (usft) 10,600.00 64.13 217.16 6,058.56 5,903.86 3.00 -53.90 44.58 10,700.00 65.93 214.51 6,100.78 5,946.08 3.00 -53.73 44.86 10,709.64 66.10 214.26 6,104.70 5,950.00 3.00 -52.61 45.06 HRZ_BASE 10,800.00 67.77 211.94 6,140.10 5,985.40 3.00 -52.51 45.06 10,900.00 69.65 209.43 6,176.41 6,021.71 3.00 -51.60 45.19 10,935.94 70.34 208.54 6,188.70 6,034.00 3.00 -50.69 45.24 K-1 11,000.00 71.57 206.98 6,209.61 6,054.91 3.00 -50.39 45.24 11,100.00 73.52 204.59 6,239.60 6,084.90 3.00 -49.88 45.23 11,200.00 75.49 202.25 6,266.32 6,111.62 3.00 49.16 45.15 11,300.00 77.49 199.95 6,289.68 6,134.98 3.00 48.54 45.02 11,323.62 77.97 199.41 6,294.70 6,140.00 3.00 -48.00 44.83 KUP C 11,400.00 79.51 197.68 6,309.62 6,154.92 3.00 -47.88 44.83 11,490.69 81.35 195.65 6,324.70 6,170.00 3.00 -47.55 44.59 KUP A5 11,500.00 81.54 195.44 6,326.08 6,171.38 3.00 47.21 44.59 11,600.00 83.58 193.23 6,339.03 6,184.33 3.00 47.18 44.30 11,700.00 85.64 191.03 6,348.42 6,193.72 3.00 46.89 43.95 11,717.54 86.00 190.65 6,349.70 6,195.00 3.00 -46.68 43.89 Hold for 20'- KUP-A4 - 7-818" x 9-718" by 11" 11,737.54 86.00 190.65 6,351.10 6,196.40 0.00 0.00 44.01 Start 3°1100' DLS, 0° TF, for 106.48' 11,800.00 87.87 190.65 6,354.43 6,199.73 3.00 0.00 44.50 11,844.01 89.19 190.65 6,355.56 6,200.86 3.00 0.00 44.86 Hold for 1716.86' 11,900.00 89.19 190.65 6,356.35 6,201.65 0.00 -19.25 45.32 12,000.00 89.19 190.65 6,357.75 6,203.05 0.00 0.00 46.18 12,100.00 89.19 190.65 6,359.16 6,204.46 0.00 0.00 47.06 12,200.00 89.19 190.65 6,360.56 6,205.86 0.00 0.00 47.97 12,300.00 89.19 190.65 6,361.97 6,207.27 0.00 0.00 48.91 12,400.00 89.19 190.65 6,363.38 6,208.68 0.00 0.00 49.88 12,500.00 89.19 190.65 6,364.78 6,210.08 0.00 0.00 50.87 12,600.00 89.19 190.65 6,366.19 6,211.49 0.00 0.00 51.88 12,700.00 89.19 190.65 6,367.59 6,212.89 0.00 0.00 52.91 12,800.00 89.19 190.65 6,369.00 6,214.30 0.00 0.00 53.97 12,900.00 89.19 190.65 6,370.41 6,215.71 0.00 0.00 55.04 13,000.00 89.19 190.65 6,371.81 6,217.11 0.00 0.00 56.14 13,100.00 89.19 190.65 6,373.22 6,218.52 0.00 0.00 57.25 13,200.00 89.19 190.65 6,374.63 6,219.93 0.00 0.00 58.37 13,300.00 89.19 190.65 6,376.03 6,221.33 0.00 0.00 48.26 13,400.00 89.19 190.65 6,377.44 6,222.74 0.00 0.00 48.58 13,500.00 89.19 190.65 6,378.84 6,224.14 0.00 0.00 48.90 6/132017 9:21:26AM Page 6 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well Plan: 2K-30 Project: Kuparuk River Unit TVD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) Site: Kuparuk 2K Pad MD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) Well: Plan: 2K-30 North Reference: True Wellbore: Plan: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30wpl2 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (0) (1 (usft) (usft) (°/100usft) V) (usft) 13,560.87 89.19 190.65 6,379.70 6,225.00 0.00 0.00 49.10 Start 3°1100' DLS, 179.12° TF, for 47.23' 13,600.00 88.02 190.67 6,380.65 6,225.95 3.00 179.12 49.21 13,608.10 87.78 190.67 6,380.95 6,226.25 3.00 179.11 49.23 Hold for 870.44' 13,700.00 87.78 190.67 6,384.51 6,229.81 0.00 -148.47 49.46 13,800.00 87.78 190.67 6,388.39 6,233.69 0.00 0.00 49.79 13,900.00 87.78 190.67 6,392.27 6,237.57 0.00 0.00 50.13 14,000.00 87.78 190.67 6,396.14 6,241.44 0.00 0.00 50.47 14,100.00 87.78 190.67 6,400.02 6,245.32 0.00 0.00 50.82 14,200.00 87.78 190.67 6,403.90 6,249.20 0.00 0.00 51.17 14,300.00 87.78 190.67 6,407.78 6,253.08 0.00 0.00 51.52 14,400.00 87.78 190.67 6,411.65 6,256.95 0.00 0.00 51.88 14,478.53 87.78 190.67 6,414.70 6,260.00 0.00 0.00 52.17 Start 0.130/100' DLS, -54.45° TF, for 4129.33' 14,500.00 87.79 190.65 6,415.53 6,260.83 0.13 -54.45 52.23 14,600.00 87.87 190.54 6,419.32 6,264.62 0.13 -54.45 52.52 14,700.00 87.94 190.44 6,422.97 6,268.27 0.13 -54.45 52.82 14,800.00 88.01 190.34 6,426.50 6,271.80 0.13 -54.45 53.12 14,900.00 88.09 190.24 6,429.91 6,275.21 0.13 -54.44 53.43 15,000.00 88.16 190.13 6,433.18 6,278.48 0.13 -54.44 53.75 15,100.00 88.23 190.03 6,436.33 6,281.63 0.13 -54.43 54.07 15,200.00 88.31 189.93 6,439.34 6,284.64 0.13 -54.43 54.40 15,300.00 88.38 189.83 6,442.23 6,287.53 0.13 -54.43 54.74 15,400.00 88.45 189.72 6,444.99 6,290.29 0.13 -54.43 55.08 15,500.00 88.53 189.62 6,447.63 6,292.93 0.13 -54.42 55.43 15,600.00 88.60 189.52 6,450.13 6,295.43 0.13 -54.42 55.79 15,700.00 88.67 189.41 6,452.51 6,297.81 0.13 -54.42 56.15 15,800.00 88.75 189.31 6,454.76 6,300.06 0.13 -54.42 56.51 15,900.00 88.82 189.21 6,456.88 6,302.18 0.13 -54.41 56.89 16,000.00 88.90 189.11 6,458.87 6,304.17 0.13 -54.41 57.26 16,100.00 88.97 189.00 6,460.73 6,306.03 0.13 -54.41 57.65 16,200.00 89.04 188.90 6,462.47 6,307.77 0.13 -54.41 58.04 16,300.00 89.12 188.80 6,464.08 6,309.38 0.13 -54.40 58.43 16,400.00 89.19 188.70 6,465.56 6,310.86 0.13 -54.40 58.83 16,500.00 89.26 188.59 6,466.91 6,312.21 0.13 -54.40 59.23 16,600.00 89.34 188.49 6,468.13 6,313.43 0.13 -54.40 59.64 16,700.00 89.41 188.39 6,469.23 6,314.53 0.13 -54.40 60.05 16,800.00 89.48 188.29 6,470.19 6,315.49 0.13 -54.40 60.47 16,900.00 89.56 188.18 6,471.03 6,316.33 0.13 -54.40 60.89 17,000.00 89.63 188.08 6,471.74 6,317.04 0.13 -54.40 61.32 17,100.00 89.70 187.98 6,472.32 6,317.62 0.13 -54.40 61.75 17,200.00 89.78 187.87 6,472.77 6,318.07 0.13 -54.39 62.19 17,300.00 89.85 187.77 6,473.10 6,318.40 0.13 -54.39 62.63 17,400.00 89.92 187.67 6,473.29 6,318.59 0.13 -54.39 63.07 61132017 9.21:26AM Page 7 COMPASS 5000.1 Build 74 r Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2K-30 Project: Kuparuk River Unit TVD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) Site: Kuparuk 2K Pad MD Reference: Plan: 39 + 115.7 B 154.70usft (Doyon142) Well: Plan: 2K-30 North Reference: True Wellbore: Plan: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30wpl2 Database: OAKEDMP2 Planned Survey 90.07 187.46 6,473.30 MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 17,500.00 90.00 187.57 6,473.36 6,318.66 0.13 -54.39 63.52 17,600.00 90.07 187.46 6,473.30 6,318.60 0.13 -54.39 63.97 17,700.00 90.14 187.36 6,473.11 6,318.41 0.13 -54.39 64.43 17,800.00 90.22 187.26 6,472.80 6,318.10 0.13 -54.39 64.89 17,900.00 90.29 187.16 6,472.35 6,317.65 0.13 -54.39 65.35 18,000.00 90.37 187.05 6,471.78 6,317.08 0.13 -54.39 65.81 18,100.00 90.44 186.95 6,471.08 6,316.38 0.13 -54.40 66.28 18,200.00 90.51 186.85 6,470.25 6,315.55 0.13 -54.40 66.76 18,300.00 90.59 186.75 6,469.29 6,314.59 0.13 -54.40 67.23 18,400.00 90.66 186.64 6,468.20 6,313.50 0.13 -54.40 67.71 18,500.00 90.73 186.54 6,466.99 6,312.29 0.13 -54.40 68.19 18,600.00 90.81 186.44 6,465.64 6,310.94 0.13 -54.40 68.68 18,607.87 90.81 186.43 6,465.53 6,310.83 0.13 -54.40 68.72 Hold for 1117.12' 18,700.00 90.81 186.43 6,464.23 6,309.53 0.00 -51.96 69.15 18,800.00 90.81 186.43 6,462.81 6,308.11 0.00 0.00 69.58 18,900.00 90.81 186.43 6,461.39 6,306.69 0.00 0.00 70.00 19,000.00 90.81 186.43 6,459.98 6,305.28 0.00 0.00 70.43 19,100.00 90.81 186.43 6,458.56 6,303.86 0.00 0.00 70.86 19,200.00 90.81 186.43 6,457.14 6,302.44 0.00 0.00 71.29 19,300.00 90.81 186.43 6,455.72 6,301.02 0.00 0.00 71.72 19,400.00 90.81 186.43 6,454.31 6,299.61 0.00 0.00 72.16 19,500.00 90.81 186.43 6,452.89 6,298.19 0.00 0.00 72.60 19,600.00 90.81 186.43 6,451.47 6,296.77 0.00 0.00 73.04 19,700.00 90.81 186.43 6,450.05 6,295.35 0.00 0.00 73.48 19,724.99 90.81 186.43 6,449.70 6,295.00 0.00 0.00 73.59 Start 3°1100' DLS, 100.57° TF, for 104.08' 19,800.00 90.40 188.64 6,448.91 6,294.21 3.00 100.57 74.62 19,829.07 90.24 189.50 6,448.75 6,294.05 3.00 100.59 74.95 Hold for 971.42' 19,900.00 90.24 189.50 6,448.45 6,293.75 0.00 95.78 75.17 20,000.00 90.24 189.50 6,448.03 6,293.33 0.00 0.00 75.61 20,100.00 90.24 189.50 6,447.62 6,292.92 0.00 0.00 76.06 20,200.00 90.24 189.50 6,447.20 6,292.50 0.00 0.00 76.50 20,300.00 90.24 189.50 6,446.78 6,292.08 0.00 0.00 76.95 20,400.00 90.24 189.50 6,446.37 6,291.67 0.00 0.00 77.40 20,500.00 90.24 189.50 6,445.95 6,291.25 0.00 0.00 77.85 20,600.00 90.24 189.50 6,445.53 6,290.83 0.00 0.00 78.31 20,700.00 90.24 189.50 6,445.12 6,290.42 0.00 0.00 78.76 20,800.00 90.24 189.50 6,444.70 6,290.00 0.00 0.00 79.22 20,800.49 90.24 189.50 6,444.70 6,290.00 0.00 0.00 79.22 Start 3°/100' DLS, -110.26° TF, for 72.67' 20,873.16 89.48 187.45 6,444.88 6,290.18 3.00 -110.26 78.79 Hold for 4418.25' 20,900.00 89.48 187.45 6,445.12 6,290.42 0.00 -114.56 78.88 6/132017 9:21:26AM Page 8 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: Plan: 2K-30 Wellbore: Plan: 2K-30 Design: 2K-30wp12 Planned Survey Schlumberger Report Local Co-ordinate Reference: Well Plan: 21K-30 TVD Reference: Plan: 39+ 115.7 @ 154.70usft (Doyonl42) MD Reference: Plan: 39+ 115.7 @ 154.70usft (Doyon142) North Reference: Tme Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 MD Inc Azl (azimuth) ND TVDSS DLeg TFace Lat. Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 21,000.00 89.48 187.45 6,446.02 6,291.32 0.00 0.00 79.34 21,100.00 89.48 187.45 6,446.92 6,292.22 0.00 0.00 79.81 21,200.00 89.48 187.45 6,447.82 6,293.12 0.00 0.00 80.27 21,300.00 89.48 187.45 6,448.72 6,294.02 0.00 0.00 80.73 21,400.00 89.48 187.45 6,449.62 6,294.92 0.00 0.00 81.20 21,500.00 89.48 187.45 6,450.53 6,295.83 0.00 0.00 81.67 21,600.00 89.48 187.45 6,451.43 6,296.73 0.00 0.00 82.14 21,700.00 89.48 187.45 6,452.33 6,297.63 0.00 0.00 82.61 21,800.00 89.48 187.45 6,453.23 6,298.53 0.00 0.00 83.08 21,900.00 89.48 187.45 6,454.13 6,299.43 0.00 0.00 83.56 22,000.00 89.48 187.45 6,455.03 6,300.33 0.00 0.00 84.03 22,100.00 89.48 187.45 6,455.93 6,301.23 0.00 0.00 84.51 22,200.00 89.48 187.45 6,456.84 6,302.14 0.00 0.00 84.99 22,300.00 89.48 187.45 6,457.74 6,303.04 0.00 0.00 85.47 22,400.00 89.48 187.45 6,458.64 6,303.94 0.00 0.00 85.95 22,500.00 89.48 187.45 6,459.54 6,304.84 0.00 0.00 86.43 22,600.00 89.48 187.45 6,460.44 6,305.74 0.00 0.00 86.91 22,700.00 89.48 187.45 6,461.34 6,306.64 0.00 0.00 87.39 22,800.00 89.48 187.45 6,462.24 6,307.54 0.00 0.00 87.88 22,900.00 89.48 187.45 6,463.15 6,308.45 0.00 0.00 88.37 23,000.00 89.48 187.45 6,464.05 6,309.35 0.00 0.00 88.85 23,100.00 89.48 187.45 6,464.95 6,310.25 0.00 0.00 89.34 23,200.00 89.48 187.45 6,465.85 6,311.15 0.00 0.00 89.83 23,300.00 89.48 187.45 6,466.75 6,312.05 0.00 0.00 90.32 23,400.00 89.48 187.45 6,467.65 6,312.95 0.00 0.00 90.81 23,500.00 89.48 187.45 6,468.55 6,313.85 0.00 0.00 91.30 23,600.00 89.48 187.45 6,469.45 6,314.75 0.00 0.00 91.80 23,700.00 89.48 187.45 6,470.36 6,315.66 0.00 0.00 92.29 23,800.00 89.48 187.45 6,471.26 6,316.56 0.00 0.00 92.79 23,900.00 89.48 187.45 6,472.16 6,317.46 0.00 0.00 93.28 24,000.00 89.48 187.45 6,473.06 6,318.36 0.00 0.00 93.78 24,100.00 89.48 187.45 6,473.96 6,319.26 0.00 0.00 94.28 24,200.00 89.48 187.45 6,474.86 6,320.16 0.00 0.00 94.78 24,300.00 89.48 187.45 6,475.76 6,321.06 0.00 0.00 95.28 24,400.00 89.48 187.45 6,476.67 6,321.97 0.00 0.00 95.78 24,500.00 89.48 187.45 6,477.57 6,322.87 0.00 0.00 96.28 24,600.00 89.48 187.45 6,478.47 6,323.77 0.00 0.00 96.79 24,700.00 89.48 187.45 6,479.37 6,324.67 0.00 0.00 97.29 24,800.00 89.48 187.45 6,480.27 6,325.57 0.00 0.00 97.79 24,900.00 89.48 187.45 6,481.17 6,326.47 0.00 0.00 98.30 25,000.00 89.48 187.45 6,482.07 6,327.37 0.00 0.00 98.80 25,100.00 89.48 187.45 6,482.97 6,328.27 0.00 0.00 99.31 25,200.00 89.48 187.45 6,483.88 6,329.18 0.00 0.00 99.82 6/132017 9:21:26AM Page 9 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: Plan: 2K-30 Wellbore: Plan: 21K-30 Design: 2K-30wp12 Planned Survey MD Inc Azi (azimuth) (usft) (°) P) 25,291.41 89.48 187.45 TD: 25291.41' MD, 6484.7' TVD Schlumberger Report Local Co-ordinate Reference: Well Plan: 2K-30 TVD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) MD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyonl42) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 TVD TVDSS DLeg TFace Lat. Error (usft) (usft) (°/100usft) (°) (usft) 6,484.70 6,330.00 0.00 0.00 100.28 6/132017 9:21:26AM Page 10 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: Plan: 2K-30 Wellbore: Plan: 2K-30 Design: 2K-30wp12 Casing Points Formations Schlumberger Report Local Co-ordinate Reference: Well Plan: 21K-30 TVD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) MD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyori North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 Measured Vertical Dip Casing Hole Depth Depth (usft) Diameter Diameter (usft) (usft) Name 5,969.70 HRZ 116.20 116.20 20"x42" 20 42 3,313.04 2,844.70 10 3/4" x 13-1/2 10-3/4 13-1/2 11,717.54 6,349.70 7-5/8" x 9-7/8" by 11" 7-5/8 11 25,291.41 6,484.70 4 1/2" x 6-314" 4-1/2 6-3/4 Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology 11,323.62 6,294.70 KUP_C 10,398.07 5,969.70 HRZ 10,935.94 6,188.70 K-1 11,490.69 6,324.70 KUP_A5 11,717.54 6,349.70 KUP_A4 4,123.77 3,207.70 C-80 9,730.21 5,675.70 C-35 10,709.64 6,104.70 HRZ_BASE 8,444.45 5,109.70 C-37 7,933.33 4,884.70 C-40 7,251.83 4,584.70 C-50 4,287.33 3,279.70 CAMP_SST 3,115.36 2,741.70 WS -Base 1,531.02 1,504.70 Base Permafrost 2,321.12 2,198.70 WS Top Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +B/ -W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 255° TF, for 500' 300.00 300.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 255° TF, for 500' 800.00 798.57 -8.46 -31.56 Start 2°/100' DLS, -25° TF, for 677.61' 1,477.61 1,454.70 -82.25 -176.71 Hold for 106.82' 1,477.61 1,454.70 -82.25 -176.71 Hold for 106.82' 1,584.43 1,554.70 -101.80 -208.79 Start 2.5°/100' DLS, -35° TF, for 1728.61' 3,313.04 2,844.70 -941.45 -901.60 Hold for 20' 3,333.04 2,854.40 -956.29 -910.86 Start 2.5°/100' DLS, 60.99° TF, for 229.14' 3,562.19 2,960.49 -1,123.01 -1,026.67 Hold for 7023.84' 10,586.03 6,052.44 -6,123.93 -4,869.19 Start 3°/100' DLS, -53.9° TF, for 1131.51' 11,717.54 6,349.70 -7,110.42 -5,295.53 Hold for 20' 11,737.54 6,351.10 -7,130.03 -5,299.21 Start 3°/100' DLS, 0° TF, for 106.48' 11,844.01 6,355.56 -7,234.57 -5,318.87 Hold for 1716.86' 13,560.87 6,379.70 -8,921.70 -5,636.06 Start 3°1100' DLS, 179.12° TF, for 47.23' 13,608.10 6,380.95 -8,968.09 -5,644.79 Hold for 870.44' 14,478.53 6,414.70 -9,822.83 -5,805.83 Start 0.13°/100' DLS, -54.45° TF, for 4129.33' 18,607.87 6,465.53 -13,904.57 -6,419.40 Hold for 1117.12' 19,724.99 6,449.70 -15,014.56 -6,544.48 Start 3°/100' DLS, 100.57° TF, for 104.08' 19,829.07 6,448.75 -15,117.62 -6,558.89 Hold for 971.42' 20,800.49 6,444.70 -16,075.71 -6,719.20 Start 3°/100' DLS,-110.26° TF, for 72.67' 20,873.16 6,444.88 -16,147.58 -6,729.91 Hold for 4418.25' 25,291.41 6,484.70 -20,528.32 -7,303.04 TD: 25291.41' MD, 6484.7' TVD 611312017 9:21:26AM Page 11 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: Plan: 2K-30 Wellbore: Plan: 2K-30 Design: 2K-30wp12 Casing Points Formations Schlumberger Report Local Co-ordinate Reference: Well Plan: 2K-30 TVD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) MD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (usft) (usft) 116.20 116.20 20"x42" 20 42 3,313.04 2,844.70 10 3/4" x 13-1/2 10-3/4 13-1/2 11,717.54 6,349.70 7-5/8" x 9-7/8" by 11" 7-5/8 11 25,291.41 6,484.70 41/2"x6-3/4" 4-1/2 6-3/4 Start 2'/100' DLS, -25" TF, for 677.61' Measured Vertical -82.25 Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 11,323.62 6,294.70 KUP_C Start 2.5°/100' DLS, -35" TF, for 1728.61' 3,313.04 10,398.07 5,969.70 HRZ -901.60 Hold for 20' 10,935.94 6,188.70 K-1 -956.29 -910.86 11,490.69 6,324.70 KUP_A5 2,960.49 -1,123.01 11,717.54 6,349.70 KUP_A4 10,586.03 6,052.44 4,123.77 3,207.70 C-80 Start 3°/100' DLS, -53.9° TF, for 1131.51' 11,717.54 9,730.21 5,675.70 C-35 -5,295.53 Hold for 20' 10,709.64 6,104.70 HRZ_BASE -7,130.03 -5,299.21 8,444.45 5,109.70 C-37 6,355.56 -7,234.57 7,933.33 4,884.70 C-40 13,560.87 6,379.70 7,251.83 4,584.70 C-50 Start 3°/100' DLS, 179.12° TF, for 47.23' 13,608.10 4,287.33 3,279.70 CAMP_SST -5,644.79 Hold for 870.44' 3,115.36 2,741.70 WS -Base -9,822.83 -5,805.83 1,531.02 1,504.70 Base Permafrost 6,465.53 -13,904.57 2,321.12 2,198.70 WS Top 19,724.99 6,449.70 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 255° TF, for 500' 300.00 300.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 255° TF, for 500' 800.00 798.57 -8.46 -31.56 Start 2'/100' DLS, -25" TF, for 677.61' 1,477.61 1,454.70 -82.25 -176.71 Hold for 106.82' 1,477.61 1,454.70 -82.25 -176.71 Hold for 106.82' 1,584.43 1,554.70 -101.80 -208.79 Start 2.5°/100' DLS, -35" TF, for 1728.61' 3,313.04 2,844.70 -941.45 -901.60 Hold for 20' 3,333.04 2,854.40 -956.29 -910.86 Start 2.5'/100' DLS, 60.99° TF, for 229.14' 3,562.19 2,960.49 -1,123.01 -1,026.67 Hold for 7023.84' 10,586.03 6,052.44 -6,123.93 -4,869.19 Start 3°/100' DLS, -53.9° TF, for 1131.51' 11,717.54 6,349.70 -7,110.42 -5,295.53 Hold for 20' 11,737.54 6,351.10 -7,130.03 -5,299.21 Start 3°/100' DLS, 0° TF, for 106.48' 11,844.01 6,355.56 -7,234.57 -5,318.87 Hold for 1716.86' 13,560.87 6,379.70 -8,921.70 -5,636.06 Start 3°/100' DLS, 179.12° TF, for 47.23' 13,608.10 6,380.95 -8,968.09 -5,644.79 Hold for 870.44' 14,478.53 6,414.70 -9,822.83 -5,805.83 Start 0.13'/100' DLS, -54.45° TF, for 4129.33' 18,607.87 6,465.53 -13,904.57 -6,419.40 Hold for 1117.12' 19,724.99 6,449.70 -15,014.56 -6,544.48 Start 3°/100' DLS, 100.57° TF, for 104.08' 19,829.07 6,448.75 -15,117.62 -6,558.89 Hold for 971.42' 20,800.49 6,444.70 -16,075.71 -6,719.20 Start 3°/100' DLS, -110.26° TF, for 72.67' 20,873.16 6,444.88 -16,147.58 -6,729.91 Hold for 4418.25' 25,291.41 6,484.70 -20,528.32 -7,303.04 TD: 25291.41' MD, 6484.7' TVD 6/132017 9:21:26AM Page 12 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2K-30 Project: Kuparuk River Unit TVD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) Site: Kuparuk 2K Pad MD Reference: Plan: 39+ 115.7 @ 154.70usft (Doyon142) Well: Plan: 2K-30 300.00 North Reference: True Wellbore: Plan: 2K-30 300.00 Survey Calculation Method: Minimum Curvature Design: 2K-30wp12 800.00 Database: OAKEDMP2 Casing Points Start 2°/100' DLS, -25° TF, for 677.61' 1,477.61 1,454.70 -82.25 -176.71 Measured Vertical 1,454.70 Casing Hole -176.71 Depth Depth 1,554.70 Diameter Diameter -208.79 (usft) (usft) Name -941.45 -901.60 116.20 116.20 20"x42" 2,854.40 20 42 -910.86 3,313.04 2,844.70 10 3/4" x 13-1/2 2,960.49 10-3/4 13-1/2 -1,026.67 11,717.54 6,349.70 7-5/8" x 9-7/8" by 11" 6,052.44 7-5/8 11 -4,869.19 25,29141 6,484.70 41/2"x6-3/4" 6,349.70 4-1/2 6-3/4 Formations Hold for 20' 11,737.54 6,351.10 -7,130.03 Measured Vertical 11,844.01 Dip -7,234.57 Depth Depth 13,560.87 Dip Direction -8,921.70 (usft) (usft) Name Lithology 6,380.95 -8,968.09 11,323.62 6,294.70 KUP_C 14,478.53 6,414.70 -9,822.83 10,398.07 5,969.70 HRZ 18,607.87 6,465.53 -13,904.57 10,935.94 6,188.70 K-1 19,724.99 6,449.70 -15,014.56 11,490.69 6,324.70 KUP_A5 19,829.07 6,448.75 -15,117.62 11,717.54 6,349.70 KUP_A4 20,800.49 6,444.70 -16,075.71 4,123.77 3,207.70 C-80 20,873.16 6,444.88 -16,147.58 9,730.21 5,675.70 C-35 25,291.41 6,484.70 -20,528.32 10,709.64 6,104.70 HRZ_BASE 8,444.45 5,109.70 C-37 7,933.33 4,884.70 C-40 7,251.83 4,584.70 C-50 4,287.33 3,279.70 CAMP_SST 3,115.36 2,741.70 WS -Base 1,531.02 1,504.70 Base Permafrost 2,321.12 2,198.70 WS -Top Plan Annotations Measured Vertical Local Coordinates Depth Depth +NI -S +E/ -W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 255° TF, for 500' 300.00 300.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 255° TF, for 500' 800.00 798.57 -8.46 -31.56 Start 2°/100' DLS, -25° TF, for 677.61' 1,477.61 1,454.70 -82.25 -176.71 Hold for 106.82' 1,477.61 1,454.70 -82.25 -176.71 Hold for 106.82' 1,584.43 1,554.70 -101.80 -208.79 Start 2.5°/100' DLS, -35° TF, for 1728.61' 3,313.04 2,844.70 -941.45 -901.60 Hold for 20' 3,333.04 2,854.40 -956.29 -910.86 Start 2.5°/100' DLS, 60.99° TF, for 229.14' 3,562.19 2,960.49 -1,123.01 -1,026.67 Hold for 7023.84' 10,586.03 6,052.44 -6,123.93 -4,869.19 Start 3°/100' DLS, -53.9° TF, for 1131.51' 11,717.54 6,349.70 -7,110.42 -5,295.53 Hold for 20' 11,737.54 6,351.10 -7,130.03 -5,299.21 Start 3°/100' DLS, 0° TF, for 106.48' 11,844.01 6,355.56 -7,234.57 -5,318.87 Hold for 1716.86' 13,560.87 6,379.70 -8,921.70 -5,636.06 Start 3°/100' DLS, 179.12° TF, for 47.23' 13,608.10 6,380.95 -8,968.09 -5,644.79 Hold for 870.44' 14,478.53 6,414.70 -9,822.83 -5,805.83 Start 0.13°/100' DLS, -54.45° TF, for 4129.33' 18,607.87 6,465.53 -13,904.57 -6,419.40 Hold for 1117.12' 19,724.99 6,449.70 -15,014.56 -6,544.48 Start 3°/100' DLS, 100.57° TF, for 104.08' 19,829.07 6,448.75 -15,117.62 -6,558.89 Hold for 971.42' 20,800.49 6,444.70 -16,075.71 -6,719.20 Start 3°/100' DLS, -110.26° TF, for 72.67' 20,873.16 6,444.88 -16,147.58 -6,729.91 Hold for 4418.25' 25,291.41 6,484.70 -20,528.32 -7,303.04 TD: 25291.41' MD, 6484.7' TVD 67132017 9:21:26AM Page 13 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2K-30 Project: Kuparuk River Unit TVD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) Site: Kuparuk 2K Pad MD Reference: Plan: 39+ 115.7 @ 154.70usft (Doyonl42) Well: Plan: 2K-30 North Reference: True Wellbore: Plan: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30wpl2 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") ("I 116.20 116.20 20" x 42" 20 42 3,313.04 2,844.70 10 3/4" x 13-1/2 10-3/4 13-1/2 11,717.54 6,349.70 7-5/8" x 9-7/8" by 11" 7-5/8 11 25,291.41 6,484.70 4 1/2' x 6-3/4" 4-1/2 6-3/4 Formations 1,477.61 1,454.70 -82.25 Measured Vertical 1,477.61 Dip Depth Depth Dip Direction (usft) (usft) Name Lithology Start 2.5°/100' DLS, -35° TF, for 1728.61' 11,323.62 6,294.70 KUP_C -941.45 -901.60 10,398.07 5,969.70 HRZ 2,854.40 -956.29 10,935.94 6,188.70 K-1 3,562.19 2,960.49 11,490.69 6,324.70 KUP_A5 Hold for 7023.84' 10,586.03 11,717.54 6,349.70 KUP_A4 -4,869.19 Start 3°/100' DLS, -53.9° TF, for 1131.51' 4,123.77 3,207.70 C-80 -7,110.42 -5,295.53 9,730.21 5,675.70 C-35 6,351.10 -7,130.03 10,709.64 6,104.70 HRZ_BASE 11,844.01 6,355.56 8,444.45 5,109.70 C-37 Hold for 1716.86' 13,560.87 7,933.33 4,884.70 C-40 -5,636.06 Start 3°/100' DLS, 179.12° TF, for 47.23' 7,251.83 4,584.70 C-50 -8,968.09 -5,644.79 4,287.33 3,279.70 CAMP -SST 6,414.70 -9,822.83 3,115.36 2,741.70 WS -Base 18,607.87 6,465.53 1,531.02 1,504.70 Base Permafrost Hold for 1117.12' 19,724.99 2,321.12 2,198.70 WS Top -6,544.48 Start 3"/100' DLS, 100.57° TF, for 104.08' Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 255° TF, for 500' 300.00 300.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 255' TF, for 500' 800.00 798.57 -8.46 -31.56 Start 2°/100' DLS, -25° TF, for 677.61' 1,477.61 1,454.70 -82.25 -176.71 Hold for 106.82' 1,477.61 1,454.70 -82.25 -176.71 Hold for 106.82' 1,584.43 1,554.70 -101.80 -208.79 Start 2.5°/100' DLS, -35° TF, for 1728.61' 3,313.04 2,844.70 -941.45 -901.60 Hold for 20' 3,333.04 2,854.40 -956.29 -910.86 Start 2.5'/100' DLS, 60.99° TF, for 229.14' 3,562.19 2,960.49 -1,123.01 -1,026.67 Hold for 7023.84' 10,586.03 6,052.44 -6,123.93 -4,869.19 Start 3°/100' DLS, -53.9° TF, for 1131.51' 11,717.54 6,349.70 -7,110.42 -5,295.53 Hold for 20' 11,737.54 6,351.10 -7,130.03 -5,299.21 Start 3°/100' DLS, 0° TF, for 106.48' 11,844.01 6,355.56 -7,234.57 -5,318.87 Hold for 1716.86' 13,560.87 6,379.70 -8,921.70 -5,636.06 Start 3°/100' DLS, 179.12° TF, for 47.23' 13,608.10 6,380.95 -8,968.09 -5,644.79 Hold for 870.44' 14,478.53 6,414.70 -9,822.83 -5,805.83 Start 0.13°/100' DLS, -54.45° TF, for 4129.33' 18,607.87 6,465.53 -13,904.57 -6,419.40 Hold for 1117.12' 19,724.99 6,449.70 -15,014.56 -6,544.48 Start 3"/100' DLS, 100.57° TF, for 104.08' 19,829.07 6,448.75 -15,117.62 -6,558.89 Hold for 971.42' 20,800.49 6,444.70 -16,075.71 -6,719.20 Start 3°/100' DLS, -110.26° TF, for 72.67' 20,873.16 6,444.88 -16,147.58 -6,729.91 Hold for 4418.25' 25,291.41 6,484.70 -20,528.32 -7,303.04 TD: 25291.41' MD, 6484.7' TVD 6/13/2017 9:21:26AM Page 14 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well Plan: 2K-30 Project: Kuparuk River Unit TVD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) Site: Kuparuk 2K Pad MD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) Well: Plan: 21K-30 300.00 North Reference: True Wellbore: Plan: 21K-30 300.00 Survey Calculation Method: Minimum Curvature Design: 2K-30wpl2 800.00 Database: OAKEDMP2 Casing Points Start 2°/100' DLS, -25° TF, for 677.61' 1,477.61 1,454.70 -82.25 -176.71 Measured Vertical 1,454.70 Casing Hole -176.71 Depth Depth 1,554.70 Diameter Diameter -208.79 (usft) (usft) Name (") (") -901.60 116.20 116.20 20"x42" 2,854.40 20 42 -910.86 3,313.04 2,844.70 10 3/4" x 13-1/2 2,960.49 10-3/4 13-1/2 -1,026.67 11,717.54 6,349.70 7-5/8" x 9-7/8" by 11" 6,052.44 7-5/8 11 -4,869.19 25,291.41 6,484.70 41/2"x6-3/4" 6,349.70 4-1/2 6-3/4 Formations Hold for 20' 11,737.54 6,351.10 -7,130.03 Measured Vertical 11,844.01 Dip -7,234.57 Depth Depth 13,560.87 Dip Direction -8,921.70 (usft) (usft) Name Llthology 6,380.95 -8,968.09 11,323.62 6,294.70 KUP_C 14,478.53 6,414.70 -9,822.83 10,398.07 5,969.70 HRZ 18,607.87 6,465.53 -13,904.57 10,935.94 6,188.70 K-1 19,724.99 6,449.70 -15,014.56 11,490.69 6,324.70 KUP_A5 19,829.07 6,448.75 -15,117.62 11,717.54 6,349.70 KUP_A4 20,800.49 6,444.70 -16,075.71 4,123.77 3,207.70 C-80 20,873.16 6,444.88 -16,147.58 9,730.21 5,675.70 C-35 25,291.41 6,484.70 -20,528.32 10,709.64 6,104.70 HRZ_BASE 8,444.45 5,109.70 C-37 7,933.33 4,884.70 C-40 7,251.83 4,584.70 C-50 4,287.33 3,279.70 CAMP -SST 3,115.36 2,741.70 WS -Base 1,531.02 1,504.70 Base Permafrost 2,321.12 2,198.70 WS Top Plan Annotations Measured Vertical Local Coordinates Depth Depth +NI -S +El -W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 255° TF, for 500' 300.00 300.00 0.00 0.00 KOP: Start 1.5"/100' DLS, 255° TF, for 500' 800.00 798.57 -8.46 -31.56 Start 2°/100' DLS, -25° TF, for 677.61' 1,477.61 1,454.70 -82.25 -176.71 Hold for 106.82' 1,477.61 1,454.70 -82.25 -176.71 Hold for 106.82' 1,584.43 1,554.70 -101.80 -208.79 Start 2.5°/100' DLS, -35" TF, for 1728.61' 3,313.04 2,844.70 -941.45 -901.60 Hold for 20' 3,333.04 2,854.40 -956.29 -910.86 Start 2.5°/100' DLS, 60.99° TF, for 229.14' 3,562.19 2,960.49 -1,123.01 -1,026.67 Hold for 7023.84' 10,586.03 6,052.44 -6,123.93 -4,869.19 Start 3°!100' DLS, -53.9° TF, for 1131.51' 11,717.54 6,349.70 -7,110.42 -5,295.53 Hold for 20' 11,737.54 6,351.10 -7,130.03 -5,299.21 Start 3°/100' DLS, 0° TF, for 106.48' 11,844.01 6,355.56 -7,234.57 -5,318.87 Hold for 1716.86' 13,560.87 6,379.70 -8,921.70 -5,636.06 Start 3°/100' DLS, 179.12° TF, for 47.23' 13,608.10 6,380.95 -8,968.09 -5,644.79 Hold for 870.44' 14,478.53 6,414.70 -9,822.83 -5,805.83 Start 0.13°/100' DLS, -54.45` TF, for 4129.33' 18,607.87 6,465.53 -13,904.57 -6,419.40 Hold for 1117.12' 19,724.99 6,449.70 -15,014.56 -6,544.48 Start 3'/100' DLS, 100.57' TF, for 104.08' 19,829.07 6,448.75 -15,117.62 -6,558.89 Hold for 971.42' 20,800.49 6,444.70 -16,075.71 -6,719.20 Start 3°/100' DLS, -110.26' TF, for 72.67' 20,873.16 6,444.88 -16,147.58 -6,729.91 Hold for 4418.25' 25,291.41 6,484.70 -20,528.32 -7,303.04 TD: 25291.41' MD, 6484.7' TVD 6/132017 9:21:26AM Page 15 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2K-30 Project: Kuparuk River Unit TVD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) Site: Kuparuk 2K Pad MD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyonl42) Well: Plan: 21K-30 300.00 North Reference: True Wellbore: Plan: 21K-30 300.00 Survey Calculation Method: Minimum Curvature Design: 2K-30wpl2 800.00 Database: OAKEDMP2 Casing Points Start 2°/100' DLS, -25" TF, for 677.61' 1,477.61 1,454.70 -82.25 -176.71 Measured Vertical 1,454.70 Casing Hole -176.71 Depth Depth 1,554.70 Diameter Diameter -208.79 (usft) (usft) Name (") (1') -901.60 116.20 116.20 20"x42" 2,854.40 20 42 -910.86 3,313.04 2,844.70 10 3/4" x 13-1/2 2,960.49 10-3/4 13-1/2 -1,026.67 11,717.54 6,349.70 7-5/8" x 9-7/8" by 11" 6,052.44 7-5/8 11 -4,869.19 25,291.41 6,484.70 4 1/2" x 6-3/4" 6,349.70 4-1/2 6-3/4 Formations Hold for 20' 11,737.54 6,351.10 -7,130.03 -5,299.21 Measured Vertical 6,355.56 Dip -5,318.87 Depth Depth 6,379.70 Dip Direction -5,636.06 (usft) (usft) Name Lithology -8,968.09 -5,644.79 11,323.62 6,294.70 KUP_C 6,414.70 -9,822.83 -5,805.83 10,398.07 5,969.70 HRZ 6,465.53 -13,904.57 -6,419.40 10,935.94 6,188.70 K-1 6,449.70 -15,014.56 -6,544.48 11,490.69 6,324.70 KUP_A5 6,448.75 -15,117.62 -6,558.89 11,717.54 6,349.70 KUP_A4 6,444.70 -16,075.71 -6,719.20 4,123.77 3,207.70 C-80 6,444.88 -16,147.58 -6,729.91 9,730.21 5,675.70 C-35 6,484.70 -20,528.32 -7,303.04 10,709.64 6,104.70 HRZ_BASE 8,444.45 5,109.70 C-37 7,933.33 4,884.70 C-40 7,251.83 4,584.70 C-50 4,287.33 3,279.70 CAMP -SST 3,115.36 2,741.70 WS -Base 1,531.02 1,504.70 Base Permafrost 2,321.12 2,198.70 WS -Top Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +B/ -W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP: Start 1.5°/100' OLS, 255° TF, for 500' 300.00 300.