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215-219
• • .2�� - 2r� ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 September 24, 2017 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 r�, Commissioner Cathy Foerster: 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. Sin rely, Roger Winter ConocoPhillips Well Integrity Field Supervisor 3 0 • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 9/25/2017 2S pad Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor! Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 2S-05 501032073900 216-039-0 22" 0.05 11" 6/7/2017 1.7 9/10/2017 2S-06 501032074700 216-085-0 4' 0.25 15" 6/10/2017 3.4 9/10/2017 2S-07 501032071300 215-079-0 22" 0.16 11" 6/7/2017 3.4 9/10/2017 2S-08 501032072200 215-174-0 17" 0.10 13" 6/7/2017 3.4 9/10/2017 2S-09A 501032074901 216-128-0 39" 0.30 12" 6/10/2017 4.25 9/20/2017 7 2S-10 501032071700 215-110-0 10' 1.50 9" 6/10/2017 1.7 9/10/2017 2S-11 501032073200 215-219-0 20" 0.10 10" 6/7/2017 3.4 9/10/2017 2S-12 501032074300 216-074-0 25" 0.10 13" 6/7/2017 4.8 9/10/2017 2S-13A 501032072001 216-104-0 30" 0.40 9" 6/7/2017 3.4 9/10/2017 2S-14 501032073300 215-220-0 27" 0.24 12" 6/7/2017 3.9 9/10/2017 27 5 09 STATE OF ALASKA ALO/A OIL AND GAS CONSERVATION COMM ION 2 7 5 4 6 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations Fracture Stimulate F Pull Tubing E Operations Shutdown Performed: Suspend E Perforate E Other Stimulate n Alter Casing E Change Approved Program Plug for Redrill E Perforate New Pool 1 Repair Well E Re-enter Susp Well 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory fl 215-219-0 _ 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-103-20732-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25590,ADL 25603 KRU 2S-11 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 15300 feet Plugs(measured) None true vertical 6265 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 8206,8299 true vertical 0 feet (true vertical) 6101, 6337 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 120 120 SURFACE 2819 10 3/4 2859 2574 INTERMEDIATE 8446 7 5/8 8485 LINER 7001 41/2 15300 6265 R -, IVED `" ' . Perforation depth: Measured depth: 0scam FEB 1201 JUN 0 3 2016 True Vertical Depth: 0 2v 4/ Tubing(size,grade,MD,and TVD) 4.5, L-80, 8305 MD,6140 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER PREMIER PRODUCTION PACKER @ 8206 MD and 6101 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9327-15152 Treatment descriptions including volumes used and final pressure: Total Well- 10 stages 1,001,300#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 0 0 0 0 0 Subsequent to operation 7000 4400 600 1600 567 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory r Development F Service [ Stratigraphic E' Copies of Logs and Surveys Run E ao 16.Well Status after work: Oil F Gas E WDSPL Printed and Electronic Fracture Stimulation Data P✓ GSTOR r WINJ E WAG E GINJ E SUSP fl SPLUG E 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-223 _ Contact Adam Klem a 263-4529 Email Adam.Klem@conocophillips.com Printed Name Adam Klem Title Completions Engineer Signature Phone:263-4529 ✓�V//6 VTL I /il)1 91 4 Form 10-404 Revised 5/2015 'hl et/7//C RBDMS JUN 0 6 2016 Submit Original Only ZS - Il 99 Y Ha ert -Sherrod, Ann (Northland Staffing Services) From: Klem,Adam Sent: Tuesday, May 03, 2016 9:32 AM To: Haggerty-Sherrod,Ann (Northland Staffing Services) Subject: FW: [EXTERNAL]RE: KRU 2S-11(PTD 215-219) Frac Sundry 316-223 Can you include this with the approved sundry? From: Loepp,Victoria T(DOA) <victoria.loepp@alaska.gov> Sent:Tuesday, May 3, 2016 11:59:59 AM To: Klem,Adam Cc:Wallace,Chris D (DOA) Subject: [EXTERNAL]RE: KRU 2S-11(PTD 215-219) Frac Sundry 316-223 Adam, Approval is granted to pump the LVT-200 during pad stages as a frac additive as outlined below. Please include this approval with your approved sundry. 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.Loepix ialaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at (907)793-1247 or Victoria.Loeor@alaska.gov From: Klem, Adam [mailto:Adam.Klem@conocophillips.com] Sent:Tuesday, May 03, 2016 8:54 AM To: Loepp, Victoria T(DOA) Cc: Wallace, Chris D (DOA) Subject: KRU 2S-11(PTD 215-219) Frac Sundry 316-223 Well: KRU 2S-11 PTD: 215-219 10-404 Frac Sundry: 316-223 Victoria, Due to a few issues on this well,we are looking to pump LVT-200 during our pad stages of the remaining four stages to frac.We are currently performing fluid rheology tests to determine the concentration to pump at, but we are planning on^3%volume during pad only.This should work out to "150-200bbls or so for all remaining stages. LVT-200 is on the sundry, but only as freeze protect, not as a frac additive. I just talked with Chris,and said I will need to add it in as an additive on the frac focus submission. 1 He informed me that the AOGCC has the on file.The rates and pressures of the jfkill not change.The post job report will include all changes to the frac fluid comp ition. We are hoping to continue pumping tomorrow since the water is on location and heated. Let me know if there is anything else you need from me, and if not,can we get permission to proceed with pumping LVT-200 during our pad stages as a frac additive? Thanks, Adam Klem Senior Completions Engineer Greater Kuparuk Area ConocoPhillips Alaska 700 G St ATO 1410 Anchorage,AK 99510 907-263-4529 Office 970-317-0300 Cell Adam.Klem@conocophillips.com 2 • 2S-11 • DTTM JOBTYP SUMMARYOPS START 4/20/16 FRACTURING VLV CREW REMOVE BPV. SET BAITED P/T ON BALL N' ROD @ 8232' RKB. PULLED SOV&SET DV @ 8113' RKB. IN PROGRESS. 4/21/16 FRACTURING MITIA TO 4000 PSI ( PASS) MITT TO 5000 PSI ( PASS) PULLED BALL N' ROD/ RHC PLUG BODY @ 8232' RKB. WELL READY FOR ALPHA SLEEVE SHEAR& FRAC. 4/23/16 FRACTURING SHEAR OPEN ALPHA SLEEVE WITH 6233PSI. PUMP MINIFRAC AND FIRST FIVE STAGES OF FRAC WITH 548,500# 16/20 CARBOLITE. SCREENED OUT DURING 4PPA STAGE OF FIFTH FRAC STAGE. PLACED APPROX 22,500#PROPPANT OF 125,000#DESIGNED FOR STAGE 5. 4/25/16 FRACTURING B&C CTU #1: PERFORM FILL CLEAN OUT, JETTING FROM SURFACE TO FRAC SLEEVE#4 AT 12309'WITH SLICK SEA WATER AND FLOVIS GEL. MAINTAIN 1:1 RETURNS THROUGHOUT WITH LIGHT- MEDIUM SAND RETURNS. WILL RETURN IN THE MORNING TO SHIFT OPEN FRAC SLEEVE#5 AT 11249'. 4/26/16 FRACTURING B&C CTU#1: SHIFT FRAC SLEEVE#5 OPEN AT 11,249'WITH 3.125"SIDE JET SHIFTING NOZZLE. SLEEVE SHIFTS AT 1600 PSI OVER INJECTION PRESSURE WITH NOZZLE ON SEAT. INJECTION PRESSURE 2900 PSI AT 2 BPM BEFORE AND 2500 PSI AFTER. RIG DOWN, MOVE OFF COIL UNIT. 4/29/16 FRACTURING ESTABLISH INJECTION. DROP 3.125"AND BEGIN PUMP STAGE#6. CUT 6PPA STAGE SHORT AND WENT TO FLUSH DUE TO INCREASING TREATING PRESSURES. DROPPED 3.25" FRAC BALL AND DISPLACE. SCREENED OUT -40BBLS SHORT OF BALL SEATING. MULTIPLE ATTEMPTS TO ESTABLISH INJECTION FAILED. 5/1/16 FRACTURING B&C CTU#1: PERFORM WEEKLY BOP TEST ON BACK DECK. CLEAN OUT LIGHT FRAC SAND FROM 2500'TO FRAC SLEEVE#6 AT 10728'WITH SLICK SEA WATER, FLOVIS GEL, AND 3.25" BALL DROP SHIFTING NOZZLE. MAINTAIN 1:1 RETURNS THROUGHOUT. AFTER FINAL BOTTOMS UP, PRESSURE UP WELL AND UNABLE TO SHIFT SLEEVE WITH DISOLVING FRAC BALL. PUMP 1/2 BALL DOWN COIL TO ISOLATE 3.25" SHIFTING NOZZLE DOWN JETS. WITH 1/2" NOZZLE BALL ON SEAT, STACK 25K#DOWN ON SLEEVE WITH SHIFTING NOZZLE. PRESSURE UP WELL DOWN COIL AND SLEEVE SHIFTS AT 3500 PSI WHP. INJECT 3 BPM AT 2100 PSI DOWN BACKSIDE OF COIL AFTER. RIG DOWN MOVE OFF COIL. 5/4/16 FRACTURING ESTABLISH INJECTION. DROP 3.25"AND BEGIN PUMP STAGE#7. PUMP STAGES 7-10. PLACED 363,700#OF DESIGNED 386,000#OR 94% OF DESIGN PROPPANT. SD AND BEGIN RDMO. 5/5/16 FRACTURING BRUSH & FLUSH TBG; SET 3.81" DBP PLUG W/SINGLE SPARTEK GAUGE @ 8232' RKB. MITT& DDT(PASS); PULLED DV @ 4285' RKB. READY FOR DHD. 5/7/16 ANNCOMM (SEC)TEST BPV-PASSED; T POT- PASSED; T PPPOT- PASSED; IC POT- PASSED; IC PPPOT- PASSED; INTERMEDIATE POT- PASSED; INTERMEDIATE PPPOT- FAILED. 5/8/16 DRILLING TREE SHELL TEST 4650 PSI PASSED WITH NO EXTERNAL LEAKS 5/10/16 DRILLING SET ST. # 1 GLV. @ 4285' RKB. REPLACED DV W/NEW DV @ ST. #2 @ 7760' SUPPORT- RKB. PULLED D.V./SET O.V. @ ST. #3 @ 8113' RKB. T x IA TRACKING. JOB IN CAPITAL PROGRESS. 5/11/16 DRILLING RAN D&D HOLE FINDER, GOOD TEST ABOVE STN# 1. REPLACED GLV @ 4285' SUPPORT- RKB & DV @ 7760' RKB. T x IA STILL TRACKING. JOB IN PROGRESS. CAPITAL 5/12/16 DRILLING REPLACED OV @ 8113' RKB. SOLID PRESSURE TEST ON TBG. PULLED BAIT SUPPORT- SUB & PRONG @ 8232' RKB. PULLED 3.81" DB LOCK&GAUGES @ 8232' RKB CAPITAL (3701 PSI) ( PERFORMED 15 MINUTE GRADENT STOP @ 8132' RKB. JOB COMPLETE. • s Hydraulic Fracturing Fluid Product Component Information Disclosure Job Start Date: 4/23/2016 Job End Date: 5/4/2016 State: Alaska -.i County: Harrison Bay 1O S API Number: 50-103-20732-00-00 Operator Name: ConocoPhillips Company/Burlington Chemical Disclosure Registry Resources Well Name and Number: 2S-11 Longitude: -150.15625300CRC.X.,,N[MATER Latitude: 70.21953200 "" Datum: NAD83 Federal/Tribal Well: NO True Vertical Depth: 6,264 Total Base Water Volume(gal): 735,363 Total Base Non Water Volume: 0 Hydraulic Fracturing Fluid Composition: Chemical Maximum Maximum Abstract Service Ingredient Ingredient Trade Name Supplier Purpose Ingredients Number oncentration in oncentration in Comments (CAS#) Additive HF Fluid (%by mass)" (%by mass)" .ea Water •perator :ase Fluid A A 100.0000: 84.5509 •ensity=8.560 arboLite 16/20 arboCeramics •roppant A A :E-6 MICROBIOCIDE, alliburton additive,Biocide, L-22 UC,CL-31 :reaker,Crosslinker, ROSSLINKER, elling Agent, OSURF-300D,MO- icrobiocide,Non- .7,OPTIFLO-II onic Surfactant,pH •ELAYED RELEASE ontrol Additive :REAKER,OPTIFLO- II DELAYED 'ELEASE BREAKER, .P BREAKER,WG-36 ELLING AGENT A A .SA-1 alliburton •roppant A A VT-200 .enreco additive A A Fingredients shown Alive are subject to 29 CrlFZ�1410.1200(6111111111nn Material Safety Data Sheets(NMSDS).Ingredients sho7 below are Non-MSD • 0 -lazardous and Non- -lazardous Ingredients Ceramic Materials and wares, 66402-68-4 100.00000 13.44957 chemicals Hydrotreated Distillate,Light..C9 64742-47-8 100.00000 1.18897 6 .Y t'(j -16 Guar gum 9000-30-0 100.00000 0.33287 Water 7732-18-5 100.00000 0.17264 Crystalline silica,quartz 14808-60-7 100.00000 0.12092 Borate salts Confidential 60.00000 0.06496 Potassium formate 590-29-4 60.00000 0.06496 Ethanol 64-17-5 60.00000 0.04079 Sodium hydroxide 1310-73-2 30.00000 0.03252 Potassium metaborate 13709-94-9 60.00000 0.03174 Oxyalkylated phenolic resin Confidential 30.00000 0.02719 Ammonium persulfate 7727-54-0 100.00000 0.02165 Heavy aromatic petroleum '64742-94-5 30.00000 0.02039 naphtha Bentonite,benzyl(hydrogenated 121888-68-4 5.00000 0.01664 tallow alkyl)dimethylammonium stearate complex Surfactant mixture 'Confidential 1.00000 0.00666 Cured acrylic resin Confidential 30.00000 0.0065C Poly(oxy-1,2-ethanediyl),alpha-127087-87-0 5.00000 0.00340 (4-nonylphenyl)-omega- hydroxy-,branched Naphthalene 91-20-3 5.00000 0.00340 Silica gel 112926-00-8 1.00000 0.00333 Potassium hydroxide 1310-58-3 5.00000 0.00265 2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00000 0.00258 Sodium chloride 7647-14-5 1.00000 0.00217 Sodium carboxymethyl cellulose 9004-32-4 1.00000 0.00108 Acrylate polymer Confidential 1.00000 0.00108Denise Tuck,Halliburton, 3000 N.Sam Houston Pkwy E., Houston,TX 77032,281- 871-6226 Sodium glycollate 2836-32-0 1.00000 0.00108 Sodium persulfate 7775-27-1 100.00000 0.00101 12,4 Trimethylbenzene 95-63-6 1.00000 0.00068 Crystalline Silica,Quartz 14808-60-7 0.10000 0.00033 Sodium sulfate 7757-82-6 0.10000 0.00000 *Total Water Volume sources may include fresh water,produced water,and/or recycled water **Information is based on the maximum potential for concentration and thus the total may be over 100% 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) KUP PD 2S-11 ConocoPhillips 9 , Well Attribute Max Angle TD Aaska.lnit ,„ --Wel(boreAPIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) CcxroccAhidli, '' 501032073200 KUPARUK RIVER UNIT PROD 95.47 12,143.18 15,300.0 -.- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 20-11,642/2016 7:29.57 AM SSSV. NONE Last WO: 39.65 4/2/2016 vertcal 5chematc(99110(1 Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,36.8 -- -' Last Tag. Rev Reason: PULLED RHC PLUG,GLV C/O pproven 5/15/2016 ■ s, Casing Strings Casing Description CONDUCTOR OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 4/6 16 15.250 40.8 119.8 119.8 62.50 H-40 Welded Lasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR;40.B-119.8 SURFACE 10 3/4 9.950 40.6 2,859.2 2,573.7 45.50 L-80 TSH 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread _. . INTERMEDIATE 75/8 6.875 39.3 8,485.3 6,193.2 29.70 L-80 Hyd 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER 4 1/2 3.958 8,299.2 15,300.0 6,264.7 12.60 L-80 Hyd 563 Liner Details I 1 Nominal ID l Top(MB) Top(TVD)(ftKB) Top Ind(*) Item Des Com (in) SUR FACE 40 6-2853 2-. 8,299.2 6,137.6 : 68.98 PACKER Baker HRD-E ZXP 5.5"x 7.63"Flex-Lock Liner top 4.810 packer L-80 Hyd 521 pin GAS L,Fi,42649 . I 2! 8,323.9 6,146.3 69.97 NIPPLE Baker 5.5""RS"Packoff Seal Nipple 17#L-80 4.250 # I 1 Hyd 563 box box 11 It 8,326.3 6,147.1 70.07 Hanger Baker 5.5"x 7.63"Flex-Lock Liner hanger P110 4.840 GAS LIFT;7,759.4AWE, Hyd 563 pin x pin 8,336.1 6,150.4 70.46 XO Reducing 5.5"Hyd 563 15.5#box 4.5"12.68 H563 pin 3.910 GAS LIFT;8,112.4 : Crossover Bushing 111. 9,105.9 6,307.3 8635 SWELL Baker-"Swell Packer-"K" SN:50494-001-8 3.958 Gauge,8,180.7 _ PACKER MI PACKER;8,205.8 9,327.2 6,310.7 90.76 FRAC PORT Baker 4-1/2"Frac Sleeve#9-(3.625"Ball,Drift w/ 3.625 NIPPLE,8,231.9 -*P1'.' - 3.50")PN:10437063 9,543.8 6,305.4 91.16 SWELL Baker-"Swell Packer"-"J" SN:50494-001-9 3.958 � PACKER LOCATOR;8,294.7 LOCATOR;8,295.7 9,807.9 6,303.8 89.37 FRAC PORT Baker 4-1/2"Frac Sleeve#8-(3.50"Ball,Drift w/ 3.400 1111 1 3.375")PN:H810-08-0393 SHOE;8,304.0 10,065.1 6,307.5 89.68 SWELL Baker-"Swell Packer'-"I" SN:50494-001-16 3.900 PACKER ly 10,288.1 6,306.3 90.61 FRAC PORT Baker 4-1/2"Frac Sleeve#7-(3.375"Ball,Drift w/ 3.275 3.25")PN:H810-08-0394 ,IF 118 10,503.4 6,302.3 90.93 SWELL Baker-"Swell Packer"-"H" SN:50494-001-12 3.900 PACKER I � r 10,727.7 6,301.7 90.11 FRAC PORT Baker 4-1/2"Frac Sleeve#6-(3.25"Ball,Drift w/ 3.150 INTERMEDIATE,39.2-8,485.3 1 3.125") PN:H810-08-0395 !" 10,985.4 6,303.3 88.23 SWELL Baker-"Swell Packer'-"G" SN:50494-001-7 3.900 PACKER j��I, 11,248.6 6,324.9 83.52 FRAC PORT Baker 4-1/2"Frac Sleeve#5-(3.125"Ball,Drift w/ 3.025 � 3.00")PN:H810-08-0396 11,506.2 6,351.9 84.08 SWELL Baker-"Swell Packer"-"F" SN:50494-001-1 3.900 PACKER 12,005.4 6,347.9 94.85 SWELL Baker-"Swell Packer"-"E" SN:50494-001-2 3.890 I PACKER Hyd Frac-Ge ledwate0 12,308.9 6,327.2 92.45 9.3270 FRAC PORT Baker 4-1/2"Frac Sleeve#4-(3.00"Ball,Drift w/ 2.900 1.1 2.875")PN:H810-08-0397 12,686.6 6,311.0 90.06 SWELL Baker-"Swell Packer"-"D" SN:50494-001-29 3.958 I I PACKER 13,110.9 6,320.4 89.58 FRAC PORT Baker 4-1/2"Frac Sleeve#3-(2.875"Ball,Drift w/ 2.775 2.75")PN:H810-08-0398 13,448.8 6,320.1 90.54 SWELL Baker-"Swell Packer"-"C" SN:50494-001-13 3.900 PACKER I 13,792.3 6,304.7 93.88 FRAC PORT Baker 4-1/2"Frac Sleeve#2-(2.75'1E411,Drift w/ 2.650 2.625")PN:H810-08-0399 14,127.2 6,291.5 91.78 SWELL Baker-"Swell Packer'-"B" SN:50494-001-10 3.910 PACKER Hyd Frac-Gelledvater,10,985.01 4,470.2 14,470.2 6,275.8 92.87 FRAC PORT Baker 4-1/2"Frac Sleeve#1-(2.625"Ball,Drift w/ 2.525 11 7 2.50")PN:H810-08-0400 14,808.7 6,267.5 90.39 SWELL Baker-"Swell Packer"-"A" SN:50494-001-5 9.900 _ .... PACKER ■ 15,152.5 6,266.4 90.60 SLEEVE Baker 4-1/2"Alpha Sleeve,4877 psi, PN 10487898 3.000 15,165.6 6,266.2 90.61 SLEEVE Baker 4-1/2"Wellbore Isolation Valve(WIV)PN H809 -89-0011 11 11 15,217.1 6,265.7 90.67 COLLAR 4-1/2"Weatherford Model 402E Float collar IBT 3.958 II Tubing Strings Tubing Description Mn...ID(in) Top(ftKB) set Depth Ift..Set Depth(TVD)(...Wt(15/ft) Grade Top Connection 11 TUBING 1String 4 1/21 3.9601 36.81 8,305 01 6,139 71 12.601L-80 IBT-M ICompletion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 36.8 36.8 0.08 HANGER Cameron 11"x 4-1/2"Tubing Hanger 3.900 Hyd Frac-Gelledwater;12.308.0 8,180.7 6,091.1 65.09 Gauge Schlumberger Gauge Carrier(measured w/collar on top) 3.958 II8,205.8 6,101.5 65.81 PACKER Baker Premier Production Packer 3.640 I 8,231.9 6,112.0 66.56 NIPPLE Camco 3.812 DB-6 nipple(3.812")w/RHC plug body(65 3.812 deg) i 1F 8,294.7 6,136.0 68.79 LOCATOR Baker 7.625"x 4.5"Shear pinned Fluted No-Go Sub- 3.950 Large OD- 8,295.8 6,136.4 68.84 LOCATOR Baker 7.625"x 4.5"Shear pinned Fluted No-Go Sub- 3.950 small OD- 8,304.0 6,139.3 69.17 SHOE Mule shoe WLEG 3.910 NEM ) 0 0 LINER;8,2s4.2-15,3C 051 t KUP aD • 2S-11 mining Conocolhillips Alaska.Inc,. CanocoMM0p4 --- 2S-11,6/2/2016 7 29 57 AM Vertmal soh3-11139(0"80 • HANGER;368—� -. Stimulations&Treatments Min Top Max Btm Depth Depth Top(TVD) Btm(TVD) (ftKB) (ftKB) (ftKB) (ORB) Type Date Com CONDUCTOR;40.8-118.8 9,327.0 10,727.0 6,310.7 6,301.7 Hyd Frac- 5/3/2016 Stage 7:86.6klbs,Stage 8:96.8klbs,Stage 9: Gelledwater 97.1klbs,Stage 10:83.2klbs 10,985.0 11,506.0 6,303.3 6,351.9 Hyd Frac- 4/29/2016 Stage 6:88.1klbs Gelledwater 12,308.0 15,152.0 6,327.2 6,266.4 Hyd Frac- 4/23/2016 Stage 1:127klbs,Stage 2:125klbs,Stage 3:125kibs, Gelledwater Stage 4:123.5klbs,Stage 5:48.5kibs Mandrel Inserts st SURFACE;40.8-2,858.2—. ati on Top(TVD) Valve Latch Port Size TRO Run GAS LIFT;4,284.9 N Top(ftKB) (ORB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Com ,11 1 4,284.9 3,515.2 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,999.0 5/12/2016 2 7,759.5 5,887.6 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/11/2016 GAS LIFT;7,759.43 8,112.4 6,061.5 Camco KBMG 1 GAS LIFT OV BK 0.313 0.0 5/12/2016 GAS LIFT;8,112.4 -.��,. Gauge;8,180.7 PACKER;8,205.8 NIPPLE;8,231 9 LOCATOR;8,294.7 LOCATOR;8,295.7 SHOE,8,304.0 x o'! INTERMEDIATE;39.2-8.4853 Hyd Frac-Gelledwater;0327 0 1 _ 1 r If Hyd Frac-Gelledwater;10,985.0 � 1 III I _1 Hyd Frac-Gelledwater,12,308.0 L_.�.. • [ i raw cti LINER;8,299.2-15,300.0- t • • O , c o d , CV • Cl o a) a) a) a) O Z C0 ch ch ch 6 r co r r r .c ...7 •Z � Cl• U_ I'. N '0 N� N CV u)N N�N N N co N N (n (n (n (n cd NI i� @ m m m •b c > co (I) (10 ao ao ao O < < < c O o 0 Z co 0 N U O U O U o U o U 0 0 U c N ( - Co— H Z ai❑ ai❑ ai❑ ai❑ ai ai rn ai air > 5 5 5 z z E � E . EE . 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E E I Z aai w I W m E o cc; co O a i m o 0 6 c G f`') ) z F C C 4 Z C m O p p Q O O Q O a w U « 0 0 0 0 0 0 O 0 0 0 ! '- N 'v rn J .� N •Q E C) O a v' 0 a ami 0 p 0 a 0 0 0 0 0 0 0 0 0 a) a o 2 aa)) 0 E a) d ¢ D a m LU LU w w w w LU w LU w 3 ? 0 a 0 1 0 0CC 0 11 I0 9 0 O N 9 vi N 0 M O o Z 1 ti N T 0n 0_ b o 5 , co 6 H N Z I07O. I J_ V Z 1 w N co I 10 O N ` O. CL n J W = Le a O W 0z C..) �°, o Z t> < N y w J Q w a � o � 0 O `V a o U o J Q s- cb baa - N I— F" 0 Z p N • CO 1 m re M v+ cc d co0 I k' Q o Q d Q z E p A I z a) • 0 1 CON co W > m e— 1— .0 N 'n 3 N o d re aCD c U w £ I co 0 O .!cu 0 E 0 Q 0ci. 2 0 0 . • ATO X75- zt Loepp, Victoria T (DOA) From: Loepp,Victoria T (DOA) Sent: Tuesday, May 03, 2016 9:00 AM To: 'Klem,Adam' Cc: Wallace, Chris D (DOA) Subject: RE: KRU 2S-11(PTD 215-219) Frac Sundry 316-223 Adam, Approval is granted to pump the LVT-200 during pad stages as a frac additive as outlined below. Please include this approval with your approved sundry. 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.LoeppCa�alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepo@alaska.gov From: Klem, Adam [mailto:Adam.Klem@conocophillips.cori;] Sent: Tuesday, May 03, 2016 8:54 AM To: Loepp, Victoria T(DOA) Cc: Wallace, Chris D (DOA) Subject: KRU 2S-11(PTD 215-219) Frac Sundry 316-223 Well: KRU 2S-11 PTD: 215-219 10-404 Frac Sundry: 316-223 Victoria, Due to a few issues on this well,we are looking to pump LVT-200 during our pad stages of the remaining four stages to frac. We are currently performing fluid rheology tests to determine the concentration to pump at, but we are planning on-3%volume during pad only.This should work out to '150-200bbls or so for all remaining stages. LVT-200 is on the sundry, but only as freeze protect, not as a frac additive. I just talked with Chris,and said I will need to add it in as an additive on the frac focus submission. He informed me that the AOGCC has the CAS on file.The rates and pressures of the job will not change.The post job report will include all changes to the frac fluid composition. • • We are hoping to continue pumping tomorrow since the water is on location and heated. Let me know if there is anything else you need from me,and if not, can we get permission to proceed with pumping LVT-200 during our pad stages as a frac additive? Thanks, Adam Klem Senior Completions Engineer Greater Kuparuk Area ConocoPhillips Alaska 700 G St ATO 1410 Anchorage,AK 99510 907-263-4529 Office 970-317-0300 Cell Adam.Klem@conocophillips.com 2 RECEIVED • STATE OF ALASKA • MAY 0 2 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANEBMC la.Well Status: Oil 0 Gas❑ SPLUG❑ Other ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Developmenfl ' Exploratory ❑ GINJ ❑ WINJ❑ WAGE WDSPL❑ No. of Completions: Services Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 3/31 /6e • 215-219 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 3/3/2016 50-103-20732-00 , 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 3074.7 FNL, 1554.9 FEL,Sec 17,T1ON, R8E, UM 3/20/2016 KRU 2S-11 Top of Productive Interval: 9. Ref Elevations: KB:159 17. Field/Pool(s): 2832 FNL, 12.58 FEL, Sec 18,T1ON, RO8E, UM GL: 120 BF: Kupurak River Field/Kuparuk Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1920 FNL,3667 FEL, Sec 8,T1ON, R8E, UM n/a ADL 25590,ADL 25603 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 481. ,_L, y- 5929973 Zone- 4 15309/6265 931898000,931899000 TPI: x- 477278 y- 5930227 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 478900 y- 5936413 Zone- 4 n/a 1429/1399 5. Directional or Inclination Survey: Yes 0 (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) I n/a 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log,spontaneous potential, gamma ray,caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation, casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res/Microscope/Periscope 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16 62.5 H-40 41 120 41 120 24 67 sx 15.7 ppg AS1 10.75 45.5 L-80 41 2859 41 2574 13.5 1054 sx 11 ppg DeepCrete, ClassG. 303 sx 15.8ppg, Class G Tail CMT 7.625 29.7 L-80 39 8485 39 6193 9.875 Stage 1:643 sx 15.8ppg,ClassG Stage 2:433 sx 15.8 ppg ClassG 4.5 11.6 L-80 8299 15300 6137 6265 6.75 Liner 24. Open to production or injection? Yes ❑ No E 25 TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 4 1/2 8305 8206/6101 8299/6138 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. COMPLETION Was hydraulic fracturing used during completion? Yes❑ No E DATE 3t3thlo Per 20 AAC 25.283(i)(2)attach electronic and printed information VERIFIED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED Lt-- 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): waiting for facility hookup Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period -0- Flow -Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate -P Form 10-407 Re is 11/2015 CONTIN ED ON PAGE 2 RBDMS �- MAYO 3 2016Submit ORIGINIAL only 1)/�s/� c -4 . ✓ • • 28. CORE DATA Conventional Core(s): Yes ❑ No RI Sidewall Cores: Yes ❑ No RI If Yes, list formations and intervals cored(MD/TVD, From/To), and summarize lithology and presence of oil, gas or water(submit separate pages with this form, if needed). Submit detailed descriptions,core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 0 Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1429 1399 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 8900 6280 information, including reports, per 20 AAC 25.071. Top W Sak(w Sak D) 1936 1855 base W Sak 2781 2521 C-80 3358 2901 C-37 6030 4701 Top HRZ 7931 5976 Upper Kalubik(base HRZ) 8225 6108 Lower Kalubik(K-1 mkr) 8472 6189 Kuparuk C(top C4) 8900 6280 Kuparuk A5 8954 6289 Kuparuk A4 9023 6298 Kuparuk A3 11119 6310 TD(Kuparuk A3) 15309 6264 Formation at total depth: Kuparuk A3 31. List of Attachments: Definitive Survey, Daily Operations Summary,Cement Report,Schematic Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey, core analysis, Paleontological report. production or well test results. per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kelsey Hallford A 265-1577 Email: Kelsey.Hallfordcop.com t ( Printed Name: G.L.Alvord Title: Alaska Drilling Manager { t l Signature: t "± Phone: 265-6120 Date: 512-I ) w INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 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 11/2015 Submit ORIGINAL Only KUP PAID 2S-11 ConocoI"hillips 3 Well AttribuMax Angle. TD fildska Inc, Wellbore APUUWI Field Name Wellbore Status incl(1) MD(ft Act Btm(ftKB) CarloccPM9rp4 ', 501032073200 KUPARUK RIVER UNIT PROD 95.47 12,143.18 15,300.0 .0 1- ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 25-11,4/28/201610:42:14 AM SSSV: NONE Last WO: 39.65 4/2/2016 Vertical schematic.(actual).... Annotation Depth(ftKB) End Date Annotation HANGER;36.8 ...q_.r...,r.-_.. Last Tag: Rev Reason: NEW WELL - _ .. _ 11 • 1 ] CONDUCTOR OD(in) 16 ID(in5).250 Top(ftKB4)0 8 Set Depth(ftKiBt)9 8 Set Depth(TVi iD9)... Wt/Le6n2(51.0..GHra4doe TwopidThrdead Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR;404-119.8 ; Casing Description OD(in) ID(in) Top(fIKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ' INTERMEDIATE 7 5/8 6.875 39.3 8,485.3 6,193.2 1 :1 Hyd 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len 9...Grade Top Thread LINER 41/2 3.958 8,299.2 15.300.0 6264.7 12.60 L-80 Hyd 563 Liner Details Nominal ID ) Top IRKS) Top(TVD)(ftKB) Top Incl(1 Item Des Corn (in) SURFACE,40.8-2,859.2-� 8,299.2 6,137.6 68.98 PACKER Baker HRD-E ZXP 5.5"x 7.63"Flex-Lock Liner top 4.810 packer L-80 Hyd 521 pin GAS LIFT;4,284.e I ': 8,323.9 6,146.3 69.97 NIPPLE Baker 5.5""RS"Packoff Seal Nipple 17#L-80 4.250 Hyd 563 box x box Mg 8,326.3 6,147.1 70.07 Hanger Baker 5.5"x 7.63"Flex-Lock Liner hanger P110 4.840 GAS LIFT;7,759.4 � ., Hyd 563 pin x pin M` 8,336.1 6,150.4 70.46 XO Reducing 5.5"Hyd 563 15.5#box x 4.5"12.6#H563 pin 3.910 GAS LIFT;8,112.4 '. Crossover Bushing NA 9,105.9 6,307.3 86.35 SWELL Baker-"Swell Packer"-"K" SN:50494-001-8 3.958 PACKER Gauge,8,180.7 1t 9,327.2 6,310.7 90.76 FRAC PORT Baker 4-1/2"Frac Sleeve#9-(3.625"Ball,Drift w/ 3.625 PACKER,8,205.8 3N• ■r 3.50")P14:10437063 NIPPLE,8,231.9 M 9,543.8- 6,305.4 91.16 SWELL Baker-"Swell Packer"-"J" SN: 50494-001-9 3.958 PLUG;8,232.0 - PACKER 9,807.9 6,303.8 89.37 FRAC PORT Baker 4-1/2"Frac Sleeve#8-(3.50"Ball,Drift w/ 3.400 LOCATOR;8,294.7 3.375")PN:H810-08-0393 LOCATOR,8,285.7 10,065.1 6,307.5 89.68 SWELL Baker-"Swell Packer'-"I" SN:50494-001-16 3.900 SHOE.8,304.0 PACKER 10,288.1 6,306.3 90.61 FRAC PORT Baker 4-1/2"Frac Sleeve#7-(3.375"Ball,Drift w/ 3.275 3.25")PN:H810-08-0394 "1 10,503.4 6,302.3 90.93 SWELL Baker-"Swell Packer"-"H" SN:50494-001-12 3.900 ' PACKER 10,727.7 6,301.7 90.11 FRAC PORT Baker 4-1/2"Frac Sleeve#6-(3.25"Ball,Drift w/ 3.150 & 3.125") PN:H810-08-0395 INTERMEDIATE:392-8 485.3 10,985.4 6,303.3 88.23 SWELL Baker-"Swell Packer'-"G" SN:50494-001-7 3.900 PACKER 11,248.6 6,324.9 83.52 FRAC PORT Baker 4-1/2"Frac Sleeve#5-(3.125"Ball,Drift w/ 3.025 it--A "---r3.00")PN:H810-08-0396 r1111` 11,506.2 6,351.9 84.08 SWELL Baker-"Swell Packer"-"F" SN:50494-001-1 3.900 PACKER liillir 12,005.4 6,347.9 94.85 SWELL Baker-"Swell Packer"-"E" SN:50494-001-2 3.890 I PACKER r0 a 12,308.9 6,327.2 92.45 FRAC PORT Baker 4-1/2"Frac Sleeve#4-(3.00"Ball,Drift wl 2.900 2.875")PN:H810-08-0397 iilliir 12,686.6 6,311.0 90.06 SWELL Baker-"Swell Packer"-"D" SN:50494-001-29 3.958 PACKER 13,110.9 6,320.4 89.58 FRAC PORT Baker 4-1/2"Frac Sleeve#3-(2.875"Ball,Drift w/ 2.775 2.75")PN:H810-08-0398 13,448.8 6,320.1 90.54 SWELL Baker-"Swell Packer'-"C" SN: 50494-001-13 3.900 illililr PACKER 13,792.3 6,304.7 93.88 FRAC PORT Baker 4-1/2"Frac Sleeve#2-(2.75"Ball,Drift w/ 2.650 ■ • 2.625") PN:H810-08-0399 14,127.2 6,291.5 91.78 SWELL Baker-"Swell Packer"-"B" SN:50494-001-10 3.910 PACKER 14,470.2 6,2758 92.87 FRAC PORT Baker 4-1/2"Frac Sleeve#1-(2.625"Ball,Drift w/ 2.525 2.50")PN:H810-08-0400 I 14,808.7 6,2675 90.39 SWELL Baker-"Swell Packer"-"A" SN: 50494-001-5 9.900 PACKER ■ 15,152.5 6,266.4 90.60 SLEEVE Baker 4-1/2"Alpha Sleeve,4877 psi, PN 10487898 3.000 15,165.6 6,266.2 90.61 SLEEVE Baker 4-1/2"Wellbore Isolation Valve(WIV)PN H809 -89-0011 • ■ 15,217.1 6,265.7 90.67 COLLAR 4-1/2"Weatherford Model 402E Float collar IBT 3.958 Tubing Strings Tubing Description String M ..ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING Ia. 41/21 3.9601 36.81 8305.01 6,139.71 12.601 L-80 I IBT-M Completion Details E El Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inti(°) Item Des Com (in) - 36.8 36.8 0.08 HANGER Cameron 11"x 4-1/2"Tubing Hanger 3.900 8,180.7 6,091.1 65.09 Gauge Schlumberger Gauge Carrier(measured w/collar on top) 3.958 I 8,205.8 6,101.5 65.81 PACKER Baker Premier Production Packer 3.640 --- 8,231.9 6,112.0 6656 NIPPLE Camco 3.812 DB-6 nipple(3.812")w/RHC plug body(65 3.812 deg) CI • 8,294.7 6,136.0 68.79 LOCATOR Baker 7.625"x 4.5"Shear pinned Fluted No-Go Sub- 3.950 Large OD- 8,295.8 6,136.4 68.84 LOCATOR Baker 7.625"x 4.5"Shear pinned Fluted No-Go Sub- 3.950 small OD- 8,304.0 6,139.3 69.17 SHOE Mule shoe WLEG 3.910 II I Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl 1. Top(ftKB) (ftKB) )) Des Coin Run Date ID(in) 8,232.0 6,112.1! 66.56!PLUG RHC PLUG IN NIPPLE 3/30/2016 • LINER;8,789.2-15,300.0 .i I 4y, KUP P D 2S-11 ConocoPhillips - ", • Alaska.Inc. c.,nocoPhillips .,..,.., ... 25-11,4/28/2016 10 42 15 AM I Vertical schemahc(actual) HANGER 368— Mandrel Inserts I CONDUCTOR;40.8-119.8 Top(TVD) Mit' N Top(ftKB) (ftKB) 1 4,284.9 3,515.2 CamcoMValve Latch Port Size TRO Run ake KBMG Mode i OD(in) Sery Type Type (in) (psi) Run Date Corn 1 GAS LIFT DMY BK-5 0.000 0.0 3/30/2016 . . 2 7,759.5 5,887.6 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 3/30/2016 3 8,112.4 6,061.5 Camco KBMG 1 GAS LIFT SOV BEK 0.000 0.0 3/30/2016 DK-2 SURFACE;40.6-2,859.2---. GAS LIFT;4,284.9 i I i a a GAS LIFT:7.7594 I it GAS LIFT;8,1124 I a Gauge;8,180.7 — P PACKER;8,2058 gll 7/1 • NIPPLE;8,231.9 I . PLUG;8,232.0 It LOCATOR,8,294.7 LOCATOR;8,295.7 2!ZOIK SHOE;8,304.0 P. — ) il IF i 1 INTERMEDIATE;28.2-8.4953 I—. 11 1-77A1E87 I 'illgar 11 ri ilillir [7 LI [7 [7 liiiir 6 6 -s•iiiir • • • . ....._. • ;i1N102,]. i . LINER;8,2992-15,300.0---.J 'A r • 1110 °° � Operations Summary (with Timelog Depths) 2S-11 ct x ocolltitiips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time '> End Time Our(hr) Phase Op Code Activity Code Time P-T-xOperatmn (ftKS)', End Depth(ftKB) 3/1/2016 3/1/2016 2.50 MIRU MOVE MOB P Skid rig floor,walk power module, 0.0 0.0 09:00 11:30 pump module,pit module away.Put on suspension and stage on far side of location via Peak. Walk casing shed away from sub. 3/1/2016 3/1/2016 0.50 MIRU MOVE RURD P Lay over Derrick 0.0 0.0 11:30 12:00 3/1/2016 3/1/2016 1.50 MIRU MOVE RURD P Secure geronimo,derrick assist and 0.0 0.0 12:00 13:30 tugger lines.Pin,raise and secure cellar box. Clear snow from beneath the pipe shed. Un-pin suspensions from power,pumps and pits. 3/1/2016 3/1/2016 1.50 MIRU MOVE MOB P Un-pin pipe shed and sub,remove 0.0 0.0 13:30 15:00 shims,walk pipe shed out from sub. Attach truck and stage pipe shed. 3/1/2016 3/1/2016 0.50 MIRU MOVE MOB P Stroke sub away from well and attach 0.0 0.0 15:00 15:30 jeep. 3/1/2016 3/1/2016 0.50 MIRU MOVE MOB P Re-move rig mats in front of sub and 0.0 0.0 15:30 16:00 transition.Walk pits and pump modules towards 2S-11. 3/1/2016 3/1/2016 1.75 MIRU MOVE MOB P Hook sows to sub and stage on rig 0.0 0.0 16:00 17:45 mats near 2S-11,remove trucks and jeep from sub. 3/1/2016 3/1/2016 1.00 MIRU MOVE MOB P Walk sub into 2S-11 and spot over 0.0 0.0 17:45 18:45 well. Hook sow to pipe shed and stage on mats under sub. Stage casing shed with truck near pipe shed. 3/1/2016 3/1/2016 3.00 MIRU MOVE MOB P Walk pits and pipe shed into sub. 0.0 0.0 18:45 21:45 Shim and pin pipe shed.Walk pump module into pit module and connect power into pump module. 3/1/2016 3/1/2016 1.25 MIRU MOVE MOB P PJSM,prep,raise derrick and pin, 0.0 0.0 21:45 23:00 walk casing module into pipe shed. 3/1/2016 3/2/2016 1.00 MIRU MOVE MOB P Prep and skid rig floor to drill position, 0.0 0.0 23:00 00:00 begin electrical interconnects. 