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 255° TF, for 500' 800.00 798.57 -8.46 -31.56 Start 2°/100' DLS, -25" TF, for 677.61' 1,477.61 1,454.70 -82.25 -176.71 Hold for 106.82' 1,477.61 1,454.70 -82.25 -176.71 Hold for 106.82' 1,584.43 1,554.70 -101.80 -208.79 Start 2.5°/100' DLS, -35" TF, for 1728.61' 3,313.04 2,844.70 -941.45 -901.60 Hold for 20' 3,333.04 2,854.40 -956.29 -910.86 Start 2.5°/100' DLS, 60.99° TF, for 229.14' 3,562.19 2,960.49 -1,123.01 -1,026.67 Hold for 7023.84' 10,586.03 6,052.44 -6,123.93 -4,869.19 Start 3°/100' DLS, -53.9° TF, for 1131.51' 11,717.54 6,349.70 -7,110.42 -5,295.53 Hold for 20' 11,737.54 6,351.10 -7,130.03 -5,299.21 Start 3°/100' DLS, 0° TF, for 106.48' 11,844.01 6,355.56 -7,234.57 -5,318.87 Hold for 1716.86' 13,560.87 6,379.70 -8,921.70 -5,636.06 Start 3'/100' DLS, 179.12° TF, for 47.23' 13,608.10 6,380.95 -8,968.09 -5,644.79 Hold for 870.44' 14,478.53 6,414.70 -9,822.83 -5,805.83 Start 0.13°/100' DLS, -54.45" TF, for 4129.33' 18,607.87 6,465.53 -13,904.57 -6,419.40 Hold for 1117.12' 19,724.99 6,449.70 -15,014.56 -6,544.48 Start 3°/100' DLS, 100.57° TF, for 104.08' 19,829.07 6,448.75 -15,117.62 -6,558.89 Hold for 971.42' 20,800.49 6,444.70 -16,075.71 -6,719.20 Start Tit 00' DLS, -110.26° TF, for 72.67' 20,873.16 6,444.88 -16,147.58 -6,729.91 Hold for 4418.25' 25,291.41 6,484.70 -20,528.32 -7,303.04 TD: 25291.41' MD, 6484.7' TVD 61132017 9.,21:26AM Page 16 COMPASS 5000.1 Build 74 AC Summary ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad Plan: 2K-30 Plan: 2K-30 501032075800 2K-30wp12 Minor Risked Clearance Summary Anticollision Report 12 June, 2017 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2K Pad -Plan: 2K -30 -Plan: 2K -30-2K31 Well Coordinates: Datum Height Plan: 39 + 115.7 @ 151 noyerlC2) Scan Range: 0.00 to 25,291.01 Leff. Measured Depth, Scan Radius is 2.725.26 Left . Clearance Factor cutoff is Unlimited Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version : 500111 Build: 74 Scan Type: GLOBAL FILTER APPLIED. All vrellpaNs miili in 200'+ 100/1000 of reference Scan type: 25 00 Anticollision Report for Plan: 2K-30 - 2K-30wp12 Tray. Cylinder North Proximity Scan on Current Surrey Data (North Reference) 233.78 Reference Design: Kuparuk 2K Patl - Plan: 2K.30. Plan: 2K-30-2K-30wp12 227.54 Scan Range: 0.00 W 25,291.41 usff. Measured DepM. 37.457 Centre Distance Scan Radius is 2,725.24 usff. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited 595.38 Measured Minimum @Measured Ellipse §Measured Clearance Summary eased on She Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (us") (usR) Ina) (Usff) usft Kuparuk 2K Pad 2K -09 -2K -09-2K-09 2K -09 -2K -09-2K-09 2K-09-2K-WL1 -2K-0911 2K49-2K-NL1-2K439L1 21<-09 - 2K-0911-01 - 2K-0911-01 2K -09-2K-091-1-01 -2K-0911-01 2K-1 0 - 2K-1 0 - 2KA 0 2K -10 -2K -10-2K-10 2K-11 -2K-11 -2K-it 2K-11 -2K-11 -2Kd1 2K -11 -2K -11A -2K -11A 2K -11 -2K -11A -2K -11A 2K-11-2K-11AL1-2K-11AL1 2K -11-21<41A 1-2K-11AL1 2K-11-2K-11AP131-2K-11APB1 2K-11-2K-11APB1-2K-11APB1 2K -12 -2K -12-2K-12 2K -12 -2K -12-2K-12 2K -13 -2K -13-2K-13 2K-13 - 2K-13 -2K-13 2K -13 -2K -13A -2K -13A 2K -13 -2K -13A -2K -13A 2K-13-2K-13AL1-21K-13AL1 21K-13.2K-13AL1-2K-13AL1 2K-13 - 2 K-13AL2 - 2K-1 MU 2K-13 - 2K-13AL2 -2K-1 MU 2K -14 -2K -14-2K-14 2K -14 -2K -14-2K-14 374.51 233.78 374.51 227.54 375.00 37.457 Centre Distance Pass - Major Risk 595.38 235.08 595.38 225.29 800.00 24,010 Clearance Factor Pass -Major Risk 374.51 233.78 374.51 22254 37500 37.458 Centre Distance Paso -Major Risk 59538 235.08 595.38 22529 600.00 24.010 Clearance Fador Pass - Major Risk 374.51 233.76 374.51 227.54 375.00 37.458 Can" Distance Pass - Major Risk 595.38 235.08 595.38 225.29 600.00 24.010 Clearance Factor Pass - Major Risk 349.98 209.60 349.98 201.80 35000 26.868 Centre Distance Pass - Major Risk 620.29 21277 620.29 198.35 625.00 14.761 Clearance Factor Pass - Major Risk W,70 185.05 50.70 182.71 50.00 79.324 Centre Distance Pass - Major Risk 596.53 188.81 596.53 17,79 600.00 17.133 Clearance Factor Pass -Major Risk 50.70 185.05 50.70 182.71 50.00 79.324 Centre Distance Paas - Major Risk 596.53 188.81 596.53 177.79 60000 17.133 Clearance Factor Pass - Major Risk 5410 185.05 54]0 18266 50.00 77.363 Centre Distance Pass - Major Risk 600.00 188.89 600.00 177.80 60D.00 17.034 Clearance Fador Pass - Major Risk 50.70 185.05 50.70 182.71 50.00 79.324 Centre Distance Pass -Major Risk 596.53 188.81 596.53 177]9 6W.W 17.133 Clearance Factor Pass - Major Risk 32542 15884 325.42 152.87 32500 26.597 Centre Distance Pass - Major Risk 596.98 161.18 5913.98 150.15 600.00 14.618 Clearance Factor Pass - Major Risk 50.70 70.15 50.70 67.58 50.00 27.260 Centre Distance Pass - Major Risk 474.88 72.05 474.86 64.05 475.00 9.005 Clearance Factor Pass -Major Risk 50.70 70.15 50.70 67.58 5).W 27.260 Centre Distance Pass -Major Risk 474.86 72.05 474.86 64.05 47500 9,005 Clearance Factor Pass - Major Risk 50.70 70.15 S) 70 67.58 50.00 27.260 Centre Distance Pass - Major Risk 474.86 72.05 474.86 84.05 475.00 9.005 Clearance Factor Pass - Major Risk 50.70 70.15 50.70 6758 50.00 27.260 Canoe Distance Pass - Major Risk 474.88 72.05 474.86 64.05 475.W 9.005 Clearance Factor Pass -Major Risk W]0 45.02 50.70 42.44 50.00 17,436 Centre Distance Pass - Major Risk 5W.W 47.05 5W.W 3858 5)0.00 5.562 Clearance Factor Pass - Major Risk 12 June, 2017 - 10:05 Page 2 of 8 COMPASS Anticollision Report for Plan: 2K-30 - 2K-30wp12 Tray. Cylinder North Proximity Scan on Current Surrey Data (North Reference) Reference Design: Kuparuk 2K Pad - Plan: 2K -30 -Plan: 2K-W-2K-3(jwpi2 Scan Range: 0.00 to 25,291.41 usff. Measured Depth. Scan Radius is 2,725.24 call. Clearance Factor cutoff is Unlimited Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separatiorwaming Comparison Well Name - Wellbore Name - Design (usK) just) (..ft) haft) USK 2K-14 - 2KA4A - 2K -14A 50]0 45.02 50.70 4244 50.00 17AW Centre Distance Pass - Major Risk 2K -14 -2K -14A -2K -14A 500.00 47.00 500.00 38.58 500.00 5.582 Clearance Factor Pass - Major Risk 2K-14-21<-14A11-2K-14AL1 50.70 45.02 50.70 42.44 50.00 12436 Centre Distance Pass -Major Risk 2K-14-2K-14AL1-2K-14 L1 50000 CLW 500.00 38.58 5000 5.582 Clearance Factor Pass - Major Risk 2K -15 -2K -15-2K-15 50.70 19.92 50.70 17.55 50.00 8.392 Centre Distance Pass - Major Risk 2K -15 -2K -15-2K-15 500.30 22.67 500.30 11.30 500.00 1.994 Clearance Factor Pass - Major Risk 2K -15 -2K -1511-2K-1511 50.70 19.92 50.70 17.55 50.00 8.392 Centre Distance Pass - Major Risk 2K-15-2K-15Li-2K-1511 5030 22.67 5W.30 11.30 500.0 1.994 Clearance Factor Pass - Major Risk 2K-15-2KA5114)1-2K-1511-01 5030 19.92 50.70 17.55 50.00 8.392 Centre Distance Pass - Major Risk 2K -15 -2K -151 -1.01 -2K -15L1-01 500.30 22.67 500.30 11.30 500.00 1.994 Clearance Factor Pass - Major Risk 2K -15 -2K -151-1-02-2K-1511-02 50.70 19.92 50.70 17.55 50.00 8.392 Centre Distance Pass - Major Risk 2K -15 -2K -1511-02-2K-1511-02 500.30 22.67 5W.30 11.30 5W.W 1,994 Clearance Factor Pass - Major Risk 2K -16 -2K -16-2K-16 W70 5.09 W.70 280 50.0 2.223 Centre Distance Pass - Min" 1/100 2K -16 -2K -16-2K-16 425.69 5.54 425.69 0.48 425.00 1.098 Clearance Factor Pass - Minor 1/100 2K -17 -2K -17-2K-17 575.99 28.83 57599 19.31 575.00 3.028 Centre Distance Pass - Major Risk 2K47 -2K -17-2K-17 65077 29.29 650.77 18.54 6W.W 2723 Clearance Factor Pass - Major Risk 2K -18 -2K -18 -2K -f8 651.05 5204 651.05 41.68 650.0 5.024 Centre Distance Pass -Major Risk 2K -18 -2K -18-2K-18 72559 52.48 725.59 40.88 72500 4.525 Clearance Factor Pass - Major Risk 2K -19 -2K -19-2K-19 1,533.50 56.18 1,53350 29.72 1,525W 2.123 Clearance Factor Pass - Major Risk 2K -19 -2K -19A -2K -19A 1,533.0 56.18 1,533.50 2977 1,525.00 2.127 Clearance Factor Pass - Major Risk 21<-19-21<49A11-2K-19AL1 1,53350 56.18 1,533.50 29.77 1,525.00 2.127 Clearance Factor Pass - Major Risk 2K -20 -2K -20-2K-20 652.30 10377 652.30 88.72 650.00 6.894 Centre Distance Pass -Major Risk 2K -20 -2K -20-2K-20 1,36094 141.37 1,30.94 78.43 1,350.00 3.381 Clearance Factor Pass - Major Risk 2K -21 -2K -21-2K-21 527.34 129.88 527.34 121.26 525.W 15066 Centre Distance Pass - Major Risk 2K -21 -2K -21-2K-21 602.66 130.50 602.66 12071 6O.W 13.331 Clearance Factor Pass - Major Risk 2K -21 -2K -21A -2K -21A 11,032.56 129.19 11,03256 76.67 11,1500 2.460 Cantre Distance Pass -Minor 1600 2K -21 -2K -21A -2K -21A 11.4878 143.51 11,048.78 56.T5 11,225.0 1.693 Clearance Factor Pass - Minor 11500 2K -22 -2K -22-2K-22 527.62 153.24 527.62 14124 525.00 12.772 Centre Distance Pass - Major Risk 2K -22 -2K42 -2K-22 602.98 154.11 02.98 140.30 6W.00 11.152 Clearance Factor Pass - Major Risk 2K -22 -2K -22A -2K -22A 527,62 153.24 527.62 141.24 525.W 12.772 Centre Distance Pass - Major Risk 12 June, 2017 - 10:05 Page 3 of 8 COMPASS Anticollision Report for Plan: 2K-30 - 2K-30wpl2 Tray. Cylinder North Proximity Scan on Comm Survey Data (North Reference) Reference Design: Kuparuk 2K Pad - Plan: 21(40 -Plan: 21(J0. 2K-30wP12 Scan Range: 0.00 to 25,291.41 usff. Measured Depth. Scan Radius is 2,725.24usff. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation blaming Comparison Well Name - Wellbore Name - Design (usR) just) hmft) (usR) usR 2K -22 -2K -22A -2K -22A 602.98 154.11 602.98 140.30 60000 11.152 Clearance Factor Pass - Major Risk 2K-22-21(-22AL1-2K-22AL1 527.62 153.24 52782 141.24 525.00 12,772 Cerium Distance Pass - Major Risk 2K-22-2K-22ALi-2K-22AL1 602.88 154.11 602.98 140.30 600.00 11.152 Clearance Factor Pass - Major Risk 2K-22-2K-22ALi-01-2K-22ALi-01 527,62 153.24 527.62 14124 525.00 12,772 Centre Distance Pass - Major Risk 2K-22-2K-22ALi-01-2K-22A11-01 602.98 154.11 802.98 140.30 600.00 11.152 Clearance Factor Pass - Major Risk 2K -23 -2K.23 -2K-23 200.70 179.89 200.70 17649 200.00 52.921 Centre Distance Pass - Major Risk 2K -23 -2K -23-2K-23 427.15 181.28 427.15 174.26 42500 25.793 Clearance Factor Pass - Major Risk 2K-23-2K-23A-2K-23A_wp06 200.70 179.89 200.70 17684 20000 58.975 Centre Distance Pass - Major Risk 2K-23-2K-23A-2K-23AwpM 427.15 181.28 427.15 17480 425.00 27.140 Clearance Factor Pass -Major Risk 2K-23-2K.23AL1-2K-23AL1_wpW 200.70 179.89 200.70 176.84 200.00 58.975 Centre Distance Pass - Major Risk 2K-23-2K-23AL1-2K-23AL1_wp08 427.15 181.28 427.15 17460 42500 27.140 Clearance Factor Pass - Major Risk 2K -24 -2K -24-2K-24 225.70 2N73 225.70 200.93 225.00 53350 Centre Distance Pass - Major Risk 2K -24 -2K -24-2K-24 376.77 205.97 376.77 199.79 37500 33.318 Clearance Factor Pass - Major Risk 2K-24-2K-24AL2-2K-24AL2_wpD2 225.70 204.73 225.70 20097 225.00 54.420 Centre Distance Pass - Major Risk 2K-24-2K-24AL2-2K-24AL2_wp02 376.77 205.97 376.77 199.83 375.00 33.573 Clearance Factor Pass - Major Risk 2K-24-2K-24AL2-01-21(-24AL2-01 wp02 225.70 204.73 22570 20097 225.00 54.420 Centre Distance Pass - Major Risk 2K-24-2K-24AL2-01-2K-24AL2-D1_wp02 376.77 205.97 376.77 19983 375.00 33.573 Clearance Factor Pass - Major Risk 2K -25 -2K -25-2K-25 50.70 230.03 50]0 22772 50.00 99.358 Centre Distance Pass - Major Risk 2K -25 -2K -25-2K-25 351.48 230.99 351.48 225.11 350.00 39.338 Clearance Factor Pass - Major Risk 2K -25 -2K -2511 -2K -25L1 50.70 .23003 5010 227.72 50,00 99.358 Centre Distance Pass - Major Risk 2K -25 -2K -2511 -2K -25L1 351.48 230.99 35148 225.11 350.00 39.336 Clearance Factor Pass - Major Risk 21(45 -2K -251141 -2K -25L1-01 50.70 230.03 50.70 227.72 50.00 99.358 Centre DisWrtce Pass - Major Risk 2K-25-2K-25LI41-2K-25L1-01 351.48 230.99 35148 225.11 350.00 39.336 Clearance Factor Pass - Major Risk 2K -27 -2K -27-2K-27 2,290.54 108.95 2,290.54 72.22 2,22500 2.986 Clearance Factor Pass - Major Risk 2K -27 -2K -27-2K-27 2,314.18 108.72 2,314.18 72,,46 2,250.00 2.998 Centre Distance Pass - Major Risk 2K -28 -2K.28 -2K-28 2,07908 97.43 2,07908 47.64 2,125.00 1.957 Centre Distance Pass -Major Risk 2K -28 -2K -28-2K-28 2,248.17 10175 2,248.17 44.36 2,30000 1.773 Clearance Factor Pass - Major Risk 2K -28 -2K -28A -2K -28A 2,079.08 97.43 2,07908 47.28 2,12500 1.943 Centre Distance Pass - Major Risk 2K -28 -2K -28A -2K -28A 2,248.17 101.75 2,248.17 43.89 2,300.00 1758 Clearance Factor Pass - Major Risk 2K-28 - 2K-28AL1 - 2K-28AL1 2,079.08 97.43 2,079.08 47.15 2.125.00 1.938 Centre Distance Pass - Major Risk 12 June, 2017 - 10:05 Page 4 of 8 COMPASS Anticollision Report for Plan: 2K-30 - 2K-30wp12 Tres, Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2K Pad - Plan: 2K-30- Plan: 2 410.2KJ0wp12 Seen Range: 0.00 to 25,291.41 usff. Measured Depth. Scan Radius is 2,725.24 usR. Clearance Factor cutoff is Unlimited. Max Ellipse Separation Is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Fardar Minimum Separation Waning Comparison Well Name -Wellbore Name - Design (..it) (usft) (ustt) (.an) usff 2K-28-2K-28AL1-2K-28AL1 2,240.17 101.75 2,248.17 43.76 2,300.00 1.755 Clearance Factor Pass - Major Risk 2K-28 - 2K-28AL1 P81-2K-28AL1 P81 2,07988 97.43 2,079.08 47.28 2,125.00 1.943 Centre Distance Pass - Major Risk 2K-28-2K-28AL1PB1-2K-28AL1PB1 2,248.17 10175 2,24817 43.89 2,300.W 1.758 Clearance Factor Pass -Major Risk 2K-28-2K-28AL1PB2-2K-28AL1PB2 2,079.08 97.43 2,07988 47.28 2,128W 1.943 Centre Distance Pass - Major Risk 2K-28-2K-28AL1PB2-2K-28AL1PB2 2,248.17 10175 2,248.17 43.89 2,300.W 1.758 Clearance Factor Pass - Major Risk 2K-28-2K-28APB1-2K-28APB1 2,079.08 9TA 2,079.08 47.28 2,125.00 1.943 Centre Distance Pass - Major Risk 2K-28-2K-28APB1-2K-28APB1 2,248.17 101.75 2,248.17 43.89 2,300.00 1.758 Clearance Factor Pass - Major Risk 2K -32 -2K -32-2K-32 248.88 49.23 248.66 44.85 250.00 11.224 Centre Distance Pass - Major Risk 21(32-21(32-21(-32 323.89 49.66 323.89 44.01 325.00 8783 Clearance Factor Pass - Major Risk 21( -34 -2K -34-2K-34 161.57 254.76 161.57 251.47 150.00 77.586 Centre Distance Pass - Major Risk 2K -34.21(.34-2K-34 557.36 257.81 557.36 24845 550.W 27.563 Clearance Factor Pass -Major Risk 2K -34 -2K -34L1 -2K -34L1 161.57 254.76 161.57 251.47 150.00 77.586 Centre Distance Pass - Major Risk 2K -4 -2K -3411-2K-3411 557.36 257,81 55235 248.45 550.00 27.563 Clearance Factor Paas - Major Risk 2K-34-2K-34PB1-2K-34PB1 161.57 25416 161.57 25164 150.00 81.735 Centre Distance Pass - Major Risk 21(34-2K-34PB1-2K-34PB1 557.36 257.81 557.38 248.23 550.00 26.933 Clearance Factor Pass - Major Risk Plan: 2K -31 -Plan: 2K411-2K-31wp05 308.71 24.99 308.71 19.52 30.00 4.565 Centre Distance Pass - Major Risk Plan: 2K -31 -Plan: 2KJl-2K-31wp05 40882 25.46 40.82 1848 40.00 3642 Clearance Factor Pass - Major Risk Plan: 2K -33 -Plan 2K-33-2K-33WF07 29840 259,911 298.40 25466 3W.W 48.863 Centre Distance Pass - Major Risk Plan: 2K -33 -Plan: 2K-33-2K-33WP07 451.05 261.12 451.05 253.53 450.00 34.414 Clearance Factor Pass - Major Risk 12 June, 2017 - 10:05 Page 5 of 8 COMPASS Anticollision Report for Plan: 2K-30 - 2K-30wp12 Survey tool pri From To (usft) (--ft) 39.00 1,200.00 2K30wp12 1,200.00 2.200.00 2K-30wpl2 2,50000 3,31304 2K30wp12 3,313.04 4,813.04 2K3hyp12 3,313.04 11,]1].54 2K-30xpl2 11,717.54 13,217.54 2K-30wp12 11,717.54 25,291.41 2K-30wpl2 Ellipse error terms are comened across survey tool tie -cm points. Calculated ellipses incorporate surface errors Separation is the actual distance betwean ellipwids. Distance Between centres is the straight line distance between wellbom centres. Clearance Factor= Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station wordinates were taiWated using the Minimum Curvature method. SurveylPlan Surrey Tool GYD-GG SS MWD MW IFR-AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC MWD MWDd FR-AK-CAZ-SC 12 June, 2017 - 10.05 Page 6 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad Plan: 2K-30 Plan: 2K-30 50103xxxxx00 2K-30wp12 Clearance Summary Anticollision Report 08 June, 2017 Trav, cylinder Notln Proximity Scan on current Survey Data (North Reference) Reference Design: Kuparuk 2K Pad - Plan: 2K -30 -Plan: 2K-30-2K-30wp12 Well Coordinates: Datum Height Plan: 39 a 1157 @? 15470usft Boyanl C2) Scan Range: 0.00 to 25,291.41 malL Measured Depth, Scan Radius is 2.725.24 usrt. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied versmn: 5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED'. All wellpaths within 200'+ 10011000 of reference Scan Type: 2540 Anticollision Report for Plan: 2K-30 - 2K-30wpl2 Tmv, Cylinder North Proximity Scan on Current Survey Data (North Reference) 233.78 374.51 227.54 Reference Design: Kuparuk 2K Pad - Plan: 2K -30 -Plan: 2K-30-2K.30vrpi2 37.457 Centre Distance Pass -Major Risk 595.38 Scan Range: 0.00 to 25,291.41 usft. Measured Depth. 595.38 225.29 60DW Scan Radius is 2,725.24 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Pass - Major Risk 374.51 Measured Minimum @Measured Ellipse jilliffientsured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (usf) (usft) (usft) just) usft Kuparuk 2K Pad 2K -09 -2K -09-2K-09 2K-09 -2K-W -2K-09 2K-09-21<-WL1-2K-OPL1 2K -09 -2K -09L1 -2K -09L1 2K -09.2K -09L1 -01-2K-0911-01 2K -09 -2K -0911-01-2K-0911-01 2K-10 - 2K-10 - 2K-10 2K -10 -2K -10-2K-10 2K-11 -2K-11 -2K-11 2K-11 -2K-11 -2K-11 2K -11 -2K -11A -2K -11A 2K -11 -2K -11A -2K -11A 2K-11-2K-11AL1-21<-11AL1 2K-11-2K-11AL1-2K-11AL1 2K-11-2K-11APBt-2K-itAPBi 2K-11-2K-11APB1-2K-11APB/ 2K -12 -2K -12-2K-12 2K.12 -2K -12-2K-12 2K -13 -2K -13-2K-13 2K -13 -2K -13-2K-13 2K -13 -2K -13A -2K -13A 2K -13 -2K -13A -2K -13A 2K-13-2K-13AL1-21<-13AL1 2K-13-2K-13AL1-2K-13AL1 2K-13-21(-13AL2-21(-13AL2 2K-13-2K-13AL2-2K-13AL2 2K -14-2K-14 -2K-14 2K -14 -2K -14-2K-14 37451 233.78 374.51 227.54 375.00 37.457 Centre Distance Pass -Major Risk 595.38 235.08 595.38 225.29 60DW 24010 Clearance Factor Pass - Major Risk 374.51 23378 374.51 227.54 37500 37.458 Centre Distance Pass - Major Risk 59538 235.08 595.38 22529 600.00 24.010 Clearance Factor Pass - Major Risk 374.51 233.78 374.51 22754 375.00 37.458 Centre Distance Pass - Major Risk 595.38 23508 595.38 225.29 600.00 24.010 Clearance Fad" Pass - Major Risk 34998 209.60 349.98 201.80 350.00 26.868 Centre Distance Pass - Major Risk 62029 212.77 62029 198.35 625.00 14.781 Clearance Factor Pass - Major Risk 50.70 18505 50.70 182.71 W.W 79324 Centre Distance Pass -Major Risk 596.53 188.81 596.53 177.79 GOO.W 17.133 Clearance Factor Pass - Major Risk 53.70 185.05 5070 182.71 50.00 79.324 Canine Distance Pass - Major Risk 596.53 188.81 596.53 177.79 600.00 17.133 Clearance Fedor Pecs - Major Risk 54.70 185.05 54.70 182.66 SDW 77.363 Centre Distance Pass - Major Risk 600.00 188.89 600.00 1T.80 WO.00 1]034 Clearance Fader Pass - Major Risk 50.70 18505 50.70 182.71 53.00 79.324 Centre Distance Pass - Major Risk 596.53 188.81 596.53 17719 60).W 17.133 Clearance Factor Pass - Major Risk 32542 158.84 325.42 152.87 325.00 26.597 Centre Distance Pass - Major Risk 596.98 WAS 596.98 153.15 000.00 14.618 Clearance Factor Pass -Major Risk 5310 70.15 50.70 67.58 W.00 27.260 Centre Distance Pass - Major Risk 474.86 7205 47486 64.05 475.00 9.W5 Clearance Fact" Pass - Major Risk 50.70 70.15 00.70 67.58 50.00 27.260 Centre Distance Pass - Major Risk 474.86 72.05 474.86 64.05 475.00 9.005 Clearance Factor Pass - Major Risk 0070 70.15 50.70 67.58 W.W 27.260 Centre Distance Pass - Major Risk 47486 72.05 474.86 6405 475.00 9.005 Clearance Factor Pass - Major Risk W]0 70.15 5370 67,58 5000 27.200 Canoe Distance Pass - Major Risk 474.86 72.05 47486 6405 47500 9,OD5 Clearance Factor Pass - Major Risk 5070 45.02 50.70 42.44 53.W VASA Centre Distance Pass - Major Risk 500.00 47.00 500.00 38.58 530.00 5.582 Cleara ce Factor Pass - Major Risk 08 June, 2017- 11:24 Page 2 of8 COMPASS Anticollision Report for Plan: 2K-30 - 2K-30wpl2 Tmv. Cylindo- North Proximity Scan on Current Survey Data (North Reference) Reverence Design: Kupamk2K Pad -Plan: 2K-30. Plan: 2K-30-21K-30wp12 Scan Range: D.00 to 25,291.41 usft. Measured Depth. Scan Radius is 2,725.24 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Silo Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) loan) usft 2K -14 -2K -14A -2K -14A 50,70 1502 5030 42.44 50.00 17.4313 Centre Distance Pass - Major Risk 2K -14 -2K -14A -2K -14A 500.00 47.00 500.00 38.58 500.00 55W Clearance Factor Pass - Major Risk 2K-14-2K-14AL1-2K-14AL1 50]0 45.02 50]0 4244 50.00 17.436 Centre Distance Pass - Major Risk 2K-14-2K-14AL1-2K-14AL1 5W.W 47.W 50000 38.58 5DDW 5.582 Clearance Fact" Pass - Major Risk 2K -15 -2K -15-2K-15 50]0 1992 50.70 17.55 50.00 8.392 Centre Distance Pass - Major Risk 2K -15 -2K -15-2K-15 500.30 22.67 500.30 1130 50000 1.994 Clearance Factor Pass - Major Risk 2K -15 -2K -1511 -2K -15L1 50.70 19.92 W.70 17.55 W.W 8.392 Centre Distance Pass - Major Risk 2K -15 -2K -151.1-2K-151_1 500.30 22.67 W0.30 11.30 500.00 1.994 Clearance Factor Pass - Major Risk 2K -15.2K -1511-01-2K-1511-01 50.70 19.92 50]0 17.55 50.00 8.392 Centre Distance Pass - Major Risk 2K -15 -2K -15L7 -01-2K-1511-01 5DD30 22.67 500.30 11.30 500.00 1.994 Clearance Factor Pass - Major Risk 2K-15-2K-15Li42-2K-1511-02 50.70 19.92 50.70 17.55 SO 00 8.392 Centre Distance Pass - Major Risk 2K -15 -2K -151_1-02-2K-151_1-02 500.30 22.67 5DD30 11.30 500.00 1.994 Clearance Factor Pass - Major Risk 2K -16 -2K -i6 -2K-16 50.70 5.09 5).70 2.72 50.00 2.145 Centre Distance Pass - Major Risk WAS .2K.16 - 2K-16 iiiiiiiiiimi iiiiiiiiiiiimi- - 2K -17 -2K -17-2K-17 57599 28.83 575.99 19.31 575W 3.028 Centre Distance Pass - Major Risk 2K -17 -2K -17-2K-17 65077 29.29 650.77 1554 650.00 2.723 Clearance Factor Pass - Major Risk 2K -18 -2K -18-2K-18 651.05 5204 651.05 41.68 650.00 5024 Centre Distance Pass - Major Risk 2K -18 -2K -18-2K-18 725.59 52.48 725.59 40.88 725.00 4.525 Clearance Factor Pass - Major Risk 2K-19-2KA9-2K-09 1,533.5) WAS 1,533.50 29.71 1,525.00 2.122 Clearance Factor Pass - Major Risk 2K -19 -2K -19A -2K -19A 1,533.W 50.18 1,533.50 29.76 1,52500 2.126 Clearance Fact" Pass - Major Risk 2K-19-2K-19AL1-2K-19AL1 1,533.50 56.18 1,53350 29.76 1,525.00 2.126 Clearance Fact" Pass - Major Risk 2K -20 -2K -20-2K-20 652.30 103.77 652.30 88.72 650.00 6.894 Centre Distance Pass - Major Risk 2K -20 -2K -20-2K-20 1,36094 11137 1,360.94 78.23 1,350.00 3.361 Clearance Fact" Pass - Major Risk 2K -21 -2K -21-2K-21 527.34 129.88 527.34 121.26 525,00 15.066 Centre Distance Pass - Major Risk 2K -21 -2K -21-2K-21 602.65 130.50 602.66 120.71 Si 13.331 Clearance Factor Pass - Major Risk 2K -21 -2K -21A -2K -21A - 2K -21 -2K -21A -2K -21A - - 2K -22 -2K -22-2K-22 527.62 15324 527.62 141.24 525.00 1Z. 2 Can" Distance Pass - Major Risk 2K -22 -2K -22-2K-22 W2.98 154.11 602.98 140.30 600.00 11.152 Clearance Fact" Pass - Major Risk 2K -22 -2K -22A -2K-224 527.62 153.24 52762 141.24 52500 12.772 Centre Distance Pass - Major Risk 08 June, 2017 - 11:24 Page 3 ov8 COMPASS Anticollision Report for Plan: 2K-30 - 2K-30wp12 Tray. Cylinder North Proximity Scan on Comm Survey Data (North Reference) Reference Design: Kuparek 2K Pad - Plan: 2K -30 -Plan: 2K-30-2K-30wp12 Scan Range: 0.00 to 25,291.41 usft. Measured Depth. Sean Radius is 2,725.24 usft. Clearance Factor cutoff is Unlimited Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (usft) (usft) (usft) (usft) usft 2K -22 -2K -22A -2K -22A 602.98 154.11 602.98 140.30 600.00 11.152 Clearance Factor Pass - Major Risk 2K-22-2K-22AL1-2K-22AL1 527.62 153.24 527.62 14124 52500 12.M Centre Distance Pass -Major Risk 2K-22-2K-22AL1-2K-22AL1 602.98 154.11 602.98 140.30 600A0 11.152 Clearznce Factor Pass - Major Risk 2K-22-2K-22ALb01-21<-22AL1-01 527.62 15324 52262 141.24 52500 12.7]2 Centre Distance Pass - Major Risk 21<-22-21(-22A11-01-2K-22AL1-01 602.98 154.11 602.98 140.30 600.00 11.152 Clearance Factor Pass - Major Risk 2K -23 -2K -23-2K-23 200.70 179.89 200,70 176.49 2(1000 52.921 Centre DSMfca Pass - Major Risk 2K -23 -2K -23-2K-23 427.15 181.28 427.15 174.26 425.00 25.793 Clearance Factor Pass - Major Risk 2K-23-2K-23A-2K-23A_wp0S 200.70 179.89 200.70 176.84 200.00 58.975 Centre Distance Pass - Major Risk 2K-23.2K-23A-2K-23A_wpW 427.15 181.28 427.15 17460 425.00 27.140 Clearance Factor Pass - Major Risk 2K-23-2K-23AL1-2K-23AL1 wP08 200.70 17989 200.70 176.84 200.00 58975 Centre Distance Pass - Major Risk 2K-23-2K-23AL1-2K-23AL1_wp08 427.15 181.28 427.15 174.60 425.00 27.140 Clearance Factor Pass - Major Risk 2K -24 -2K -24-2K-24 225.70 204.73 225.70 200.93 225.00 53.750 Centre Distance Pass - Major Risk 2K -24 -2K -24-2K-24 376.77 205.97 376.77 199.79 375.00 33.318 Clearance Factor Pass - Major Risk 2K-24.2K-24AL2-2K-24AL2_wpM 225.70 20473 225.70 200.97 225.00 54.420 Centre Distance Pass - Major Risk 2K-24-2K-24AL2-2K-24AL2wP02 376.77 205.97 376.77 199.83 375.00 33.573 Clearance Factor Pass - Major Risk 2K-24-21K-24AL24)1-2K-2"U411_sp02 225.70 20473 225.70 200.97 22500 54.420 Centre Distance Pass - Major Risk 21<-24-21<-24AL2-01-2K-24AL2-01_wp02 376.77 205.97 376.77 199.83 37500 33.573 Clearance Factor Pass - Major Risk 2K -25 -2K -25-2K-25 W.70 230.03 50.70 22728 50.00 83]25 Centre Distance Pass - Major Risk 2K -25 -2K -25-2K-25 35148 230.99 351.48 22507 350.00 39.025 Clearance Factor Pass - Major Risk 2K -25 -2K -251-1-2K-2511 50.70 23003 W.70 227.28 5000 83.725 Centre Distance Pass - Major Risk 2K -25 -2K -2511-2K-2511 35148 230.99 351.48 22507 350.00 39.025 Clearance Factor Pass - Major Risk 2K -25 -2K -251101-2K-251-1-01 5070 230.03 50.70 22802 5000 114.268 Centre Distance Pass - Major Risk 2K -25 -2K -2511 -01 -2K -25L1-01 351.48 23099 351.48 22542 35000 41.470 Clearance Factor Pass - Major Risk 2K -27 -2K -27-2K-27 2,290.54 10895 2,290.54 72.40 2,225.00 2981 Clearance Factor Pass - Major Risk 2K -27 -2K -27-2K-27 2,314.18 10872 2,314.18 72.56 2,250.00 3008 Centre Distance Pass - Major Risk 2K -28 -2K -28-2K-28 2,079.08 97.43 2,079.08 48.44 2,125.00 1,989 Centre Distance Pass - Major Risk 2K -28 -2K -28-2K-28 2,248.17 101.75 2,248.17 45.22 2,300.00 1.800 Clearance Factor Pass - Major Risk 2K -26 -2K -28A -2K -28A 2,079.08 97,43 2,079.08 48.07 2,125.00 1.974 Centre Distance Pass -Major Risk 2K -28 -2K -28A -2K -28A 2,248.17 101.75 2,248.17 44.74 2,300.00 1.785 Clearance Factor Pass - Major Risk 2K-28-2K-28AL1-2K-28AL1 2,079.08 9743 2,079.08 47.94 2.125.00 1.969 Centre Distance Pass - Major Risk 08 June, 2017 - 11:24 Page 4 of 6 COMPASS Anticollision Report for Plan: 2K-30 - 2K-30wp12 Tri Cylinder North Proximity Sean on Current Survey Data (North Reference) Reference Design: Kupamk2K Pad -Plan: 2K -50 -Plan: 2K-30-21K.30wp12 Scan Range: 0.00 to 25,291.41 ash. Measured Depth. Scan Radius is2,725.24usM. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse iiialeasured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (usft) (usK) (usK) (usft) usft 2K-28-2K-28AL1-21K-28AL1 2,248.17 10175 2,24847 44.61 2,300.00 1.781 Clearance Factor Pass - Major Risk 2K-28-2K-28AL1 PBI -2K-284LI PBI 2,079.08 9743 2,07908 48.07 2,125.00 1.974 Centre Distance Pass - Major Risk 2K-28-2K-28ALiPB1-2K-2BAL1PB1 2,248.17 101.75 2,248.17 44.74 2,300.00 1.785 Clearance Factor Pass - Major Risk 2K-28 - 2K-28AL1PB2 - 2K-2BAL1PB2 2,079.08 97.43 2,079.08 48.07 2,125.00 1,974 Centre Distance Pass - Major Risk 2K -28 -2K -28A 1PB2-2K-28AL1PB2 2,248.17 101.75 2,248.17 44.74 2,300.00 1.785 Clearance Factor Pass - Major Risk 2K-28-2K-28AP81-2K-28APB1 2,07908 97.43 2,079.08 4807 2,125.00 1.974 Centre Distance Pass - Major Risk 2K-2B-2K-28APB1-2K-28APB1 2,248.17 101.75 2,248.17 44.74 2,300.00 1.785 Clearance Facts Pass - Major Risk 2K -34 -2K -34-2K-34 16157 254.76 161.57 251.86 150.00 87.904 Centre Distance Pass - Major Risk 2K -34 -2K34 -2K-34 557.36 257.81 557.36 248.45 550.00 27.563 Clearance Factor Pass - Major Risk 2K-34-21<341_1-2K34Li 161.57 254.76 161.57 251.86 15000 87.904 Centre Distance Pass - Major Risk 2K34-21<34L1-2K34L1 557.36 257.81 557.38 248.45 550.00 27.563 Clearance Factor Pass - Major Risk 2K34-21(-34PB1-21<34PB1 161.57 25476 161.57 25147 15000 77.586 Centre Distance Pass - Major Risk 21(34-2K-34PB1-2K34PB1 557.36 257.81 557.36 248.45 550.00 27.563 Clearance Factor Pass - Major Risk Plan: 2K31 -Plan. 2K -31-2K31 wp05 308.71 24.99 308.71 19.52 300.00 4.565 Centre Distance Pass - Major Risk Plan: 2K31 -Plan: 2K-31-2K-31wp05 408.82 2548 408.82 18.48 40000 3.642 Clearance Factor Pass - Major Risk Plan: 2K33 -Plan: 21(33-2K-33WP07 298.40 259.98 298.40 254.66 300.00 48.863 Centre Distance Pass - Major Risk Plan: 2K33 -Plan: 21(33-2K-33NP07 451.05 261.12 451.05 253.53 450.00 34.414 Clearance Factor Pass - Major Risk TO 2K32.21<32 -2K32 248.88 49,23 248.88 44.85 250.00 11.224 Centre Data. Pass - Major Risk TD: 2K -32 -2K -32-2K32 323.89 49.66 32389 44.01 325.00 8.783 Clearance Factor Pass - Major Risk 06June,2017- 11:24 Page5o18 COMPASS Anticollision Report for Plan: 2K-30 - 2K-30wp12 Survey tool program From To (--ft) (--ft) 39.00 1,3W.W 2K-30wpl2 1,3W.W 3,31304 21<SOwp12 2,3W.W 3,313.04 21<30wp12 3,313.04 4,813.04 21<JOwp12 3,313.04 11,712.78 2K4tOwp12 11,712.78 11,732.78 21<-30wp12 11,712.78 25,291.41 21(-WwpV Ellipse emor tens ere conelaoxi across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids, Distance Between centres is the smsght line distance between wellbore centres. Clearance Factor = Distance Between Profiles /(Distance Between Profiles - Ellipse Separation). All station cconlinates wane calculated usaw the Minimum Curvature method. SurveylPlan Survey Tool GVD GC -SS MWD MWD.IFR-AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC MWD MW IFR-AK-CAZSC 08 June, 2017 - 1124 Page 6 of 6 COMPASS Ladder View View 9:54, da"e a 2017Ladder 2 K -30w p 1 2 The Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. of 00 300-- O 0 m ro oU � I 150-- so U 0 Fqul l.nl MgMlc OISIah¢ Q 0 3500 7000 10500 14000 17500 21000 Displayed interval could be less than entire well:Measured Depth 39.00 To 25291.41 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.00 1200.00 2K-30wp12 (Plan: 2K-30) GYD-GC-SS 116.20 116.20 20" x 42" 1200.00 2200.00 2K-30wpl2 (Plan: 2K-30) MWD 2844.70 3313.04 103/4" x 13-1/2 2500.00 3313.04 2K-30wpl2 (Plan: 2K-30) MWD+IFR-AK-CAZ-SC 6349.70 11717.54 7-5/8" x 9-7/8" by 11" 3313.04 4813.04 2K-30wpl2 (Plan: 2K-30) MWD 6484.70 25291.41 4 1/2" x 6-3/4" 3313.04 11717.54 2K-30wpl2 (Plan: 2K-30) MWD+IFR-AK-CAZ-SC 11717.54 13217.54 2K-30wpl2(Plan: 2K-30) MWD 11717.54 25291.41 2K-3Owpl2(Plan: 2K-30) MWD+IFR-AK-CAZ-SC _ liu n n M nL' y N 60 c I N ad N 2 30- 0 0 0 0 500 1000 1500 2000 2500 3000 3500 Partial Measured Depth TC View AC Wells Only AC wells ONLY (NOT a 5P)der) Kuparuk 2S Pad Easling (3500 ustVin) 23 {43ALNp0P08 AC Flipbook i 2K-30WP12 • • • To 3350.00 .. • Y�«MNq• w^ . � � o s• All , : � iFIE • � r,1 ' • • • + • ����•ni . 111♦1���1� 1F Y• Qr�� �I P ��r� ��.�' ��.�M,�Qi�1✓�`��;,.� � ���.T���-•sem ����,��\1� . . . h+ o:- �NwyygII�S�vlir,l: f Ir 2K-30wp1z 335o.00 To »750.00 v.re°wq .°,o ii6.q ia,.J° 3, .a:,: :ay.`n iyN „-.s�,. 94- 0/36o >,,,� m.ao ,Swm UIH �nn.N 11J :wR.q�^ .. i 3o'W:,(Rart,wp� m,oyn(ganazl°I 3gO.W iR3oWnlPartiF.lo) i. ,N„x1o1 O:)N JF,eryn(gan:iM13o) :vn.N ixNWnlwh,x.,n) W[N.X ux 39 300 3 00 - 490 MD Azi 3900 0.00 490 670 300.00 0.00 0 800.00 255.00 -30/33 0 670 860 1477.61 238.64 86o-1040 158443 238.64 3313.04 211.96 ,. 1040 1230 333304 211.96 1230 1410 3562.19 217.54 10586.03 217.54 -6o/300 6o 1410 1600 11717.54 19o.65 - 1600 z5go 1173754 190.65 2590 3580 11844.0119o.65 1356o.87 19o.65 3 O 3580 4560 136o8.10 19o.67 4560 5550 14478.53 190.67 18607.87 186.43 5550 6540 19724.99 186.43 -(0/270 9 0 6540 7520 19829.07189.5o 7520 8510 20800.49 189.50 20873.16 18745 8510 - 9500 25291-41 187-45 30 9500 11470 11470 13450 13450 15420 -120/240 120 15420 17400 6o 17400 19370 19370 21340 21340 23320 -150/210 150 23320 25291 90 -18o/18o 1o:o9, June 13 2017 i 2K-30wp12 » 75o.00 To 25291.4 GLry an> i°° i 3)lnx 6H9 )o pilH 6083.]0 i5i9,3 Mtlk X011"0'ilx ])li°,9-IMhn /x"a63N' / N m waw J)O.W 3)O.W 36011)11 SumY�^ Poaam SwgryYn 1i00eo ix.N ilmrt,xeo) 330, ,K3d^9n(pma1. OBO.W ak3aSa(Nm) ,x -3a i)0.51 a 3ro,IP,rt ax9e) ,.)a, 1001 cO «sc WD ux 39 300 300 490 MD Azi0 3900 0.00 490 670 300.00 0.00 90 800.00 255.00-30133 0 670 860 1477.61 238.64 - 86o 1040 1584.43 238.64 33804 211.96 1040 1230 3333.04 211.96 60 1230 1410 3562.19 217.54 - 1410 1600 10586.03 217.54 -601300 60 11717.54 19o.65 1600 2590 11737.54 190.65 2590 3580 11844.01 19o.65 13560.87 19o.65 30 _ 3580 4560 136o8.lo 19o.67 - 4560 5550 14478.53 19o.67 5550 6540 18607.87 186.43 1972499 186.43 -(0/270 (g 0 6540 7520 19829.o7 189.50 7520 8510 20800.49 189.5o 20873.16 187.45 8510 9500 25291.41 187.45 0 -30,) 9500 11470 11470 8450 8450 15420 -120/240 120 15420 17400 6o 17400 19370 19370 21340 21340 23320 -150/210 150 23320 25291 90 -18o/18o 10:14, June 13 2017 Errors Report ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad Plan: 2K-30 Plan: 2K-30 Plan: 2K-30wp12 Report - Errors 13 June, 2017 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: Plan: 2K-30 Wellbore: Plan: 2K-30 Design: 2K-30wpl2 Schlumberger Report - Errors Local Co-ordinate Reference: Well Plan: 2K-30 TVD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) MD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 'roject Kuparuk River Unit, North Slope Alaska, United States lap System: System Datum: Mean Sea Level leo Datum: Using Well Reference Point lap Zone: Using geodetic scale factor Site Kuparuk 2K Pad Site Position: From: Map Position Uncertainty: Well Plan: 2K-30 Well Position +N/,S +EI -W Position Uncertainty Wellbore Magnetics Design Audit Notes: Version: Vertical Section: Northing: Easting: 0.00 usft Slot Radius: Plan: 2K-30 Model Name 0.00 usft 0.00 usft 0.00 usft BGGM2016 2K-30wpl2 Northing: Easting: Wellhead Elevation Sample Date Declination (°I 6/25/2017 Phase: PLAN Depth From (TVD) +N/ -S (usft) (usft) 39.00 0.00 Latitude: Longitude: 0" Grid Convergence: -0.02 Latitude: Longitude: 0.00 usft Ground Level: 115.70 usft Dip Angle Field Strength (°) (nT) 17.43 80.86 57.528 Tie On Depth: 39.00 +E/ -W Direction (usft) (°) 0.00 190.00 Survey Tool Program Date 6/8/2017 From To (usft) (usft) Survey (Wellbore) Tool Name Description 39.00 1,200.00 2K-30wpl2 (Plan: 2K-30) GYD-GC-SS Gyrodata gyro single shots 1,200.00 2,200.00 2K-30wpl2 (Plan: 2K-30) MWD MWD- Standard 2,500.00 3,313.04 2K-30wpl2 (Plan: 2K-30) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3,313.04 4,813,04 2K-30wpl2 (Plan: 2K-30) MWD MWD - Standard 3,313.04 11,717.54 2K-30wpl2 (Plan: 2K-30) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11,717.54 13,217.54 2K-30wpl2 (Plan: 2K-30) MWD MWD - Standard 11,717.54 25,291.41 2K-30wpl2 (Plan: 2K-30) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 39.00 0.00 0.00 0.00 -115.70 0.00 0.00 0.00 100.00 1.15 0.00 0.00 -54.70 1.15 0.04 0.04 116.20 1.15 0.00 0.00 -38.50 1.15 0.19 0.19 20" x 42" 200.00 1.15 0.00 0.00 45.30 1.15 0.19 0.19 300.00 1.15 0.00 0.00 145.30 1.15 0.33 0.33 KOP: Start 1.5°/100' DLS, 255° TF, for 500' - KOP: Start 1.5°/100' DLS, 255° TF, for 500' 6/132017 9:20:07AM Page 2 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Plan: 39 + 115.7 @ 154.70usft (Doyon142) Site: Kuparuk 2K Pad MD Reference: Well: Plan: 2K-30 Plan: 39 + 115.7 @ 154.70usft (Doyonl42) Wellbore: Plan: 2K-30 True Design: 2K-30wp12 Survey Calculation Method: Minimum Curvature Planned Survey Database: MD MD Error Inc (usft) (usft) (°) 400.00 1.15 1.50 500.00 1.15 3.00 600.00 1.15 4.50 700.00 1.16 6.00 800.00 1.16 7.50 Start 2°/100' DLS, -25° TF, for 677.61' 1.15 900.00 1.17 9.35 1,000.00 1.17 11.25 1,100.00 1.18 13.18 1,200.00 1.20 15.13 1,300.00 1.22 17.09 1,400.00 1.23 19.06 1,477.61 1.25 20.59 Hold for 106.82' - Hold for 106.82' 75.87 1,500.00 1.25 20.59 1,531.02 1.26 20.59 Base Permafrost 1.40 1.32 1,584.43 1.26 20.59 Start 2.5°1100' DLS, -35° TF, for 1728.61' 69.57 1,600.00 1.26 20.91 1,700.00 1.29 23.01 1,800.00 1.33 25.19 1,900.00 1.37 27.41 2,000.00 1.42 29.68 2,100.00 1.49 31.98 2,200.00 1.57 34.30 2,300.00 1.66 36.64 2,321.12 1.77 37.14 WS -Top 1.61 60.06 2,400.00 1.77 39.00 2,500.00 1.90 41.38 2,600.00 2.04 43.76 2,700.00 2.18 46.16 2,800.00 2.32 48.56 2,900.00 2.47 50.98 3,000.00 2.62 53.39 3,100.00 2.78 55.82 3,115.36 2.93 56.19 WS Base 2.14 51.76 3,200.00 2.93 58.24 3,300.00 3.08 60.67 3,313.04 3.12 60.99 Hold for 20'. 10 3/4" x 13-1/2 2,044.00 3,333.04 3.12 60.99 Start 2.5°/100' DLS. 60.99° TF. for 229.14' 2,106.09 Schlumberger Report - Errors Local Co-ordinate Reference: Well Plan: 21K-30 TVD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) MD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyonl42) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (°) (usft) (usft) (usft) (usft) 135.00 245.29 1.15 0.44 0.44 164.31 345.21 1.15 0.53 0.53 163.55 444.99 1.15 0.65 0.64 135.00 544.57 1.15 0.78 0.77 77.26 643.87 1.15 0.92 0.90 77.17 742.79 1.15 1.07 1.04 75.87 841.18 1.15 1.23 1.17 73.45 938.91 1.15 1.40 1.32 71.10 1,035.87 1.15 1.58 1.46 69.57 1,131.93 1.15 1.70 1.53 64.70 1,227.00 1.15 1.82 1.54 62.06 1,300.00 1.15 2.02 1.55 61.55 1,320.96 1.14 2.09 1.56 60.21 1,350.00 1.15 2.40 1.61 60.21 1,400.00 1.15 2.40 1.61 60.06 1,414.56 1.16 2.46 1.61 58.92 1,507.30 1.17 2.88 1.67 57.54 1,598.58 1.18 3.39 1.76 56.05 1,688.23 1.19 3.97 1.87 54.56 1,776.07 1.22 4.62 2.00 53.12 1,861.94 1.26 5.33 2.14 51.76 1,945.67 1.31 6.10 2.31 50.46 2,027.11 1.38 6.93 2.48 49.25 2,044.00 1.47 7.81 2.67 49.25 2,106.09 1.47 7.81 2.67 48.63 2,182.48 1.48 8.33 2.77 48.39 2,256.12 1.48 8.49 2.76 48.08 2,326.87 1.48 8.67 2.76 47.70 2,394.60 1.49 8.88 2.76 47.27 2,459.18 1.51 9.12 2.76 46.78 2,520.49 1.55 9.38 2.75 46.25 2,578.41 1.59 9.67 2.75 45.68 2,587.00 1.65 9.98 2.76 45.68 2,632.83 1.65 9.98 2.76 45.09 2,683.64 1.72 10.32 2.76 45.03 2,690.00 1.68 10.39 2.76 44.82 2,699.70 1.68 10.55 2.76 6/132017 9:20:07AM Page 3 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: Plan: 21K-30 Wellbore: Plan: 21K-30 Design: 2K-30wp12 Planned Survey OAKEDMP2 MD MD Error Inc (usft) (usft) 0 3,400.00 3,500.00 3,562.19 Hold for 7023.84' 3,600.00 3,700.00 3,800.00 3,900.00 4,000.00 4,100.00 4,123.77 C-80 4,200.00 4,287.33 CAMP SST 4,300.00 4,400.00 4,500.00 4,600.00 4,700.00 4,800.00 4,900.00 5,000.00 5,100.00 5,200.00 5,300.00 5,400.00 5,500.00 5,600.00 5,700.00 5,800.00 5,900.00 6,000.00 6,100.00 6,200.00 6,300.00 6,400.00 6,500.00 6,600.00 6,700.00 6,800.00 6,900.00 7,000.00 7,100.00 7,200.00 2.98 61.81 2.79 63.08 2.70 63.88 Schlumberger Report - Errors Local Co-ordinate Reference: Well Plan: 2K-30 TVD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyonl42) MD Reference: Plan: 39+ 115.7 @ 154.70usft (Doyon142) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (°) (usft) (usft) (usft) (usft) 44.16 2,731.75 1.70 11.17 2.70 43.31 2,778.02 1.77 12.17 2.65 42.90 2,805.79 1.83 12.83 2.65 2.70 63.88 42.69 2,822.43 1.88 13.21 2.70 2.71 63.88 42.21 2,866.45 2.04 14.25 2.83 2.71 63.88 41.78 2,910.47 2.22 15.34 3.00 2.72 63.88 41.40 2,954.50 2.43 16.46 3.20 2.73 63.88 41.07 2,998.52 2.66 17.62 3.41 2.74 63.88 40.78 3,042.54 2.90 18.81 3.65 2.75 63.88 40.52 3,053.00 3.15 20.01 3.89 2.75 63.88 40.52 3,086.56 3.15 20.01 3.89 2.75 63.88 40.30 3,125.00 3.41 21.24 4.16 2.75 63.88 40.30 3,130.58 3.41 21.24 4.16 2.76 63.88 40.10 3,174.60 3.67 22.48 2.77 63.88 39.93 3,218.62 3.94 23.73 2.78 63.88 39.77 3,262.64 4.22 24.99 2.79 63.88 39.63 3,306.66 4.49 26.27 2.80 63.88 39.51 3,350.68 4.77 27.55 2.84 63.88 41.56 3,394.70 2.97 16.09 2.85 63.88 41.40 3,438.72 3.10 16.52 2.86 63.88 41.24 3,482.75 3.23 16.96 2.87 63.88 41.10 3,526.77 3.36 17.41 2.88 63.88 40.96 3,570.79 3.50 17.86 2.89 63.88 40.83 3,614.81 3.63 18.31 2.90 63.88 40.70 3,658.83 3.77 18.77 2.91 63.88 40.58 3,702.85 3.91 19.24 2.92 63.88 40.47 3,746.87 4.05 19.71 2.93 63.88 40.36 3,790.89 4.19 20.18 2.94 63.88 40.26 3,834.91 4.33 20.65 2.95 63.88 40.16 3,878.93 4.47 21.13 2.96 63.88 40.07 3,922.95 4.61 21.61 2.98 63.88 39.98 3,966.97 4.76 22.09 2.99 63.88 39.90 4,010.99 4.90 22.58 3.00 63.88 39.82 4,055.02 5.05 23.07 3.01 63.88 39.74 4,099.04 5.19 23.56 3.02 63.88 39.67 4,143.06 5.34 24.05 3.04 63.88 39.60 4,187.08 5.48 24.54 3.05 63.88 39.53 4,231.10 5.63 25.04 3.06 63.88 39.47 4,275.12 5.78 25.53 3.07 63.88 39.41 4,319.14 5.92 26.03 3.09 63.88 39.35 4,363.16 6.07 26.53 3.10 63.88 39.30 4,407.18 6.22 27.04 4.43 4.70 4.99 5.28 5.58 3.71 3.83 3.96 4.10 4.23 4.37 4.51 4.65 4.80 4.94 5.09 5.24 5.39 5.54 5.69 5.85 6.00 6.16 6.31 6.47 6.63 6.78 6.94 7.10 6/13!1017 9:20:07AM Page 4 COMPASS 5000.1 Build 74 Schlumberger Report - Errors Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2K-30 Project: Kuparuk River Unit TVD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) Site: Kuparuk 2K Pad MD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyonl42) Well: Plan: 2K-30 North Reference: True Wellbore: Plan: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30wpl2 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (usft) (usft) 0 0 (usft) (usft) (usft) (usft) 7,251.83 3.11 63.88 39.24 4,430.00 6.37 27.54 7.26 C-50 7,300.00 3.11 63.88 39.24 4,451.20 6.37 27.54 7.26 7,400.00 3.13 63.88 39.19 4,495.22 6.52 28.04 7.42 7,500.00 3.14 63.88 39.14 4,539.24 6.67 28.55 7.58 7,600.00 3.15 63.88 39.10 4,583.27 6.81 29.06 7.74 7,700.00 3.17 63.88 39.05 4,627.29 6.96 29.56 7.91 7,800.00 3.18 63.88 39.01 4,671.31 7.11 30.07 8.07 7,900.00 3.19 63.88 38.97 4,715.33 7.26 30.58 8.23 7,933.33 3.21 63.88 38.93 4,730.00 7.41 31.09 8.39 C-40 8,000.00 3.21 63.88 38.93 4,759.35 7.41 31.09 8.39 8,100.00 3.22 63.88 38.89 4,803.37 7.56 31.61 8.56 8,200.00 3.24 63.88 38.85 4,847.39 7.71 32.12 8.72 8,300.00 3.25 63.88 38.82 4,891.41 7.86 32.63 8.88 8,400.00 3.27 63.88 38.78 4,935.43 8.01 33.15 9.05 8,444.45 3.28 63.88 38.75 4,955.00 8.16 33.66 9.21 C-37 8,500.00 3.28 63.88 38.75 4,979.45 8.16 33.66 9.21 8,600.00 3.29 63.88 38.72 5,023.47 8.31 34.18 9.37 8,700.00 3.31 63.88 38.69 5,067.49 8.46 34.69 9.54 8,800.00 3.32 63.88 38.66 5,111.52 8.61 35.21 9.70 8,900.00 3.34 63.88 38.63 5,155.54 8.76 35.73 9.87 9,000.00 3.35 63.88 38.60 5,199.56 8.91 36.25 10.03 9,100.00 3.37 63.88 38.57 5,243.58 9.07 36.76 10.20 9,200.00 3.38 63.88 38.55 5,287.60 9.22 37.28 10.36 9,300.00 3.40 63.88 38.52 5,331.62 9.37 37.80 10.53 9,400.00 3.42 63.88 38.50 5,375.64 9.52 38.32 10.70 9,500.00 3.43 63.88 38.47 5,419.66 9.67 38.84 10.86 9,600.00 3.45 63.88 38.45 5,463.68 9.82 39.37 11.03 9,700.00 3.46 63.88 38.43 5,507.70 9.97 39.89 11.19 9,730.21 3.48 63.88 38.41 5,521.00 10.12 40.41 11.36 C-35 9,800.00 3.48 63.88 38.41 5,551.72 10.12 40.41 11.36 9,900.00 3.49 63.88 38.39 5,595.74 10.28 40.93 11.53 10,000.00 3.51 63.88 38.37 5,639.76 10.43 41.45 11.69 10,100.00 3.53 63.88 38.35 5,683.79 10.58 41.98 11.86 10,200.00 3.54 63.88 38.33 5,727.81 10.73 42.50 12.03 10,300.00 3.56 63.88 38.31 5,771.83 10.88 43.02 12.19 10,398.07 3.58 63.88 38.29 5,815.00 11.03 43.55 12.36 HRZ 10,400.00 3.58 63.88 38.29 5,815.85 11.03 43.55 12.36 10,500.00 3.59 63.88 38.27 5,859.87 11.19 44.07 12.53 10,586.03 3.61 63.88 38.26 5,897.74 11.32 44.53 12.67 Start W/100' DLS, 53.90 TF, for 1131.51' 6/132017 9:20.07AM Page 5 COMPASS 5000.1 Build 74 Schlumberger Report - Errors Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2K-30 Project: Kuparuk River Unit TVD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) Site: Kuparuk 2K Pad MD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyonl42) Well: Plan: 2K-30 North Reference: True Wellbore: Plan: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30wpl2 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 10,600.00 3.68 64.13 38.26 5,903.86 11.34 44.58 12.69 10,700.00 4.62 65.93 38.24 5,946.08 11.49 44.86 12.85 10,709.64 6.05 66.10 38.20 5,950.00 11.64 45.06 13.03 HRZ_BASE 10,800.00 6.05 67.77 38.20 5,985.40 11.64 45.06 13.03 10,900.00 7.70 69.65 38.14 6,021.71 11.80 45.19 13.21 10,935.94 9.46 70.34 38.06 6,034.00 11.96 45.24 13.37 K-1 11,000.00 9.46 71.57 38.06 6,054.91 11.96 45.24 13.37 11,100.00 11.26 73.52 37.96 6,084.90 12.12 45.23 13.49 11,200.00 13.08 75.49 37.84 6,111.62 12.29 45.15 13.58 11,300.00 14.91 77.49 37.70 6,134.98 12.45 45.02 13.63 11,323.62 16.72 77.97 37.53 6,140.00 12.62 44.83 13.64 KUP_C 11,400.00 16.72 79.51 37.53 6,154.92 12.62 44.83 13.64 11,490.69 18.52 81.35 37.35 6,170.00 12.79 44.59 13.62 KUP_A5 11,500.00 18.52 81.54 37.35 6,171.38 12.79 44.59 13.62 11,600.00 20.29 83.58 37.15 6,184.33 12.96 44.30 13.58 11,700.00 22.02 85.64 36.93 6,193.72 13.13 43.95 13.53 11,717.54 22.33 86.00 36.89 6,195.00 13.16 43.89 13.53 Hold for 20' - KUP_A4 - 7-518" x 9-718" by 11" 11,737.54 22.38 86.00 36.90 6,196.40 13.16 44.01 13.54 Start V100' DLS, 0° TF, for 106.48' 11,800.00 22.50 87.87 36.64 6,199.73 13.16 44.50 13.35 11,844.01 22.57 89.19 36.46 6,200.86 13.17 44.86 13.24 Hold for 1716.86' 11,900.00 22.57 89.19 36.22 6,201.65 13.18 45.32 13.24 12,000.00 22.57 89.19 35.78 6,203.05 13.20 46.18 13.27 12,100.00 22.58 89.19 35.34 6,204.46 13.23 47.06 13.30 12,200.00 22.58 89.19 34.88 6,205.86 13.28 47.97 13.34 12,300.00 22.58 89.19 34.42 6,207.27 13.33 48.91 13.40 12,400.00 22.59 89.19 33.96 6,208.68 13.39 49.88 13.46 12,500.00 22.59 89.19 33.49 6,210.08 13.46 50.87 13.53 12,600.00 22.59 89.19 33.03 6,211.49 13.54 51.88 13.61 12,700.00 22.60 89.19 32.57 6,212.89 13.64 52.91 13.70 12,800.00 22.60 89.19 32.11 6,214.30 13.74 53.97 13.80 12,900.00 22.60 89.19 31.65 6,215.71 13.85 55.04 13.91 13,000.00 22.60 89.19 31.20 6,217.11 13.96 56.14 14.03 13,100.00 22.61 89.19 30.76 6,218.52 14.09 57.25 14.15 13,200.00 22.61 89.19 30.32 6,219.93 14.23 58.37 14.29 13,300.00 22.61 89.19 34.65 6,221.33 13.46 48.26 13.53 13,400.00 22.62 89.19 34.49 6,222.74 13.50 48.58 13.57 13,500.00 22.62 89.19 34.32 6,224.14 13.54 48.90 13.61 6/132017 9:20.:07AM Page 6 COMPASS 5000.1 Build 74 �I Schlumberger Report - Errors Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2K-30 Project: Kuparuk River Unit TVD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) Site: Kuparuk 2K Pad MD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) Well: Plan: 2K-30 North Reference: True Wellbore: Plan: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30wp12 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 13,560.87 22.62 89.19 34.21 6,225.00 13.57 49.10 13.63 Start 3°/100' DLS, 179.12° TF, for 47.23' 13,600.00 22.55 88.02 34.17 6,225.95 13.58 49.21 13.75 13,608.10 22.53 87.78 34.16 6,226.25 13.59 49.23 13.78 Hold for 870.44' 13,700.00 22.53 87.78 34.06 6,229.81 13.63 49.46 13.82 13,800.00 22.54 87.78 33.89 6,233.69 13.68 49.79 13.87 13,900.00 22.54 87.78 33.72 6,237.57 13.73 50.13 13.92 14,000.00 22.54 87.78 33.54 6,241.44 13.78 50.47 13.97 14,100.00 22.55 87.78 33.37 6,245.32 13.83 50.82 14.02 14,200.00 22.55 87.78 33.20 6,249.20 13.89 51.17 14.08 14,300.00 22.56 87.78 33.02 6,253.08 13.95. 51.52 14.13 14,400.00 22.56 87.78 32.85 6,256.95 14.01 51.88 14.19 14,478.53 22.56 87.78 32.71 6,260.00 14.05 52.17 14.24 Start 0.13°1100' OLS, -54.45° TF, for 4129.33' 14,500.00 22.58 87.79 32.67 6,260.83 14.07 52.23 14.25 14,600.00 22.68 87.87 32.52 6,264.62 14.13 52.52 14.31 14,700.00 22.77 87.94 32.37 6,268.27 14.20 52.82 14.37 14,800.00 22.86 88.01 32.21 6,271.80 14.27 53.12 14.43 14,900.00 22.96 88.09 32.05 6,275.21 14.34 53.43 14.49 15,000.00 23.05 88.16 31.89 6,278.48 14.41 53.75 14.56 15,100.00 23.15 88.23 31.73 6,281.63 14.48 54.07 14.62 15,200.00 23.24 88.31 31.56 6,284.64 14.56 54.40 14.69 15,300.00 23.34 88.38 31.39 6,287.53 14.64 54.74 14.76 15,400.00 23.43 88.45 31.21 6,290.29 14.71 55.08 14.83 15,500.00 23.53 88.53 31.04 6,292.93 14.80 55.43 14.91 15,600.00 23.63 88.60 30.86 6,295.43 14.88 55.79 14.98 15,700.00 23.72 88.67 30.68 6,297.81 14.96 56.15 15.06 15,800.00 23.82 88.75 30.50 6,300.06 15.05 56.51 15.14 15,900.00 23.92 88.82 30.31 6,302.18 15.14 56.89 15.22 16,000.00 24.02 88.90 30.13 6,304.17 15.23 57.26 15.31 16,100.00 24.11 88.97 29.94 6,306.03 15.32 57.65 15.39 16,200.00 24.21 89.04 29.76 6,307.77 15.41 58.04 15.48 16,300.00 24.31 89.12 29.57 6,309.38 15.50 58.43 15.57 16,400.00 24.41 89.19 29.38 6,310.86 15.60 58.83 15.66 16,500.00 24.51 89.26 29.19 6,312.21 15.70 59.23 15.75 16,600.00 24.61 89.34 29.00 6,313.43 15.79 59.64 15.84 16,700.00 24.71 89.41 28.81 6,314.53 15.89 60.05 15.93 16,800.00 24.81 89.48 28.62 6,315.49 15.99 60.47 16.03 16,900.00 24.92 89.56 28.42 6,316.33 16.10 60.89 16.13 17,000.00 25.02 89.63 28.23 6,317.04 16.20 61.32 16.23 17,100.00 25.12 89.70 28.04 6,317.62 16.31 61.75 16.33 17,200.00 25.22 89.78 27.85 6,318.07 16.41 62.19 16.43 17,300.00 25.33 89.85 27.66 6,318.40 16.52 62.63 16.53 17,400.00 25.43 89.92 27.46 6,318.59 16.63 63.07 16.63 6/132017 9:20:07AM Page 7 COMPASS 5000.1 Build 74 Schlumberger Report - Errors Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2K-30 Project: Kuparuk River Unit TVD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) Site: Kuparuk 2K Pad MD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) Well: Plan: 2K-30 North Reference: True Wellbore: Plan: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30wpl2 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (usft) (usft) 0 V) (usft) (usft) (usft) (usft) 17,500.00 25.54 90.00 27.27 6,318.66 16.74 63.52 16.74 17,600.00 25.64 90.07 27.08 6,318.60 16.85 63.97 16.85 17,700.00 25.74 90.14 26.89 6,318.41 16.96 64.43 16.95 17,800.00 25.85 90.22 26.70 6,318.10 17.08 64.89 17.06 17,900.00 25.96 90.29 26.51 6,317.65 17.19 65.35 17.17 18,000.00 26.06 90.37 26.32 6,317.08 17.31 65.81 17.29 18,100.00 26.17 90.44 26.13 6,316.38 17.42 66.28 17.40 18,200.00 26.28 90.51 25.94 6,315.55 17.54 66.76 17.51 18,300.00 26.39 90.59 25.75 6,314.59 17.66 67.23 17.63 18,400.00 26.49 90.66 25.56 6,313.50 17.78 67.71 17.74 18,500.00 26.60 90.73 25.38 6,312.29 17.90 68.19 17.86 18,600.00 26.71 90.81 25.19 6,310.94 18.02 68.68 17.98 18,607.87 26.72 90.81 25.18 6,310.83 18.03 68.72 17.99 Hold for 1117.12' 18,700.00 26.72 90.81 25.03 6,309.53 18.15 69.15 18.10 18,800.00 26.73 90.81 24.89 6,308.11 18.27 69.58 18.23 18,900.00 26.73 90.81 24.76 6,306.69 18.40 70.00 18.35 19,000.00 26.74 90.81 24.63 6,305.28 18.52 70.43 18.48 19,100.00 26.74 90.81 24.49 6,303.86 18.65 70.86 18.60 19,200.00 26.74 90.81 24.36 6,302.44 18.77 71.29 18.73 19,300.00 26.75 90.81 24.23 6,301.02 18.90 71.72 18.86 19,400.00 26.75 90.81 24.10 6,299.61 19.03 72.16 18.99 19,500.00 26.76 90.81 23.97 6,298.19 19.16 72.60 19.12 19,600.00 26.76 90.81 23.84 6,296.77 19.29 73.04 19.25 19,700.00 26.76 90.81 23.71 6,295.35 19.42 73.48 19.38 19,724.99 26.77 90.81 23.68 6,295.00 19.46 73.59 19.41 Start 3'1100' DLS, 100.57° TF, for 104.08' 19,800.00 24.45 90.40 23.62 6,294.21 19.56 74.62 19.53 19,829.07 23.58 90.24 23.62 6,294.05 19.59 74.95 19.58 Hold for 971.42' 19,900.00 23.58 90.24 23.57 6,293.75 19.69 75.17 19.68 20,000.00 23.59 90.24 23.47 6,293.33 19.82 75.61 19.81 20,100.00 23.59 90.24 23.36 6,292.92 19.96 76.06 19.94 20,200.00 23.60 90.24 23.25 6,292.50 20.09 76.50 20.08 20,300.00 23.60 90.24 23.14 