3/2/2016 3/2/2016 2.00 MIRU MOVE RURD P Raise cattle chute,lower C-Section, 0.0 0.0 00:00 02:00 hook up electrical innerconnects,spot motor shed up to pump complex. Roll steam thoughout rig.Secure steps and hand rails throughout rig. 3/2/2016 3/2/2016 2.50 MIRU MOVE RURD P Shim cellar and lower cellar box. 0.0 0.0 02:00 04:30 Prepare derrick for scope.Continue hooking up electrical and high pressure mud lines. Concurrenity,load 5"drill pipe into casing shed. 3/2/2016 3/2/2016 1.50 MIRU MOVE RURD P Swap power to 3516 rig generators. 0.0 0.0 04:30 06:00 Check Emergency Shut Down devices.Start Amphion system and spool up slack on draw works drum. Un-pin blocks and top drive.Bridle up and continue to work fluid innerconnects. 3/2/2016 3/2/2016 2.00 MIRU MOVE RURD P Scope derrick up,bridle down.Rig 0.0 0.0 06:00 08:00 Accepted by CPAI Rig Supervisor at 08:00,March 2,2016. Page 1/38 Report Printed: 4/5/2016 « 1 Operations Summary (with Timelog gielPths) ix-N.. 2S-11 . Phitlips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/2/2016 3/2/2016 2.00 MIRU MOVE RURD P Install 4"Riser pipe and conductor 0.0 0.0 08:00 10:00 valves on well head. Concurrently,continue to load and strap 5"drill pipe into casing shed. 3/2/2016 3/2/2016 2.00 MIRU MOVE SEQP P Nipple up surface riser to diverter T 0.0 0.0 10:00 12:00 and surface annular. Engage WQ seals on adapter flange and test to 500psi for 5 min.(Good Test). Crossover koomy lines from stack to surface annular and energize koomy. Concurrently,continue to load and strap 5"drill pipe into casing shed, bringing on water into the pits to build spud mud. Calibrate block height on Amphion and TOTCO. 3/2/2016 3/2/2016 2.50 MIRU MOVE NUND P Obtain RKB's. Torque diverter T to 0.0 0.0 12:00 14:30 diverter adapter flange. Nipple up flow box,flow line,hole fill and jet lines. Install flow nipple. Re-position and tighten 4"risers and valves on conductor. Concurrently,perform derrick inspections and continue to load,strap and tally 5"drill pipe. 3/2/2016 3/2/2016 1.50 MIRU MOVE RURD P Change out saver sub to 4-1/2"IF 0.0 0.0 14:30 16:00 3/2/2016 3/2/2016 2.00 MIRU MOVE BOPE P Pick up 5"drill pipe tagging rat hole at 0.0 0.0 16:00 18:00 101.5'MD.Diverter Test waived by Johnnie Hill.Function test annular and kife valve. Perform diverter and accumulator drawdown test. Closing times for Knife Valve=13sec;Surface Annular=3lsec. Initial manifold= 1500psi,Accumulator=3000psi.After Surface Annular function, accumulator=2100psi with a 200psi recharge with electric pumps= 12sec; full recharge=59sec. 6 bottle average pressure=1967psi. 3/2/2016 3/2/2016 3.50 MIRU MOVE PULD P Install PS-21 slip inserts and build 0.0 0.0 18:00 21:30 stands of 5"drill pipe with singles and rack back in derrick. Concurrently,clean#2 suction manifold and build spud mud. 3/2/2016 3/2/2016 0.50 MIRU MOVE SVRG P Service and inspect ST-80 roughneck 0.0 0.0 21:30 22:00 while changing out hydraulic hose. 3/2/2016 3/3/2016 2.00 MIRU MOVE PULD P Continue to build stands of 5"drill pipe 0.0 0.0 22:00 00:00 and rack back in derrick. 3/3/2016 3/3/2016 4.50 MIRU MOVE PULD P Pick up and rack back 5"drill pipe in 0.0 0.0 00:00 04:30 derrick.(88stands) Concurrently,load 10-3/4"surface casing and 13-1/2"BHA into the casing shed to be strapped and tallied. Page 2/38 Report Printed: 4/5/2016 ,� • 44�tI - Operations Summary (with Timelog gPpths) = 2S-11 201 ConcwoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log ' Start Depth Start Time End Time Dor Mr) Phase Op Code Activity Code Time P-T-X Operation 090), End Depth(WE) 3/3/2016 3/3/2016 1.00 MIRU MOVE PULD P Pick up 6 stands of 5"HWDP and rack 0.0 0.0 04:30 05:30 back in derrick. Concurrently,clean suction pod on Mud Pump#1. 3/3/2016 3/3/2016 1.50 MIRU MOVE RURD P Remove PS21 slips,clean and send 0.0 0.0 05:30 07:00 out to shop. Install master bushings, clean and clear rig floor prior to picking up BHA. Flood all jet lines/hole fill and verify BHA order in pipe shed. Lock out kill line Demco on rig floor. 3/3/2016 3/3/2016 0.50 MIRU MOVE SFTY P Perform Pre-Spud meeting with day 0.0 0.0 07:00 07:30 crew. 3/3/2016 3/3/2016 2.00 MIRU MOVE BHAH P PJSM for picking up BHA. Pick up 0.0 86.0 07:30 09:30 BHA as per Schlumberger Directional Driller/MWD to 86'MD. Concurrently,swap from generator power to High Line power. 3/3/2016 3/3/2016 0.50 MIRU MOVE SEQP P Flood all high pressure lines. Fill 86.0 86.0 09:30 10:00 conductor and riser with water. Test high pressure mud lines to 3500psi. Concurrently,rig up Halliburton Hoisting/Gyro Data 3/3/2016 3/3/2016 1.00 SURFAC MOVE DRLG P Stage up pumps to 450 GPM,460psi, 86.0 120.0 10:00 11:00 24%flow out. Drill out conductor with water from 86'MD to 120'MD. 3/3/2016 3/3/2016 1.00 SURFAC DRILL DDRL P Swap over to spud mud and drill 13- 120.0 277.0 11:00 12:00 1/2"surface hole from 120'MD to 277' MD using 450 GPM,540psi,35%flow out,40 RPM, 10-12k WOB,and 3K TQ. PU wt=60k,SO wt=60k,ROT wt=60k.Off bottom pressure=460psi. 3/3/2016 3/3/2016 0.25 SURFAC DRILL SRVY P Scribe and perform gyro survey. 277.0 277.0 12:00 12:15 3/3/2016 3/3/2016 1.25 SURFAC DRILL TRIP P Pull out of hole from 277'MD to the 277.0 85.0 12:15 13:30 UBHO sub at 85'MD. 3/3/2016 3/3/2016 1.00 SURFAC DRILL BHAH P Make up remainder of BHA as per 85.0 277.0 13:30 14:30 Schlumberger and run in the hole to 277'MD while staging up the pumps to 450 GPM. 3/3/2016 3/3/2016 3.50 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 277' 277.0 564.0 14:30 18:00 MD to 564'MD/563'TVD using 500 GPM,890psi,39%flow out,70 RPM, 20k WOB,4-5k TQ and performing Gyro surveys at each connection. PU wt=76k,SO wt=84k, ROT wt= 83k,Off bottom TQ=2k,Off bottom pressure=700psi. Page 3/38 Report Printed: 4/5/2016 i Operations Summary (with Timelog 'pths) et 2S-11 conocontlinps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase : Op Code Activity Code Time P-T-X Operation {MO) End Depth(ftKB) 3/3/2016 3/4/2016 6.00 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 564' 564.0 1,035.0 18:00 00:00 MD to1035'MD/1025'TVD using 625 GPM, 1400psi,44%flow out,80 RPM, 25k WOB,5k TQ and performing Gyro surveys at each connection. PU wt=93k,SO wt=95k,ROT wt= 95k,Off bottom TQ=2k,Off bottom pressure=1290psi. Concurrently,rig down Gyro Services @ 939'MD. 3/4/2016 3/4/2016 6.00 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 1035' 1,035.0 1,630.0 00:00 06:00 MD to 1630'MD/1581'TVD using 650 GPM, 1789psi,42%flow out,80 RPM,30k WOB,6-7k TQ. PU wt=100k,SO wt=100k,ROT wt= 101k,Off bottom TQ=3k,Off bottom pressure=1444psi. 3/4/2016 3/4/2016 6.00 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 1630' 1,630.0 2,200.0 06:00 12:00 MD to 2200'MD/2087'TVD using 700 GPM,2000psi,46%flow out,80 RPM,26k WOB,6k TQ. PU wt=119k,SO wt=112k, ROT wt= 113k,Off bottom TQ=3.5k,Off bottom pressure= 1800psi. 3/4/2016 3/4/2016 6.00 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 2200' 2,200.0 2,738.0 12:00 18:00 MD to 2738'MD/2500'TVD using 700 GPM,2100psi,46%flow out,80 RPM,28k WOB,9k TQ. PU wt=127k,SO wt= 117k, ROT wt= 121k,Off bottom TQ=4k,Off bottom pressure= 1860psi. 3/4/2016 3/4/2016 1.75 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 2738' 2,738.0 2,868.0 18:00 19:45 MD to 2868'MD/2575'TVD using 750 GPM,2285psi,47%flow out,80 RPM,27k WOB,8k TQ. PU wt=127k,SO wt=118k,ROT wt= 120k,Off bottom TQ=5k,Off bottom pressure=2110psi. AST=6.4,ART=5.98,ADT=12.38, Total Bit hours=18.74,Total Jar Hours=36.11 3/4/2016 3/4/2016 1.25 SURFAC CASING CIRC P Obtain Survey,lay down top double of 2,864.0 2,864.0 19:45 21:00 stand#23,circulate bottoms up while rotating and reciprocating from 2864' MD to 2768'MD using 750 GPM, 2080psi,48%flow out, 100 RPM,5K TQ. 3/4/2016 3/4/2016 0.25 SURFAC CASING OWFF P Observe well for flow prior to 2,864.0 2,864.0 21:00 21:15 backreaming to base of permafrost. Page 4/38 Report Printed: 4/5/2016 Operations Summary (with Timelog Depths) OP '��t" "�. 2S-11 If Phillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time '.' Dur(hr) Phase - Op Code Activity Code.. Time P-T-X Operation (ftKB)`. End Depth(ftKB)'.. 3/4/2016 3/5/2016 2.75 SURFAC CASING BKRM P Backream back to base of permafrost 2,864.0 21:15 00:00 from 2864'MD to 1794'MD using 750 GM, 1930psi,45%flow out, 100 RPM, 5K TQ. Monitoring well via pits#2,#3, and#4. Up Wt=105k, Down Wt= 107k,and ROT wt= 108k. 3/5/2016 3/5/2016 2.25 SURFAC CASING BKRM P Backream out of hole from 1794'MD 1,794.0 1,321.0 00:00 02:15 to 1321'MD using 750 GPM, 1920psi, 45%flow out, 100 RPM,5k TQ. Monitor well via Pits#2,#3,and#4. PU wt= 103k,SO wt=98k. 3/5/2016 3/5/2016 1.25 SURFAC CASING TRIP P Pull out of hole on elevators from 1,321.0 192.0 02:15 03:30 1321'MD to BHA at 192'MD while monitoring well on pits#2 and#3. PU wt=95k,SO wt=93k 3/5/2016 3/5/2016 2.50 SURFAC CASING BHAH P Lay down BHA#1 as per 192.0 0.0 03:30 06:00 Schlumberger Directional Driller from 192'MD. 3/5/2016 3/5/2016 0.75 SURFAC CASING BHAH P Clear and clean rig floor of surface 0.0 0.0 06:00 06:45 BHA#1. 3/5/2016 3/5/2016 2.00 SURFAC CASING RURD P Rig up to run 10-3/4",45.5#L-80 0.0 0.0 06:45 08:45 Hydril 563 Dopeless casing 3/5/2016 3/5/2016 1.00 SURFAC CASING PUTB P PJSM with rig crew,CPAI company 0.0 170.0 08:45 09:45 rep,GBR Casing Rep,and Doyon Tool Pusher on running casing. Run 10-3/4"45.5#L-80 Hydril 563 to 170' MD using Volant Casing Running tool. Baker-Loc shoe track and pin of casing joint#4. Check floats(Good). 3/5/2016 3/5/2016 3.75 SURFAC CASING PUTB P Continue to run 10-3/4"45.5#L-80 170.0 1,648.0 09:45 13:30 Hydril 563 dopeless casing with Volant casing running tool from 170'MD to 1648'MD. Connections made up to 20k ftlbs. Fill each joint on the fly and top off every 10 joints. Monitor displacement via pits#2 and #3. SO wt 70k. 3/5/2016 3/5/2016 0.75 SURFAC CASING CIRC P Circulate bottoms up while staging the 1,648.0 1,648.0 13:30 14:15 pumps up to 6 BPM, 154psi,and 35% flow out. PU wt=106k,SO wt=95k. 3/5/2016 3/5/2016 2.00 SURFAC CASING PUTB P Continue to run 10-3/4"45.5#L-80 1,648.0 2,815.0 14:15 16:15 Hydril 563 dopeless casing with Volant casing running tool from 1648'MD to 2815'MD. Connections made up to 20k ftlbs. Fill each joint on the fly and top off every 10 joints. Monitor displacement via pits#2 and #3. 3/5/2016 3/5/2016 0.75 SURFAC CASING CIRC P Circulate bottoms up while staging the 2,815.0 2,815.0 16:15 17:00 pumps up to 6 BPM,210psi,and 37% flow out. PU wt= 106k,SO wt=95k. Page 5/38 Report Printed: 4/5/2016 x4 Operations Summary (with Timelog Depths)ths) 2S-11 ConocoPhiilips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code-' Time P-T-X Operation MKS), End Depth(ftKB) 3/5/2016 3/5/2016 1.00 SURFAC CASING HOSO P Make up casing hanger/landing joint 2,815.0 2,859.0 17:00 18:00 and wash down from 2815'MD to 2859'MD at 1 BPM, 115psi,29%flow out.Land Hanger at 17:50. 3/5/2016 3/5/2016 1.00 SURFAC CEMENT CIRC P Circulate and reciprocating casing 2,859.0 2,859.0 18:00 19:00 from 2859'MD to 2839'MD while staging up pumps from 1 BPM to 6 BPM. 1BPM, 11 Opsi,27%flow out; 2BPM, 115psi,35%flow out;3BPM, 145psi,33%flow out;4BPM, 160psi, 35%flow out;5BPM, 165psi,35%flow out;6BPM,205psi,37%flow out. PU wt=140k,SO wt=125k. 3/5/2016 3/5/2016 2.00 SURFAC CEMENT WAIT T Continue to circulate and reciprocate 2,859.0 2,859.0 19:00 21:00 while waiting on Schlumberger Cementing Services to arrive at rig. Convoy got behind unpassable loads of rig move for Doyon 142. Concurrently, Dis-engage Volant Casing running tool and blow down top drive. Attach cement hose to top drive and re-establish circuation while staging pump up from 1 BPM to 6 BPM. 1BPM,45psi,24%flow out; 2BPM,50psi,26%flow out;3BPM, 80psi,27%flow out;4BPM, 120psi, 28%flow out;5BPM, 160psi,30%flow out;6BPM,212psi,32%flow out. PU wt= 140k SO wt=132k. 3/5/2016 3/6/2016 3.00 SURFAC CEMENT RURD P Rig up Schlumberger Cementing 2,859.0 2,859.0 21:00 00:00 System while continue to circulate and condition wellbore. 3/6/2016 3/6/2016 1.00 SURFAC CEMENT RURD P Rig up Schlumberger cementing. 2,859.0 2,859.0 00:00 01:00 Perform PJSM for surface cement job. Concurrently,circulate and condition mud from 2859'MD to 2839'MD using 6BPM, 190psi,32%flow out. PU wt=155k,SO wt=133k Page 6/38 Report Printed: 4/5/2016 •erations Summary (with Timelog Depths) 0 0 2S-11 Conocr Phillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation. (ftKB) End Depth(ftKB) 3/6/2016 3/6/2016 3.75 SURFAC CEMENT CMNT P Pressure test cement lines to 500psi 2,859.0 40.7 01:00 04:45 Low and 3500psi high(Test Charted- Good Test). Reciprocating casing, pump 40bbls of CW100 using 6.4BPM, 170psi, 18%flow out and chase with 76bbls of 10.5ppg Mud Push II using 5BPM, 140psi, 15%flow out. Drop bottom plug. Continue to reciprocate while pumping 358bbls of 11 ppg DeepCrete Lead cement using 6BPM, 190psi, 18%flow out. Chase Lead cement with 15.8ppg Class G Tail cement using 6BPM,358psi, 15% flow out. Drop top plug and kick out using 3bbls of tail cement and 10bbls of water using 5BPM, 170psi, 11% flow out. Switch over to rig pumps and continue displacement of cement using 9.7ppg spud mud at 7BPM, 263psi,25%flow out. Caught up to cement at 670stks and diverted to cellar at 700stks when cement returns came to surface. Reduce rate to 5 BPM,274psi and again to 4BPM, 286psi to help with cellar returns. Increase rate to 5 BPM,387psi at 1600stks followed by reductin rate to 3BPM,51 psi at 2000stks and 1 BPM at,515psi at 2400stks. Bump plug at 2502stks.Pressure up 500psi over circulating pressure to 1020psi and hold for 10min. Bleed off to check floats(Floats held). Cement in place at 04:30 with Note: Experienced 50k overpull after kickout of Top Plug. Displaced cement while sitting on landing ring. 182bbls of cement returned to surface 3/6/2016 3/6/2016 3.25 SURFAC CEMENT RURD P Rig down volant casing running tool, 40.7 0.0 04:45 08:00 lay down landing joint,change out elevators to 5".Drain stack and flush with black water pill. Remove 4"risers from outlets on conductor. Remove PS-21's and clean rotary table and flow line. Concurrently,clean out all cement valves and rig down Schlumberger cementers. 3/6/2016 3/6/2016 3.00 SURFAC CEMENT NUND P Nipple down surface riser,flowline, 0.0 0.0 08:00 11:00 surface annular preventer,diverter T, and diverter line. 3/6/2016 3/6/2016 1.00 SURFAC WHDBOP NUND P Nipple up wellhead and test to 0.0 0.0 11:00 12:00 5000psi for 10min(CPAI witness-R. Reinhardt,Good Test). Page 7/38 Report Printed: 4/5/2016 0. ,fz �� ; , Operations Summary (with Timelog Depths) 0 2S-11 Corso #hiipps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB). End Depth(ftKB) 3/6/2016 3/6/2016 6.00 SURFAC WHDBOP NUND P Nipple up Drilling Spool Adaptor, 0.0 0.0 12:00 18:00 extension and riser. Nipple up choke and kill lines. Nipple up BOP stack to riser. Pull 2'extension in cellar for flow box clearance of RCD head on stack. Re-install 2'riser and continue to nipple up BOPE and MPD equipment. Concurrently,inspect,tighten drawworks encoders and bearings. Begin loading and strapping 7-5/8" casing into the pipe shed. Clean pits. 3/6/2016 3/6/2016 2.00 SURFAC WHDBOP MPDA P Install Cameron Lower test plug, 0.0 0.0 18:00 20:00 install MPD test cap and test MPD air actuated valve to 250psi/1200psi for 5 min(Charted-Good Test). Remove test cap and install trip nipple. 3/6/2016 3/7/2016 4.00 SURFAC WHDBOP BOPE P Rig up and test BOP.Test BOPE 0.0 0.0 20:00 00:00 (witness waived by AOGCC Rep Bob Noble):All tests 250psi low/3500psi high for 5 charted minutes with exception of manual operated and super choke(250psi low/2000psi high)for 5 charted minutes. Using 4" and 5"test joints,test annular,2- 7/8"x5-1/2"UPR,2-7/8"x5-1/2"LPR, Choke Valves#1 to#15,Manual Operated and super choke,choke and kill manuals and NCR's,4"valve on kill line,5"TIW#1,5"dart,and upper and lower IBOP's,Perform Koomy drawdown(Prior to: Accumulator=3000psi, Manifold=1500psi,Function 3 rams and Annular,After test Accumulator= 1600psi,21 sec for 200psi with 1 electric pump, 114sec to build system to full pressure with 2 electric and 2 air pumps).Closing times:Annular- 23sec;UPR-17sec; Blind/Shears- 16sec;LPR-16sec;Choke HCR- 2sec;Kill HCR-2 sec. 3/7/2016 3/7/2016 0.50 SURFAC WHDBOP BOPE P Using 4"jest joint,test Lower 2-7/8"x 0.0 0.0 00:00 00:30 5-1/2"VPR to 250psi Low/3500psi High for 5/5min charted. 3/7/2016 3/7/2016 1.25 SURFAC WHDBOP RURD P Pull test plug.Install 10"ID wear 0.0 0.0 00:30 01:45 bushing.Blow down choke manifold, choke and kill lines. 3/7/2016 3/7/2016 1.75 SURFAC CEMENT BHAH P Pick up BHA#2 as per Schlumberger 0.0 197.0 01:45 03:30 Directional Driller:9-7/8"x 11"Rotary Steerable with RipTide Under-reamer. Monitor displacement via Pit#2. 3/7/2016 3/7/2016 0.25 SURFAC CEMENT TRIP P Run in hole on elevators with 5" 197.0 478.0 03:30 03:45 HWDP from 197'MD to 478'MD. Monitor displacement via pit#2. 3/7/2016 3/7/2016 0.25 SURFAC CEMENT BHAH P Pick up 6-1/4""jars and run in hole to 478.0 510.0 03:45 04:00 510'MD 3/7/2016 3/7/2016 0.25 SURFAC CEMENT RURD P Change out hand slips inserts to 5"" 510.0 510.0 04:00 04:15 inserts on PS-21's Page 8/38 Report Printed: 4/5/2016 wt :_ Operations Summary (with Timelog tpths) 4:4 " r 2S-11 41) Con acoPhiiitps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dor(hr) Phase Op Code Activity Code'. Time P-T-X Operation (MO)l End Depth(ftKB) 3/7/2016 3/7/2016 1.25 SURFAC CEMENT TRIP P Run in the hole on elevators with 5" 510.0 1,701.0 04:15 05:30 HWDP and 5"drill pipe from 510'MD to 1701'MD while monitoring displacment via Pit#2. 3/7/2016 3/7/2016 0.25 SURFAC CEMENT DHEQ P Conduct shallow hole test of 1,701.0 1,701.0 05:30 05:45 Schlumberger MWD/LWD tools using 450 GPM,995psi,and 27%flow out (Good Test).Blow down top drive. 3/7/2016 3/7/2016 0.75 SURFAC CEMENT TRIP P Continue to run in hole on elevators 1,701.0 2,651.0 05:45 06:30 with 5"drill pipe from 1701'MD to 2651'MD.Monitor dislacement via Pit #2. PU wt=125k,SO wt= 104k 3/7/2016 3/7/2016 1.75 SURFAC CEMENT SLPC P Slip and cut 96'of drill line.Calibrate 2,651.0 2,651.0 06:30 08:15 TOTCO and Amphion systems. Concurrently,circulate with 105 GPM, 100psi, 13%flow out 3/7/2016 3/7/2016 1.25 SURFAC CEMENT PRTS P Rig up and test casing to 3500psi for 2,651.0 2,651.0 08:15 09:30 30 charted min(Good Test).Required 4bbls to pressure up to 3500psi with 4bbls bled back after test completed. 3/7/2016 3/7/2016 0.50 SURFAC CEMENT COCF P Wash and ream down from 2651'MD 2,651.0 2,747.0 09:30 10:00 to top of cement at 2747'MD using 55OGPM, 1513psi,27%flow out,and 80 RPM. PU wt= 125k,SO wt=104k,ROT wt= 108k. Off bottom TQ=2-8k. 3/7/2016 3/7/2016 1.00 SURFAC CEMENT COCF P Drill cement from 2747'MD to 2771' 2,747.0 2,771.0 10:00 11:00 MD using 550 GPM, 1515psi,27% flow out,80 RPM,5k WOB,and 2-8k TQ. PU wt=125k,SO wt=104k,ROT wt= 108k,Off bottom TQ=8k 3/7/2016 3/7/2016 4.50 SURFAC CEMENT DRLG P Drill floats and float collar from 2771' 2,771.0 2,868.0 11:00 15:30 MD to 2772'MD with 350-550 GPM, 589-640psi, 19-27%flow out,60 RPM, 2-10k WOB,and 7k TQ. Shoe track from 2772'MD to 2858'MD with 500 GPM, 1170psi,25%flow out,60 RPM, 3k WOB,6-9k TQ. Tag shoe at 2858' MD.Drill out shoe from 2858'MD to 2868'MD using 410GPM,850psi, 22%flow out,80 RPM,2k WOB,and 4-9k TQ. PU wt=125k,SO wt=104k,and ROT wt=108k,Off bottom TQ=8k Page 9/38 Report Printed: 4/5/2016 • Operations Summary (with Timelog Depths) aot 2S-11 � R �3�y 33 COtiOCCIP9itmmpS Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X . Operation MKS) End,Depth(ftKB), 3/7/2016 3/7/2016 0.25 SURFAC CEMENT DRLG P Drill rat hole from 2858'MD to 2868 2,868.0 15:30 15:45 MD using 410GPM,850psi,22%flow out,80 RPM,2k WOB,and 4-9k TQ. 3/7/2016 3/7/2016 0.25 SURFAC CEMENT DDRL P Drill 20'new formation to 2888'MD 2,868.0 2,888.0 15:45 16:00 using 600 GPM, 1630psi,28%flow out, 120 RPM, 12k WOB,and 5-11k TQ. PU wt= 130k,SO wt=105k,ROT wt= 110k,Off bottom TQ=6-8k. 3/7/2016 3/7/2016 0.50 SURFAC CEMENT CIRC P Circulate bottoms up while rotating 2,888.0 2,840.0 16:00 16:30 and reciprocating from 2888'MD to 2840'MD in order to ensure a clean shoe. Rack stand back. 3/7/2016 3/7/2016 0.75 SURFAC CEMENT LOT P Blow down top drive,rig up test 2,840.0 2,840.0 16:30 17:15 equipment and perform Leak Off Test by pumping 1.1bbl(llstks,865psi)for a 14.6ppg equivalent mud weight. Bleed off pressure(lbbl returned)and blow down and rig down test equipment. 