6,292.08 20.23 76.95 20.21 20,400.00 23.61 90.24 23.04 6,291.67 20.36 77.40 20.35 20,500.00 23.61 90.24 22.93 6,291.25 20.50 77.85 20.49 20,600.00 23.62 90.24 22.83 6,290.83 20.64 78.31 20.63 20,700.00 23.62 90.24 22.72 6,290.42 20.78 78.76 20.76 20,800.00 23.63 90.24 22.62 6,290.00 20.92 79.22 20.90 20,800.49 23.63 90.24 22.62 6,290.00 20.92 79.22 20.90 Start 3°1100' DLS, -110.26' TF, for 72.67' 20,873.16 25.78 89.48 22.57 6,290.18 21.02 78.79 21.04 Hold for 4418.25' 20,900.00 25.78 89.48 22.55 6,290.42 21.06 78.88 21.08 6/132017 9:20:07AM Page 8 COMPASS 5000.1 Build 74 Schlumberger Report - Errors Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2K-30 Project: Kuparuk River Unit TVD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) Site: Kuparuk 2K Pad MD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon 142) Well: Plan: 2K-30 North Reference: True Wellbore: Plan: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30wp12 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Let Error Hom Error (usft) (usft) (0) V) (usft) (usft) (usft) (rift) 21,000.00 25.79 89.48 22.44 6,291.32 21.20 79.34 21.22 21,100.00 25.79 89.48 22.33 6,292.22 21.34 79.81 21.36 21,200.00 25.80 89.48 22.22 6,293.12 21.48 80.27 21.50 21,300.00 25.80 89.48 22.11 6,294.02 21.62 80.73 21.65 21,400.00 25.81 89.48 22.00 6,294.92 21.76 81.20 21.79 21,500.00 25.81 89.48 21.89 6,295.83 21.91 81.67 21.93 21,600.00 25.82 89.48 21.79 6,296.73 22.05 82.14 22.07 21,700.00 25.82 89.48 21.68 6,297.63 22.19 82.61 22.22 21,800.00 25.83 89.48 21.58 6,298.53 22.34 83.08 22.36 21,900.00 25.83 89.48 21.47 6,299.43 22.48 83.56 22.51 22,000.00 25.84 89.48 21.37 6,300.33 22.63 84.03 22.65 22,100.00 25.84 89.48 21.27 6,301.23 22.77 84.51 22.80 22,200.00 25.85 89.48 21.17 6,302.14 22.92 84.99 22.94 22,300.00 25.85 89.48 21.07 6,303.04 23.07 85.47 23.09 22,400.00 25.86 89.48 20.97 6,303.94 23.21 85.95 23.24 22,500.00 25.86 89.48 20.87 6,304.84 23.36 86.43 23.39 22,600.00 25.87 89.48 20.77 6,305.74 23.51 86.91 23.53 22,700.00 25.87 89.48 20.68 6,306.64 23.66 87.39 23.68 22,800.00 25.88 89.48 20.58 6,307.54 23.81 87.88 23.83 22,900.00 25.88 89.48 20.49 6,308.45 23.96 88.37 23.98 23,000.00 25.89 89.48 20.39 6,309.35 24.11 88.85 24.13 23,100.00 25.89 89.48 20.30 6,310.25 24.26 89.34 24.28 23,200.00 25.90 89.48 20.21 6,311.15 24.41 89.83 24.43 23,300.00 25.90 89.48 20.12 6,312.05 24.56 90.32 24.58 23,400.00 25.91 89.48 20.03 6,312.95 24.71 90.81 24.73 23,500.00 25.91 89.48 19.94 6,313.85 24.86 91.30 24.89 23,600.00 25.92 89.48 19.85 6,314.75 25.02 91.80 25.04 23,700.00 25.92 89.48 19.76 6,315.66 25.17 92.29 25.19 23,800.00 25.93 89.48 19.68 6,316.56 25.32 92.79 25.34 23,900.00 25.93 89.48 19.59 6,317.46 25.48 93.28 25.50 24,000.00 25.94 89.48 19.51 6,318.36 25.63 93.78 25.65 24,100.00 25.94 89.48 19.42 6,319.26 25.78 94.28 25.80 24,200.00 25.95 89.48 19.34 6,320.16 25.94 94.78 25.96 24,300.00 25.95 89.48 19.26 6,321.06 26.09 95.28 26.11 24,400.00 25.96 89.48 19.17 6,321.97 26.25 95.78 26.27 24,500.00 25.96 89.48 19.09 6,322.87 26.40 96.28 26.42 24,600.00 25.97 89.48 19.01 6,323.77 26.56 96.79 26.58 24,700.00 25.98 89.48 18.93 6,324.67 26.71 97.29 26.73 24,800.00 25.98 89.48 18.86 6,325.57 26.87 97.79 26.89 24,900.00 25.99 89.48 18.78 6,326.47 27.03 98.30 27.05 25,000.00 25.99 89.48 18.70 6,327.37 27.18 98.80 27.20 25,100.00 26.00 89.48 18.63 6,328.27 27.34 99.31 27.36 25,200.00 26.00 89.48 18.55 6,329.18 27.50 99.82 27.52 6/132017 9:20:07AM Page 9 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: Plan: 2K-30 Wellbore: Plan: 2K-30 Design: 2K-30wp12 Planned Survey MD MD Error Inc (usft) (usft) (°) 25,291.41 26.01 89.48 TD: 25291.41' MD, 6484.7' TVD Schlumberger Report - Errors Local Coordinate Reference: Well Plan: 2K-30 TVD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) MD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 Ellipse Inc TVDSS Vert. Error Let Error Horn. Error (°) (usft) (usft) (usft) (usft) 18.48 6,330.00 27.64 100.28 27.66 6/1312017 9:20:07AM Page 10 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: Plan: 2K-30 Wellbore: Plan: 2K-30 Design: 2K-30wp12 Casing Points Formations Schlumberger Report - Errors Local Co-ordinate Reference: Well Plan: 2K-30 TVD Reference: Plan: 39+ 115.7 @ 154.70usft (Doyon142) MD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (usft) (usft) 116.20 116.20 20"x42" 20 42 3,313.04 2,844.70 103/4"x13-1/2 10-3/4 13-1/2 11,717.54 6,349.70 7-5/8" x 9-7/8" by 11" 7-5/8 11 25,291.41 6,484.70 41/2"x6-3/4" 4-1/2 6-3/4 Measured Vertical 1,454.70 Dip Depth Depth Dip Direction (usft) (usft) Name Lithology 1,584.43 11,323.62 6,294.70 KUP_C -208.79 Start 2.5°/100' DLS, -35° TF, for 1728.61' 10,398.07 5,969.70 HRZ -941.45 -901.60 10,935.94 6,188.70 K-1 2,854.40 -956.29 11,490.69 6,324.70 KUP_A5 3,562.19 2,960.49 11,717.54 6,349.70 KUP_A4 Hold for 7023.84' 10,586.03 4,123.77 3,207.70 C-80 -4,869.19 Start 3°/100' DLS,-53.9° TF, for 1131.51' 9,730.21 5,675.70 C-35 -7,110.42 -5,295.53 10,709.64 6,104.70 HRZ_BASE 6,351.10 -7,130.03 8,444.45 5,109.70 C-37 11,844.01 6,355.56 7,933.33 4,884.70 C-40 Hold for 1716.86' 13,560.87 7,251.83 4,584.70 C-50 -5,636.06 Start 3°/100' DLS, 179.12° TF, for 47.23' 4,287.33 3,279.70 CAMP -SST -8,968.09 -5,644.79 3,115.36 2,741.70 WS -Base 6,414.70 -9,822.83 1,531.02 1,504.70 Base Permafrost 18,607.87 6,465.53 2,321.12 2,198.70 WS -Top Hold for 1117.12' 19,724.99 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP. Start 1.5°/100' DLS, 255' TF, for 500' 300.00 300.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 255" TF, for 500' 800.00 798.57 -8.46 -31.56 Start 2°/100' DLS, -25" TF, for 677.61' 1,477.61 1,454.70 -82.25 -176.71 Hold for 106.82' 1,477.61 1,454.70 -82.25 -176.71 Hold for 106.82' 1,584.43 1,554.70 -101.80 -208.79 Start 2.5°/100' DLS, -35° TF, for 1728.61' 3,313.04 2,844.70 -941.45 -901.60 Hold for 20' 3,333.04 2,854.40 -956.29 -910.86 Start 2.5'/100' DLS, 60.99° TF, for 229.14' 3,562.19 2,960.49 -1,123.01 -1,026.67 Hold for 7023.84' 10,586.03 6,052.44 -6,123.93 -4,869.19 Start 3°/100' DLS,-53.9° TF, for 1131.51' 11,717.54 6,349.70 -7,110.42 -5,295.53 Hold for 20' 11,737.54 6,351.10 -7,130.03 -5,299.21 Start 3°/100' DLS, 0° TF, for 106.48' 11,844.01 6,355.56 -7,234.57 -5,318.87 Hold for 1716.86' 13,560.87 6,379.70 -8,921.70 -5,636.06 Start 3°/100' DLS, 179.12° TF, for 47.23' 13,608.10 6,380.95 -8,968.09 -5,644.79 Hold for 870.44' 14,478.53 6,414.70 -9,822.83 -5,805.83 Start 0.13°/100' DLS, -54.45° TF, for 4129.33' 18,607.87 6,465.53 -13,904.57 -6,419.40 Hold for 1117.12' 19,724.99 6,449.70 -15,014.56 -6,544.48 Start 3°/100' DLS, 100.57° TF, for 104.08' 19,829.07 6,448.75 -15,117.62 -6,558.89 Hold for 971.42' 20,800.49 6,444.70 -16,075.71 -6,719.20 Start 3°/100' DLS, -110.26° TF, for 72.67' 20,873.16 6,444.88 -16,147.58 -6,729.91 Hold for 4418.25' 25,291.41 6,484.70 -20,528.32 -7,303.04 TD: 25291.41' MD, 6484.7' TVD 6/13/2017 9:20:07AM Page 11 COMPASS 5000.1 Build 74 Pool Report 2K-30wpl2 Surface Location r,% CPAI Coordinate Datum: NAD83 Region: alaska (- Latitude/Longitude IDecimalDegiees f UTM Zone: r' South t: State Plane Zone:Units: r Legal Description (NAD27 only) �- Starting Coordinates: ------ X: ----X: 1638342.% Y: 5937915.25 i 4. CPAI Coordinate From Datum fNAD83 Region. alaska !" Latilude/Longilude IDecimalDegrees (' UTM Zone: f— r South I-- State Plane Zone: F4-:-:] Units: usft .Ctio'o To Datum NAD27 _ Region: alaska l' Latitude/Longitude IDecimalDegiees (` UTM Zone: True r South 6- State Plane Zone: I' --�-] Units: us{t C Legal Description (NAD27 only) Ending Coordinates: X: 1498310148586085 Y: 15938165.19506962 quit I Help o:._ —__ _- __. ---- ._._.--- — Datum NAD27 Region: alaska C Latitude/Longitude DecimalDegrees (` UTM Zone: True T- South f State Poane Zone:—:-] one:� Units: usft R Legal Description (NAD27 only) - Starting Coordinates ---_________ --� Legal Description X: 11638342.95 Township: 010 I"J Range: DOB 1`J Y: 5937915.25 MeridianSection: 11 FNL � 138.69118 FEL 94.405757 Translorm i quit Help I 2K-30wp12 Surface Casing t �. CPAI Coordinate Convert. From: To. ._—__-- Datum: TAB- - Region: alaska Datum. NAD27 Region: alaska f Latitudekongitude Decimal Degrees 7 r Latitude/Longitude Decimal Degrees r' UTM Zone: F— r- South r UTM Zone: True F South i B State Plane Zone: I' J Units: us -ft C•' Slale Plane Zone:�� Units: us -ft r Legal Description (NADZ7 only) r Legal Description (NAD27 only) - Starting Coordinates:- ----- -- ----- - Ending Coordinates:------- -----� X: 1637441.18 1 X: F497408 34-8985382 Y: 5936974.15 i Y: 5937224.13404428 I ( ................Transform...............- Quit Help Q CPA[Coordinate From: Datum: NAD83 Region:alaska r Latitude/Longitude IDecimalDegrees --� f UTM Zone: [— r South C• State Plane Zone: F-':-:1 Units: us -ft Starting Coordinates: X: 1637441.18 Y: 5936974.15 Datum: NAp27 Regiar[alaska r- Latitude/Longitude IDecimalDegmes C' UTM Zane: True r South r State Plane Zane: Units: us -fl r•' Legal Description (NAD27 ony) Township: D10 I"J Range: 008 Meridian: Fu-----,] Sectionfj 1- FFNF.j 11080.1049 FEL 77F996.75468 .------ .--__.........--�--........, Transform ) Quit Help 2K-30wpl2 Intermediate Casing & Production Horizon Q CPAI Coordinate Converter From: To: Datum: NAD83 Region: alaska Datum FEF --D- Region. a-1. r Latitude/Longitude IDeamailDegfers t Latitude/Longitude IDecimalDegrees - j r UTM Zone: I — r South f UTM Zone: True r South G State Plane Zone: I" J Units: unfit (•' Slate Plane Zone: F Units: usft j f Legal Description (NAD27 only) f Legal Description (NAD27 only) 1 - Starling Coordinates: X: 1633046.D rErding Coordinates: — XX: 493012.999247049 Y: 5930807.00 Y: 5931057.20670675 Transform � quit Help M CPAI Coordinate Converter ..,.From:_-- --____----. __. __..__ To: Datum: FNA—D-83 Region: alaska .'. Datum: NAD27 Region: alaska r Latitude/Longitude IDecimal Degrees r Latitude/Longitude IDecimalDegrees f UTM Zone: r South f UTM Zone: IT,, ( South f C State Plane Zone: �� Units: I" J us�ft �—� r Slate Plane Zone: 1' _! Units: urft r Legal Description (NAD27 only) r Starting Coordinates: - --- - Legal Description- - ---- ---- -- - - -- X: 1633046.00 Township 010 FJ] Range: 008 FJ] Y: 5930807.00 Meddian: F-----] Secfion:l5 FNL 1970.4467 FEL .115.56295 i Trmsfcrm i quit Help 2K-30wp12 TD I Q CPAS Coordinate Converter_ From: ..____.- To: Datum: NA083 Region: alaska Datum: NAD27 - Region: aMa r Lafilude/Longitude IDecanalDegrees T Latitude/Longitude Decimal Degrees r UTM Zone: �- r" South i UTM Zone: Tme r South R State Plane Zone: I' J Units: us -ft G State Plane Zone: I' J Units: us.ft r Legal Description (NAD27 only) r Legal Description (NAD27 only) - Starling Coordinates:-- ---- - i Ending Coordinates- — - - X: 1631035.0 X 491001.799293336 Y: 5917391.0 Y: 5917641.55465642 (.............TransFonn.............. Quit Help ❑. CPA! Coordinate Converter - is k(al° d From: ...__.. ... .. _ _. ._.. Datum: NAD63 Region: alaska T Latitude/Longitude IDecimalDegiees r UTM Zone:1 r South G State Plane Zone:F I Units: urft C L c D27 only) Starting Coordinates:-- - - ----- X: 1631035.0 Y: 5917391.0 To:.__..— Datum: NAD27 Region: alaska r latitude/Longitude IDecimalDegrees—� C UTM Zone: True r South f Slate Plane Zone: I' J Units: w4t C•' Legal Description (NAD27 only( Legal Description ----------- --- --- - Ta ship: 570 I"J Range: �6 I`J Meddiarc 1" J Sectiarr 27 FNL 4829.5637 FEL 2133.5204 �_ Transform Quit Help 10:18, Jure 1320'7 2K-30wp12 °i"'xo a�waea.rwi M 7 w in.sa: nm.ao� Quarter Mile View " w °" """ ze.ma: An.+i1"u`o�aew"n"n u�mmwnaom 4500 .. _. 2K-0911 y a 0 �n _nII. -,P- �Y')APB, K 2K 1 rvr N 4500 r ic 4k. ' MWIO2 O v,LO 4 ? K 28,01 9 _ZK.2� 2 9000 _ 2K-ZZA4h01?25C I1 Ai. _ O Z 7513500- - + I j -18000---- I 2K-30wp,3 -18000 -13500 -9000 -4500 0 4500 9000 13500 18000 West( -)/East(+) (4500 usftlin) Tollerable Collision Risk Worksheet �w-" i ConocoPhillips Alaska ATolerable Collision Risk Worksheet based on Rev. 1 - 29 Jul 99 Use this sheet to describe a well intederencs scenario where nRA may be applicable. Check first that the scenario really 1 deferent fmm those described on exialin�i wrksheal . PraParetl b"� ,`J Voss it1 -7T �afJ_ AuthdnrW,ed p4: Paj el -------� ConocoPhillips Alaska, Inc Drilling Anti -Collision Management Generic name of scenario e - Collision risk with P&A'd 2K-16 wellbore while drilling 2K-30. Desonptton: (6es(y p*, In i�dRn`ai faccsina ;afs t ellher the oust of colllslan or ho costar- The cost of collision is estimated to be $750,000. That includes lost dg time to place cement plug and re -drill. These costs also Include all charges for equipment, personnel, and service on sfandy by during a second attempt. Do the consequences of collision include a risk to personnel or the environment? calhslo� and the'necessary Cles relryeialdion The consequence of a collision may Includes damaging the cement plug, P&A the curenl well, set whipstock and redrill Flow could the pftol ilyof; if:;lgn'or "the seveljly' oof the consequences` 6eTed ced$l�owmlghtthls r, impadilhedniknil opetakon? cast Gyro while unuN will be uee for and.. hole to provide accurate survey meawmlent enough the collision zone minimiztrg the chance of wllsion. $100009 a a tliapawallon email is uG4zeD for d t6rm ahead, I recommend bels Sauey yalp, lhe Sint swveybIc named huntlred feet sear k feet ff. ( Menept ofr final femme, Bine Producllon Database CDmpesa eloping) Praplanw0atabas cmdeptON) Are the consequences of collision Is there a practical way to substantially reduce either the probability of collision or the severlt�r of the consequences. t4M C = $750.000 V= $6,400,000 F = 0.05 subslag thally reducing ---'I V= $100,000 e risk 1, V F / C = 0.019047619 wen the �uncer)alnty In the above esjimefeb,'by,how If VF 1 men close approach tolerances need not be set nany limes must the saJirlgs made from n`6 ?P" C VF he risk — twelgh the risk itselfo,(Ggideline — 20) C < i men Tolerable Collision Risk = 1 In C / V F M= 71�1 7.5 F = 1 / M = 0.14 —� Tolerable Collision Risk = 1 in 53 9 ConocoPhillips Alaska ATolerable Collision Risk Worksheet bused on Rev, i-29 Jul W Use this sheet to describe a wall inteaderenc, ""= where diffe Q�'A I May his applicable. Check first that the so`iar is from these described on existing m7h., jy 1'�'jJacob cas J� N�4_� ConocoPhillips Alaska, Inc Drilling Anti -Collision Management Generic nameW Collision risk with 2K 21A wellbore while drilling 2K-30. DO d' bi , WN-l"It"SNOW's go !I lWhEii,51- -�N.2 KinN ,- ML'l _x" 'M '$ The cost of collision Is estimated to be roughly $41,110, 12.6 days. That Includes lost rig time to place cement plug and re -drill. Thew costs also Include all charges for equipment, personnel, and service on standy by during a second attempt. Since 2K -21A Is going to be P&Ncl due to it's subsidence problems, no costs were associated with hitting the lateral section of the well. Do the consequences of collision include a risk to personnel or the environment? Of. I fie consequence or a coinsion may Inclunnes camaging the willing assembly an could be set cement plug, P&A the curent "it, set whipstock and redrin the well. Willill sit . Mr IN:n Vr i RAW r 'a Ig a' Since 2K -21A Is a QYD Lateral in the Ko,rulk each, O."W91. well on.1.1 will dsnmt. or eslum Na chance a hiring We lateral as 2K - Well be above in (he Joileadit siale ikonm 5100,000 he nti�oelflaon intareal. V= $100,000 M= 7__J� 7.5 F F = 11 M = 0.14 Are the04. consequences of collision JAMUFAUSSMI C= $4.000,000 1 aw I V = $6,400,000 1 F = 0.06 VFIC= 0.003571429 It V F - I their close approach telencures neW not be set C If VF C, < I then Tolerable Collision task = I in C / V F Tolerable Collision Risk = 1 in 280 i As -built 3 15/22/4 MEH I NRB I (DRAWN PER K14002BACS 4 I4/21/IA LGM I JAH I IREV. PER K170005ACS 0 0 N Of a < a u SEE SHEET 2 & 3 FOR LOCATION ps , Inc. 2H I �_......_.._ _ 1 35� 36 w w 31 CO m TI IN ar( Tl ON 0 6 2G t .nl 2 1 PROJECT LOCATION 1 2K 11 12 7 9[�31911WRITIM&I NOTES: 1. BASIS OF LOCATION AND ELEVATION IS DS2K MONUMENTATION PER LOUNSBURY & ASSOC. 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES ARE NAD 27. 3. ELEVATIONS ARE B.P.M.S.L. 4. ALL CONDUCTORS ARE LOCATED WITHIN 2 1 PROTRACTED SECTION 2 & 11, TOWNSHIP 10 11+ 12 NORTH, RANGE 8 EAST, UMIAT MERIDIAN, AL 5. DATES OF SURVEY: 4/20/17 6. ALL DISTANCES SHOWN ARE GROUND AREA: 2K 0 AS -BUILT CONDUCTOR LOCATION • EXISTING CONDUCTOR LOCATION XPLUGGED AND ABANDON WELL GRAPHIC SCALE 5 iso wo i I I I inch = 150 it. LOUNSBURY & ASSOCIATES, INC. W"ORB RNCMUS MNMRS DS2K WELL CONDUCTORS 4SBUILT LOCATIONS —6211D14 1'" 1 OF 3 1'"*4 \ J—®30 --L x 2 \ 4.8' \ • 26 7029 — — • 1 — 2 4 29 • 1x8 \ \\ • 4 •5 5.3' •6 • 7 -�•34 —� 434 • 10 / • 20 • 21 • 11 �;` • 12 SEE SHEET 2 & 3 FOR LOCATION ps , Inc. 2H I �_......_.._ _ 1 35� 36 w w 31 CO m TI IN ar( Tl ON 0 6 2G t .nl 2 1 PROJECT LOCATION 1 2K 11 12 7 9[�31911WRITIM&I NOTES: 1. BASIS OF LOCATION AND ELEVATION IS DS2K MONUMENTATION PER LOUNSBURY & ASSOC. 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES ARE NAD 27. 3. ELEVATIONS ARE B.P.M.S.L. 4. ALL CONDUCTORS ARE LOCATED WITHIN 2 1 PROTRACTED SECTION 2 & 11, TOWNSHIP 10 11+ 12 NORTH, RANGE 8 EAST, UMIAT MERIDIAN, AL 5. DATES OF SURVEY: 4/20/17 6. ALL DISTANCES SHOWN ARE GROUND AREA: 2K 0 AS -BUILT CONDUCTOR LOCATION • EXISTING CONDUCTOR LOCATION XPLUGGED AND ABANDON WELL GRAPHIC SCALE 5 iso wo i I I I inch = 150 it. LOUNSBURY & ASSOCIATES, INC. W"ORB RNCMUS MNMRS DS2K WELL CONDUCTORS 4SBUILT LOCATIONS —6211D14 1'" 1 OF 3 1'"*4 J—®30 \ \ • 13 5.1' \ • 14 x16 15 30. x 17 --- 32818 ®32 • 19 / • 20 • 21 X18 / • 22 • 23 •'24 DS 2K x 27 SEE SHEET 2 & 3 FOR LOCATION ps , Inc. 2H I �_......_.._ _ 1 35� 36 w w 31 CO m TI IN ar( Tl ON 0 6 2G t .nl 2 1 PROJECT LOCATION 1 2K 11 12 7 9[�31911WRITIM&I NOTES: 1. BASIS OF LOCATION AND ELEVATION IS DS2K MONUMENTATION PER LOUNSBURY & ASSOC. 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES ARE NAD 27. 3. ELEVATIONS ARE B.P.M.S.L. 4. ALL CONDUCTORS ARE LOCATED WITHIN 2 1 PROTRACTED SECTION 2 & 11, TOWNSHIP 10 11+ 12 NORTH, RANGE 8 EAST, UMIAT MERIDIAN, AL 5. DATES OF SURVEY: 4/20/17 6. ALL DISTANCES SHOWN ARE GROUND AREA: 2K 0 AS -BUILT CONDUCTOR LOCATION • EXISTING CONDUCTOR LOCATION XPLUGGED AND ABANDON WELL GRAPHIC SCALE 5 iso wo i I I I inch = 150 it. LOUNSBURY & ASSOCIATES, INC. W"ORB RNCMUS MNMRS DS2K WELL CONDUCTORS 4SBUILT LOCATIONS —6211D14 1'" 1 OF 3 1'"*4 13 15/22/141 MEH I NRB I ]DRAWN PERK140028ACS 14 14/21/171 LGM I JAH I (REV. PER K170005ACS Ii CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 2, T. 10 N., R. 8 E., UMIAT MERIDIAN Well No. NAD 27 ASP Coordinates NAD 27 Geographic Coordinates Section Off let Elev. Y X Lat. Long. F.S.L. F.E.L. O.G. Pad 1 5,938,600.18 498,310.17 70' 14' 36.519" 150' 00' 49.133" 296' 94' 114.0' 118.5' **2 5,938,575.14 498,310.28 70' 14' 36.273" 150' 00' 49.130" 271' 94' 113.9' 118.5' 3 5,938,550.30 498,310.35 70' 14' 36.029" 150' 00' 49.128" 246' 94' 113.8' 118.5' 4 5,938,525.46 498,310.06 70' 14' 35.784" 150' 00' 49.136" 222' 94' 113.8' 118.5' 5 5,938,500.19 498,310.12 70' 14' 35.536" 150' 00' 49.134" 196' 94' 113.8' 118.5' 6 5,938,475.14 498,310.33 70' 14' 35.289" 150' 00' 49.128" 171' 94' 113.6' 118.5' 7 5,938,450.36 498,310.36 70' 14' 35.046" 150' 00' 49.127" 148' 94' 113.8' 118.5' **6 5,938,425.30 498,310.18 70' 14' 34.799" 150' 00' 49.132" 121' 94' 113.8' 118.5' 9 5,938,400.30 498,309.98 70' 14' 34.553" 150' 00' 49.137" 96' 94' 113.8' 118.5' 10 5,938,375.19 498,310.14 70' 14' 34.306" 150' 00' 49.133" 71' 94' 113.9' 118.5' 11 5,938,350.22 498,310.14 1 70' 14' 34.061" 150' 00' 49.133" 46' 1 94' 113.9' 1 118.5' 12 5,938,325.20 498,310.17 70' 14' 33.815" 150' 00' 49.131" 21' 94' 113.9' 118.5' 26 5,938,625.14 498,310.10 70' 14' 36.765" 150' 00' 49.135" 321' 94' 114.0' 118.5' 29 5,938,570.32 498,310.59 70' 14' 36.226" 150' 00' 49.121" 266' 94' 113.9'Ell .1' 34 5,938,419.98 498,309.81 70' 14' 34.747" 150' 00' 49.143" 116' 94' 113.8'.8' * CONDUCTORS ASBUILT THIS SURVEY ** PLUGGED AND ABANDON WELL 'hillips Alaska, Inc. SURVEYOR'S CER77FlCA7E I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRAC710E LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION ARE CORRECT AS OF APRIL 20, 2017. AREA: 2K LOUNSBURY & ASSOCUTES, INC. FnYOA8 NNOQ UM PIA W= DS2K WELL CONDUCTORS ,.nvv na ,w. urtmm�� nu. PART: REV: LK6211D14 7/12/01 CEA-D2KX-6211D14 I 2 OF 3 1 4 20 REVI DATE I BY I CK I APP I DESCRIPTION IREVI DATE IDYICKIAPPI DESCRIPTION 1 4/21/17 LGM I JAH I I CREATE DRAWING PER K170005AC5 CONDUCTORS ARE LOCATED IN PROTRACTED SEC71ON 11, T. 10 N., R. 8 E., UMIAT MERIDIAN Well No. NAD 27 ASP Coordinates NAD 27 Geographic Coordinates Section Offset Elev. Y X Lat. Long, F.N.L. F.E.L. O.G. Pod 13 5,938,235.31 498,310,37 70' 74' 32.930 750' 00' 49.125" 69' 94' 113.7' 118.5' 14 5,938,210.14 498,370.16 70' 14' 32.683 150' 00' 49.731" 94' 94' 113.7' 118.5' 75 5,938,185.12 498,370.16 70' 14' 32.437" 150' 00' 49.131" 119' 94' 113.8' 118.5' •*16 5,938,160.11 498,310.20 70' 14' 32197" 150' 00' 49.130" 144' 94' 113.8' 118.5' **17 5,938,135.21 498,310.18 70' 14' 31.946" 150' 00' 49.130" 769' 94' 113.9' 118.5' **18 5,938,110.19 498,310.29 70' 74' 31.700 150' 00' 49.127" 194 94' 114.0' 118.5' 19 5,938,085.20 498,310.27 70' 14' 31.454 150' 00' 49.727" 219' 94' 174.0' 118.5' 20 5,938,060.14 498,310.22 70' 14' 31.207" 750' 00' 49.128" 244' 94' 714.1' 118.5' 21 5,938,035.76 498,310.16 70' 14' 30.962 150' 00' 49.130" 269' 94' 114.0' 118.5' 21 5,938,035.76 498,370.16 70' 14' 30.962" 150' 00' 49.130" 269' 94' 114.0' 178.5' 22 5,938,070.40 498,310.19 70' 14' 30.718" 150' 00' 49.129" 294' 94' 114.0' 118.5' 23 5,937,985.32 498,310.13 70' 14' 30.471" 150' 00' 49.130" 319' 95' 114.0' 118.5' 24 5,937,960.29 498,310.08 70' 14' 30.225" 150' 00' 49.132" 344' 95' 113.9' 118.5' 25 5,937,935.20 498,310.13 70' 14' 29.979" 150' 00' 49.130" 369' 95' 113.9' 118.5' **27 5,937,910.36. 498,310.26 70' 14' 29.734" 150' 00' 49.126" 394' 94' 113.8' 118.5' 28 5,938,300.61 498,310.32 70' 14' 33,573" 150' 00' 49.727" 3' 94' 113.8' 118.5' *30 5,938,165.20 498,310.15 70' 14' 32.241" 150' 00' 49.131" 139' 94' 113.8, 115.7' *32 5,936,115.25 498,310.31 70' 14' 31.749" 150' 00 + CONDUCTORS ASBUILT THIS SURVEY ** PLUGGED AND ABANDON WELL LOUNSBURY k ASSOCIATES, INC. 66 1�RY6YM3 HN61NS6RB PLANN¢g3 ConocoPhillips Alaska, Inc. AREA: 2K MODULE: XXXX DS2K WELL CONDUCTORS ASBUILT LOCATIONS UNIT: 20 GADD FlLE . LK6211D1N04 4/21/17 CEA-D2KX-6211D14 DRAWING NO. PART: 3 OF 3 REV: 1 ' 49.126" 189' 94' 114.0' 116.7' TRANSMITTAL LETTER CHECKLIST WELL NAME: I<AU a K - 3G (Ak PTD: -in 2 ✓ Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: ��t� /J0/ / \1 y POOL: I�la�C10i��/�/ lvtN4Qd G!��/bJ dr % 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 l 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 KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK RIV UNIT 2K30_ Program DEV _ - ..._ Well bore seg ❑ 1 PTD#:2170720 Company CONOCOPHILLIP&_ALASKA,. INC. Initial Class/Type —DEV/1-OIL, _GeoArea $9Q __ _ _ Unit 11160 On/Off Shore On Annular Disposal ❑ r Administration 17 Nonconven, gas conforms to AS31,05.030(1.1.A),0.2.A-D) _ _ NA 1 Permit. fee attached _ _ NA. Yes set to. 3313' MD 2 Lease number appropriate _ _ _ _ _ Yes _ ADL0025588, Surf;. ADL0025605, Portion of;. ADL0025604, Top Prod; ADL025607, TD. _ 147% excess cement _ 3 Unique well. name and number _ _ _ _ _ Yes _ _ KRU 2K-30 _ 4 Well located in a defined pool _ _ _ _ _ _ .. Yes _ KUPARUK RIVER,. KUPARUK_ RIV OIL.- 400100,_ governed_ by Conservation. Order No, 432D, Productive. interval will be completed with swell packers and. frac sleeves 5 Well located proper distance from drilling unit. boundary. _ _ _ _ Yes _ _ CO 432D contains no spacing restrictions with respect to drilling unit boundaries. _ 6 Well located proper distance from other wells _ _ _ _ Yes CO 4320 has no interwell spacing. restrictions. Rig has steel tanks; all waste to approved disposal wells 7 Sufficient acreage. available in drilling unit _ Yes NA 8 If. deviated, is. wellbore plat included _ _ _ _ _ Yes Yes 9 Operator only affected party _ Yes Wellbore will be more than 500' from an external property line where ownership or landownership changes. 