3/7/2016 3/7/2016 0.25 INTRM1 DRILL WASH P Wash down from 2840'MD to 2888' 2,840.0 2,888.0 17:15 17:30 MD while staging up the pumps to 600 GPM. 3/7/2016 3/7/2016 1.25 INTRM1 DRILL DDRL P Continue drilling 9-7/8"intermediate 2,888.0 2,990.0 17:30 18:45 hole from 2888'MD to 2990'MD using 600 GPM, 1690psi,28%flow out,80 RPM, 15k WOB,5-9k TQ. PU wt=131k,SO wt= 107k, ROT= 115k,off bottom TQ=7k. Displaced well to LSND mud while drilling ahead from 2935'MD. 3/7/2016 3/7/2016 1.00 INTRM1 DRILL CIRC P Drop 10 RFID chips and pump down 2,990.0 2,990.0 18:45 19:45 as per Weatherford Rep with no indication of Riptide reamer opening, repeat again,200psi drop and 8k over puls with blades at shoe indicate that Riptide reamer is open. 3/7/2016 3/8/2016 4.25 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"intermediate hole 2,990.0 3,332.0 19:45 00:00 with Riptide under reamer from 2990' MD to 3332'MD/2885'TVD using 750 GPM, 1700psi,32%flow out, 120 RPM,8k WOB,6-8.5k TQ. PU wt= 137k,SO wt=111k,ROT wt= 118k,Off bottom TQ=7k AST/ART=3.82,ADT=3.82.Total Bit Hr=3.82,Total Jars=129.39 3/8/2016 3/8/2016 6.00 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"intermediate hole 3,332.0 3,972.0 00:00 06:00 with Riptide under reamer from 3332' MD to 3972'MD/3310'TVD using 750 GPM, 1980psi,32%flow out, 120 RPM, 10k WOB and 8-10k TQ. PU wt= 150k,SO wt=119k,ROT wt= 131k,Off bottom TQ=6.5k Pump 25bbl nut plug sweep at 3312' MD&3520'MD;Pump 25bbl 11.7ppg sweep at 4069'MD. Page 10/38 Report Printed: 4/5/2016 • " s � r- Operations Summary (with Timelog Depths) ailoB a F a 2S-11 f'ttillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time S End Time Dur(hr) Phase Op Code Activity Code Time P-T-x Operation (ftKB)', End Depth(ftKB) 3/8/2016 3/8/2016 6.00 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"intermediate hole 3,972.0 4,542.0 06:00 12:00 with Riptide under reamer from 3972' MD to 4542'MD/3683'TVD using 750 GPM,2030psi,33%flow out, 120 RPM, 10k WOB and 10k TQ. PU wt=162k,SO wt= 125k, ROT wt= 135k,Off bottom TQ=9k Pump 25bb1 nut plug sweep at 4290' MD. Concurrently,added 14 gallons of cement to 10-3/4"x 16"annulus,Top of Cement:2.5' 3/8/2016 3/8/2016 6.00 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"intermediate hole 4,542.0 5,110.0 12:00 18:00 with Riptide under reamer from 4542' MD to 5110'MD/4055'TVD using 750 GPM,2140psi,32%flow out, 120 RPM, 16k WOB and 10-14k TQ. Faults crossed at 4800'MD.. PU wt=204k,SO wt=132k,ROT wt= 153k,Off bottom TQ=13k Pump 25bb1 nut plug sweep at 5260' MD;Pump 25bb1 11.6ppg sweep at 5520'MD. 3/8/2016 3/9/2016 6.00 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"intermediate hole 5,110.0 5,678.0 18:00 00:00 with Riptide under reamer from 5110' MD to 5678'MD/4444 TVD using 750 GPM,2240psi,32%flow out, 130 RPM,22k WOB and 12-16k TQ. Fault crossed at 5196'MD, experienced initial 45bb1 loss,slowed to dynamic losses of 20BPH,7BPH with pumps off. Observed initial flowback during connections, monitored and observed a decreasing trend in flowback during each connection. Discussed with Superintendent and continued drilling. PU wt=204k,SO wt=132k,ROT wt= 153k,Off bottom TQ=13k Pump 25bbl nut plug sweep at 5260' MD;Pump 25bb1 11.6ppg sweep at 5520'MD. ART/ADT=17.31,ADT=17.31,Total Bit Hours=21.13,Total Jars= 146.70, Total Losses=225bb1s. 3/9/2016 3/9/2016 4.50 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"intermediate hole 5,678.0 6,054.0 00:00 04:30 with Riptide under reamer from 5678' MD to 6054'MD/4711'TVD using 750 GPM,2480psi,32%flow out, 100- 130 RPM, 15-20k WOB and 12-18k TQ. PU wt= 184k,SO wt=138k,ROT wt= 160k,Off bottom TQ=12k Pump weighted(11.6ppg)sweeps every 2 stands. Page 11/38 Report Printed: 4/5/2016 • • 4, Operations Summary (with Timelog Depths) 2S-11 ConocoPhiliips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time. End.Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/9/2016 3/9/2016 0.50 INTRM1 DRILL CIRC P Rotate and reciprocate from 6054'MD 6,054.0 6,054.0 04:30 05:00 to 5960'MD spotting a 40bbl 40ppb nut plug pill across expected loss zone with 350 GPM,629psi, 19%flow out, 80 RPM. PU wt=184k,SO wt= 138k, ROT wt= 160k,Off bottom TQ= 12k 3/9/2016 3/9/2016 0.50 INTRM1 DRILL OWFF P Monitor well until to ensure it is static 6,054.0 6,054.0 05:00 05:30 prior to pulling trip nipple and installing RCD bearing. 3/9/2016 3/9/2016 1.00 INTRM1 DRILL MPDA P PJSM for removing trip nipple and 6,054.0 6,054.0 05:30 06:30 installing RCD bearing. Pull trip nipple and install RCD bearing.Calibrate chokes on MPD skid. 3/9/2016 3/9/2016 5.50 INTRM1 DRILL DDRL P Continue drilling 9-7/8"x 11" 6,054.0 6,509.0 06:30 12:00 intermediate hole with Riptide under reamer from 6054'MD to 6509'MD/ 5058'TVD using 750 GPM,2546psi, 30%flow out, 140 RPM, 1l k WOB and 9-16k TQ. PU wt= 194k,SO wt=144k, ROT wt= 163k,Off bottom TQ=1l k Losses static. 3/9/2016 3/9/2016 6.00 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"intermediate hole 6,509.0 7,096.0 12:00 18:00 with Riptide under reamer from 6509' MD to 7096'MD/5488'TVD using 750 GPM,2558psi,32%flow out, 130 RPM,20k WOB and 13-20k TQ. PU wt=245k,SO wt= 147k,ROT wt= 177k,Off bottom TQ= 14k Dump and dilute at 6820'MD 3/9/2016 3/9/2016 5.50 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"intermediate hole 7,096.0 7,570.0 18:00 23:30 with Riptide under reamer from 7096' MD to 7570'MD/5786'TVD using 750 GPM,2648psi,31%flow out, 150 RPM, 18k WOB and 15-22k TQ. PU wt=252k,SO wt=147k,ROT wt= 179k,Off bottom TQ=15k,Losses at —7BPH. 3/9/2016 3/10/2016 0.50 INTRM1 DRILL SVRG P Service Top Drive/IBOP. 7,570.0 7,570.0 23:30 00:00 ART/ADT= 14.92,Bit Hours=36.05, and Total Jar Hours= 161.62. 3/10/2016 3/10/2016 2.50 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"intermediate hole 7,570.0 7,855.0 00:00 02:30 with Riptide under reamer from 7570' MD to 7855'MD/5939'TVD using 750 GPM,2715psi,32%flow out, 150 RPM, 16k WOB and 20-22k TQ. PU wt=256k,SO wt=154k,ROT wt= 179k,Off bottom TQ= 13k Page 12/38 Report Printed: 4/5/2016 • Operations Summary (with Timelog Depths) 4 - Y t . 2S-11 hex=. ;;>h e � ConocoPhritrps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time..-. . End Time Dur(hr) Phase Op.Code Activity Code Time P-T-X Operation MKB) End;,Depth(ftKB) 3/10/2016 3/10/2016 0.75 INTRM1 DRILL CIRC P Rotate and reciprocate from 7855'MD 7,855.0 7,855.0 02:30 03:15 to 7798'MD using 750 GPM,2670psi, 32%flow out,80 RPM prior to change out of MPD bearing Pu wt=256k,SO wt=154k,ROT wt= 179k Off bottom TQ=13. 3/10/2016 3/10/2016 0.50 INTRM1 DRILL MPDA T Change out failed MPD bearing 7,855.0 7,855.0 03:15 03:45 (Lower seal failure)with new MPD bearing. 3/10/2016 3/10/2016 1.25 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"intermediate hole 7,855.0 7,949.0 03:45 05:00 with Riptide under reamer from 7855' MD to 7949'MD/5990'TVD using 750 GPM,2669psi,32%flow out, 150 RPM, 16k WOB and 20-22k TQ. PU wt=256k,SO wt=154k,ROT wt= 179k,Off bottom TQ=13k 3/10/2016 3/10/2016 1.00 INTRMI DRILL CIRC P Rotate and reciprocate from 7949'MD 7,949.0 7,949.0 05:00 06:00 to 7885'MD conditioning mud system with Resinex and Amphasol prior to entering HRZ formation Performed using 750 GPM,2620psi,32%flow out,80 RPM. PU wt=256k,SO wt= 154k, ROT wt= 179k,Off bottom TQ= 13k 3/10/2016 3/10/2016 11.00 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"intermediate hole 7,949.0 8,492.0 06:00 17:00 with Riptide under reamer from 7949' MD to 8492'MD/6193'TVD(TD of 9- 7/8"x 11"hole section)using 750 GPM,2350-2669psi,32%flow out, 140-150 RPM,9-16k WOB and 12- 21k TQ. PU wt=260k,SO wt= 145k, ROT wt= 180k,Off bottom TQ= 17k 3/10/2016 3/10/2016 1.50 INTRM1 CASING CIRC P Obtain survey and slow pump rates. 8,492.0 8,492.0 17:00 18:30 Drop RFID chips and pump down as per Weatherford rep. Confirm under reamer blades closed with 270psi increase. 3/10/2016 3/10/2016 3.50 INTRM1 CASING PMPO P Pump out of hole following MPD ramp 8,492.0 7,855.0 18:30 22:00 schedule from 8492'MD to 7855'MD using 650 GPM,2150psi,26%flow out. Reduce pulling speed to obtain one(1)bottoms up per stand from 7950 to 7855'MD 3/10/2016 3/10/2016 1.25 INTRM1 CASING OWFF P Blow down top drive,perform MPD 7,855.0 7,855.0 22:00 23:15 drawdown test(Static with 9.6ppg MW). 3/10/2016 3/10/2016 0.50 INTRM1 CASING OWFF P Circulate across top of wellbore while 7,855.0 7,855.0 23:15 23:45 monitoring well on trip tank for flow for 30min.(Static) 3/10/2016 3/11/2016 0.25 INTRMI CASING CIRC P Line up injection line to MPD skid 7,855.0 7,855.0 23:45 00:00 establishing circulation through chokes. Page 13/38 Report Printed: 4/5/2016 Operations Summary (with Timelog Depths) �, r 4' 2S-11 Conahilltps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) I Phase' Op Code Activity Code Time P-T-X Operation (ftKB), End Depth(ftKB) 3/11/2016 3/11/2016 4.25 INTRM1 CASING SMPD P Strip out of the hole from 7855'MD to 7,855.0 2,740.0 00:00 04:15 2740'MD maintaining annulus pressure as per stripping schedule. PU wt=235k,SO wt=140k 3/11/2016 3/11/2016 0.50 INTRM1 CASING CIRC P Rotate and reciprocate from 2740'MD 2,740.0 2,740.0 04:15 04:45 to 2649'MD using 650 GPM, 1600psi, 30%flow out,80 RPM, PU wt= 117k,SO wt=100k,Off bottom TQ=6k. 3/11/2016 3/11/2016 0.50 INTRM1 CASING OWFF P Observe well for flow for 30min 2,740.0 2,740.0 04:45 05:15 (Static) 3/11/2016 3/11/2016 1.25 INTRM1 CASING MPDA P Pull MPD bearing and install trip 2,740.0 2,740.0 05:15 06:30 nipple. Flush MPD skid with water. Blow down injection line and MPD skid. 3/11/2016 3/11/2016 0.75 INTRM1 CASING TRIP P Pull out of hole on elevators from 2,740.0 759.0 06:30 07:15 2740'MD to 759'MD while monitoring displcement via Trip Tank#1. PU wt=117k,SO wt=110k. 3/11/2016 3/11/2016 0.25 INTRM1 CASING OWFF P Observe well for flow for 10min prior to 759.0 759.0 07:15 07:30 pulling BHA through the BOP stack. (Static) 3/11/2016 3/11/2016 1.50 INTRM1 CASING TRIP P Pull out of hole from 759'MD to 197' 759.0 197.0 07:30 09:00 MD. Lay down HWDP and jars. Monitor well via Trip Tank#1. 3/11/2016 3/11/2016 2.00 INTRM1 CASING BHAH P Lay down BHA#2 as per 197.0 0.0 09:00 11:00 Schlumberger Directional Driller from 197'to surface. Monitor displacment via Trip Tank#1. 3/11/2016 3/11/2016 1.00 INTRM1 CASING BHAH P Clear and clean rig floor. 0.0 0.0 11:00 12:00 3/11/2016 3/11/2016 0.75 INTRM1 CASING WWWH P Pull wear bushing,make up stack 0.0 0.0 12:00 12:45 flushing tool and flush stack with 885' GPM, 165psi,36%flow out,40 RPM, 1k TQ. Blow down top drive. Concurrently,mobilize casing running tools to rig floor 3/11/2016 3/11/2016 0.50 INTRM1 CASING RURD P Install test plug,lay down 5"test joint 0.0 0.0 12:45 13:15 and pick up 7-5/8"test joint. Make up test plug. 3/11/2016 3/11/2016 0.75 INTRMI CASING RURD P Change out 2-7/8"x 5"upper rams 0.0 0.0 13:15 14:00 with 7-5/8"casing rams. 3/11/2016 3/11/2016 1.50 INTRMI CASING BOPE P Using 7-5/8"test joint,test Annular 0.0 0.0 14:00 15:30 and 7-5/8"upper pipe rams to a low of 250psi and high of 3500psi for 5 charted min each.(Good Test) 3/11/2016 3/11/2016 0.25 INTRM1 CASING BOPE P Pull test plug and lay down 7-5/8"test 0.0 0.0 15:30 15:45 joint. Blow down kill line and test equipment. 3/11/2016 3/11/2016 1.25 INTRM1 CASING RURD P Rig up to run 7-5/8"29.7#L-80 Hydril 0.0 0.0 15:45 17:00 563 casing. 3/11/2016 3/11/2016 0.75 INTRM1 CASING PUTB P Run in hole with 7-5/8"29.7ppf L80 0.0 168.0 17:00 17:45 Hydril 563 casing to 168'MD. Baker- Loc shoe track.Pump through to check floats(Good). Page 14/38 Report Printed: 4/5/2016 411 6/ 41(1: Aerations Summary (with Timelog 6epths) F 2S-11 ConocoPhiiiips5,". Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase '; Op Code Activity Code Time P-T-X Operation (ftKB). Did Depth MKS)' 3/11/2016 3/11/2016 5.50 INTRM1 CASING PUTB P Continue with 7-5/8"casing to 168' 168.0 2,847.0 17:45 23:15 MD to 2847'MD. Monitor displacement via Pits#2 and#3. Connections are torqued to 14.4k ft- lbs. PU wt=111k,SO wt=105k. 3/11/2016 3/12/2016 0.75 INTRM1 CASING CIRC P Circulate bottoms up while 2,847.0 2,847.0 23:15 00:00 reciprocating from 2847'MD to 2807' MD using 6BPM, 145psi, 15%flow out. 3/12/2016 3/12/2016 4.25 INTRM1 CASING PUTB P Run in hole with 7-5/8"29.7ppf, L-80 2,847.0 5,169.0 00:00 04:15 Hydril 563 casing from 2847'MD to 5169'MD. PU wt=143k,SO wt=113k. Monitor displacement via pits#2 and#3. Torque connections to 14.4k ftlbs. 