10 Operator has. appropriate bond in force Yes 28 Appr Date 11 Permit can be issued without conservation order Yes VTL 6/22/2017 12 Permit can be issued without administrative approval Yes _ PKB 6/14/2017 13 Can permit be approved before 15 -day wail... Yes _ 14 Well located within area andstrata authorized by Injection Order# (put 0# in. comments) (For. NA Choke manifold complies w/API. RP -53 (May 84) 15 All wells within 1/4 mile area.of review identified (For service well only) _ NA 32 16 Pre -produced injector; duration of pre production less than 3 months. (For. service well only) NA 18 Conductor string. provided _ ..... _ Yes 140' driven conductor . Engineering 19 Surface casing. protects all known USDWs _ Yes set to. 3313' MD 20 CMT vol adequate. to circulate. on conductor & surf csg _ Yes 147% excess cement _ 21 CMT vol adequate to tie-in long string to surf csg Yes _ 22 CMT will cover all known_ productive horizons _ -No Productive. interval will be completed with swell packers and. frac sleeves 23 Casing designs adequate for C, T, B &. permafrost.. Yes _ 24 Adequate tankage. or reserve pit Yes Rig has steel tanks; all waste to approved disposal wells 25 If a re -drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Anti -collision analysis complete; Major risk failures 2K-16 is P&A'd; 2K-21 will be SI while drilling 27 If diverter required, does it meet regulations Yes Diverter meets regulations _ Appr Date 28 Drilling fluid. program schemafic & equip list adequate Yes Max formation pressure is. 3142 psig(10.0 ppg EMW); will drill. w/ 8,6-11,0 ppg EMW VTL 6/22/2017 29 BOPEs, do they meet regulation _ _ Yes 30 BOPE_press rating appropriate; test to (put psig in comments) Yes MPSP is 2507 psig; will test BOPS -to 3500 psig 31 Choke manifold complies w/API. RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S measures required 34 Mechanical condition of wells within AOR verified (For service well only) NA _ 35 Permit can be issued w/o hydrogen sulfide measures No Wells. on 2K -Pad are H2S-bearing. H2S measures required. Geology 36 Data presented on potential overpressure zones Yes Max. potential reservoir pressure is 10.0 ppg EMW;. will be drilled with 8,6 to 11.0 ppg mud.. Appr Date 37 Seismic analysis of shallow gas zones NA _ PKB 6/14/2017 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Onshore development well to. be drilled. Geologic Engineering Revision covers change in TD due to additional lateral footage and adjustment of heel location for lateral orientation. Commissioner: Date: Commissioner: Date C missione Date I DTS 6/22/2017 CPF 6/22/2017 r HF i� g 1 2_'� '� THE STATE °fALASKA GOVERNOR BILL WALKER G.L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2K-30 ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-072 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Surface Location: 139' FNL, 94' FEL, SEC. 11, T10N, RBE, UM Bottomhole Location: 2046' FNL, 1963' FEL, SEC. 27, TION, RBE, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. s�' DATED this /day of June, 2017. Sincerely, or—z�*� Daniel T. Seamount, Jr. Commissioner / STATE OF ALASKA , i AL, _KA OIL AND GAS CONSERVATION COMW JON PERMIT TO DRILL RECEIVED MAY 0 4 2017 Anr+r+r% Ia. Type of Work: 1b. Proposed Well Class: Exploratory - Gas ❑ <v 1l LJ.VVJ Service - WAG Service - Disp ❑ J7\_�`4 vv 1c. Specify if is Drill ❑✓ + Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑✓ Service - Winj ❑ Single Zone well proposed for: Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development -Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑� Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 KRU 2K-30 3. Address: P.O. 6. Proposed Depth: 64 yS 12. Field/Pool(s): Box 100360 Anchorage, AK 99510-0360 MD: 22,52 - TVD: R ^ oR Kupamk River Field 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 139' FNL, 94' FEL, Sec 11, TI ON, R008E, UM t ADL 25588, 25605, 25604, 25607 t Kuparuk River Oil Pool , Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1970' FNL, 116' FEL, Sec 15, TION, R008E, UM 2674, 2675, 2677, 2678 6/3/2017 Total Depth: 2046' FNL, 1963' FEL, Sec 27, TI ON. R008E, UM 9. Acres in Property: 14. Distance to Nearest Property: 10240 v 1963' from ADL 392952 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 154.7 15. Distance to Nearest Well Open Surface: x- 498310 y- 5938165 Zone- 4 GL Elevation above MSL (ft): 115.7 to Same Pool: KRU 2K -21A: 503' 16. Deviated wells: Kickoff depth: 300 feet • 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91.3 degrees Downhole: 3142 - Surface: 2507 , 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MO TVD (including stage data) 42" 20" 62.5# H-40 Welded 140' 39' 39' 179' 179' Driven 13.5" 10.75" 45.5# L-80 Hydril 563 3,274' 39' 39' 3313' 2845' 1436 sx 11# / 202 sx 12# DeepCRETE 11" 7.625" 29.7# L-80 Hydril 563 11,674' 39' 39' 11713' 6350' 552 sx 15.8 Class G 6.75" 4.5" 12.6# L-80 Hydril 563 10,959' 11563' 6330' 22522' 6495' Liner with Swell Packer/Frac Sleeves a. PRESENT WELL CONDITION SUMMARY (To be completed for Reddll and Re -Entry Operations) MD Junk Pertoration Depth MD (ft): Perforation Depth TVD (11): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program QTime v. Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch Q Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements[] 21. Verbal Approval: Commission Representative: i 7 22. I hereby certify that the foregoing is true and the procedure aDate roved happroved will not Jacob Voss @ 265-6935 be deviated from without prior written approval. Contact I Name G.L. Alvord Title Alaska Drilling Manager Phone 265-6120 �!Iv10 Permit to Drill API Number: Permit Approval See cover letter for other Number: 50-103-9 5 � (13 Date: 5I I � requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: /SDP 7G5--1 -/o UO T->51 - Samples re d: Yes No[r� I✓ 3$ P� 5 G o P r Mud log req'd: Yes❑ Nall firsnvla v � �Clr� �Cd iJ ' HiS measures: Yes No� Directional svy req'd: Yes[ No,❑,�// �t LL✓y G� C%I �(� eav-� CI r �'i avt S Spacing exception req'd: Yes ❑ No Inclination -only svy req'd: Yes❑ NoLQ v F i} -121J rOVU. I" Fo t- fw zf [_WO - 5cr-" L C Post initial injection MIT req'd: Yes❑ NOR' v APPROVED BY / I :d by: YIAZ . (]� 'ZITCOMMISSIONER THE COMMISSION Date: Form 10-401`( �ised 11/2015) i 1 2 the from the date of a Submit Form and //iy�n approval (20 AAC 25.005(8)) Attachments in Duplicate KRU 2K-30(PTD 217-072) Conditions of Approval: Approval is granted to run the LWD-Sonic on upcoming well KRU 2K-30 with the following provisions: 1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as soon as they become available. The evaluation is to include/highlight the intervals of competent cement (and lengths) that CPA[ is using to meet the objective requirements for annular isolation, reservoir isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation is not acceptable. 2. LWD sonic logs must show free pipe and Top of Cement, just as the a -line log does. CPAI must start the log at a depth to insure the free pipe above the TOC is captured as well as the TOC. Starting the log below the actual TOC based on calculations predicting a different TOC will not be acceptable. 3. CPAI will provide a cementjob summary report and evaluation along with the cement log and evaluation to the AOGCC when they become available 4. CPAI will provide the results of the FIT when available. 5. Depending on the cement job results indicated by the cement job report, the logs and the FIT, remedial measures or additional logging may be required. Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone (907) 265-6935 Email: Jake.voss(a)conocophillips com May 04, 2016 Alaska Oil and Gas Conservation Commission 333 West 71" Avenue, Suite 100 Anchorage, Alaska 99501 Application for Permit to Drill, Well 2K-30 ConocoPhillips RECEIVED MAY 0 4 2017 Re: Application for Permit to Drill Well 2K-30, A Kuparuk A4 Sand Producer AOGCC Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a permit to drill an onshore grassroots producer well from the 2K pad. The expected spud date for this well is June 3`d, 2017. It is planned to use rig Doyon 142. ✓ 2K-30 is planned to be a horizontal well in the Kuparuk A4 sand. The surface section will be drilled with 13-1/2" bit and run 10-3/4" casing to +/-3,313' MD / 2,845' TVD. The intermediate section will be drilled with 9-7/8" x 11" bit/under Reamer and run 7-5/8" casing to 11,713'MD / 6,350'TVD. The production hole will be drilled with 6-3/4" bit and run 4- 1/2" liner with frac sleeves/swell packers to +/- 22,5221MD / 6,495'TVD. The upper completion will be run with 3-1/2" tubing. This well will be frac'd post rig. F -r i r- XYZ Stern ti(afirsv, Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Jake Voss at 265-6935 (fake vols conocoohillios com) or Chip Alvord at 265-6120. Sincerely, A -e. -a,4, Chip Alvord Drilling Manager Application for Permit to Drill Document AMN Kuparuk Well 2K-30 1W Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as 2K-30 Location Summary Requirements of 20 AAC 25.005(,)(2) An application fora Permit to Drill must be accompanied by each of the following items. except for an item already on file with the commission and identified in the application. (2) a plat identifying the property and the property's inmers and showing (A)!he coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines, (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system far this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth: Location at Surface 139' FNL, 94' FEL, Sec 11, TION R008E UM NGSCoordmates RKB Elevation 154.7' AMSL Northings: c neo �..��....:;gs: .,,>.,0,165' Eastings: 49&",3iv"' � Pad Elevation 115TAMSL Location at Top of 11970' FNL, 116' FEL, Sec 15, TION, ROME, UM Productive Interval (Kuvaruk A4 Sand) Northings: 5,931,057' Eastings: 493,013' Total Location at Total De th 2046' FNL, 1963' FEL, Sec 27, T1 ON, R008E, UM NGS Coordinates Northings: 5,920,425' Eastings: 491,171, Measured De th, RKB: 22,522' Total Vertical De th, RKB: 6,495' Total Vertical Depth, SS: 6,340' (D) other information required by 20 AAC 15.050(b): Reauirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Fore, 10-401) must (1) include a plat, drawn to a satiable scale, showing the path of the proposed wellbore, including all adjacent uellbores within 200 feet of any portion of the proposed well; Please see Attachment: Directional Plan And (2) for all wells within 100 feet of the proposed wellhore (A) list the names of the operators of those wells, to the extent that those names are knornor discoverable m public records, and show that each named operator has been f rnished a copy of the application by certified mail: or (B) state that the applicant is the only affected at, The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(,)(3) An application for a Permit to Drill most be accompanied by each of the folloring items, except for an item already on file nvah the commission and identified in the application: (3) a diagram and description of the blorout prevention equipment (HOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 142. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items. except far an item already on file with the commission and identified in the application: (4) information on drilling ha_ards, including (.A) the maximum dmrnhole pressure that may he encountered criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The maximum potential surface pressure (MPSP) while drilling 2K-30 is calculated using an estimated maximum reservoir pressure of 3,142 psi (10.0 ppg, based on 2K-21 development well on 4/25/17), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A4 sand at 6,350' TVD (WPI 1): A Sand Estimated. BHP = 3,142psi A Sand estimated depth (WP09) = 6,350' TVD Gas Gradient — 0.10 psi/ft Hydrostatic of full gas column = 635 psi MPSP = BHP — gas column = 2,507psi as per 20 AAC 25.005 (e)(4)(A) (6,350' TVD * 0.10 psi/ft) (3,142 psi — 635 psi) (3) data on potential gas cones; The well bore is not expected to penetrate any shallow gas zones. And (C) data concerningpotential causes of hole problems such as abnormally geo-pressured strata, lost circa/avian =ones, and cones that have a propensitvfm differential sticking; See attached 2K-30 Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the follou mg items, except/ far on item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests. as required under 20 AAC 25.030(9; A procedure is on file with the commission for performing LOT'S. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) Aa application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application.' (6) a complete proposed casing and cementing program cis required by 10 AAC 25.030, and a description of am, slotted liner. pre -perforated liner, or screen to be installed Casing and Cement Program 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling I Length I MD 7VD MD TVD (including stage data) 42" 20" 62.5# 1+40 Welded 140' 39' 39' 179' 179' Driven 13.5" 10.75" 45.5# L-80 Hydril 563 3,274' 39' 39' 3313' 2845' 1436 sx 11#/ 202 sx 12# DeepCRE 11" 7.625" 29.7# L-80 Hydril 563 11,674' 39' 39' 11713' 6350' 552 sx 15.8 Class G 6.75" 4.5" 12.6# L-80 Hydril 563 10,959' 11563' 6330' 22522' 6495' Liner w ith Swell Packer/Frac Sleeve 2K-30_wp11 Cementing Schematic 9-7/8" x 11" Hole Kalubik 10,738' MD / 6,105' TVD ....... ........ I.................... I Kuparuk A4 11,714' MD / 6,350' TVD 6-3/4" Hole 20" Conductor to 140' ................................. 10-3/4" 45.5# L-80 HYD563 3,313 MD / 2,845' TVD @ 61 ° inc. ............................................ Top of Cement (top HRZ) ................. 7-5/8" 29.7# L-80 HYD563 Casing 11,714' MD / 6,350' TVD @ 850 4-1/2" Liner 11.6# L80 IBT .... 22,522. MD / 6,495'.TVD..... 10-3/4" Surface casing run to 3,313' MD / 2,8451 TVD Cement from 3313' MD to 2813'(500' of tail) with DeepCRETE @ 12 ppg, and from 2813' to surface with 11 ppg DeepCrete. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (1531' MD), zero excess in 20" conductor. 2K-30 Cement Calculations Surface Cement: Surface to 3,480' MD Hole Size ft (TOC) Ift(Bottom)l OD I ID I ppf Conductor Depth: 42 39 179 20 18.5 94 Surface Casing Depth: 13.5 39 3313 10.75 9.95 45.5 Intermediate Casing Depth: 11 10425 11713 7.625 6.875 29.7 Surface Cement: Surface to 3,480' MD Lead 1.84 113 sx of / 11.0 ppg DeepCRETE Capacities Tail 1.64 ft3/ sx of 12.0 DeepCRETE OH 0.177045 Permafrost (PF) depth 1531 ft 13-1/2" x 10-3/4" 0.064783 XS% Above PF 250% 20" x 10-3/4" 0.220213 XS% Below PF 50% 10-3/4" 0.096175 Tail Cement Length 500 ft 500 x 0.06478288 x 1.5 48.6 Shoe Track 80 ft 80 x 0.09617496 x 1 7.7 Open Hole 10 x 0.17704488 x 1.5 2.7 Total 59 bbl 331 ft3 202 sx Lead Top Tail Cement to Permafrost 1282 ft 1282 x 0.06478288 x 1.5 124.6 bbl Permafrost to 20" Casing 1352 ft 1352 x 0.06478288 x 3.5 306.6 bbl Conductor Length 80 ft 179 x 0.22021323 39.4 bbl Total: 471 bbl 2642 ft3 1436 sx 7-5/8" Intermediate casing run to 11,713' MD / 6 350' TVD Intermediate slurry designed to be at the top of HRZ at 10,425' MD/ 5,970' TVD which is 1288' MD / 380' TVD above the Kuparuk Oil Pool. Assume 40% excess annular volume. Intermediate #1 Cement: SI urrv: Cement from 11,713' MD to 10,425' MD Capacities: 15.8ppg Class G yi eldi ng 1.16ftA3/sk 11"x7-5/8" 0.061064 XS%for open hole and annulus: 400% 11" OH 0.117544 7-5/8" Casing 4-1/2" Liner 7-5/8" ST 0.045916 Annulus Cement 1288 x 0.06106409 x 1.4 = 110.1108 bbls Rathole Cement 2 x 0.1175442 x 1.4 = 0.329124 bbls Shoe Track 80 x 0.0459157 x 1 = 3.673256 bbls Total YP 114 bbls 16-24 16-24 641 M 200-300 N/A 552 sx Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill most be accompanied by each of the following trews, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25 035, unless this requirement is waived by the commission under 20 AA C 25.035(h)(2); Please reference diverter schematic on file for Doyon 142. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill umsi be accompanied by each of the following items. except for an Hem already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 10 AAC 25.033,• Mud Program Summary Surface Intermediate Production 13-1/2" Hole 9-7/8" x 11" Hole 6-3/4" Hole 10-3/4" Casing 7-5/8" Casing 4-1/2" Liner Mud System Spud (WBM) LSND (WBM) FlowPro (WBM Density 8.6-10 9.2-10.8 9.5-11.0 PV 30-50 10-20 10-20 YP 40-80 16-24 16-24 Funnel Viscosity 200-300 N/A N/A Initial Gel 30-50 10-12 5 - 8 10 minute Gel 30-50 10-18 5-12 API Filtrate NC < 6 < 6 HTHP Fluid Loss at 160 F N/A <10 < 10 H 9.0-10.0 9.0-10.0 9.5-10.0 Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (0(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application far a Permit to Drill must be accompanied by each of the folloiring items, except for an item already on file mith the commission and identified in the application: The proposed drilling program is listed below. Please refer to attachment for proposed well schematic 1. Move in / rig up Doyon Rig 142. Install Annular with 16" diverter line and function test. 2. Spud and directionally drill 13.5" hole to casing point at +/- 3313' MD / 2,845' TVD as per directional plan (wp11). Survey with MWD, Gamma, GWD - NOTE: Due to 2K-30 being a development well, Resistivity will not be used in surface hole similar to 2K-32. 3. Run and cement 10-3/4", 45.5#, L80, Hyd-563 casing to surface. Displace cement with mud. Evacuate top 2 feet of cement from annulus for sealantjob (post rig.) 4. In the event cement returns are not seen at surface, perform a top job. Notify AOGCC if this occurs. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP'S to 3500 psi (annular preventer to 3500 psi) high and 250 psi low. Notify AOGCC 24 hrs before test. / 6. PU 9-7/8" PDC bit and directional drilling assembly, with MWD/LWD (Gamma, resistivity)) RIH and clean out to 100' above shoe. Test surface casing to 3500 psi for 30 minutes. 7. Drill out shoe track and 20' of new hole. Perform leak off test to a minimum of 13.0 ppg, maximum of 15 ppg EMW leak off, recording results. 8. Open 9-5/8" x I I" Under Reamer and directionally drill to the top of the C-37. 9. Perform Wiper trip to surface shoe and CBU until shakers are clean. 10. Install RCD bearing at this time for use of MPD if necessary. 11. Run back in hole to C-37. 12. Directionally drill to intermediate TD of 11,713 MD / 6,350' TVD, wellsite geologist will call intermediate TD. Circulate and rotate at maximum rates until shakers are clean, minimum of 3 bottoms up. 13. POOH on elevators. Closely monitor drag and address any problem areas by dropping below and circulating/rotating to clean up. 14. Lay down intermediate BHA and rack back 5" DP 15. Run 7-5/8", 29.7# L80, Hydril 563 casing from surface to TD at 11,713' MD, 16. Pump cement job as per Schlumberger proposal. Top of cement to be -10,425' MD (top of HRZ formation OR approximately 1288 MD / 380' TVD above Kuparuk Pool), 17. Flush 10-3/4" x 7-5/8" annulus with water, followed by diesel to freeze protect. 18. Lay down 5" DP. 19. PU 4" DP, 6-3/4" bit, and drilling assembly with MWD/LWD (Gamma, resistivity, Periscope, and neutron density, SonicScope11 Top of cement for Frac�rv) 5tt 5�4n "r- O° di t�� 5 OF "VP " r4- 1 20. RIH and clean out cement to 100' above shoe. Test intermediate casing to 3500 psi for 30 minutes and chart. 21. Drill out shoe track and 20' of new hole. Perform formation integrity test to minimum of 13.0 ppg, maximum of 14.0 ppg EMW leak off, recording results. 22. Install RCD and swap mud over to 9.5 ppg FlowPro mud system 23. Directionally drill 6-3/4" hole geosteering through the Kuparuk A4 sand to TD -22,522' MD as per directional plan (wpl 1). Hold back pressure on connections with MPD as needed. 24. Circulate hole clean and BROOH to shoe. Circulate hole clean and swap to KWF brine. POOH 25. Lay down production BHA. 26. PU and run 4-1/2", 11.6# liner. The top of liner will be placed at—] 1,563 MD, allowing for 150' of overlap in the 7-5/8" casing. 27. Set liner hanger. Slackoff and set liner top packer. 28. Monitor well for flow for 15 minutes 29. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes, chart results. 30. Flow check well for 30 minutes and POOH 31. Run 3-1/2" upper completion. 32. Nipple down BOPE, nipple up tree and test. 33. Freeze protect well with diesel and install BPV. 34. RDMO Please Note — This well will be frae'd. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application jar a Permit to Drill music be accompanied hp each of the following neurs, except for an ,rear already on file irith the commission and identified in the application: (1 4) a general description of houthe operator plans to dispose of drilling nmd and cuttings and a statement of whether the operator intends to request authorisation tinder 20 AAC 25.080 for an annular disposal operation in the well.: Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (DSIB). All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Well Schematic Attachment 2 Diverter Layout Diagram Attachment 3 Directional Plan Attachment 4 Drilling Hazards Summary Victoria T From: Voss, Jake <Jake.Voss@conocophillips.com> Sent: Tuesday, May 30, 2017 10:08 AM To: Loepp, Victoria T (DOA) Subject: RE: KRU 2K-30(PTD 217-072) Anti -collision Well KRU 2K -21A is currently shut in. Depending on timing, the wells group may have KRU 2K -21A cemented in preparation for the upcoming P&A of that well. In addition, we will have Geologic Certainty that we will not hit KRU 2K -21A since that well is located in the Kuparuk Sand and KRU 2K-30 will be passing the anti -collision interval while drilling the Kalubik formation. Thanks, Jake From: Loepp, Victoria T (DOA) (mailto:victoria.loepp@alaska.gov] Sent: Tuesday, May 30, 2017 10:01 AM To: Voss, Jake <Jake.Voss@conocophillips.com> Subject: [EXTERNAL]KRU 2K-30(PTD 217-072) Anti -collision Jake, The anti -collision major risk failure of KRU 2K-30 with KRU 2K -21A requires mitigation measures. Will KRU 2K -21A be shut in while drilling the intermediate hole? 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 Loeoo(G)alaska aov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(sl. It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or victoria Loepp'sn(ask(La,;v 2K-30 (Gulper) ConocoPhillips Grassroots Horizontal ASand Producer Proposed Wellbore Schemabc(wD111 ^� d o Last Eked: sx•o®,mppn:ax+zm�mr Voss 4/31/17 m-cepapom.to-tea 13.5" Surface Hole TW Wmts.t: 021- ror:lm•mm rrffi wx.ua: v is rm n�z 3vo 3-%" x t -K" CAmm MAG GLM &rbgg Cam 10,14.45.50 L-80 rlydrd 563 2,845'MD/2,845TVD(61- INC) 9-7/8" x 11" Intermediate Hole Tubing: 341 9.3 i LA EUE 8RDMOD arrmw C.l]:MK YaINm'M1 11,713' MD/ 6,350' TVD (65"INC) 22,522'MD/ 6.496,TVDm 2K-30wp11 [_.Permit WSAM,flase r4 �1u nrl I Per P STC-5D7C M9 0 BW 0 5000 t 10000 15004, 20000 20' x 4T 10 3r4" x 1&1 Measured Depth P6/8' x &7/8' by 11" J,- 20"x4 Geodetic Datum: ^n0 Degh Reference: Plan: 39+115.]@154.]0us1t lDOYon142) 103/d'x 13-1/ Rg: Doyon142 0 0 0 0 0 0 3500 7000 SURVEY PROGRAM :pth From Depth To SurveyrPlan 39.00 2500.00 2K -30x,,11 (Plan: 2K30) 210.00 3313.04 2"Ihspll (Plan: 2K-1) 210.00 3313.04 2K31)W11 (Plan: 2K-30) 3313.04 4813.04 W3Qrpll (Plan: 2K-30) 3313.04 11712.78 2K-3Uxp11 (Plan: 2K-30) 11712.]8 13212]8 2K -30x,,11 (Plan: 2K-30) 11712.78 22521.54 2K-301,,11 (Plan: 2K-30) Too GYD-GC-SE MWC MWD+IFR-AK CAZ-SC MW MWD+IFR-AK-CW MW MWD+IFR-AK-CAZ- Sec MD Inc A i WD +W -S +FJ -W 1 39.00 0.00 0.00 39.00 0.00 0.00 2 300.1 0.00 0.00 300.00 0.00 0.00 3 800.00 7.1 255.00 798.57 -8.46 -31.56 4 1477.61 20.59 238.64 1454]0 -82.25 -176.71 5 1584.43 20.59 238.64 1554.70 -101.80 -208.79 6 3313.04 60.99 211.96 2W.70 -941.45 -901.60 7 3333.04 60.99 211.96 2854.40 -955.29 -910.86 8 3561.82 63.99 217.45 291.12 -1122.91 -1026.42 9 10614.22 63.99 217+5 152.72 6154.69 -4880.41 10 11712.78 M.00 190.90 6349.70 -7110.42 -5295.53 11 11732.78 85.00 190.90 6351.44 -7129.99 -5299.29 12 41942.97 91.29 190.1 6358.24 -7336.31 -5338.27 13 13588.31 91.29 190.1 6321.10 -8953.70 -5638.00 14 13800.98 90.00 197.83 6318]0 -9159.74 -5690.00 15 14048.54 82.39 201.99 6335.12 -9391.78 -5774.01 16 14154.89 82.39 201.99 6349.19 -9489.53 -5813.48 17 14543.97 86.00 188.79 6388.70 -9061.87 -5915.83 18 14637.05 89.26 188.79 6392.55 -9953]6 -5930.04 19 22521.54 69.26 188.79 6494.70 -17744.99 -7134.78 Steering 7500 21000 Surface Location North / Y: East / X: Pad Elevation: 115.70 Plan Summary 0 D CASING DETAILS C TVD MD Name D 116.20 116.20 20' x 4T 2644.70 3313.04 10 3/4' x 18-1/2 149.70 11712.78 7-W" x 9-70 by 11' 6494.70 22521.54 41/2' x 6-3/4" SECTION DETAILS Dleg TFace VSect Target 0.00 0.00 0.00 0100 0.00 0.00 1.50 255.00 13.81 2.00 -25.00 111.68 0.1 0.00 136.51 2.1 -35.00 100.70 OAO OM 1099.93 2.1 1.65 1284.09 0.00 0.00 6908.66 3.00 -54.95 7921.96 2K-30 01.11.1 W2417 JM 0.00 0.00 ]941.88 3.00 -3.61 8151.84 0.1 000 979610 3.50 99.9510008.84 2K -W M.PMFauIt 020817 JM 3.50 151.4810251.74 0.00 0.0010354.86 3.50 -75.3810739.32 2K-3003.Pos1Fault 020817 JM 3.50 0.00 10832.28 0.00 0.0018714.35 2K-30 M.Toe 020817 JM Prepared by: ( Checked by ( I AcceplM by. B Tempo H. Anh E. Stark lee ,II 39300 300 - 490 490 - 670 070 - WO 860- 1 0 1040 - 1230 1230 - 410 141 0 - IWO W0 - 24W 241MW 331 -4230 4230 - 5100 5100 - sw 5960 - OW We) - 7730 7730 - 9600 100 - 10 1 10.540 - 120a I.0 - 13621 13820 - 1554 I15W - 17301 173W low IN40 am 20700 - n5Z Map iic MWN: BGGMW16 f Mapnclic Metlal Date: 15.45-17 Mao el DDiireBan: aTme To come4 a MagneSc Diredicn to a Trve predlon, A6tl 17.45°Fast Ar-Matldn KOP: Start 1.5°/1W DLS, 255°TF, for 500' 1504.7 Star1211110' DLS,-25°TF, for 677.61' Hold for 100%' Base Permakod Siad 2.5°/1001DLS, -35° TF, far 1728.61' Hold for 20' 2190] Start 2.51100' DLS, 59.65°TF, for 228.78' WS_Top Hold for 7052.4' Start 31100 DLS, -54.95°T5 for 1098.56 2741.7 Hold for 20' W6 Base Start 31100' DLS,-3.61°TF, for 210.19' 3� Hold for 164534' SIM 3.51100' DLS, 99.95°TF, W212.66 Adjust TF to 151.48°, for 247.56' Hold for 106.35' CAMP_SST Star) 351100 DLS, -75.38° T5 for 389.08' Must TF to 0°, for 93.08' Hold for 7884AY 0's a$8n TD: 22521.54' MD, 6494.7 TVD - G37 Fails AC against 2K-1"' and 2K -21A. KUP_M Approved by: J. Voss Dleg TFace VSect Target 0.00 0.00 0.00 0100 0.00 0.00 1.50 255.00 13.81 2.00 -25.00 111.68 0.1 0.00 136.51 2.1 -35.00 100.70 OAO OM 1099.93 2.1 1.65 1284.09 0.00 0.00 6908.66 3.00 -54.95 7921.96 2K-30 01.11.1 W2417 JM 0.00 0.00 ]941.88 3.00 -3.61 8151.84 0.1 000 979610 3.50 99.9510008.84 2K -W M.PMFauIt 020817 JM 3.50 151.4810251.74 0.00 0.0010354.86 3.50 -75.3810739.32 2K-3003.Pos1Fault 020817 JM 3.50 0.00 10832.28 0.00 0.0018714.35 2K-30 M.Toe 020817 JM Prepared by: ( Checked by ( I AcceplM by. B Tempo H. Anh E. Stark lee ,II 39300 300 - 490 490 - 670 070 - WO 860- 1 0 1040 - 1230 1230 - 410 141 0 - IWO W0 - 24W 241MW 331 -4230 4230 - 5100 5100 - sw 5960 - OW We) - 7730 7730 - 9600 100 - 10 1 10.540 - 120a I.0 - 13621 13820 - 1554 I15W - 17301 173W low IN40 am 20700 - n5Z Map iic MWN: BGGMW16 f Mapnclic Metlal Date: 15.45-17 Mao el DDiireBan: aTme To come4 a MagneSc Diredicn to a Trve predlon, A6tl 17.45°Fast Ar-Matldn KOP: Start 1.5°/1W DLS, 255°TF, for 500' 1504.7 Star1211110' DLS,-25°TF, for 677.61' Hold for 100%' Base Permakod Siad 2.5°/1001DLS, -35° TF, far 1728.61' Hold for 20' 2190] Start 2.51100' DLS, 59.65°TF, for 228.78' WS_Top Hold for 7052.4' Start 31100 DLS, -54.95°T5 for 1098.56 2741.7 Hold for 20' W6 Base Start 31100' DLS,-3.61°TF, for 210.19' 3� Hold for 164534' SIM 3.51100' DLS, 99.95°TF, W212.66 Adjust TF to 151.48°, for 247.56' Hold for 106.35' CAMP_SST Star) 351100 DLS, -75.38° T5 for 389.08' Must TF to 0°, for 93.08' Hold for 7884AY 0's a$8n TD: 22521.54' MD, 6494.7 TVD - G37 Fails AC against 2K-1"' and 2K -21A. KUP_M Approved by: J. Voss Prepared by: ( Checked by ( I AcceplM by. B Tempo H. Anh E. Stark lee ,II 39300 300 - 490 490 - 670 070 - WO 860- 1 0 1040 - 1230 1230 - 410 141 0 - IWO W0 - 24W 241MW 331 -4230 4230 - 5100 5100 - sw 5960 - OW We) - 7730 7730 - 9600 100 - 10 1 10.540 - 120a I.0 - 13621 13820 - 1554 I15W - 17301 173W low IN40 am 20700 - n5Z Map iic MWN: BGGMW16 f Mapnclic Metlal Date: 15.45-17 Mao el DDiireBan: aTme To come4 a MagneSc Diredicn to a Trve predlon, A6tl 17.45°Fast Ar-Matldn KOP: Start 1.5°/1W DLS, 255°TF, for 500' 1504.7 Star1211110' DLS,-25°TF, for 677.61' Hold for 100%' Base Permakod Siad 2.5°/1001DLS, -35° TF, far 1728.61' Hold for 20' 2190] Start 2.51100' DLS, 59.65°TF, for 228.78' WS_Top Hold for 7052.4' Start 31100 DLS, -54.95°T5 for 1098.56 2741.7 Hold for 20' W6 Base Start 31100' DLS,-3.61°TF, for 210.19' 3� Hold for 164534' SIM 3.51100' DLS, 99.95°TF, W212.66 Adjust TF to 151.48°, for 247.56' Hold for 106.35' CAMP_SST Star) 351100 DLS, -75.38° T5 for 389.08' Must TF to 0°, for 93.08' Hold for 7884AY 0's a$8n TD: 22521.54' MD, 6494.7 TVD - G37 Fails AC against 2K-1"' and 2K -21A. KUP_M Approved by: J. Voss G37 Fails AC against 2K-1"' and 2K -21A. KUP_M Approved by: J. Voss Spider View May 02 VPAR i5 1244 / M -OB 2M-32L1PB2 2�3Rb13Q41' V • 2M-35 2M)2M IILI 2S -09A 2S-Od 25-0] 2S -OS 25-09 Kuparuk 2S Pad _ /1 /1 r 25-02 f 2S-06 2S-10 #1 2S-03PB1 1 2S-01 2S-03 Easting (3000 ustuln) P� �9EIHf Ku aruk 2K 2M-09 ��K-0PAP P 2K-13AL2 2K-21 '2K-30wp11 Fasting 16 2K -1P 2K -22A T2K-22 2K-22AL1-01 2K-22AL1 r 2K -0]/(26 2G-13 2G -1d 2G-14AL13AL2 K-15 2WAL1 2K-23 t 2K-25 2K-24 1 99-9§0-01 2G-IMESC1 0 S m Plan View 2K-30wp11 0 2K-32wp10 -16000 -20000 -16000 -1 Plan View 13000 K -22A 18000 15000 7-5/8"x 9-7/8" by 11" 16000 17000 18000 19000 20000 21000 _ K-30wp 11 J 22000-. 