3/12/2016 3/12/2016 1.00 INTRMI CASING WASH P Casing started to take weight(20k)@ 5,169.0 5,249.0 04:15 05:15 5169'MD. Establish circulation at 2BPM,362psi, 13%flow out,and wash down to 5209'MD. Increase flow rate to 3 BPM,390psi, 16%flow out. Continue to wash down from 5209'MD to 5249'MD. Note:Fault drilled at 5196'MD 3/12/2016 3/12/2016 1.75 INTRM1 CASING PUTB P Continue running in the hole with 7- 5,249.0 6,120.0 05:15 07:00 5/8"casing from 5249'MD to 6120' MD. Monitor displacement via pit#2 and#3. 3/12/2016 3/12/2016 1.50 INTRM1 CASING WASH P Wash casing down with 7-5/8"casing 6,120.0 6,154.0 07:00 08:30 from 6120'MD to 6154'MD while staging up pumps from 2 BPM to 6 BPM. Initial Circulating Pressure= 325psi and Final Circulating Pressure=230psi, 15%flow out. PU wt= 187k,SO wt=134k. 3/12/2016 3/12/2016 3.50 INTRMI CASING PUTB P Continue running in the hole with 7- 6,154.0 8,205.0 08:30 12:00 5/8"casing from 6154'MD to 8205' MD. Monitor displacement via pit#2 and#3. SO wt= 139k. 3/12/2016 3/12/2016 1.75 INTRM1 CASING WASH P Wash down with 7-5/8"casing from 8,205.0 8,443.0 12:00 13:45 8205'MD to 8443'MD using 150 GPM,480 psi, 19%flow out. At initial circulation,mud weight returning was 10.5ppg,after circulation was 9.6+ppg. 3/12/2016 3/12/2016 0.50 INTRM1 CASING HOSO P Make up 7-5/8"hanger and landing 8,443.0 8,485.3 13:45 14:15 joint. Wash down at 130 GPM, 360psi, 17%flow out, SO wt=146k. Hanger landed at 14:15,3/12/2016 Page 15/38 Report Printed: 4/5/2016 xN, '"b Operations Summary (with Timelog•pths) Attir • 2S-11 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth '..Start Time End Time Our(hr) ',. Phase Op Code Activity Code Time P-T-X Operation {ft(B)', End,Depth(ftKB) 3/12/2016 3/12/2016 0.50 INTRM1 CEMENT CIRC P Circulate while reciprocating. Stage 8,485.3 8,485.3 14:15 14:45 up pumps to 5BPM,300psi, 15%flow out. PU wt=262k,SO wt=146k,MWin= 9.9ppg MWout=10.2ppg 3/12/2016 3/12/2016 0.25 INTRM1 CEMENT RURD P Blow down top drive and rig up 8,485.3 8,485.3 14:45 15:00 cement hose 3/12/2016 3/12/2016 1.75 INTRM1 CEMENT CIRC P Circulate while reciprocating.Stage up 8,485.3 8,485.3 15:00 16:45 to 6 BPM,330psi, 16%flow out;7 BPM,500psi, 17%flow out;and 8 BPM,560psi, 18%flow out. MWin/out=9.9+ppg. PU wt=270k,SO wt=145k. 3/12/2016 3/12/2016 3.25 INTRM1 CEMENT CMNT P 1st Stage Cement 7-5/8"casing: 8,485.3 8,485.3 16:45 20:00 Pump 5 bbl water,test trips on cement unit and pressure test cement lines to 3500psi(Good Test). Pump 40bbl of 11.5ppg Mud Push II at 4.7 BPM, 285psi,drop bottom plug and chase with 134bbls of 15.8ppg cement @ 5.7 BPM,250psi. Drop shut off plug and pump 2bbls of cement on top and chase with 1 Obbls of H2O from cement unit. Swap to rig pumps and continue displacment using drill mud (9.9+ppg)at 7 BPM, 160psi. Final circulating pressure was 3 BPM, 725psi. Plug bumped at 3660stk and pressured up to 1225psi for 5min. Bleed off 3.5bbls and check floats (Floats holding). Pressure up to shear stage tool. Shearted out at 2740psi. Verified open with 3 BPM,290psi, 12%flow out. Cement in place at 19:15hrs,3/12/2016. 3/12/2016 3/12/2016 1.25 INTRM1 CEMENT CIRC P Circuate bottoms up through stage 8,485.3 8,485.3 20:00 21:15 tool using 7 BPM,440 psi, 17%flow out. Page 16/38 Report Printed: 4/5/2016 • Operations Summary (with Timelog�pths) 4, e . 2S-11 ConocoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)', 3/12/2016 3/12/2016 2.25 INTRM1 CEMENT CMNT P 2nd Stage Cement 7-5/8"casing 8,485.3 0.0 21:15 23:30 (Stage Tool): Pump 5bbl of H2O.Test trips on cement unit and pressure test cement lines to 3500psi(Good Test). Pump 43.3bbl of 11.5ppg Mud Push II at 5.0 BPM,212psi. Chase with 90.1 bbls of 15.8ppg cement at 5.2 BPM,200 psi. Drop closing plug and pump 2bbls of cement on top of plug followed by I Obbls of H2O from cement unit. Swap over to rig pumps and continue displacing cement with initial circulating rate of 7BPM, 160 psi and a final circulating rate of 3 BPM, 710psi. Bump plug at 2790stks and pressure up to 1770psi,observe stage tool close,hold pressure for 5min. Bleed off 3 bbls and check floats. (Floats holding).Cement in place at 23:18,3/12/2016. Note:35 bbls lost during cement job. 3/12/2016 3/13/2016 0.50 INTRM1 CEMENT RURD P Rig down volant casing running tool. 0.0 0.0 23:30 00:00 Blow down top drive and pull landing joint. 3/13/2016 3/13/2016 2.00 INTRM1 CEMENT WWSP P Make up 10-3/4"x 7-5/8"pack-off and 0.0 0.0 00:00 02:00 install. Run in lock down screws. Test to 5000psi for 10min (Witnessed by CPAI rep:Kurt Alexa-Good Test). Concurrently,remove 7-5/8"casing tools from rig floor,clean all cement valves,and lay down landing joint. 3/13/2016 3/13/2016 1.00 INTRM1 CEMENT OTHR P Spring ahead with clocks 0.0 0.0 02:00 03:00 3/13/2016 3/13/2016 1.00 INTRM1 CEMENT BOPE P Pick up 4"test joint and set test plug. 0.0 0.0 03:00 04:00 Concurrently,change out upper 7-5/8" casing rams to 2-7/8"x 5-1/2"pipe rams. Test upper rams with 4"test joint to 250psi/3500psi for 5/5min (Good Test). Pull test plug and lay down 4"test joint. 3/13/2016 3/13/2016 0.50 INTRMI CEMENT RURD P Install 5"elevators and PS-21 9-5/8" 0.0 0.0 04:00 04:30 slip inserts. Pick up and install 9-5/8" mousehole. 3/13/2016 3/13/2016 11.25 INTRMI CEMENT PULD P Lay down 5"drill pipe 0.0 0.0 04:30 15:45 Concurrently,perform injectivity test on OA. 5 bbls pumped,broke over at 480psi. Flush OA with 113bbls fresh water. Load and prepare 4-1/2"tubing in casing shed. 3/13/2016 3/13/2016 0.50 INTRM1 CEMENT RURD P Lay down mouse hole, Pick up test 0.0 0.0 15:45 16:15 joint and set wear bushing 3/13/2016 3/13/2016 1.75 INTRM1 CEMENT RURD P Change out saver sub to XT-39. 0.0 0.0 16:15 18:00 Change out elevators and slip inserts. Page 17/38 Report Printed: 4/5/2016 ,„,.„,,,,t„,,,,,,, • • iiii,„ N°, - Operations Summary (with Timelog Depths) 4, 2S-11 Conoccehiiiips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr)..; Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/13/2016 3/13/2016 1.75 INTRM1 CEMENT PULD P Run in hole picking up 4"HWDP to 0.0 1,658.0 18:00 19:45 1658'MD. Monitor displacement via trip tank. Concurrently,freeze protect OA with Little Red Services: Flood lines and test to 1500psi(Good Test). Pump 91 bbls of Isotherm @ 2 BPM. Initial Circulating Pressure=800psi;Final Circulating Pressure=1250psi. Continue to load and prepare 4"drill pipe into casing shed. 3/13/2016 3/13/2016 2.25 INTRM1 CEMENT PULD P Run in hole with 52 doubles from 1,658.0 4,947.0 19:45 22:00 1658'MD to 4947'MD. Montior displacement via trip tank. 3/13/2016 3/13/2016 1.00 INTRM1 CEMENT PULD P Run in hole with 34singles from 4947' 4,947.0 6,022.0 22:00 23:00 MD to 6022'MD. Monitor displacment via trip tank. PU wt= 151k,SO wt=97k 3/13/2016 3/14/2016 1.00 INTRM1 CEMENT TRIP P Trip out of hole from 6022'MD to 6,022.0 3,746.0 23:00 00:00 3746'MD. Monitor displacment via trip tank. 3/14/2016 3/14/2016 2.75 INTRM1 CEMENT TRIP P Pull out of hole on elevators racking 3,746.0 0.0 00:00 02:45 back 4"drill pipe from 3746'MD to surface. Monitoring displacement viat trip tank#1. 3/14/2016 3/14/2016 0.50 INTRM1 CEMENT RURD P Clean rig floor prior to picking up next 0.0 0.0 02:45 03:15 run of 4"drill pipe. 3/14/2016 3/14/2016 5.75 INTRM1 CEMENT PULD P Pick up 189 joints of XT-39 4"drill pipe 0.0 5,962.0 03:15 09:00 from pipe shed and run in hole to 5962'MD while monitoring displacement via trip tank#1. 3/14/2016 3/14/2016 0.50 INTRM1 CEMENT CIRC P Circulate one drill string volume at 5,962.0 5,962.0 09:00 09:30 5962'MD using 350 GPM, 1179 psi, 19%flow out. Pump dry job.blow down top drive PU wt= 130k,SO wt=88k. 3/14/2016 3/14/2016 2.50 INTRM1 CEMENT TRIP P Pull out of hole on elevators racking 5,962.0 0.0 09:30 12:00 back 4"drill pipe from 5962'MD to surface. Monitoring displacment via trip tank#1. 3/14/2016 3/14/2016 3.00 INTRMI CEMENT PULD P Pick up 99 joints of XT-39 4"drill pipe 0.0 3,120.0 12:00 15:00 from pipe shed and run in hole to 3120'MD while monitoring displacement via trip tank#1. 3/14/2016 3/14/2016 1.00 INTRM1 CEMENT SLPC P Slip and cut 94'of 6x19 Extra 3,120.0 3,120.0 15:00 16:00 Improved Plow steel Drill line. 3/14/2016 3/14/2016 0.75 INTRM1 CEMENT SVRG P Service top drive,blocks and crown. 3,120.0 3,120.0- 16:00 16:45 Calibrate Amphion,TOTCO and Schlumberger block height. 3/14/2016 3/14/2016 1.50 INTRM1 CEMENT TRIP P Pull out of hole on elevators racking 3,120.0 0.0 16:45 18:15 back stands from 3120'MD to surface. Monitoring displacement via trip tank #1. 3/14/2016 3/14/2016 0.50 INTRMI WHDBOP RURD P Pull wear bushing and install test plug 0.0 0.0 18:15 18:45 3/14/2016 3/14/2016 0.50 INTRM1 WHDBOP RURD P Rig up for BOPE system test,flood 0.0 0.0 18:45 19:15 lines and perform shell test. Page 18/38 Report Printed: 4/5/2016 • • " tier Operations Summary (with Timelog Depths) 2S-11 ks conocomihps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X ' Operation (MKS) End Depth(ftKB) 3/14/2016 3/15/2016 4.75 INTRM1 WHDBOP BOPE P Test BOPE(witness waived by 0.0 0.0 19:15 00:00 AOGCC Rep Jeff Jones):All tests 250psi low/3500psi high for 5 charted minutes with exception of manual operated and super choke(250psi low/2000psi high)for 5 charted minutes. Using 4" test joints,test annular,2-7/8"x5-1/2"UPR,2-7/8"x5- 1/2"LPR,With 4-1/2"test joint test annular,choke Valves#1 to#15, Manual Operated and super choke, choke and kill manuals and HCR's,4" valve on kill line,4"TIW,4"dart,3- 1/2"TIW,3-1/2"dart and upper and lower IBOP's, Perform Koomy drawdown(Prior to: Accu m u l a to r=2950 ps i, Manifold=1500psi,Function 3 rams and Annular,After test Accumulator= 1550psi,20sec for 200psi with 2 electric pump, 127sec to build system to full pressure with 2 electric and 2 air pumps.Closing times:Annular- 23sec;UPR-18sec;Blind/Shears- 24sec;LPR-16sec;Choke HCR- 2sec;Kill HCR-2 sec. Perform CPAI Pump Performance test with UPR/LPR/HCR:59 sec for 2 electric pumps and 156sec for 2 air pumps. 3/15/2016 3/15/2016 0.50 INTRM1 WHDBOP BOPE P Continue to test BOPE,AOGCC rep 0.0 0.0 00:00 00:30 Jeff Jones waived witness of test.Test with 4-1/2"test joint.Test upper and lower variable rams(2-7/8"x 5-1/2")to 250 psi low and 3500 psi high,hold each test f/5 minutes,charted tests. 3/15/2016 3/15/2016 1.00 INTRM1 WHDBOP RURD P Pull test plug,then install Cameron 0.0 0.0 00:30 01:30 10"ID wear bushing.Run in(2)lock down screws.Lay down the 4-1/2"test joint. Blow down the choke manifold, choke and kill lines. 3/15/2016 3/15/2016 3.25 INTRM1 CEMENT BHAH P Pick up 6-3/4"production bottom hole 0.0 415.0 01:30 04:45 assembly.Make up and run in the hole to 415'.Monitor the displacement via the trip tank. 3/15/2016 3/15/2016 0.25 INTRM1 CEMENT RURD P Remove hand slips,install 4"inserts in 415.0 415.0 04:45 05:00 the PS-21 flush mount slips. 