4 1/2" x 6-3/4" -8000 -4000 0 4000 West( -)/East(+) (4000 usft/in) WIN 12000 16000 Section View 20" x 42" 1000 --- Base Permafrost 10 3/4" x 13-1/2 0 --WS_Topu.c>p`� pp--_--_-- ___. WS Base -"b pp _-C-80-: CAMP SST 60 ®0 7-5/8" x 9-7/8" by 11" �� pp C-50 _ 0 0 r, -----C-40- - - HRL Section View 4 1/2" x 6-3/4" C-37 o 00 00 0 0 0 0 0 0 __HRZ_BASE -: C-35 - K-1— ---- °' 0 0 0 m m- ;o _ — a �'-KUP te N N CY C KUP_ A5 'o 0 KUP A4 0 0 0 0 2K 30 02.PraFault 020817 J 10000 2K-30 01.Heel022417 J 2K-30 03.PostFault 020817 M 0 2500 5000 7500 10000 12500 15000 0 Vertical Section at 190.00' (2500 usft/in) 20000 Plan Report ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad Plan: 2K-30 Plan: 2K-30 Plan: 2K-30wp11 Report 02 May, 2017 Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 21K-30 Project: Kupamk River Unit TVD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon142) Site: Kuparuk 2K Pad MD Reference: Plan: 39+ 115.7 @ 154.70usft (Doyonl42) Well: Plan: 2K-30 North Reference: True Wellbore: Plan: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30wpl l Database: OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States 0.00 Map System: Version: System Datum: Mean Sea Level Geo Datum: Depth From (TVD) +N/S +E/ -W Using Well Reference Point Map Zone: (usft) (usft) (usft) Using geodetic scale factor Site Kupamk 2K Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: -0.02 ° Well Plan: 2K-30 Well Position +N/ -S 0.00 usft Northing: Latitude: MD +E/ -W 0.00 usft Easting: Longitude: Position Uncertainty BGGM2016 6/15/2017 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 115.70 usft Wellbore Plan: 2K-30 Magnetics Model Name Sample Date Declination Dip Angle Field Strength MD Inc P) V) (nT) TVDSS BGGM2016 6/15/2017 17.45 80.86 57,528 (usft) (") (°) (usft) Design 2K-30wp11 V) (usft) Audit Notes: 0.00 0.00 39.00 Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (TVD) +N/S +E/ -W Direction 100.00 (usft) (usft) (usft) (I 0.04 39.00 0.00 0.00 190.00 116.20 -38.50 0.00 0.00 Survey Tool Program Date 5/2/2017 From To (usft) (usft) Survey (Wellbore) Tool Name Description 39.00 2,500.00 2K-30wp11 (Plan: 2K-30) GYD-GC-SS Gyrodata gyro single shots 2,500.00 3,313.04 2K-30wp11 (Plan: 2K-30) MWD MWD -Standard 2,500.00 3,313.04 2K-30wpll (Plan: 2K-30) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 3,313.04 4,813.04 2K-30wpll (Plan: 2K-30) MWD MWD -Standard 3,313.04 11,712.78 2K-30wp11 (Plan: 2K-30) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11,712.78 13,212.78 2K-30wpll (Plan: 2K-30) MWD MWD- Standard 11,712.78 22,521.54 2K-30wpi1 (Plan: 2K-30) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (") (°) (usft) (usft) ('1100usft) V) (usft) 39.00 0.00 0.00 39.00 -115.70 0.00 0.00 0.00 100.00 0.00 0.00 100.00 -54.70 0.00 0.00 0.04 116.20 0.00 0.00 116.20 -38.50 0.00 0.00 0.19 20^:42^ 200.00 0.00 0.00 200.00 45.30 0.00 0.00 0.19 300.00 0.00 0.00 300.00 145.30 0.00 0.00 0.33 400.00 1.50 255.00 399.99 245.29 1.50 255.00 044 SWO17 1:05.'12PM Page 2 COMPASS 5000.1 Build 74 r Report Company: ConocoPhillips(Alaska) Inc.-Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kupamk 2K Pad MD Reference: Well: Plan: 2K-30 North Reference: Wellbore: Plan: 2K-30 Survey Calculation Method: Design: 2K-30wpll Database: Well Plan: 2K-30 Plan: 39 + 115.7 @ 154.70usft (Doyonl42) Plan: 39 + 115.7 @ 154.70usft (Doyon142) True Minimum Curvature OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) V) (°) (usft) (usft) (°/100usft) (°) (usft) 500.00 3.00 255.00 499.91 345.21 1.50 0.00 0.53 600.00 4.50 255.00 599.69 444.99 1.50 0.00 0.65 700.00 6.00 255.00 699.27 544.57 1.50 0.00 0.78 800.00 7.50 255.00 798.57 643.87 1.50 0.00 0.92 900.00 9.35 249.79 897.49 742.79 2.00 -25.00 1.07 1,000.00 11.25 246.31 995.88 841.18 2.00 -19.85 1.23 1,100.00 13.18 243.83 1,093.61 938.91 2.00 -16.42 1.40 1,200.00 15.13 241.98 1,190.57 1,035.87 2.00 -14.00 1.58 1,300.00 17.09 240.54 1,286.63 1,131.93 2.00 -12.20 1.78 1,400.00 19.06 239.39 1,381.70 1,227.00 2.00 -10.82 2.00 1,477.61 20.59 238.64 1,454.70 1,300.00 2.00 -9.73 2.18 1,500.00 20.59 230.64 1,475.66 1,320.96 0.00 0.00 2.23 1,584.43 20.59 238.64 1,554.70 1,400.00 0.00 0.00 2.43 1,600.00 20.91 238.02 1,569.26 1,414.56 2.50 -35.00 2.47 1,700.00 23.01 234.40 1,662.00 1,507.30 2.50 -34.42 2.72 1,800.00 25.19 231.37 1,753.26 1,598.58 2.50 -31.06 2.98 1,900.00 27.41 228.80 1,842.93 1,688.23 2.50 -28.29 3.26 2,000.00 29.68 226.59 1,930.77 1,776.07 2.50 -25.99 3.56 2,100.00 31.98 224.66 2,016.64 1,861.94 2.50 -24.04 3.87 2,200.00 34.30 222.97 2,100.37 1,945.67 2.50 -22.39 4.21 2,300.00 36.64 221.47 2,181.81 2,027.11 2.50 -20.98 4.57 2,400.00 39.00 220.13 2,260.79 2,106.09 2.50 -19.75 4.95 2,500.00 41.38 218.92 2,337.18 2,182.48 2.50 -18.69 5.35 2,600.00 43.76 217.82 2,410.82 2,256.12 2.50 -17.77 5.58 2,700.00 46.16 216.81 2,481.57 2,326.87 2.50 -16.96 5.77 2,800.00 48.56 215.87 2,549.30 2,394.60 2.50 -16.24 6.16 2,900.00 50.98 215.01 2,613.88 2,459.16 2.50 -15.61 6.73 3,000.00 53.39 214.20 2,675.19 2,520.49 2.50 -15.05 7.47 3,100.00 55.82 213.44 2,733.11 2,578.41 2.50 -14.55 8.34 3,200.00 58.24 212.72 2,787.53 2,632.83 2.50 -14.11 9.31 3,300.00 60.67 212.04 2,838.34 2,683.64 2.50 -13.72 10.38 3,313.04 60.99 211.96 2,844.70 2,690.00 2.50 -13.38 6.59 10 3/4" x 13-1/2 3,333.04 60.99 211,96 2,854.40 2,699.70 0.00 0.00 6.66 3,400.00 61.85 213.60 2,886.44 2,731.74 2.50 59.65 6.97 3,500.00 63.16 216.00 2,932.61 2,777.91 2.50 58.87 7.62 3,561.82 63.99 217.45 2,960.12 2,805.42 2.50 57.76 8.12 3,600.00 63.99 217.45 2,976.87 2,822.17 0.00 0.00 8.44 3,700.00 63.99 217.45 3,020.72 2,866.02 0.00 0.00 9.32 3,800.00 63.99 217.45 3,064.57 2,909.67 0.00 0.00 10.31 3,900.00 63.99 217.45 3,108.42 2,953.72 0.00 0.00 11.38 4,000.00 63.99 217.45 3,152.27 2,997.57 0.00 0.00 12.50 4,100.00 63.99 217.45 3,196.13 3,041.43 0.00 0.00 13.66 4,200.00 63.99 217.45 3,239.98 3,085.28 0.00 0.00 14.86 4,300.00 63.99 217.45 3,283.83 3,129.13 0.00 0.00 16.08 522017 1:05.12PM Page 3 COMPASS 5000.1 Build 74 Report Company: ConocoPhillips(Alaska) Inc.-Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 2K Pad MD Reference: Well: Plan: 2K-30 North Reference: Wellbore: Plan: 2K-30 Survey Calculation Method: Design: 2K-30wp11 Database: Well Plan: 2K-30 Plan: 39 + 115.7 @ 154.70usft (Doyonl42) Plan: 39 + 115.7 @ 154.70usft (Doyon142) True Minimum Curvature OAKEDMP2 522017 1:06:12PM Page 4 COMPASS 5000.1 Build 74 Inc Azi (azimuth) TVD TVOSS DLeg TFace Lat. Error T (°) (°) (usft) (usft) (°/100usft) (°) (usft63.99 217.45 3,327.68 3,172.98 0.00 0.00 17.32 63.99 217.45 3,371.53 3,216.83 0.00 0.00 18.58 63.99 217.45 3,415.38 3,260.68 0.00 0.00 19.85 63.99 217.45 3,459.24 3,304.54 0.00 0.00 21.13 4,800.00 63.99 217.45 3,503.09 3,348.39 0.00 0.00 22.42 4,900.00 63.99 217.45 3,546.94 3,392.24 0.00 0.00 11.53 5,000.00 63.99 217.45 3,590.79 3,436.09 0.00 0.00 11.98 5,100.00 63.99 217.45 3,634.64 3,479.94 0.00 0.00 12.43 5,200.00 63.99 217.45 3,678.49 3,523.79 0.00 0.00 12.89 5,300.00 63.99 217.45 3,722.35 3,567.65 0.00 0.00 13.35 5,400.00 63.99 217.45 3,766.20 3,611.50 0.00 0.00 13.82 5,500.00 63.99 217.45 3,810.05 3,655.35 0.00 0.00 14.29 5,600.00 63.99 217.45 3,853.90 3,699.20 0.00 0.00 14,77 5,700.00 63.99 217.45 3,897.75 3,743.05 0.00 0.00 15.25 5,800.00 63.99 217.45 3,941.61 3,786.91 0.00 0.00 15.74 5,900.00 63.99 217.45 3,985.46 3,830.76 0.00 0.00 16.23 6,000.00 63.99 217.45 4,029.31 3,874.61 0.00 0.00 16.72 6,100.00 63.99 217.45 4,073.16 3,918.46 0.00 0.00 17.22 6,200.00 63.99 217.45 4,117.01 3,962.31 0.00 0.00 17,71 6,300.00 63.99 217.45 4,160.86 4,006.16 0.00 0.00 18.21 6,400.00 63.99 217.45 4,204.72 4,050.02 0.00 0.00 18.72 6,500.00 63.99 217.45 4,248.57 4,093.87 0.00 0.00 19.22 6,600.00 63.99 217.45 4,292.42 4,137.72 0.00 0.00 19.73 6,700.00 63.99 217.45 4,336.27 4,181.57 0.00 0.00 20.23 6,800.00 63.99 217.45 4,380.12 4,225.42 0.00 0.00 20.74 6,900.00 63.99 217.45 4,423.97 4,269.27 0.00 0.00 21.25 7,000.00 63.99 217.45 4,467.83 4,313.13 0.00 0.00 21.76 7,100.00 63.99 217.45 4,511.68 4,356.98 0.00 0.00 22.28 7,200.00 63.99 217.45 4,555.53 4,400.83 0.00 0.00 22.79 7,300.00 63.99 217.45 4,599.38 4,444.68 0.00 0.00 23.31 7,400.00 63.99 217.45 4,643.23 4,488.53 0.00 0.00 23.82 7,500.00 63.99 217.45 4,687.09 4,532.39 0.00 0.00 24.34 7,600.00 63.99 217.45 4,730.94 4,576.24 0.00 0.00 24.86 7,700.00 63.99 217.45 4,774.79 4,620.09 0.00 0.00 25.38 7,800.00 63.99 217.45 4,818.64 4,663.94 0.00 0.00 25.90 7,900.00 63.99 217.45 4,862.49 4,707.79 0.00 0.00 26.42 8,000.00 63.99 217.45 4,906.34 4,751.64 0.00 0.00 26.94 8,100.00 63.99 217.45 4,950.20 4,795.50 0.00 0.00 27.46 8,200.00 63.99 217.45 4,994.05 4,839.35 0.00 0.00 27.98 8,300.00 63.99 217.45 5,037.90 4,883.20 0.00 0.00 28.50 8,400.00 63.99 217.45 5,081.75 4,927.05 0.00 0.00 29.03 8,500.00 63.99 217.45 5,125.60 4,970.90 0.00 0.00 29.55 8,600.00 63.99 217.45 5,169.45 5,014.75 0.00 0.00 30.08 8,700.00 63.99 217.45 5,213.31 5,058.61 0.00 0.00 30.60 522017 1:06:12PM Page 4 COMPASS 5000.1 Build 74 Report Company: ConoccPhillips(Alaska) Inc.-Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kupamk 2K Pad MD Reference: Well: Plan: 2K-30 North Reference: Wellbore: Plan: 2K-30 Survey Calculation Method: Design: 2K-30wpi1 Database: Well Plan: 21K-30 Plan: 39 + 115.7 @ 154.70usft (Doyon142) Plan: 39+ 115.7 @ 154.70usft (Doyon142) True Minimum Curvature OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 8,800.00 63.99 217.45 5,257.16 5,102.46 0.00 0.00 31.13 8,900.00 63.99 217.45 5,301.01 5,146.31 0.00 0.00 31.65 9,000.00 63.99 217.45 5,344.86 5,190.16 0.00 0.00 32.18 9,100.00 63.99 217.45 5,388.71 5,234.01 0.00 0.00 32.70 9,200.00 63.99 217.45 5,432.56 5,277.86 0.00 0.00 33.23 9,300.00 63.99 217.45 5,476.42 5,321.72 0.00 0.00 33.76 9,400.00 63.99 217.45 5,520.27 5,365.57 0.00 0.00 34.29 9,500.00 63.99 217.45 5,564.12 5,409.42 0.00 0.00 34.81 9,600.00 63.99 217.45 5,607.97 5,453.27 0.00 0.00 35.34 9,700.00 63.99 217.45 5,651.82 5,497.12 0.00 0.00 35.87 9,800.00 63.99 217.45 5,695.68 5,540.98 0.00 0.00 36.40 9,900.00 63.99 217.45 5,739.53 5,584.83 0.00 0.00 36.93 10,000.00 63.99 217.45 5,783.38 5,628.68 0.00 0.00 37.46 10,100.00 63.99 217.45 5,827.23 5,672.53 0.00 0.00 37.99 10,200.00 63.99 217.45 5,871.08 5,716.38 0.00 0.00 38.52 10,300.00 63.99 217.45 5,914.93 5,760.23 0.00 0.00 39.05 10,400.00 63.99 217.45 5,958.79 5,804.09 0.00 0.00 39.58 10,500.00 63.99 217.45 6,002.64 5,847.94 0.00 0.00 40.11 10,600.00 63.99 217.45 6,046.49 5,891.79 0.00 0.00 40.64 10,614.22 63.99 217.45 6,052.72 5,898.02 0.00 0.00 40.71 10,700.00 65.49 215.13 6,089.33 5,934.63 3.00 -54.95 41.07 10,800.00 67.27 212.50 6,129.40 5,974.70 3.00 -53.96 41.32 10,900.00 69.10 209.94 6,166.56 6,011.86 3.00 -52.91 41.50 11,000.00 70.97 207.44 6,200.71 6,046.01 3.00 -51.95 41.61 11,100.00 72.87 205.00 6,231.74 6,077.04 3.00 -51.10 41.66 11,200.00 74.80 202.61 6,259.58 6,104.88 3.00 -50.34 41.64 11,300.00 76.75 200.26 6,284.16 6,129.46 3.00 49.68 41.58 11,400.00 78.73 197.95 6,305.40 6,150.70 3.00 49.10 41.45 11,500.00 80.72 195.67 6,323.24 6,168.54 3.00 -48.61 41.28 11,600.00 82.72 193.41 6,337.64 6,182.94 3.00 48.20 41.06 11,700.00 84.74 191.18 6,348.56 6,193.86 3.00 -47.88 40.79 11,712.78 85.00 190.90 6,349.70 6,195.00 3.00 -47.63 40.76 7.5/8" x 9-7/8" by 11" 11,732.78 85.00 190.90 6,351.44 6,196.74 0.00 0.00 40.87 11,800.00 87.01 190.77 6,356.12 6,201.42 3.00 -3.61 41.31 11,900.00 90.01 190.58 6,358.73 6,204.03 3.00 -3.60 41.99 11,942.97 91.29 190.50 6,358.24 6,203.54 3.00 -3.60 42.30 12,000.00 91.29 190.50 6,356.95 6,202.25 0.00 0.00 42.76 12,100.00 91.29 190.50 6,354.69 6,199.99 0.00 0.00 43.58 12,200.00 91.29 190.50 6,35244 6,197.74 0.00 0.00 44.43 12,300.00 91.29 190.50 6,350.18 6,195.48 0.00 0.00 45.32 12,400.00 91.29 190.50 6,347.92 6,193.22 0.00 0.00 46.24 12,500.00 91.29 190.50 6,345.67 6,190.97 0.00 0.00 47.19 12,600.00 91.29 190.50 6,343.41 6,188.71 0.00 0.00 48.16 SV2017 1:05:12PM Page 5 COMPASS 5000.1 Build 74 Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference Project: Kuparuk River Unit TVD Reference: Site: Kupamk 2K Pad MD Reference: Well: Plan: 2K-30 North Reference: Wellbore: Plan: 2K-30 Survey Calculation Method: Design: 2K-30wp11 Database: Well Plan: 2K-30 Plan: 39 + 115.7 @ 154.70usft (Doyon142) Plan: 39 + 115.7 @ 154.70usft (Doyon142) True Minimum Curvature OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Let Error (usft) (°) (°) (usft) (usft) (°1100usft) (°) (usft) 12,700.00 9129 190.50 6,341.15 6,186.45 0.00 0.00 49.18 12,800.00 91.29 190.50 6,338.89 6,164.19 0.00 0.00 50.18 12,900.00 91.29 190.50 6,336.64 6,181.94 0.00 0.00 51.22 13,000.00 91.29 190.50 6,334.38 6,179.68 0.00 0.00 52.28 13,100.00 91.29 190.50 6,332.12 6,177.42 0.00 0.00 53.37 13,200.00 91.29 190.50 6,329.87 6,175.17 0.00 0.00 54.47 13,300.00 91.29 190.50 6,327.61 6,172.91 0.00 0.00 44,73 13,400.00 91.29 190.50 6,325.35 6,170.65 0.00 0.00 45.04 13,500.00 91.29 190.50 6,323.10 6,168.40 0.00 0.00 45.35 13,588.31 91.29 190.50 6,321.10 6,166.40 0.00 0.00 45.63 13,600.00 91.22 190.90 6,320.85 6,166.15 3.50 99.95 45.79 13,700.00 90.62 194.35 6,319.24 6,164.54 3.50 99.96 47.00 13,800.00 90.01 197.80 6,318.70 6,164.00 3.50 100.01 48.05 13,800.98 90.00 197.83 6,318.70 6,164.00 3.50 100.03 48.05 13,900.00 86.96 199.49 6,321.33 6,166.63 3.50 151.48 48.60 14,000.00 83.88 201.17 6,329.32 6,174.62 3.50 151.43 49,09 14,048.54 82.39 201.99 6,335.12 6,180.42 3.50 151.30 49.32 14,100.00 82.39 201.99 6,341.93 6,187.23 0.00 0.00 49.44 14,154.89 82.39 201.99 6,349.19 6,194.49 0.00 0.00 49,61 14,200.00 82.79 200.45 6,355.01 6,200.31 3.50 -75.38 49,48 14,300.00 83.70 197.05 6,366.77 6,212.07 3.50 -75.19 49.05 14,400.00 84.63 193.66 6,376.93 6,222.23 3.50 -74.79 48.46 14,500.00 85.58 190.27 6,385.47 6,230.77 3.50 -74.44 4772 14,543.97 86.00 188.79 6,388.70 6,234.00 3.50 -74.15 47.35 14,600.00 87.96 188.79 6,391.65 6,236.95 3.50 0.00 47.52 14,637.05 89.26 188.79 6,392.55 6,237.85 3.50 0.00 47,64 14,700.00 89.26 188.79 6,393.37 6,238.67 0.00 0.00 14,800.00 89.26 188.79 6,394.66 6,239.96 47.85 0.00 0.00 48.19 14,900.00 89.26 188.79 6,395.96 6,241.26 0.00 0.00 48.53 15,000.00 89.26 188.79 6,397.25 6,242.55 0.00 0.00 48.88 15,100.00 89.26 188.79 6,398.55 6,243.85 0.00 0.00 49.23 15,200.00 89.26 188.79 6,399.84 6,245.14 0.00 0.00 49.59 15,300.00 89.26 188.79 6,401.14 6,246.44 0.00 0.00 49.95 15,400.00 89.26 188.79 6,402.43 6,247.73 0.00 0.00 50.31 15,500.00 89.26 188.79 6,403.73 6,249.03 0.00 0.00 15,600.00 89.26 188.79 6,405.03 6,250.33 0.00 0.00 50.68 15,700.00 89.26 188.79 6,406.32 6,251.62 0.00 0.00 51.05 15,800.00 89.26 188.79 6,407.62 6,252.92 51.42 0.00 0.00 51.80 15,900.00 89.26 188.79 6,408.91 6,254.21 0.00 0.00 52.19 16,000.00 89.26 188.79 6,410.21 6,255.51 0.00 0.00 52.57 16,100.00 89.26 188.79 6,411.50 6,256.80 0.00 0.00 52.96 16,200.00 89.26 188.79 6,412.80 6,258.10 0.00 0.00 53.36 16,300.00 89.26 188.79 6,414.10 6,259.40 0.00 0.00 53.75 16,400.00 89.26 188.79 6,415.39 6,260.69 0.00 0.00 54.15 522017 1:O5:12PM Page 6 COMPASS 5000.1 Build 74 Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 2K Pad MD Reference: Well: Plan: 2K-30 North Reference: Wellbore: Plan: 2K-30 Survey Calculation Method: Design: 2K-30wpll Database: Well Plan: 2K-30 Plan: 39 + 115.7 @ 154.70usft (Doyon142) Plan: 39+ 115.7 @ 154.70usft (Doyon142) True Minimum Curvature OAKEDMP2 ed Survey MD (usft) 16,500.00 16,600.00 16,700.00 16,800.00 F Inc (°) 89.26 89.26 89.26 89.26 AV (azimuth) (°) 188.79 188.79 188.79 188.79 TVD (usft) 6,416.69 6,417.98 6,419.28 6,420.57 TVDSS (usft) 6,261.99 6,263.28 6,264.58 6,265.87 DLeg (°/100usft) 0.00 0.00 0.00 0.00 TPace (°) 0.00 0.00 0.00 0.00 tat Error Nam 54.56 54.96 55.37 55.78 16,900.00 17,000.00 17,100.00 17,200.00 17,300.00 89.26 89.26 89.26 89.26 89.26 188.79 188.79 168.79 188.79 188.79 6,421.87 6,423.16 6,424.46 6,425.76 6,427.05 6,267.17 6,268.46 6,269.76 6,271.06 6,272.35 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 56.20 56.62 57.04 57.46 57,89 17,400.00 17,500.00 17,600.00 17,700.00 17,800.00 89.26 89.26 89.26 89.26 89.26 188.79 188.79 188.79 188.79 188.79 6,428.35 6,429.64 6,430.94 6,432.23 6,433.53 6,273.65 6,274.94 6,276.24 6,277.53 6,278.83 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 58.32 58.75 59.18 59.62 60.06 17,900.00 18,000.00 18,100.00 18,200.00 18,300.00 89.26 89.26 89.26 89.26 89.26 186.79 188.79 168.79 188.79 188.79 6,434.82 6,436.12 6,437.42 6,438.71 6,440.01 6,280.12 6,281.42 6,282.72 6,284.01 6,285.31 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 60.50 60.94 61.39 61.84 62.29 18,400.00 18,500.00 18,600.00 18,700.00 18,800.00 69.26 89.26 89.26 89.26 89.26 168.79 186.79 188.79 188.79 186.79 6,441.30 6,442.60 6,443.89 6,445.19 5,446.46 6,286.60 6,287.90 6,289.19 6,290.49 6,291.78 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 62,74 63.20 63.65 64.11 64.57 18,900.00 19,000.00 19,100.00 19,200.00 19,300.00 89.26 89.26 89.26 89.26 89.26 188.79 188.79 186.79 188.79 188.79 6,447.78 6,449.08 6,450.37 6,451.67 6,452.96 6,293.06 6,294.38 6,295.67 6,296.97 6,298.26 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 65.03 65.50 65.96 66.43 66.90 19,400.00 19,500.00 19,600.00 19,700.00 19,800.00 89.26 89.26 89.26 89.26 89.26 188.79 188.79 188.79 188.79 188.79 6,454.26 6,455.55 6,456.85 6,458.14 6,459.44 6,299.56 6,300.85 6,302.15 6,303.44 6,304.74 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 67.37 67.84 68.32 68.79 69.27 19,900.00 20,000.00 20,100.00 20,200.00 20,300.00 89.26 89.26 89.26 89.26 89.26 188.79 188.79 188.79 188.79 188.79 6,460.74 6,462.03 6,463.33 6,464.62 6,465.92 6,306.04 6,307.33 6,308.63 6,309.92 6,311.22 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 69.75 70.23 70,71 71.20 71.68 20,400.00 20,500.00 20,600.00 20,700.00 20,800.00 89.26 89.26 89.26 89.26 89.26 188.79 166.79 188.79 188.79 188.79 6,467.21 6,468.51 6,469.80 6,471.10 6,472.40 6,312.51 6,313.81 6,315.10 6,316.40 6,317.70 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 72,17 72.65 73,14 73.63 74.13 5WO17 1:05:12PM Page 7 COMPASS 5000.1 Build 74 Report Company: Con000Phillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit Site: Kuparuk 2K Pad TVD Reference: Well: Plan: 2K-30 MD Reference: Wellbore: Plan: 2K-30 North Reference: Design: 2K-30wpll Survey Calculation Method: Database: Well Plan: 2K-30 Plan: 39+ 115.7 @ 154.70usft (Doyon142) Plan: 39 + 115.7 @ 154.70usft (Doyon142) True Minimum Curvature nAKFnLAP1 Planned Survey MD (waft) 20,900.00 21,000.00 21,100.00 21,200.00 21,300.00 21,400.00 21,500.00 21,600.00 21,700.00 21,600.00 21,900.00 22,000.00 22,100.00 22,200.00 22,300.00 22,400.00 22,500.00 22,521.54 Inc V) 89.26 89.26 89.26 89.26 89.26 89.26 89.26 88.26 89.26 89.26 89.26 89.26 89.26 89.26 89.26 89.26 89.26 89.26 Azi(azimuth) (,) 188.79 788.79 768.79 188.79 188.79 188.79 788.79 168.79 168.79 768.79 188.79 188.79 168.79 168.79 188.79 188.79 188.79 188.79 TVD (usft) 6,473.69 8,474.99 8,478.26 6,477.56 6,478.87 6,480.17 6,467.47 6,462.78 6,484.06 8,485.35 6,486.65 6,487.94 6,488.24 6,490.53 6,491.83 6,493.13 6,494.42 6,494.70 / TVDSS (usft) 6,318.99 6,320.29 6,321.58 6,322.88 6,324.17 6,325.47 6,326.77 6,328.06 6,329.36 6,330.65 6,331.95 6,333.24 6,334.54 6,335.83 6,337.13 6,338.43 6,339.72 6,340.00 DLeg (°1100usR) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 7Face (°) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.90 Let Error (usft) 74.62 75.11 75.61 76.70 76.80 77.10 77.60 78.10 78.60 79.10 79.61 80.11 80.62 81.13 81.63 82.14 82.65 82.76 5/2/2017 1:05:12PM Page 8 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -KUP2 Project: Kupamk River Unit Site: Kuparuk 21K Pad Well: Plan: 2K-30 Wellbore: Plan: 2K-30 Design: 2K-30wpl l Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: 2K-30 Plan: 39+ 115.7 @ 154.70usft (Doyon142) Plan: 39 + 115.7 @ 154.70usft (Doyon142) True Minimum Curvature OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (•) 116.20 116.20 20" x 42" 20 42 3,313.04 2,844.70 10 3/4"x 13-1/2 10-3/4 13-1/2 11,712.78 6,349.70 7-5/8" x 9-7/8" by 11" 7-5/8 11 22,521.54 6,494.70 4 1/2" x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Depth Depth pip (wait) (usft) Dip DirectionName Lithology 2,321.12 2,198.70 WS -Top 10,424.89 5,969.70 HRZ 4,126.39 3,207.70 C-80 8,463.74 5,109.70 C-37 4,290.58 3,279.70 CAMP SST 7,950.64 4,884.70 C-40 1,531.02 1,504.70 Base Permafrost 3,115.36 2,741.70 WS Base 11,347.66 6,294.70 KUP_C 10,963.80 6,186.70 K-1 10,737.51 6,104.70 HRZ_BASE 9,754.45 5,675.70 C-35 11,712.78 6,349.70 KUP_A4 11,509.14 6,324.70 KUP_AS 7,266.52 4,584.70 C-50 Plan Annotations - - Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP: Start 1.5"/100' DLS, 255- TF, for 500' 800.00 798.57 -8.46 -31.56 Start 2'/100' DLS, -25° TF, for 677.61' 1,477.61 1,454.70 -82.25 -176.71 Hold for 106.82' 1,584.43 1,554.70 -101.80 -208.79 Start 2.5°/100' DLS, -35° TF, for 1728.61' 3,313.04 2,844.70 -941.45 -901.60 Hold for 20' 3,333.04 2,854.40 -956.29 -910.86 Start 2.5°/100' DLS, 59.65' TF, for 228.78' 3,561.82 2,960.12 -1,122.91 -1,026.42 Hold for 7052.4' 10,614.22 6,052.72 -6,154.69 -4,880.41 Start 3°/100' DLS, -54.95° TF, for 1098.56' 11,712.78 6,349.70 -7,110.42 -5,295.53 Hold for 20' 11,732.78 6,351.44 -7,129.99 -5,299.29 Start 3°/100'DLS,-3.61°TF, for 210.19' 11,942.97 6,358.24 -7,336.31 -5,338.27 Hold for 1645.34' 13,588.31 6,321.10 -8,953.70 -5,638.00 Start 3.5°/100' DLS, 99.95° TF, for 212.66- 13,800.98 6,318.70 -9,159.74 -5,690.00 Adjust TF to 151.48", for 247.56' 14,048.54 6,335.12 -9,391.78 -5,774.01 Hold for 106.35' 14,154.89 6,349.19 -9,489.53 -5,813.48 Start 3.5°/100' DLS, -75.38° TF, for 389.08' 14,543.97 6,388.70 -9,861.67 -5,915.83 Adjust TF to 0", for 93.08' 14,637.05 6,392.55 -9,953.76 -5,930.04 Hold for 7884.49' 22,521.54 6,494.70 -17,744.99 -7,134.78 TD: 22521.54'MD, 6494.7'TVD Checked By: Approved By: Date: 5/2/2017 1:05:12PM Page 9 COMPASS 5000.1 Build 74 AC Summary ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad Plan: 2K-30 Plan: 2K-30 50103xxxxx00 2K-30wp11 Failed on Clearance Summary Anticollision Report 02 May, 2017 Tray. CyOnder North Proximity Scan on Current Survey Data (Noah Reference( Reference Design: Kuparuk 2K Pad Plan: 2K -30 -Plan: 2K-30-2K-30wp11 Well Coordinates: 5,937,915 25 N,1,638,342.95 E (70° 10' 31.14" N,150° 01 0019" W) Datum Height: Plan: 39 + 115.7 @ 154,70usft(Doyon162) Scan Range: 0.00 t0 22,521.54 usft, Measured Depth, Scan Radius is 2,449.25 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED Ail n'ellpa0s within 200'+ 10011000 of reference Anticollision Report for Plan: 2K-30 - 2K-30wp11 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) 234.05 374.50 22296 Reference Design: Kupmuk 2K Pad - Plan: 2K-30- Plan: 2 410-2K-31kvp11 38.422 Centre Distance Pass - Major Risk Scan Range: 0.00 to 22,521.64 usft. Messured Depth. 235.35 595.37 225.70 Scan Radius is 2,"8.25 usft. Clearance Factor cutoff Is Unlimited. Max Ellipse Separation is Unlimited 24.391 Clearance Factor Measured Site Name Minimum @Measumd Ellipse @Measured Clearance Summary Based on Depth Distance Depth Separation Depth Factor Minimum Separation blaming Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft ) (usft) usft Kuparuk 2K Pad 2K -09 -2K -09-2K-09 2K -09 -2K -09-2K-09 2K-09-2K-0911-2K-O9L1 2K -09 -2K -091-1-2K-0911 2K -09-2K-0911-01 -2K-0911-01 2K -W - 2K -09L1 -01 -2K-09L1-01 2K -10 -2K -10-2K-10 2K -10 -2K -10-2K-10 2K-11 -2K-11 -2K-11 2K-11- 2K-11 - 2K-11 2K-11 - 2K -11A- 2K -11A 2K -11 -2K -11A -2K -11A 2K-it-2K-11AL1-2K-11AL1 2K-11-2K-11AL1 -2K-11 AL1 2K -11-2K-11 AP51 - 2K-11AP81 2K-11-2K41AP81-2K-11 APB1 2K -12 -2K -12-2K-12 2K -12 -2K -12-2K-12 2K -13 -2K -13-2K-13 2K -13 -2K -13-2K-13 2K -13 -2K -13A -2K -13A 2K -13 -2K -13A -2K -13A 2K-13-21(-13AL1-2K-13AL1 2K-13-2K-13AL1-2K-13AL1 2K-13-2K-13AL2-2K-13AL2 2K-13-2K-13Al2-2K-1 MU 2K-14 - 2K-14 -2KA4 2K -14 -2K -14-2K-14 374.50 234.05 374.50 22296 375.00 38.422 Centre Distance Pass - Major Risk 595.37 235.35 595.37 225.70 600.00 24.391 Clearance Factor Pass - Major Risk 374.50 234.05 374.50 228.30 375.00 40.757 Centre Distance Pass - Major Risk 59537 235.35 595.37 22605 600.00 25.307 Clearance Factor Pass - Major Risk 37450 234.05 374.50 228.30 375.00 40.757 Centre Distance Pass - Major Risk 595.37 235.35 595.37 226.05 600.00 25.307 Clearence Factor Pass - Major Risk 349.98 209.70 349.98 202.56 350.00 29.467 Cer4re Distance Pass - Major Risk 620.30 212.86 620.30 199.13 625.00 15.503 Clearance Factor Pass - Major Risk 175.70 18506 175.70 181.84 17500 57.451 Centre Distance Pass - Major Risk 596.52 18861 596.52 177.89 600.00 17.593 Clearance Factor Pass - Major Risk 175.70 18506 175.70 182.57 175.00 74.417 Centre Distance Pass - Major Risk 59652 188.61 596.52 178.24 600.00 18.185 Clearance Factor Pass - Major Risk 175.70 185.06 175.70 182.57 175.00 74.417 Centre Distance Pass - Major Risk 596.52 188.61 596.52 17824 600.00 18-185 Clearance, Factor Pass - Major Risk 175.70 185.06 175.70 181.84 175.00 57.451 Centre Distance Pass - Major Risk 596.52 188.61 596.52 177.89 600.00 17,593 Clearance Factor Pass - Major Risk 32543 159.31 325.43 153.84 3250D 28088 Centre Distance Pass - Major Risk 596.98 161.65 596.98 150.93 600.00 15.071 Clearance Factor Pass - Major Risk 50.70 70.15 50.70 67.58 5000 27.260 Centre Distance Pass - Major Risk 474.86 7205 474.86 64.05 475.00 9.005 Clearance Factor Pass - Major Risk 50.70 70.15 50.70 67.58 50.00 27.260 Centre Distance Pass - Major Risk 474.86 72.05 474.86 64.05 475.00 9.005 Clearance Factor Pass - Major Risk 5070 70.15 50.70 67.58 5000 27.260 Centre Distance Pass - Major Risk 474.86 72.05 474.86 64,05 475.00 9.005 Clearance Factor Pass - Major Risk 50.70 70.15 50.70 6758 50.00 27.260 Centre Distance Pass - Major Risk 474.86 72.05 474.86 64.05 475.00 9.005 Clearance Factor Pass - Major Risk 50.70 45.00 50.70 42.42 50.00 17.477 Centre Distance Pass - Major Risk 500.00 46.97 500.00 38.55 500.00 5.581 Clearance Factor Pass - Major Risk 02 May. 2017 - 12:23 Page 2 of 8 COMPASS Anticollision Report for Plan: 2K-30 - 2K-3Owp11 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) ReferenceDesign: Kuparuk 2K Pad -Plan: 2)(40 -Plan: 2K-30-2K-30wp11 Scan Range: 0.00 to 22,521.56 usft Measured Depth. Scan Radius is 2,448.25 usft. Clearance Factor cutoff is Unlimited Max Ellipse Separation is Unlimited 2K -20 -2K -20-2K-20 Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Pass - Major Risk Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Wanting Comparison Well Name -Wellbore Name - Design (usft) (usft) (deal (.sit) usft 15.078 Centre Distance Pass - Major Risk 2K -14 -2K -14A -2K -14A 50.70 45.00 50.70 42.42 50.00 17.477 Centre Distance Pass -Major Risk 2K -14 -2K -14A -2K -14A 500.00 46.97 500.00 38.55 500.00 5581 Clearance Factor Pass - Major Risk 2K-14-2K-14AL1-2K-14AL1 50.70 4500 50.70 42.42 50.00 17.477 Centre Distance Pass - Major Risk 2K-14-2K-14A1.1-2K-14AL1 500.00 46.97 500.00 38.55 500D0 5.581 Cluster. Factor Pass - Major Risk 2K-15-2K-15-2KA5 50.70 19.92 50.70 17.58 50.00 8.489 Centre Distance Pass - Major Risk 2K -15 -2K -15-2K-15 500.30 22.66 500.30 11.32 500.00 1.999 Clearance Factor Pass - Major Risk 2K -15 -2K -15L1 -2K -15L1 50.70 19.92 50.70 17.58 50.00 8.489 Centre Distance Pass - Major Risk 2K -15 -2K -15L1 -2K-151.1 50030 2266 500.30 11.32 500.00 1.999 Clearance Factor Pass -Major Risk 2K -15 -2K -151_1.01 -2K -15L1-01 50.70 19.92 5070 17.58 50.00 8.489 Centre Distance Pass - Major Risk 2K -15 -2K -151-1-01-2K-1511-01 500.30 22.66 500.30 11.32 500.00 1.999 Clearance Factor Pass - Major Risk 2K -15 -2K -15L1 -02 -2K -15L1-02 50.70 19.92 50.70 17.58 50.00 8.489 Centre Distance Pass - Major Risk 2K -15 -2K -15L1 -02-2K-1511-02 500.30 22.66 W0.30 11.32 500.00 1.999 Clearance Factor Pass - Major Risk 2K -16 -2K -16-2K-16 50.70 509 50.70 2,74 50.00 2.169 Centre Distance Pass - Major Risk 2K -16 -2K -16-2K-16 - 2K -17 -2K -17-21(d7 575.99 28.82 575.99 19.26 575.00 3.013 Centre Distance - Pass -Major Risk 2K -17 -2K -17-2K-17 650.78 2929 650.78 18.48 650.00 2.710 Clearance Factor Pass - Major Risk 2K -18 -2K -18-2K-18 651.05 5203. 65105 41.68 650.00 5.026 Centre Distance Pass - Major Risk 2K -18 -2K -18-2K-18 725.59 52.48 725.59 40.88 72500 4.526 Clearance Factor Pass - Major Risk 2K -19 -2K -19-2K-19 1.533.97 56.18 1,533.50 29.15 1,525.00 2.079 Centre Distance Pass -Major Risk 2K -19 -2K -19-2K-19 1,558,12 9754 1,558.12 29.14 1,55000 2.063 Clearance Factor Pass - Major Risk 2K -19 -2K -19A -2K -19A 1,533.50 56.18 1,53350 29.20 1,525.00 2.082 Centre Distance Pass - Major Risk 2K -19 -2K -19A -2K -19A 1,558.12 56.54 1,558.12 29.18 1,550.00 2.067 Clearance Factor Pass - Major Risk 2K-19-2K-19AL1-2K-19AL1 1,533.50 56.18 1,533.50 29.20 1,525.00 2.082 Centre Distance Pass - Major Risk 2K-19-2K-19AL1-2K-19AL1 1,558.12 58.54 1,558.12 29.18 1,550.00 2.067 Clearance Factor Pass - Major Risk 2K -20 -2K -20-2K-20 652.30 103.77 652.30 88.74 6W.00 6.906 Centre Distance Pass - Major Risk 2K -20 -2K -20-2K-20 1,360.94 111.37 1,360.94 78.11 1,350.00 3.349 Clearance Factor Pass - Major Risk 2K -21 -2K -21-2K-21 527.34 129.88 527.34 121.26 525.00 15.078 Centre Distance Pass - Major Risk 2K -21 -2K -21-2K-21 602.66 13050 602.66 120.72 600.00 13.340 Clearance Factor Pass - Major Risk 2K -21 -2K -21A -2K -21A 52234 129.88 527.34 121.22 52500 14.996 Centre Distance Pass - Major Risk 2K -21 -2K -21A -2K -21A 02 May, 2017 - 12:23 Page 3 of 6 COMPASS Anticollision Report for Plan: 2K-30 - 2K-30wp11 -Scan Tray. Cylinder North Proximity on Current Survey Data (North Reference) Reference Design: Kuparuk 2K Pad - Plan: 2K -30 -Plan: 21(410-2 40wp11 Scan Range: 0.00 W 2;521.54 usft. Measured Depth. Scan Radius is 2,448.25 can. Clearance Fedor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured allies @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) just) (usX) usft 2K -22 -2K -22-2K-22 527.62 153.24 527.62 141.22 525.00 12.750 Centre Distance Pass - Major Risk 2K -22 -2K -22-2K-22 602.98 154.12 602.98 140.28 6W.00 11.136 Clearance Fedor Pass - Major Risk 2K -22 -2K -22A -2K -22A 527.62 153.24 527.62 141.27 525.00 12.800 Centre Distance Pass - Major Risk 2K -22 -2K -22A -2K -22A W2.98 154.12 602.98 140.32 600,00 11.174 Clearance Factor Pass - Major Risk 2K-22-2K-22AL1-2K-22AL1 527.62 153.24 527,62 14122 525.00 12.750 Centre Distance Pass - Major Risk 21(-22-2K-22ALi-2K-22AL1 602.98 154.12 602.98 140.28 600.00 11.136 Clearance Fedor Pass - Major Risk 2K-22-2K-22AL1-01-2K-22AL1-01 527,62 153.24 527,62 141.22 52500 12.750 Centre Distance Pass -Major Risk 2K-22-2K.UAL1-01-2K-22A11-01 602.98 154.12 602.98 140.28 600.00 11.136 Clearance Fador Pass - Major Risk 2K -23 -2K -23-2K-23 200.70 17690 2(10]0 17670 200.00 56283 Cane Distance Pass - Major Risk 2K -23 -2K -23-2K-23 427.15 181.29 427.15 174.43 425.00 26.433 Clearance Factor Pass - Major Risk 2K-23-2K-23A-21(-23A_wp06 200.70 179.90 2W 70 177,05 200A0 63.181 Centre Distance Pass - Major Risk 2K-23-2K-23A-2K-23A_wpW 427.15 181.29 427.15 174.78 425.00 27.849 Clearance Fedor Pass - Major Risk 2K-23-2K-23AL1-2K-23AL1_wpOB 200.70 179.90 200.70 177.05 260.00 63.181 Centre Distance Pass -Major Risk 2K-23-2K-23AL1-2K-23AL1_wp08 427.15 181.29 427.15 174.78 425.00 27.849 Clearance Fedor Pass - Major Risk 2K -24 -2K -24-2K-24 225.70 204.86 22510 201.25 225.00 56.758 Centre Distance Pass - Major Risk 2K -24 -2K -24-2K-24 376.77 206.10 376.77 200.08 375.00 34.217 Clearance Factor Pass - Major Risk 2K-24-2K-24AL2-2K-24AL2_wp02 225.70 204.86 225.70 201.60 225.00 62833 Centre Distance Pass -Major Risk 2K-24-2K-24AL2-2K-24AL2_wpW 37677 206.10 376.77 200.42 375.00 36.321 Clearance Fedor Pass - Major Risk 2K-24-2K-24Al2-M-2K-24AI2-01_w W 225.70 204.86 225,70 201.60 22560 62.833 Centre Distance Pass - Major Risk 2K-24-2K-24AL2-01-2K-24Al2-01_wp02 376.77 2WAD 376.77 2WA2 375.00 36.321 Claimants Fader Pass - Major Risk 2K -25 -2K -25-2K-25 175.70 230.04 175.70 226.85 175.00 71,985 Centre Distance Pass - Major Risk 2K -25 -2K -25-2K-25 351.49 230.80 551.49 225.09 35000 40.352 Clearance Factor Pass - Major Risk 2K-25-2K-25Li-2K-25L1 175.70 230.04 175.70 226.85 175.00 71.985 Centre Distance Pass - Major Risk 2K -25 -2K -2511-2K-2511 35149 230.80 351.49 225.09 350.00 40.352 Clearance Fedor Pass - Major Risk 2K -25 -2K -2511 -01 -2K -25L'401 175.70 230.04 175.70 226.85 17500 71.985 Centre Distance Pass - Major Risk 2K -25 -2K -25L1 -01 -2K -25L1-01 351.49 230.80 351.49 22509 35.00 40.352 Clearance Factor Pass - Major Risk 2K -27 -2K -27-2K-27 2,314.18 108.72 2,314.18 70.05 2,250.00 2811 Clearance Fedor Pass - Major Risk 2K -28 -2K -28-2K-28 2,079.08 97.43 2,079.08 50.04 2,125.60 2.056 Centre Distance Pass -Major Risk 2K -28 -2K -28-2K-28 2200.00 99.67 2,200.00 48.10 2,250.00 1,932 Clearance Fedor Pass - Major Risk 2K -28 -2K -28A -2K -28A 2,079.08 97.43 2,079.08 49.67 2,125.W 2.040 Centre Distance Pass - Major Risk 02 May, 2017 - 12:23 Page 4 0/8 COMPASS Anticollision Report for Plan: 2K-30 - 2K-30wp11 Trav, Cylinder North Proximity Scan on Current Survey Data (North Reference) ReferenceDesign: Kuparuk 2K Pad -Plan: 2K30 -Plan: 21(30-21(-30wp11 Scan Range: 0.00 to 22,521.54 usft. Measured Depth. Scan Radius is 2,448.25 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measumd Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name Design (usft) (usft) (usft) (usft) usft 2K -26 -2K -28A -2K -28A 2,20000 9987 2,200.00 47.65 2,25000 1916 Clearance Factor Pass - Major Risk 2K-28-2K-2aAL1-21(-28AL1 2,079.08 97.43 2,07908 4972 2,125.00 2.042 Centre Distance Pass - Major Risk 2K-28-2K-28AL1-2K-28AL1 2,200.00 99.67 2,200.00 47.70 2,25).00 1.918 Clearance Factor Pass - Major Risk 2K-28-2K-28AL1 PB1-2K-28AL1 P31 2,079.08 97.43 2,079.08 49.67 2,125.00 2.040 Centre Distance Pass - Major Risk 2K-28-2K-28ALiPB1-2K-28AL1PB1 2,200.00 9967 2,200.00 47.65 2.25000 1916 Clearance Factor Pass - Major Risk 2K-28-2K-28AL1 PB2-2K-28ALi P32 2,079.08 97.43 2,079.08 4967 2,125.00 2.040 Centre Distance Pass - Major Risk 2K-28-2K-28AL1PB2-2K-28AL1 PB2 2,200.00 99.67 2,20000 4765 2,250.00 1.916 Clearance Fedor Pass - Major Risk 2K-28-2K-28APB1-2K-28APB1 2,079.08 97.43 2,079.08 4967 2,125.00 2.040 Centre Distance Pass - Major Risk 2K-28-2K-28APS1-2K-28APBi 2,200.00 99.67 2,200.00 47.65 2,250.00 1.916 Clearance Factor Pass - Major Risk 2K -34 -2K34 -2K-34 161.57 254.76 161.57 251.86 150.00 87.904 Centre Distance Pa. - Major Risk 2K -34 -2K -34-2K-34 557.36 257.81 557.36 248.45 550.00 2]563 Clearance Fedor Pass - Major Risk 2K -34 -2K -341_1-2K-341_1 161.57 254.76 161.57 251.86 15000 87.904 Cents Distance Pass - Major Risk 2K -34 -21(34L1 -2K -34L1 557.36 257.81 557.35 248.45 550.00 27.563 Clearance Factor Pass - Major Risk 2K-34-2K34PB1-2K-34PBi 161.57 254.76 181.57 251.47 150.00 77.586 Centre Distance Pass - Major Risk 2K-34-2K-34PBi-2K34PB1 557.36 257.81 557.36 24845 550.00 27.563 Clearance Fedor Pass - Major Risk Plan :2K31 -Plan 2K-31-2K31wp05 30831 24.% 308.71 19.52 30000 4.565 Cents Distance Pass - Major Risk Plan: 2K -31 -Plan: 21(-31-2K-31wp05 408.82 2548 40882 18.48 400.00 3.642 Clearance Factor Pass - Major Risk Plan: 2K -33 -Plan: 2K33-2K33W()7 298.40 259.98 298.40 254.66 300.00 48.863 Centre Distance Pass -Major Risk Plan: 21(33 -Plan: 2K-33-2K-33WP07 451.05 261.12 451.05 25363 450.00 34.414 Clearance Factor Pass - Major Risk Ran: 2K-Timbedlne-Plan 2K-TimbedlnePB1-2K-Tim 45822 24.16 458.22 16.22 45000 3.045 Cents Distance Pass - Major Risk Plan: 2K-Timbedine-Plan 2K-TmbedlnePB1-2K-Tina 507.97 24.57 507.97 15.85 500.00 2.822 Clearance Factor Pass - Major Risk Plan: 2K-Tmbedine-Plan: 2K -Timberline -2K -Timber 458.22 24.16 45822 1622 450.00 3.045 Centre Distance Pass - Major Risk Plan: 2K-Tmbedine-Plan: 2K-Tmbedine-2K-Timber 507.97 24.57 507.7 1586 500.00 2.822 Clemente Fedor Pass - Major Risk Rig: 2K -32 -Rig: 21(32-2K-32wp10 299.90 4996 299.00 44.63 300.00 9,375 Cents Distance Pass - Major Risk Rig: 2K -32 -Rig: 2K-32-2K-32wp10 399.28 50.52 39928 43.67 400.00 7.375 Clearance Factor Pass - Major Risk Rig: 2K -32 -Rig: 2K -32 -Rig: 2K-32 248.88 49.19 248.88 4480 250.00 11.214 Centre Distance Pass - Major Risk Rig: 2K -32 -Rig: 2K -32 -Rig: 21(32 323.89 49.61 323.69 43.96 325.00 B.T75 Clearance Fedor Pass - Major Risk 02 May, 2017 - 12:23 Page 5 of a COMPASS Anticollision Report for Plan: 2K-30 - 2K-30wp11 Sumey fool Program From To (usft) (usft) 39.00 2,497.20 2K-30wp11 2,49720 3,315.47 2K-3(Mpl1 2,497.20 3,315.47 21<-30wp11 3,315.47 4,815.47 2K30wp11 3,315.47 11,]1132 2K-30wp11 11,711.32 13,211.32 21<-30wp11 11,711.32 22,521.12 2K-30wp11 Ellipse error teems aro correlated across survey tool tie -on points. Calmlated ellipses incorporate surtax emors. Separation is the actual distance between ellipsoids. Distance Betwean tenths is the straight line distanoe between wellbore canines. Clearance Factor= Distance Between Profiles / (Distance Between Pmfiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method, SumeyMlan Survey Tool GYD-GC-SS MWD MWO-IFR-AK-CAZ-SC MWD MWD«IFR-AK-CAZSC MWD MM+lFR-AK-CPZ-SC 02 May, 2017 - 1223 Page 6 of 8 COMPASS Ladder View 18:85, May 83 3817 Ladder View 2K-30wp11 The Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. a 5 ra 300 -- 0 A a m V) m 150 U 0 m c d U Fwwara M9MIc Msta; 0 1 _r 0 3500 7000 10500 14000 17500 21000 Displayed interval could be less than entire wellhMeasured Depth 39.00 To 22521.54 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.00 2500.00 2K-30wpll (Plan: 2K-30) GYD-GC-SS 116.20 116.20 20" x 42" 2500.00 3313.04 2K-30wpll (Plan: 2K-30) MWD 2844.70 3313.04 10 3/4" x 13-1/2 2500.00 3313.04 2K-30wpll (Plan: 2K-30) MWD+IFR-AK-CAZ-SC 6349.70 11712.78 7-5/8" x 9-7/8" by 11" 3313.04 4813.04 2K-30wpl1 (Plan: 2K-30) MWD 6494.70 22521.54 41/2"x6-3/4" 3313.04 11712.78 2K-30wp11 (Plan: 2K-30) MWD+IFR-AK-CAZ-SC 11712.78 13212.78 2K-30wpl1 (Plan: 2K-30) MWD 11712.78 22521.54 2K -30w p11 (Plan: 2K-30) MWD+IFR-AK-CAZ-SC 5 a 60-- IIIH 11% ZI[IIIII[TIH11111111111 c 0 `m40 a d U T 30 C030- U 0 0 d c m o U Equlvtlenl MagMlc Olabar 0 0 500 1000 1500 2000 2500 3000 3500 Partial Measured Depth TC View y.. 2K-30wpll 39 300 39.00 To 22521.54 1 1 1 I .1 I'1 4 1 MM Emil 131230- 1 •:1 1 1 1 1 11 11 •:1 ':1 1 lm I /4�i/ ♦ ♦ •1 1 1 :1 111,��������•j��$ p �a�1,11,1 ,... vi11,'r.�`j;�'I \,������'8���1'f}�/�< �• /L, �1I�1\I ��►�: /Ii/���,�'`s �L�iR ,�i `wAw�t x'11,\\�„ �A�V� � ,`` ��,_�q� ��IE����I�" �►'���,'�,��„/�.�'� `3 i .�7i� E" � • I17 �'1; ����/'1�1`\�`A: V p ♦p If ���s+1�. ��r I. �af AC Wells Only AC wells ONLY (NOT a SDIder) Kuparuk 2S Pad =a r easnng(3500uswin) Kuparuk 2G Pad d2K 2K-09L1 09L1-01 Kuparuk 2K PaCK-10 2K-23 AC Flipbook 2K-30wpl1 39.00 To 3350.00 MD Azi 39.00 0.00 300.00 0.00 800.00 255.00 1477.61 238.64 158443 23864 3313.04 211.96 333304 211.96 3561.82 21745 1o614.22 217.45 -60 11712.78 190.90 11732.78 190.90 11942.97 190.50 13588.31 190.50 13800.98 197.83 14048.54 201.99 14154.89 2o1.99 14543.97 188.79 - 0 / 2, 14637.05 188.79 22521.54 188.79 -120 Vt 39� a5�� aM1)o ))�)u. ioy.'�a YyN a5m.m ))gw s »�a•.9mrw 94.1 �r as�14 1. w..n a=ups. .w•s.)p' 11 i.o. 0�e:ryn 0/360 )ml M...99 �aw�u MWD wwian.u.uuc -18o/18o 13:14, May o2 2017 39 300 300 490 490 670 670 86o 86o 1040 1040 1230 1230 1410 1410 1600 16o0 2480 2480 3350 3350 4230 4230 5100 5100 598o 5980 6850 6850 7730 7730 8600 8600 10340 10340 1208o 12080 13820 13820 1556o 15560 17300 17300 19040 19040 2078o 20780 22522 2K-30wplt 335o.00 To 11750.00 MD Azi 3900 0.00 300.00 0.00 800.00 255.00 1477.61 238.64 1584.43 238.64 3313.04 211.96 333304 211.96 3561.82 21745 to614.22 217.45 _6 11712.78 190.90 11732.78 190.90 11942.97 190.50 13588.31 190.50 13800.98 197.83 14048.54 201.99 14154.89 201.99 1454397 188.79 - o/ 14637.05 188.79 22521.54 188.79 iPa 0/36o -18o / 18o 13:16, May 02 2017 W 39 300 300 490 490 670 670 86o 860 1040 1040 1230 1230 1410 1410 1600 1600 2480 2480 3350 3350 4230 4230 5100 5100 5980 W, 6850 6850 7730 7730 8600 8600 10340 0/36o -18o / 18o 13:16, May 02 2017 W 39 300 300 490 490 670 670 86o 860 1040 1040 1230 1230 1410 1410 1600 1600 2480 2480 3350 3350 4230 4230 5100 5100 5980 5980 6850 6850 7730 7730 8600 8600 10340 10340 12080 12080 - 13820 13820 15560 1556o 17300 17300 19040 19040 20780 2078o 22522 2K-3owp11 1175o.00 To 22521.54 MD Azi 3900 0.00 300.00 0.00 800.00 255.00 1477.61 238.64 1584.43 238.64 3313.04 211.96 333304 211.96 3561.82 217.45 10614.22 217.45 -6o/ 11712.78 19o.90 11732.78 190.90 11942.97 190.50 13588.31 190.50 13800.98 197.83 14048.54 201.99 14154.89 201.99 1454397 188.79 - 0/27( 14637.05 188.79 22521.54 188.79 -120/ 13:17, May 02 2017 0/360 -18o/18o m 39 300 300 490 rv➢ MO me q, wW)a 1040 1040 1230 ry.w ,3wa aeHgo 33 p.o9 �oyfa�a4�4 2480 Y�'w 6)99Jo 7�,)9 )SIB°29918"Ey�f fm.00 33RW 6999.p nY�39 9 h"+6.3N• 330.09 33Aq 9 �'.'1 �0 .8 0/360 -18o/18o m 39 300 300 490 490 670 67o 860 860 1040 1040 1230 1230 1410 1410 - 1600 1600 2480 2480 3350 3350 - 4230 4230 5100 5100 - 598o 5980 6850 6850 7730 7730 8600 8600 10340 10340 12080 12080 13820 13820 15560 1556o 173oo 17300 19040 19040 2078o 20780 22522 Errors Report ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad Plan: 2K-30 Plan: 2K-30 Plan: 2K-30wp11 Errors Report 02 May, 2017 Errors Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 21K-30 Project: Kupamk River Unit TVD Reference: Plan: 39 + 115.7 @ 154.70usft (Doyon -142) Site: Kuparuk 2K Pad MD Reference: Plan: 39+ 115.7 @ 154.70usft (Doyon142) Well: Plan: 2K-30 North Reference: True Wellbore: Plan: 2K-30 Survey Calculation Method: Minimum Curvature Design: 2K-30wp11 Database: OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: 2,500.00 System Datum: Mean Sea Level Geo Datum: MWD -Standard Using Well Reference Point Map Zone: 3,313.042K-30wp11(PIan: 2K-30) Using geodetic scale factor site Kuparuk 2K Pad 3,313.04 Site Position: Northing: Latitude: MWD - Standard From: Map Easting: Longitude: 11,712.78 2K-30wp11 (Plan: 2K-30) Position Uncertainty: 0.00 usft Slot Radius: W Grid Convergence: -0.02 ° Well Plan: 2K-30 Audit Notes: Well Position +N/ -S 0.00 usft Northing: Latitude: PLAN +E/ -W 0.00 usft Easting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 115.70 usft Wellbore Plan: 2K-30 Magnetics Model Name Sample Date Declination Dip Angle Field Strength V) (') (nT) BGGM2016 6/15/2017 17.45 80.86 57,528 Design 2K-30wpll Date 5/22017 Audit Notes: From Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (TVD) +N/ -S +EI -W Direction (usft) Wait) (usft) (I 39.00 0.00 0.00 190.00 Survey Tool Program Date 5/22017 From To (usft) (usft) Survey (Wellbore) Tool Name Description 39.00 2,500.00 2K-30wp11 (Plan: 2K-30) GYD-GC-SS Gyrodata gyro single shots 2,500.00 3,313.04 2K-30wp11 (Plan: 2K-30) MWD MWD -Standard 2,500.00 3,313.042K-30wp11(PIan: 2K-30) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3,313.04 4,813.04 2K-30wp11 (Plan: 2K-30) MWD MWD - Standard 3,313.04 11,712.78 2K-30wp11 (Plan: 2K-30) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11,712.78 13,212.78 2K-30wpll (Plan: 2K-30) MWD MWD- Standard 11,712.78 22,521.54 2K-30wp11 (Plan: 2K-30) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Hoa. Error (usft) (usft) (•) (°) (usft) (usft)usft ( 1 (usft) 39.00 0.00 0.00 0.00 -115.70 0.00 0.00 0.00 100.00 1.15 0.00 0.00 -54.70 1.15 0.04 0.04 116.20 1.15 0.00 0.00 -38.50 1.15 0.19 0.19 20" x 42" 200.00 1.15 0.00 0.00 45.30 1.15 0.19 0.19 300.00 1.15 0.00 9.90 145.30 1.15 0.33 0.33 400.00 1.15 1.50 135.00 245.29 1.15 0.44 0.44 522017 1:03.42PM Page 2 COMPASS 5000.1 Build 74 Errors Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 2K Pad MD Reference: Well: Plan: 2K-30 North Reference: Wellbore: Plan: 2K-30 Survey Calculation Method: Design: 2K-30wpll Database: Well Plan: 2K-30 Plan: 39+ 115.7 @ 154.70usft (Doyon142) Plan: 39 + 115.7 @ 154.70usft (Doyon142) True Minimum Curvature OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc NDSS Vert. Error Lat Error Hors. Error (usft) (usft) V) (") (waft) (usft) (usft) (usft) 500.00 1.15 3.00 164.31 345.21 1.15 0.53 0.53 600.00 1.15 4.50 163.55 444.99 1.15 0.65 0.64 700.00 1.16 6.00 135.00 544.57 1.15 0.78 0.77 800.00 1.16 7.50 77.26 643.87 1.15 0.92 0.90 900.00 1.17 9.35 77.17 742.79 1.15 1.07 1.04 1,000.00 1.17 11.25 75.87 841.18 1.15 1.23 1.17 1,100.00 1.18 13.18 73.45 938.91 1.15 1.40 1.32 1,200.00 1.20 15.13 71.10 1,035.87 1.15 1.58 1.46 1,300.00 1.21 17.09 69.06 1,131.93 1.16 1.78 1.61 1,400.00 1.23 19.06 67.31 1,227.00 1.16 2.00 1.76 1,477.61 1.25 20.59 66.17 1,300.00 1.17 2.18 1.88 1,500.00 1.25 20.59 65.92 1,320.96 1.17 2.23 1.92 1,584.43 1.26 20.59 64.75 1,400.00 1.19 2.43 2.07 1,600.00 1.26 20.91 64.61 1,414.56 1.20 2.47 2.09 1,700.00 1.30 23.01 63.50 1,507.30 1.22 2.72 2.26 1,800.00 1.35 25.19 62.25 1,598.58 1.25 2.98 2.43 1,900.00 1.41 27.41 60.80 1,688.23 1.28 3.26 2.60 2,000.00 1.48 29.68 59.25 1,776.07 1.33 3.56 2.78 2,100.00 1.56 31.98 57.68 1,861.94 1.39 3.87 2.96 2,200.00 1.65 34.30 56.13 1,945.67 1.46 4.21 3.14 2,300.00 1.76 36.64 54.63 2,027.11 1.55 4.57 3.32 2,400.00 1.88 39.00 53.19 2,106.09 1.65 4.95 3.51 2,500.00 2.01 41.38 51.81 2,182.48 1.78 5.35 3.70 2,600.00 2.17 43.76 51.19 2,256.12 1.82 5.58 3.77 2,700.00 2.31 46.16 49.75 2,326.87 1.83 5.77 3.72 2,800.00 2.46 48.56 47.32 2,394.60 1.86 6.16 3.70 2,900.00 2.61 50.98 44.69 2,459.18 1.92 6.73 3.68 3,000.00 2.75 53.39 42.36 2,520.49 2.01 7.47 3.69 3,100.00 2.90 55.82 40.47 2,578.41 2.13 8.34 3.72 3,200.00 3.05 58.24 38.96 2,632.83 2.28 9.31 3.78 3,300.00 3.21 60.67 37.75 2,683.64 2.46 10.38 3.85 3,313.04 3.20 60.99 44.53 2,690.00 1.94 6.59 3.37 10 3/4" x 13-1/2 3,333.04 3.20 60.99 44.19 2,699.70 1.94 6.66 3.37 3,400.00 3.20 61.85 42.90 2,731.74 1.96 6.97 3.34 3,500.00 3.21 63.16 41.04 2,777.91 2.02 7.62 3.33 3,561.82 3.23 63.99 40.15 2,805.42 2.07 8.12 3.34 3,600.00 3.23 63.99 39.74 2,822.17 2.12 8.44 3.37 3,700.00 3.24 63.99 38.96 2,866.02 2.26 9.32 3.48 3,800.00 3.24 63.99 38.42 2,909.87 2.43 10.31 3.62 3,900.00 3.25 63.99 38.05 2,953.72 2.62 11.38 3.78 4,000.00 3.26 63.99 37.79 2,997.57 2.83 12.50 3.97 4,100.00 3.26 63.99 37.61 3,041.43 3.06 13.66 4.17 4,200.00 3.27 63.99 37.48 3,085.28 3.30 14.86 4.39 4,300.00 3.28 63.99 37.39 3,129.13 3.55 16.08 4.62 5WO17 1:03:42PM Page 3 COMPASS 5000.1 Build 74 Errors Report Company: ConowPhillips(Alaska) Inc.-Kup2 Local Co-ordinate Reference: Project: Kupawk River Unit TVD Reference: Site: Kupawk 2K Pad MD Reference: Well: Plan: 2K-30 North Reference: Wellbore: Plan: 2K-30 Survey Calculation Method: Design: 2K30wpll Database: Well Plan: 2K-30 Plan: 39 + 115.7 @ 154.70usft (Doyonl42) Plan: 39 + 115.7 @ 154.70usft (Doyonl42) True Minimum Curvature OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Let Error Hors. Error (usft) (usft) (°) (°) (usft) (waft) (usft) (usft) 4,400.00 3.28 63.99 37.33 3,172.98 3.80 17.32 4.87 4,500.00 3.29 63.99 37.28 3,216.83 4.07 18.58 5.12 4,600.00 3.30 63.99 37.25 3,260.68 4.33 19.85 5.39 4,700.00 3.31 63.99 37.22 3,304.54 4.60 21.13 5.66 4,800.00 3.31 63.99 37.20 3,348.39 4.88 22.42 5.94 4,900.00 3.32 63.99 38.38 3,392.24 3.13 11.53 4.22 5,000.00 3.33 63.99 38.24 3,436.09 3.25 11.98 4.33 5,100.00 3.33 63.99 38.12 3,479.94 3.38 12.43 4.45 5,200.00 3.34 63.99 38.02 3,523.79 3.50 12.89 4.56 5,300.00 3.35 63.99 37.93 3,567.65 3.63 13.35 4.69 5,400.00 3.36 63.99 37.84 3,611.50 3.76 13.82 4.81 5,500.00 3.37 63.99 37.77 3,655.35 3:90 14.29 4.94 5,600.00 3.38 63.99 37.70 3,699.20 4.03 14.77 5.07 5,700.00 3.39 63.99 37.65 3,743.05 4.17 15.25 5.20 5,800.00 3.40 63.99 37.59 3,786.91 4.30 15.74 5.34 5,900.00 3.41 63.99 37.55 3,830.76 4.44 16.23 5.48 6,000.00 3.42 63.99 37.50 3,874.61 4.58 16.72 5.61 6,100.00 3.43 63.99 37.46 3,918.46 4.72 17.22 5.75 6,200.00 3.44 63.99 37.43 3,962.31 4.86 17.71 5.90 6,300.00 3.45 63.99 37.40 4,006.16 5.00 18.21 6.04 6,400.00 3.46 63.99 37.37 4,050.02 5.15 18.72 6.19 6,500.00 3.47 63.99 37.34 4,093.87 5.29 19.22 6.33 6,600.00 3.48 63.99 37.32 4,137.72 5.43 19.73 6.48 6,700.00 3.49 63.99 37.29 4,181.57 5.58 20.23 6.63 5,800.00 3.50 63.99 37.27 4,225.42 5.72 20.74 6.78 6,900.00 3.51 63.99 37.25 4,269.27 5.87 21.25 6.93 7,000.00 3.52 63.99 37.24 4,313.13 6.01 21.76 7.08 7,100.00 3.53 63.99 37.22 4,356.98 6.16 22.28 7.23 7,200.00 3.54 63.99 37.21 4,400.83 6.30 22.79 7.38 7,300.00 3.56 63.99 37.19 4,444.68 6.45 23.31 7.54 7,400.00 3.57 63.99 37.18 4,488.53 6.60 23.82 7.69 7,500.00 3.58 63.99 37.17 4,532.39 6.74 24.34 7.85 7,600.00 3.59 63.99 37.16 4,576.24 6.89 24.86 8.00 7,700.00 3.60 63.99 37.15 4,620.09 7.04 25.38 8.16 7,800.00 3.62 63.99 37.14 4,663.94 7.19 25.90 8.32 7,900.00 3.63 63.99 37.13 4,707.79 7.34 26.42 8.48 8,000.00 3.64 63.99 37.12 4,751.64 7.48 26.94 8.63 8,100.00 3.65 63.99 37.12 4,795.50 7.63 27.46 B.79 8,200.00 3.66 63.99 37.11 4,839.35 7.78 27.98 8.95 8,300.00 3.68 63.99 37.10 4,883.20 7.93 28.50 9.11 8,400.00 3.69 63.99 37.10 4,927.05 8.08 29.03 9.27 8,500.00 3.70 63.99 37.09 4,970.90 8.23 29.55 9.43 8,600.00 3.72 63.99 37.09 5,014.75 8.38 30.08 9.59 8,700.00 3.73 63.99 37.08 5,058.61 8.53 30.60 9.75 51212017 1:03:42PM Page 4 COMPASS 5000.1 Build 74 Errors Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 2K Pad MD Reference: Well: Plan: 21K-30 North Reference: Wellbore: Plan: 2K-30 Survey Calculation Method: Design: 2K-30wpll Database: Well Plan: 2K-30 Plan: 39+ 115.7 @ 154.70usft (Doyon142) Plan: 39 + 115.7 @ 154.70usft (Doyon142) True Minimum Curvature OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert Error Lat. Emor Horz. Error (usft) (usft) (`) (°) (usft) (usft) (usft) (usft) 8,800.00 3.74 63.99 37.08 5,102.46 8.68 31.13 9.91 8,900.00 3.76 63.99 37.07 5,146.31 8.83 31.65 10.08 9,000.00 3.77 63.99 37.07 5,190.16 8.98 32.18 10.24 9,100.00 3.78 63.99 37.06 5,234.01 9.13 32.70 10.40 9,200.00 3.80 63.99 37.06 5,277.86 9.28 3323 10.56 9,300.00 3.81 63.99 37.06 5,321.72 9.43 33.76 10.72 9,400.00 3.82 63.99 37.05 5,365.57 9.58 34.29 10.89 9,500.00 3.84 63.99 37.05 5,409.42 9.73 34.81 11.05 9,600.00 3.85 63.99 37.05 5,453.27 9.88 35.34 1121 9,700.00 3.87 63.99 37.04 5,497.12 10.03 35.87 11.38 9,800.00 3.88 63.99 37.04 5,540.98 10.18 36.40 11.54 9,900.00 3.89 63.99 37.04 5,584.83 10.33 36.93 11.71 10,000.00 3.91 63.99 37.04 5,628.68 10.49 37.46 11.87 10,100.00 3.92 63.99 37.03 5,672.53 10.64 37.99 12.03 10,200.00 3.94 63.99 37.03 5,716.38 10.79 38.52 12.20 10,300.00 3.95 63.99 37.03 5,760.23 10.94 39.05 12.36 10,400.00 3.97 63.99 37.03 5,804.09 11.09 39.58 12.53 10,500.00 3.98 63.99 37.03 5,847.94 11.24 40.11 12.69 10,600.00 4.00 63.99 37.03 5,891.79 11.39 40.64 12.86 10,614.22 4.00 63.99 37.03 5,898.02 11.42 40.71 12.88 10,700.00 4.34 65.49 37.02 5,934.63 11.55 41.07 12.98 10,800.00 5.29 67.27 36.99 5,974.70 11.70 41.32 13.12 10,900.00 6.60 69.10 36.94 6,011.86 11.85 41.50 13.27 11,000.00 8.09 70.97 36.87 6,046.01 12.01 41.61 13.41 11,100.00 9.67 72.87 36.78 6,077.04 12.17 41.66 13.53 11,200.00 11.31 74.80 36.66 6,104.88 12.34 41.64 13.62 11,300.00 12.97 76.75 36.52 6,129.46 12.50 41.58 13.68 11,400.00 14.63 78.73 36.37 6,150.70 12.67 41.45 13.71 11,500.00 16.29 80.72 36.19 6,168.54 12.84 41.28 13.71 11,600.00 17.93 82.72 35.98 6,182.94 13.01 41.06 13.69 11,700.00 19.55 64.74 35.76 6,193.86 13.18 40.79 13.66 11,712.78 19.75 85.00 35.73 6,195.00 13.20 40.76 13.65 7-518" x 9.718" by 11" 11,732.78 19.81 85.00 35.75 6,196.74 13.20 40.87 13.67 11,800.00 20.03 87.01 35.48 6,201.42 13.20 41.31 13.47 11,900.00 20.34 90.01 35.06 6,204.03 13.21 41.99 13.21 11,942.97 20.46 91.29 34.87 6,203.54 13.22 42.30 13.12 12,000.00 20.47 91.29 34.61 6,202.25 13.24 42.76 13.13 12,100.00 20.47 91.29 34.15 6,199.99 13.27 43.58 13.17 12,200.00 20.47 91.29 33.68 6,197.74 13.31 44.43 13.21 12,300.00 20.48 91.29 33.19 6,195.48 13.36 45.32 13.26 12,400.00 20.48 91.29 32.70 6,193.22 13.43 46.24 13.33 12,500.00 20.48 91.29 32.21 6,190.97 13.50 47.19 13.40 12,600.00 20.49 91.29 31.71 6,188.71 13.58 48.16 13.48 522017 1:03:42PM Page 5 COMPASS 5000.1 Build 74 Errors Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kupamk River Unit TVD Reference: Site: Kupamk 2K Pad MD Reference: Well: Plan: 2K-30 North Reference: Wellbore: Plan: 2K-30 Survey Calculation Method: Design: 2K-30wpll Database: Well Plan: 2K-30 Plan: 39 + 115.7 @ 154.70usft (Doyon142) Plan: 39 + 115.7 @ 154.70usft (Doyon142) True Minimum Curvature OAKEDMP2 SWO17 1:03:42PM Page 6 COMPASS 5000.1 Build 74 D Error Inc Ellipse Inc TVDSS Vert. Error Let Error Hoa. Error (usft) W V) (") (usft) (usft)(usft) (usft) 20.49 91.29 31.22 6,186.45 13.67 49.16 13.57 20.49 91.29 30.73 6,184.19 13.77 50.18 13.67 20.50 91.29 30.25 6,181.94 13.88 51.22 13.79 20.50 91.29 29.77 6,179.68 14.00 52.28 13.90 13,100.00 20.50 91.29 29.29 6,177.42 14.13 53.37 14.03 13,200.00 20.51 91.29 28.83 6,175.17 14.26 54.47 14.17 13,300.00 20.51 91.29 33.41 6,172.91 13.50 44.73 13.39 13,400.00 20.51 91.29 33.24 6,170.65 13.53 45.04 13.43 13,500.00 20.51 91.29 33.06 6,168.40 13.57 45.35 13.47 13,588.31 20.52 91.29 32.89 6,166.40 13.61 45.63 13.51 13,600.00 20.23 91.22 32.88 6,166.15 13.62 45.79 13.52 13,700.00 17.79 90.62 32.78 6,164.54 13.66 47.00 13.61 13,800.00 15.39 90.01 32.69 6,164.00 13.71 48.05 13.71 13,800.98 15.39 90.00 32.69 6,164.00 13.71 48.05 13.71 13,900.00 14.00 86.96 32.63 6,166.63 13.76 48.60 14.03 14,000.00 12.61 83.88 32.60 6,174.62 13.81 49.09 14.35 14,048.54 11.94 82.39 32.58 6,180.42 13.84 49.32 14.49 14,100.00 11.95 82.39 32.55 6,187.23 13.87 4944 1452 14,154.89 11.95 82.39 32.49 6,194.49 13.90 49.61 14.55 14,200.00 13.00 82.79 32.45 6,200.31 13.92 49.48 14.54 14,300.00 15.46 83.70 32.36 6,212.07 13.98 49.05 14.53 14,400.00 18.01 84.63 32.26 6,222.23 14.04 48.46 14.51 14,500.00 20.59 85.58 32.13 6,230.77 14.10 47.72 14.49 14,543.97 21.73 86.00 32.07 6,234.00 14.13 47.35 14.47 14,600.00 21.85 87.96 31.98 6,236.95 14.16 47.52 14.33 14,637.05 21.92 69.26 31.91 6,237.85 14.19 47.64 14.25 14,700.00 21.93 89.26 31.79 6,238.67 14.23 47.85 14.29 14,800.00 21.93 89.26 31.61 6,239.96 14.30 48.19 14.35 14,900.00 21.93 89.26 31.42 6,241.26 14.37 48.53 14.42 15,000.00 21.94 89.26 31.24 6,242.55 14.44 48.88 14.50 15,100.00 21.94 89.26 31.05 6,243.85 14.51 49.23 14.57 15,200.00 21.95 89.26 30.86 6,245.14 14.59 49.59 14.64 15,300.00 21.95 89.26 30.67 6,246.44 14.67 49.95 14.72 15,400.00 21.95 89.26 30.48 6,247.73 14.74 50.31 14.80 15,500.00 21.96 89.26 30.29 6,249.03 14.83 50.68 14.88 15,600.00 21.96 89.26 30.10 6,250.33 14.91 51.05 14.96 15,700.00 21.97 89.26 29.91 6,251.62 14.99 51.42 15.05 15,800.00 21.97 89.26 29.72 6,252.92 15.08 51.80 15.13 15,900.00 21.97 89.26 29.53 6,254.21 15.17 52.19 15.22 16,000.00 21.98 89.26 29.34 6,255.51 15.25 52.57 15.31 16,100.00 21.98 89.26 29.15 6,256.80 15.35 52.96 15.40 16,200.00 21.99 89.26 28.96 6,258.10 15.44 53.36 15.49 16,300.00 21.99 89.26 28.77 6,259.40 15.53 53.75 15.58 16,400.00 21.99 89.26 28.58 6,260.69 15.63 54.15 15.68 SWO17 1:03:42PM Page 6 COMPASS 5000.1 Build 74 Errors Report Company: ConowPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 2K Pad MD Reference: Well: Plan: 21K-30 North Reference: Wellbore: Plan: 2K-30 Survey Calculation Method: Design: 2K-30wpll Database: Well Plan: 2K-30 Plan: 39 + 115.7 @ 154.70usft (Doyon142) Plan: 39 + 115.7 @ 154.70usft (Doyon142) True Minimum Curvature OAKEDMP2 Planned survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Hors. Error (usft) (usft) 1°) 1°I (usft) (usft) (usft) (usft) 16,500.00 22.00 89.26 28.40 6,261.99 15.72 54.56 15.78 16,600.00 22.00 89.26 28.21 6,263.28 15.82 54.96 15.87 16,700.00 22.01 89.26 28.03 6,264.58 15.92 55.37 15.97 16,800.00 22.01 89.26 27.84 6,265.87 16.02 55.78 16.07 16,900.00 22.02 89.26 27.66 6,267.17 16.12 56.20 16.17 17,000.00 22.02 89.26 27.48 6,268.46 16.23 56.62 16.28 17,100.00 22.03 89.26 27.30 6,269.76 16.33 57.04 16.38 17,200.00 22.03 89.26 27.12 6,271.06 16.44 57.46 16.49 17,300.00 22.03 89.26 26.94 6,272.35 16.55 57.89 16.60 17,400.00 22.04 89.26 26.76 6,273.65 16.65 58.32 16.70 17,500.00 22.04 89.26 26.59 6,274.94 16.76 58.75 16.81 17,600.00 22.05 89.26 26.41 6,276.24 16.88 59.18 16.92 17,700.00 22.05 89.26 26.24 6,277.53 16.99 59.62 17.04 17,800.00 22.06 89.26 26.07 6,278.83 17.10 60.06 17.15 17,900.00 22.06 89.26 25.90 6,280.12 17.22 60.50 17.26 18,000.00 22.07 89.26 25.73 6,281.42 17.33 60.94 17.38 18,100.00 22.07 89.26 25.56 6,282.72 17.45 61.39 17.50 18,200.00 22.08 89.26 25.40 6,284.01 17.57 61.84 17.61 18,300.00 22.06 89.26 25.24 6,285.31 17.69 62.29 17.73 18,400.00 22.08 89.26 25.07 6,286.60 17.80 62.74 17.85 18,500.00 22.09 89.26 24.91 6,287.90 17.93 63.20 17.97 18,600.00 22.09 89.26 24.75 6,289.19 18.05 63.65 18.09 18,700.00 22.10 89.26 24.60 6,290.49 18.17 64.11 18.22 18,800.00 22.10 89.26 24.44 6,291.78 18.29 64.57 18.34 18,900.00 22.11 89.26 24.29 6,293.08 18.42 65.03 18.46 19,000.00 22.11 89.26 24.14 6,294.38 18.54 65.50 18.59 19,100.00 22.12 89.26 23.99 6,295.67 18.67 65.96 18.71 19,200.00 22.12 89.26 23.84 6,296.97 18.80 66.43 18.84 19,300.00 22.13 89.26 23.69 6,298.26 18.93 66.90 18.97 19,400.00 22.13 89.26 23.54 6,299.56 19.05 67.37 19.10 19,500.00 22.14 89.26 23.40 6,300.85 19.18 67.84 19.23 19,600.00 22.14 89.26 23.26 6,302.15 19.31 68.32 19.36 19,700.00 22.15 89.26 23.12 6,303.44 19.45 68.79 19.49 19,800.00 22.15 89.26 22.98 6,304.74 19.58 69.27 19.62 19,900.00 22.16 89.26 22.84 6,306.04 19.71 69.75 19.75 20,000.00 22.16 89.26 22.71 6,307.33 19.84 70.23 19.89 20,100.00 22.17 89.26 22.57 6,308.63 19.98 70.71 20.02 20,200.00 22.17 89.26 22.44 6,309.92 20.11 71.20 20.15 20,300.00 22.18 89.26 22.31 6,311.22 20.25 71.68 20.29 20,400.00 22.18 89.26 22.18 6,312.51 20.38 72.17 20.43 20,500.00 22.19 89.26 22.05 6,313.81 20.52 72.65 20.56 20,600.00 22.20 89.26 21.93 6,315.10 20.66 73.14 20.70 20,700.00 22.20 89.26 21.80 6,316.40 20.80 73.63 20.84 20,800.00 22.21 89.26 21.68 6,317.70 20.94 74.13 20.98 51/2017 1:03:42PM Page 7 COMPASS 5000.1 BOild 74 Errors Report Company: Con000Phillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2K-30 Project: Site: Kuparuk River Unit TVD Reference: Plan: 39+ 115.7 @ 154.70usft (Dcyon142) Well: Kuparuk 2K Pad Plan: 2K-30 MD Reference: Plan: 39+115.7@ 154.70usft(Doyon142) Wellbore: Plan: 21K-30 North Reference: True Design: 2K-30wp11 Survey Calculation Method: Minimum Curvature 6,325.47 6,326.77 6,328.06 6,329.36 6,330.65 21.78 27.92 22.07 22.21 22.36 Database: OAKEDMP2 Planned Survey MD (usft) 20,900.00 21,000.00 21,100.00 21,200.00 21,300.00 MD Error (usft) 22.21 22.22 22.22 22.23 22.23 Inc 0 89.26 89.26 89.26 89.26 89.26 Ellipse Inc V) 21.56 21.44 21.32 21.21 21.09 TVDSS (usft) 6,318.99 6,320.29 6,321.58 6,322.88 6,324.17 Vert Error (waft) 21.08 21.22 21.36 21.50 21.64 Lat. Error (usft) 74.62 75.11 75.61 76.10 76.60 Horz. Error (usft) 21.12 21.26 21.40 27.54 21.68 21,400.00 21,500.00 21,600.00 21,700.00 21,800.00 22.24 22.24 22.25 22.25 22.26 89.26 89.26 89.26 89.26 89.26 20.98 20.87 20.76 20.65 20.54 6,325.47 6,326.77 6,328.06 6,329.36 6,330.65 21.78 27.92 22.07 22.21 22.36 77.10 77.60 78.10 78.60 79.10 21.82 21.86 22.11 22.25 22.39 21,900.00 22,000.00 22,100.00 22,200.00 22,300.00 22.27 22.27 22.28 22.28 22.29 89.26 89.26 89.26 89.26 89.26 20.43 20.33 20.22 20.12 20.02 6,331.95 6,333.24 6,334.54 6,335.83 6,337.13 22.50 22.65 22.79 22.94 23.09 79.61 80.11 60.62 81.13 81.63 22.54 22.68 22.83 22.88 23.12 22,400.00 22,500.00 22,521.54 22.29 22.30 22.30 89.26 89.26 89.26 19.92 19.82 19.80 6,338.43 6,339.72 6,340.00 23.23 23.38 23.41 82.14 82.65 82.76 23.27 23.42 23.45 5WO17 1:03:42PM Page e COMPASS 5000.1 Build 74 Company: ConowPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kupamk 2K Pad Well: Plan: 2K-30 Wellbore: Plan: 2K-30 Design: 2K-30wpl l Casing Points Formations Errors Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method; Database: r Well Plan: 2K-30 Plan: 39 1115.7 @ 154.70usft (Doyon -142) Plan: 39 + 115.7 @ 154.70usft (Doyonl42) True Minimum Curvature OAKEDMP2 Measured Vertical Casing Hole Depth Depth (usft) Diameter Diameter (usft) (usft) Name 5,969.70 HRZ 116.20 116.20 20"x42" 20 42 3,313.04 2,844.70 10 3/4" x 13-1/2 10-3/4 13-1/2 11,712.78 6,349.70 7-5/8"x 9-7/8"by 11" 7-5/8 11 22,521.54 6,494.70 41/2"x6-3/4" 4-1/2 6-3/4 Measured Vertical Depth Depth Measured (usft) (usft) Dip Name Litholo9y (°) 2,321.12 2,198.70 WS_Top 10,424.89 5,969.70 HRZ 4,126.39 3,207.70 C-80 8,463.74 5,109.70 C-37 4,290.58 3,279.70 CAMP SST 7,950.64 4,884.70 C40 1,531.02 1,504.70 Base Permafrost 3,115.36 2,741.70 WS Base 11,347.66 6,294.70 KUP_C 10,963.80 6,188.70 K-1 10,737.51 6,104.70 HRZ_BASE 9,754.45 5,675.70 C-35 11,712.78 6,349.70 KUP_A4 11,509.14 6,324.70 KUP_A5 7,266.52 4,584.70 C-50 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +EAW (waft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP: Start 1.5"/100' DLS, 255° TF, for 500' 800.00 798.57 -8.46 -31.56 Start 2°/100' DLS, -25' TF, for 677.61- 1,477.61 1,454.70 -82.25 -176.71 Hold for 106.82' 1,584.43 1,554.70 -101.80 -208.79 Start 2.5°/100' DLS, -35° TF, for 1728.61' 3,313.04 2,844.70 -941.45 -901.60 Hold for 20' 3,333.04 2,854.40 -956.29 -910.86 Start 2.5°/100' DLS, 59.65° TF, for 228.78' 3,561.82 2,960.12 -1,122.91 -1,026.42 Hold for 7052.4' 10,614.22 6,052.72 -6,154.69 -4,880.41 Start 3°/100' DLS, -54.95° TF, for 1098.56' 11,712.78 6,349.70 -7,110.42 -5,295.53 Hold for 20' 11,732.78 6,351.44 -7,129.99 -5,299.29 Start 3°/100' DLS, -3.61° TF, for 210.19' 11,942.97 6,358.24 -7,336.31 -5,338.27 Hold for 1645.34- 13,588.31 6,321.10 -8,953.70 -5,638.00 Start 3.5°/100' DLS, 99.95° TF, for 212.66' 13,800.98 6,318.70 -9,159.74 -5,690.00 Adjust TF to 151.48°, for 247.56' 14,048.54 6,335.12 -9,391.76 -5,774.01 Hold for 106.35' 14,154.89 6,349.19 -9,489.53 -5,813.48 Start 3.5°/l00'DLS, -75.38°TF, for 389.08' 14,543.97 6,388.70 -9,861.87 -5,915.83 Adjust TF to 0', for 93.08' 14,637.05 6,392.55 -9,953.76 -5,930.04 Hold for 7884.49' 22,521.54 6,494.70 -17,744.99 -7,134.78 TD: 22521.54' MD, 6494.7' TVD Checked By: Approved By: Date: 5212017 1:03:42PM Page 9 COMPASS 5000.1 Build 74 Pool Report I 2K-30wp11 Surface Location M CPAI Coordinate From: Datum: NA683 . Region: alaska r Latitude/Longitude IDecimalDegrees (- UTM Zone: r— r South R State Plane Zone: F --]-I Units: Ps—ft--I (' Legal Description (NAD27 only) - To: Datum: NAD27 Region: alaska . r Latitude/Longitude IDecimalDegrees .l r UTM Zone: True r South (: Stale Plane Zone: F----] Units: us ft . r Legal Description (NAD27 only) - Starting Coordinates:---- r- Ending Coordinates: X: 11638342.95 Y: 5937915.25 a. CPAI Coordinate From: - - -- - - - Datum: NAD83 Region: alaska . ( Latitude/Longitude IDecimal Degrees r UTM Zone: i— r South G State Plane Zone: Units: usft . C' L�gnl C-�.ccPlirm (bt'.Du oir49 X: 498310.148586085 Y. 593816519506062 _Transform Quit Help ................ ........... ._....... : - Starting Coordinates:-- --- X: 1638342.95 Y: 15937915.25 To. Datum: NAD27 Region: alaska . r Latitude/Longitude IDecimalDegrees r UTM Zane: True F South r Stale Plane Zone: I" -�-] Units: us -It R Legal Description (NAD27 only) Legal Description-- ------ -.--- Township: 010 FN—,l Range: Iom Meridian: F------] Section: 11 FNL . 138.69118 FEL . 94.405757 Transform .....................................................r QUO Help I Surface M CPA[Coordinate From_—._— Datum: NAD83 Region: alaska ]- r" Latitude/Longitude Decimal Degrees r UTM Zone: r South R State Plane Zone: I" Units: FF:-] r Legal Description (NAD27 only) Datum: NAD27 Region: alaska r Latitude/Longitude Dec -al Degrees f UTM Zone: Tore r South G State Plane Zone: F7-:1 Units: unfit r Legal Description (NAD27 only) Starting Coordmtes:-- ----- FclingCoordinates: - -- X- 11637441.18 x- F497408 —34M5382 Y: 5936974.15 Y: 5937224.13404428 M CPAI Coordinate From:— -- Datum: NAD83 Region: alaska r" Latitude/Longitude D;'— egmes r UTM Zone:I — r South State Plane Zone: I' J Units: —f r' -]nI D�<c iplmr li!D�rr iGln,r 1i 1' �'GC nrilJtil Starting Coordinates: --- X' 1637441.16 Y: 5936974.15 :..._. Quit Help -To:— Datum To: Datum NAD27 Regiore alaska . r Latitude/Longitude Decimal Degrees rUTM Zone: True f South r` State Plane Zone: rqj Units: us -ft I* Legal Description (NAD27 only) LegalDescription--------- Township: 010 FJ] Range: 008 Meridian I" Section:11 FNL 1080.1049 FEL 996.75466 ,TransformQuit Help 2K-30wp11 Intermediate Casing & Production Horizon Q CPA( From: Datum NAD83 Region: alaska r Latitude/Longitude' Decimal Degrees I r UTM Zone: r— r South N State Plane Zone: 14 J Units: usfit . r Legal Description (NAD27 only) r Starling Cowdmates:. -- -- -- -- — _—_ X: 1633046.00 Y: 5930807.D0 M CPA7 Coordinate r. Datum: NAD83 . Region alaska c- Latitude/Longitude Decimal Degrees r UTM Zone: r- r South r: State Plane Zone: Units: us.Ft r Legal Deo ription Ql�.G27 on(gl Starling Coordinates: X 1633046.00 Y: 5930807.00 To: — Datum NAD27 Region alaska r Latitude/Longitude Decimal Degrees C UTM Zone: True r South R State Plane Zane: F----] Units: usft . r' Legal Description (NAD27 only) Ending Coordnat%: - X: 493012.999247049 Y: 5931057.20670675 Transform ...._........._........................................: Quit Help Datum NADP? - Region: alaska . r Latitude/Longitude DecimalDegrees r UTM Zone: True r South r' State Plane Zone: F --]-:J Units: urFt t: Legal Description(NAD27 onty) Township: 010 Range: FO -OS It J Meridian ' Section: 15 FNL 1970.446-7r FEL 1115.56295 _Transform t..Quit Help.......... 11 TD 8 CPAICoordinate From: -- - -.. Datum: NAD83 Region: alaska r Latitude/Longitude Decimal Degrees r UTM Zone: F' r- South F State Plane Zone: 14 -1 Units: utft r Legal Description (NAD27 o..dJJy) - To: - Datum: NAD27 Region: alaska r Latitude/Longitude Decimal Degrees r UTM Zone: True r South (-- State Plane Zone: rq � Units: Fu.-ft-3- r rft.r Legal Description (NAD27 only) IF Starling Cocrdinates: Ending Coordinates: X' 1631204.00 X— 491170.63497392 Y: 5920174.00 ' Y: 5920424.48670067 Transform M CPAI Coordinate From: Datum: NAD83 Region: alaska r Latitude/Longitude Decimal Degrees r UTM Zone: F- r South r State Plane Zone: Units: us -ft r L.�g�i D��_nnvI, l2b1u n;ao1 Starting Coordinates: ------- X 11631204.00 --Y— 5920774.00 Quit I Help To: Datum: NAD27 . Region: alaska . r Latitude/Longitude Decimal Degrees r UTM Zone: True r South r State Plane Zone:ar—_'( Units: us -Ft r Legal Description (NAD27 o,ly)y) Description— Township: 010 I"J Range: Foos— E Meridian:Ij j �I Section: P7 FT-:] 2046.1720 FEL 1963.1076 ( .Transform .......................i Quit Help I 3M, May �" I 2K-30wp11 Quarter Mile View 2K 32, -pia -20000 -16000 -12000 -8000 -4000 0 4000 Of Eff 12000 (+) (4000 usft/in) Tollerable Collision Risk Worksheet As -built 3 15/22/11 MEH I NRB DRAWN PER K140028ACS 4 /21/1 LGM JAH REV. PER K170005ACS l2B N 0- 35 36 w w 31 a 00 rn T11 N a *' Tl ON O 6 2G 2 PROJECT LOCATION 2R [7029 — X 2 \ 11 12 7 .8'\ • 26 VICINITY MAP • 1 1"= 1 MILE 2429 • • 4 NOTES: 1. BASIS OF LOCATION AND ELEVATION IS DS2K 1 • 5 MONUMENTATION PER LOUNSBURY & ASSOC. `� r� 3rX 8 \ \ • 7 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4. N.A.D. 27, AND GEODETIC COORDINATES 034 4 34 ARE NAD 27. �;' • 10 3. ELEVATIONS ARE B.P.M.S.L. �, — - • 11 4. ALL CONDUCTORS ARE LOCATED WITHIN ti =�� • 12 211 PROTRACTED SECTION 2 & 11, TOWNSHIP 10 11 12 NORTH, RANGE 8 EAST, UMIAT MERIDIAN, ALASKA J—.30 \ • 13 S. DATES OF SURVEY: 4/20/17 \ 5.1 \ • 14 6. ALL DISTANCES SHOWN ARE GROUND x1615 3O 16 _ x 17 — — 321a 18 LEGEND • 19 O AS—BUILT CONDUCTOR LOCATION ®32 / • 20 • EXISTING CONDUCTOR LOCATION 5.1' / • 21 X18 / • ?2 X PLUGGED AND ABANDON WELL • 23 • 24 GRAPHIC SCALE 0 75 750 300 DS 2K x 27 1 inch = 150 ft. SEE SHEET 2 & 3 FOR LOCATION LOUNSBURY & ABSOCUTO, INC. " YORS RNGMnS P NNRRS W-1 N MUOULt: XXXX UNIT: 2D ConocoPhillips DS2K WELL CONDUCTORS ASBUILT LOCATIONS GAAlaska, LK621ID14 7/12/01 DRAWING N0. CEA—D2KX-6211D14 PART. 1 OF 3 REV.4 3 I5/22/1M MEH I NRB I (DRAWN PERK140028ACS 14 14/21/171 LGM I JAH I IREV. PER K170005ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 2, T. 10 N., R. 8 E., UMIAT MERIDIAN Well No. NAD 27 ASP Coordinates NAD 27 Geographic Coordinates Section Offset Elev. Y X Lot. Long. F.S.L. F.E.L. O.G. Pad 1 5,938,600.18 498,310.17 70' 14' 36.519" 150' 00' 49.133" 296' 94' 114.0' 118.5' **2 5,938,575.14 498,310.28 70' 14' 36.273" 150' 00' 49.130" 271 94' 113.9' 118.5' 3 5,938,550.30 498,310.35 70' 14' 36.029" 150' 00' 49.128" 246' 94' 113.8' 118.5' 4 5,938,525.46 498,310.06 70' 14' 35,784" 150' 00' 49.136" 222' 94' 113.8' 118.5' 5 5,938,500.19 498,310.12 70' 14' 35.536" 150' 00' 49.134" 196' 94' 113.8' 118.5- 6 5,938,475.14 498,310.33 70' 14' 35.289" 150' 00' 49.128" 171' 94' 113.6' 118.5- 7 5,938,450.36 498,310.36 70' 14' 35.046" 150' 00' 49.127" 146' 94' 113.8' 118.5' **8 5,938,425.30 498,310.18 70' S4' 34.799" 150' 00' 49.132" 121' 94' 113.8' 118.5' 9 5,938,400.30 498,309.98 70' 14' 34.553" 150' 00' 49.137" 96' 94' 113.8' 118.5' 10 5,938,375.19 498,310.14 70' 14' 34.306" 150' 00' 49.133" 71' 94' 113.9' 118.5' 11 5,938,350.22 498,310.14 70' 14' 34.061" 150' 00' 49.133" 46' 94' 113.9' 118.5' 12 5,938,325.20 498,310.17 70' 14' 33.815' 150' 00' 49.131" 21' 94' 113.9' 118.5' 26 5,938,625.14 498,310.10 70' 14' 36.765" 150' 00' 49.135" 321' 94' 114.0' 118.5' 29 5,938,570.32 498,310.59 70' 14' 36.226" 150' 00' 49.121" 266' 94' 113.9' 116.1' 34 5,938,419.98 498,309.81 70' 14' 34.747" 150' 00' 49.143" 116' 94' 113.8' 115.6' * CONDUCTORS ASBUILT THIS SURVEY ** PLUGGED AND ABANDON WELL illips iska. Inc. 7 SURVEYOR'S CERTIFICATE 1 HEREBY CERTIFY THAT 1 AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION ARE CORRECT AS OF APRIL 20, 2017. LOUNSBURY & ASSOCIATES, INC. l4*YONS %NGM m PL N.. MODULE: XXXX UNIT: 2D DS2K WELL CONDUCTORS 2OF3 REV: 2K-30 Drilling Hazards Summary 13-1/2" Hole / 10-3/4" Casing Interval Event Risk Level Mitigation Strate gy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, Additions of Lecithin. Anti -collision High Due to the P&A of 2K-16, 2K-30 is 511 away from 2K -16's existing High ECD and swabbing with higher Low surface location. The well fails anti -collision and requires a TCR. Run MW's required Gyro While Drilling as needed for magnetic interference and to mitigate AC issues. Gravel / Sand Sloughing Low Increase mud weight / viscosity, High viscositysweeps. Monitor fill on connections. Hole Swabbing / Tight Hole on Trips Moderate Circulate hole clean prior to trip. Proper hole fill (use of trip sheets), Pumping out of hole as needed. Lost circulation Moderate Prevent by keeping hole clean. If losses occur - reduce pump rates and Hole cleaning Low mud theology, use LCM Unsuccessful cementiob Moderate Use lower density cement slurry. Due to subsidence— offsite 2K wells Anti -collision High have had to erfortn to 'obs. Use LCM in slu as needed. 9-7/8" x 11" Hole / 7-5/8" Casing Interval Event Risk Level Mitiation Strategy Shale stability Moderate For the unstable HRZ and Kalubik shales with high inclination control MW's required with higher MW and proper tripping practices to avoid surging or swabbing. Minimize pressure cycling by stripping out using MPD to Abnormal Reservoir Pressure Moderate eliminate swab. High ECD and swabbing with higher Low Condition mud prior to trips. Monitor ECD's with PWD tool while MW's required drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Lost circulation Low Use PWD and TAD to monitor hole cleaning. Reduced pump rates, adjust mud rheology, add LCM. Use GKA LCM decision tree. Keep ECD below known frac gradient of —12.0 -12.5 ppg. In event that overburden cannot be strengthened to —12 ppg FG, top setting is back Stuck pipe Moderate up pin for 2K-30. Hole cleaning Low Use PWD and TAD to monitor hole cleaning. Control the ROP and use Hole swabbing on trips Moderate the best hole clewing practice. Anti -collision High Due to the landing area of 2K-30 with regards to 2K-21 A, the well path fails anti -collision. This is due to tool error uncertainty; however, when 2K-30 passes over the top of 2K-21 A, it will be above the Kupamk A4 reservoir and with logging data we will be geologically certain that we will not hit 2K -21A. 2K-30 passes over 2K -21A while it is drilling the Kalubik formation around 11,000' to 11,100' MD. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is higher than expected. BHP of 2K -21A was taken in April at 10.0 ppg EMW. Well has been on production to help aid in drawdown while offset injectors are off. 6-3/4" Hole / 4-1/2" Liner Interval EventRisk Level Mitigation Strategy High ECD and swabbing with higher Moderate Condition mud prior to trips. Monitor ECD's with PWD tool while MW's required drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Utilize MPD to contain any pressure and prevent allowing an influx in the even[ Dressure is higher than expected. Lost Circulation Moderate Use PWD and TAD to monitor hole cleaning. Reduced pump rates, adjust mud rheology, add LCM. Use GKA LC decision tree. Use of MPD will allow lower mud weights to reduce ECD while shutting on connections to revent my potential influx. Stuck pipe Moderate Good hole cleaning, stabilized BHA, proper mud weight to minimize differential stuck, PWD monitor ECD. Hole swabbing on trips Moderate Monitor proper hole fill while tripping, good hole cleaning. Backream out to intermediate shoe, then utilize MPD to strip out and eliminate swab. Well 2K-30 I <== Data — Data --–•a•••�rrar 7U.1fU I<==Data Input Weak point or LOT - INNMeasured depth (ft)16 85.0° <_= Data Input Weak point or LOT True vertical depth (ft)<_= Pmax EMW Data Input Weak point or LOT - Hole angle (deg) M — Data Input Weak point or LOT - Hole size (in) 151' — Data Input Weak point pressure or LOT - EMW (ppg)<_= Data Input Zone of interest - Measured depth (ft) Zone of interest - True vertical depth (ft) Zone of interest - Hole angle (deg) Zone of interest - Hole size (in) Zone of interest - Pore pressure EMW (ppg) 11,713' — Data Input — Data Input — Data Input — Data Input Input 6,350' 85.0° 11.000" 10.00 Pmax EMW Gas gradient (psilft) 0.10 <_= Data Input Max anticipatedtion pressure (psi): Bottom hole assembly OD (in) Bottom hole assembly length (ft) Drill pipe OD (in) 8.0" <_= Data Input <_= Data Input <== Data Input 151' 5.000'• BHA annular vol. @ zone of interest (bbl/ft) DP annular vol. @ zone of interest (bbl/ft) DP annular vol. @ weak point (bbl/ft) 0.0554 0.0933 0,1528 Weak point pressure (psi): Plo 1,923 psi ure-Safety margin: Weak point!9,n Pmax 1,923 psi Pmax EMW 13.00 pp Max anticipatedtion pressure (psi): Pf 3,302 psi Weak Pt to Zone of st distance (ND ft): OH( ND} 3,505' Weak Pt to Zone ofst distance (MD ft): OH (MD) $,400' Maximum influx het the bit (ND ft): H (TVD) 1,277' Maximum influx hat the bit (MD ft): H (MD} 14,656' Calc. voof {H}around BHA: Calc. volum} around drill pipe: Vlbha Vldp 8.4 bbl 1352.7 bb! Calc. volume that Hls initial shut in; V1 1361.1 bbl Calc. vol. that H equweak point (MD ft): VWp 390.2 bbl Calc. volumep @ initial shut in: V2 227 hhl Tolerance: V2 227.3 TRANSMITTAL LETTER CHECKLIST WELL NAME: K �� K b PTD: S2 / � - z " Development _ Service _ Exploratory _ Stratigraphic Test Non -Conventional FIELD: 211 POOL: L/6 iC 4 iV6T Check Boa 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. (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 rmit). 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 throw 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. (Com an 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 da s after com letion, sus ension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL -490100 _ Well Name: KUPARUK RIV UNi7 2K-30 _ ._ _ Program DEV _ Well bore seg ❑ PTD#:2170720 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV / PEND GeoArea 890 Unit 11160 On/Off Shore 9a Annular Disposal ❑ r Administration 17 Nonconven. gas conforms to AS31.059300. 1.A),(J,2.A-D) . _ _ NA 1 Permit fee attached _ _ _ _ _ _ _ _ _ ... _ NA 2 Lease number appropriate..... _ _ _ _ _ _ _ _ _ Yes 3 Unique well. name and number _ _ _ _ Yes 4 Well located in. a defined. pool _ _ _ -_ _ _ _ _ Yes 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 PKB 5/5/2017 13 Can permit be approved before 15 -day wait _ Yes 14 Well located within area and strata authorized by Injection Order # (put. 1O# in comments) (For NA 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 Engineering 19 Surface casing. protects all known USOWs Yes 20 CMT vot adequate to circulate. on conductor & surf csg Yes 21 CMT vol adequate to tie-in long string to. surf csg_ Yes 22 CMT will cover all known. productive horizons No 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes 25 If a re -drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes 27 If diverter required, does it meet regulations. Yes Appr Date 28 Drilling fluid program schematic & equip list. adequate Yes VTL 5/30/2017 29 BOPEs, do they meet regulation _ Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes 31 Choke. manifold complies w/API RP -53 (May 84) Yes 32 Work will occur without operation shutdown.. Yes 33 Is presence of 1-12S gas probable Yes 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No Geology 36 Data presented on potential overpressure zones Yes Appr Date 37 Seismic analysis of shallow gas. zones NA. PKB 5/5/2017 38 Seabed condition survey (if off -shore) _ _ _ NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Geologic Engineering Public Commissioner: Date: Commissioner: Date G o Public Date I, it-. ADL0025588, Surf;ADL0025605, Portion of; ADL0025604, Top Prod; ADL025607, TD, KRU 2K-30 KUPARUK RIVER,. KUPARUK. RIV OIL.- 4901.00,. governed. by Conservation Order No, 432D.. CO 432D contains no spacing restrictions with respect to drilling unit boundaries. - CO 432D has no interwell spacing restrictions, _ Wellbore. will be more than 500' from an external property line where ownership or landownership changes. 140' driven conductor set to 3313' MD 147%. excess cement Productive interval will be completed with swell packers and frac sleeves Rig has steel tanks; all waste to approved disposal wells Anti -collision analysis complete; Major risk failures 2K-16 is P&Nd; 2K-21. will be SI while drilling Diverter meets regulations Max formation pressure is 3142 psig(10.0 ppg. EMW ),, will drill w/ 8,6-11.0. ppg EMW MPSP is 2507 psig; will test BOPs to 3500 psig 1-12S measures required Wells.on 2K -Pad are H2S-bearing. H2$ measures required. Max. potential reservoir pressure is 10.0 ppg. EMW; will be drilled with 8.6 to 11.0 ppg mud. Onshore development well to be drilled.