3/15/2016 3/15/2016 0.75 INTRM1 CEMENT TRIP P Trip in the hole w/bottom hole 415.0 2,305.0 05:00 05:45 assembly on 4"XT-39 drill pipe from 415'to 2305'. Monitor the displacement via the trip tank. 3/15/2016 3/15/2016 0.50 INTRM1 CEMENT DHEQ P Fill pipe,then shallow test 2,305.0 2,305.0 05:45 06:15 Schlumberger MWD tools. Pumping 232 gpm w/1190 psi 17%flow out.All checks good.Pumped 118 bbls.Blow down the top drive. 3/15/2016 3/15/2016 2.25 INTRM1 CEMENT TRIP P Continue to trip in the hole w/bottom 2,305.0 6,189.0 06:15 08:30 hole assembly on 4"XT-39 drill pipe from 2305'to 6189'. Monitor the displacement via the trip tank. PU wt 147k,SO wt 94k. Page 19/38 Report Printed: 4/5/2016 •erations Summary (with Timelog Depths) 014)1t wow oluollmullle &■ells 2S-11 ConocoPhiliips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time -Ertti 3'itn0 Out(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB} End Depth(ftKB)'.. 3/15/2016 3/15/2016 0.75 INTRM1 CEMENT COCF P Wash down from 6189'to top of 6,189.0 6,237.0 08:30 09:15 cement @ 6237'.Pumping 230 gpm w/1512 psi, 15%flow out.Set down 10k bit weight. 3/15/2016 3/15/2016 0.75 INTRM1 CEMENT COCF P Drill cement f/6237'to 6295'.Pumping 6,237.0 6,295.0 09:15 10:00 230 gpm w/1573 psi, 16%flow out. Rotate 40 rpm w/8k ft lbs of torque. Weight on bit 5k.PU wt 147k,SO wt 94k,Rot wt 117,with off bottom torque 7k ft lbs. 3/15/2016 3/15/2016 1.00 INTRM1 CEMENT CIRC P Circ 2 bottoms up to clean hole for 6,295.0 6,295.0 10:00 11:00 casing test above the stage tool. Pumping 230 gpm w/1558 psi, 16% flow out.Rotate and reciprocate from 6280'to 6295'.Rotating 40 rpm w/8k ftlbs torque.PU wt 147k,SO wt 94k, Rot wt 117k,Rot torque 7k ftlbs. 3/15/2016 3/15/2016 0.50 INTRM1 CEMENT TRIP P Stand back a stand from 6295'to 6,295.0 6,283.0 11:00 11:30 6283'. Blow down the top drive. 3/15/2016 3/15/2016 0.25 INTRM1 CEMENT RURD P Rig up to test the 7-5/8"29.7 ppf L-80 6,283.0 6,283.0 11:30 11:45 Hyd 563 casing. 3/15/2016 3/15/2016 0.50 INTRM1 CEMENT PRTS P Test the casing to 3600 psi for 10 6,283.0 6,283.0 11:45 12:15 minutes w/'100 psi leak off in 15 minutes,pump back up to 3600 psi with simular results. 3/15/2016 3/15/2016 0.25 INTRM1 CEMENT RURD P Rig down testing equipment. 6,283.0 6,283.0 12:15 12:30 3/15/2016 3/15/2016 1.25 INTRM1 CEMENT COCF P Continue to drill cement in the 7-5/8" 6,283.0 6,330.0 12:30 13:45 casing f/6295'to 6318'(tagged up on Weatherford closing plug 12'higher than expected).Drill Weatherford closing plug,then cement to 6330'. Pumping 230 gpm w/1610 psi, 15% flow out.Rotate 40-70 rpm w/9k ft lbs of torque.PU wt 147k,SO wt 95k. Rotating weight 116k w/8.5k ftlbs of torque.Drill w/3-12k weight on bit. Tag Weatherford stage tool @ 6330'. Re-tag and confirm depth of 6330'. 3/15/2016 3/15/2016 1.25 INTRM1 CEMENT CIRC P Circulate,reciprocate and rotate from 6,330.0 6,330.0 13:45 15:00 6328'to 6280'.Pumping 230 gpm w/ 1580 psi, 14%flow out.Rotate 40 rpm w/8.5k ft lbs of torque.Pumped 410 bbls.Mud weight in and out 9.8 ppg. 3/15/2016 3/15/2016 1.00 INTRM1 CEMENT DRLG P Drill out Weatherford stage tool f/ 6,330.0 6,469.0 15:00 16:00 6330'to 6332'.Pumping 230 gpm w/ 1540 psi, 14%flow out.Rotate 40-60 rpm w/7-14k ft lbs of torque.Weight on bit 1-4k.Work through stage tool 3 times with out pumps and rotary-ok. Wash and ream to 6469'. PU wt 151k,SO wt 100k. 3/15/2016 3/15/2016 1.25 INTRM1 CEMENT TRIP P Blow down the top drive,then trip in 6,469.0 8,179.0 16:00 17:15 the hole from 6469'to 8179'MD 3/15/2016 3/15/2016 0.25 INTRM1 CEMENT COCF P Wash and ream f/8178'to 8280'MD, 8,179.0 8,280.0 17:15 17:30 pumping 230 gpm w/1795 psi, 14% flow out. Rotate 40 rpm w/9k ft lbs of torque. Page 20/38 Report Printed: 4/5/2016 �.z Operations Summary (with Timelog Depths) , . . t2S-11 Phillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)'.. 3/15/2016 3/15/2016 1.00 INTRM1 CEMENT COCF P Tag top of cement @ 8280'MD w/ 8,280.0 8,325.0 17:30 18:30 10K to verify. Drilled cement f/8280' to 8325'MD,pumping 230 gpm w/ 1815 psi, 14%flow out.Rotate 40 rpm w/11-13k ft lbs of torque,6k WOB. 3/15/2016 3/15/2016 2.00 INTRM1 CEMENT CIRC P Pump 20 BBL hi vis sweep and chase 8,325.0 8,325.0 18:30 20:30 with mud pumping 230 gpm w/1700 psi, 14%flow out.Rotate 50 rpm w/ 12k ft lbs of torque. 3/15/2016 3/15/2016 1.50 INTRM1 CEMENT PRTS P Perform 30 Min 7-5/8"casing @ 8325' 8,325.0 8,325.0 20:30 22:00 MD to 3500 PSI,charted and witnessed. Good test. PU=207K, SO= 102K,ROT= 129K. 3/15/2016 3/16/2016 2.00 INTRM1 CEMENT DRLG P Drill cement and float equipment f/ 8,325.0 8,359.0 22:00 00:00 8325'to 8359'MD @ 230 gpm, 1670 psi, 13%FO,60 rpm, 12k TQ and 7k WOB. Tag Baffle collar @ 8353'MD and drill out w/150-230 GPM,3-15k, WOB and 40-70 rpm. 3/16/2016 3/16/2016 4.25 INTRM1 CEMENT DRLG P Cont.to drill cement and float 8,359.0 8,492.0 00:00 04:15 equipment f/8359'to 8492'MD @ 230 gpm, 1500 psi, 13%FO,60 rpm, 12k TQ and 7k WOB. Tag Float collar @ 8398'MD and tag float shoe @ 8483' MD. 3/16/2016 3/16/2016 1.25 INTRM1 CEMENT DDRL P Cont.drilling 6-3/4"production hole 8,492.0 8,512.0 04:15 05:30 from 8492'to 8512"MD(20'new hole) with 230 GPM, 1715 psi, 14%flow out,60 RPM, 11k TQ, 11 k WOB, PU wt=210k,SO wt=101 k,ROT wt=134k, with 12k off bottom TQ. 3/16/2016 3/16/2016 1.75 INTRM1 CEMENT CIRC P Circulate BU while rotate and recip f/ 8,512.0 8,512.0 05:30 07:15 8512'to 8459'MD with 230 GPM, 1680 psi, 14%flow out,60 RPM, 12k TQ, Pumped a total of 415 BBLS. MW In=9.7 PPG,MW out=9.7,PU wt=210k,SO wt=101 k, ROT wt=134k. 3/16/2016 3/16/2016 1.25 INTRM1 CEMENT LOT P POOH f/8512'to 8459'MD. Conduct 8,512.0 8,512.0 07:15 08:30 LOT to 14.7 PPG EMW. 5.4 BBL pumped,2.7 BBL bled back. 3/16/2016 3/16/2016 2.25 PROD1 DRILL DDRL P Displace well to 10.5 PPG FloPro 8,512.0 8,543.0 08:30 10:45 while drilling 6-3/4"production hole from 8512'to 8543"MD with 230 GPM,2350 psi, 14%flow out,60 RPM, 10k TQ, ilk WOB,ECD 11.4 PPG. Pumped 450 BBLs. PU wt=164k,SO wt=114k,ROT wt=133k, with 8k off bottom TQ.ART/ ADT=1.52,Total bit hrs= 1.52 Total Jar hrs= 1.52 3/16/2016 3/16/2016 1.25 PROD1 DRILL MPDA P OWFF. Pull Trip nipple and install 8,543.0 8,543.0 10:45 12:00 MPD bearing and calibrate same. Obtain Slow pump rates. 3/16/2016 3/16/2016 2.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 8543' 8,543.0 8,648.0 12:00 14:00 to 8648"MD with 260 GPM,2560 psi, 19%flow out, 100 RPM, 10k TQ, ilk WOB,ECD 11.63 PPG. Off bottom= 2550 psi. PU wt=167k,SO wt=100k, ROT wt=129k,with 9k off bottom TQ. Page 21/38 Report Printed: 4/5/2016 iirrf Operations Summary (with Timelog Depths) air 2S-11 ConocoPhiltitps ;afask.� Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time as(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/16/2016 3/16/2016 1.25 PROD1 DRILL CIRC P Drop Rhino Reamer activation ball @ 8,648.0 8,648.0 14:00 15:15 8630'MD and pump down @ 110 GPM,980 PSI, 10 RPM,7K TQ. Ball on seat @ 470 stks,pres up to 2920 PSI and observe shear. PU into shoe w/10K overpull to verify open. Ream down f/8630'to 8648'MD. 3/16/2016 3/16/2016 2.75 PROD1 DRILL DDRL P Drill 6-3/4"X 7-1/2" production hole 8,648.0 8,855.0 15:15 18:00 from 8648'to 8855"MD,6274'TVD with 350 GPM,3060 psi,22%flow out, 130 RPM, 10k TQ, 12k WOB, ECD 12.13 PPG. Off bottom=3040 psi. PU wt=176k,SO wt=98k, ROT wt=128k,with 9k off bottom TQ.ART/ ADT=3.49,Total bit hrs=5.01 Total Jar hrs=5.01 3/16/2016 3/16/2016 5.00 PROD1 DRILL DDRL P Drill 6-3/4"X 7-1/2" production hole 8,855.0 9,185.0 18:00 23:00 from 8855'to 9185"MD,6388'TVD (open to 7-1/2"to 9045'MD)with 350 GPM,3100 psi,22%flow out, 100 RPM, 12k TQ,8k WOB,ECD 12.06 PPG. Off bottom=3050 psi. PU wt=171k,SO wt=98k,ROT wt=130k, with 10k off bottom TQ.ART/ADT= 4.0,Total bit hrs=9.01 Total Jar hrs= 9.01 3/16/2016 3/17/2016 1.00 PROD1 DRILL CIRC P Circulate BU while rotate and recip f/ 9,185.0 9,185.0 23:00 00:00 9183'to 9117'MD with 350 GPM, 3000 psi,22%flow out, 120 RPM, 12k TQ, 11.96 PPG. Pumped a total of 330 BBLS. MW In/Out=10.5 PPG, PU wt=163k,SO wt=101k, ROT wt=123k. Obtain slow pump rates. 3/17/2016 3/17/2016 2.00 PROD1 DRILL SMPD P Strip out of hole f/9185'to 8457'MD. 9,185.0 8,457.0 00:00 02:00 Used MPD pres sch w/690 psi on choke while POOH and 450 psi in slips. 3/17/2016 3/17/2016 0.75 PROD1 DRILL OWFF P Conduct MPD drawdown test. 8,457.0 8,457.0 02:00 02:45 Observe 68 PSI increase for each bleed-off. 3/17/2016 3/17/2016 1.50 PROD1 DRILL CIRC P Circulate BU while rotate and recip f/ 8,457.0 8,457.0 02:45 04:15 8457'MD with 300 GPM,2305 psi, 21%flow out, Pumped a total of 585 BBLS. PU wt=145k,SO wt=100k, 3/17/2016 3/17/2016 0.75 PROD1 DRILL CIRC P Drop 1.75"ball to open Well 8,457.0 8,457.0 04:15 05:00 Commander and pump down @ 85 GPM,671 psi. Ball on seat at 319 stks. Pres up to 3150 psi in 500 psi increments until sleeve opened. 3/17/2016 3/17/2016 2.50 PROD1 DRILL DISP P Displace well while rotate and recip f/ 8,457.0 8,457.0 05:00 07:30 8457'to 8425'MD with 300 to 100 GPM, 1058 to 288 psi, 13%flow out, 20 RPM,7k TQ, Pumped a total of 385 BBLS. MW In=11.9 PPG,MW out=11.9,PU wt=165k,SO wt=107k, ROT wt=117k. 3/17/2016 3/17/2016 0.75 PROD1 DRILL CRC P Drop 1.75"ball to close Well 8,457.0 8,457.0 07:30 08:15 Commander and pump down @ 85 GPM, 185 psi. Ball on seat at 337 stks. Pres up to 2725 psi in 500 psi increments until sleeve closed. Page 22/38 Report Printed: 4/5/2016 t,z.„,. • a Operations Summary (with Timelog Depths) . `1 2S-11 ConoccifIlitlips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) '; Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/17/2016 3/17/2016 1.25 PROD1 DRILL MPDA P Pull MPD bearing and instal trip 8,457.0 8,457.0 08:15 09:30 nipple. OWFF.(static) 3/17/2016 3/17/2016 0.50 PROD1 DRILL SVRG P Service PS21 slips,topdrive and 8,457.0 8,457.0 09:30 10:00 blocks. 3/17/2016 3/17/2016 3.50 PROD1 DRILL TRIP P POOH on elevators f/8457' to 416' 8,457.0 416.0 10:00 13:30 MD. PU=165k,SO=107k. 3/17/2016 3/17/2016 0.25 PROD1 DRILL OWFF P Monitor well f/10 min. 416.0 416.0 13:30 13:45 3/17/2016 3/17/2016 1.75 PROD1 DRILL BHAH P POOH w/BHA to 125'. Remove 416.0 125.0 13:45 15:30 source f/BHA. Stand back HWDP and DC's. Lay down Well Commander and Rhino Reamer. 3/17/2016 3/17/2016 0.50 PROD1 DRILL BHAH P POOH and inspect BHA&bit 125.0 0.0 15:30 16:00 3/17/2016 3/17/2016 0.25 PROD1 DRILL BHAH P Clean&clear rig floor. 0.0 0.0 16:00 16:15 3/17/2016 3/17/2016 1.25 PROD1 DRILL BHAH P PU BHA,install RA source,cont RIH 0.0 388.0 16:15 17:30 w/BHA out of derrick to 388'MD. 3/17/2016 3/17/2016 0.50 PROD1 DRILL TRIP P TIH f/388'to 1803'MD. 388.0 1,803.0 17:30 18:00 3/17/2016 3/17/2016 0.50 PROD1 DRILL DHEQ P Perform shallow hole test on MWD 1,803.0 1,803.0 18:00 18:30 (good) 3/17/2016 3/17/2016 3.25 PROD1 DRILL TRIP P Cont. RIH f/1803'to 8434'MD. PU= 1,803.0 8,434.0 18:30 21:45 172k,SO= 102k 3/17/2016 3/17/2016 0.25 PROD1 DRILL MPDA P Pull trip nipple, Install MPD bearing 8,434.0 8,434.0 21:45 22:00 3/17/2016 3/18/2016 2.00 PROD1 DRILL DISP P Establish circ thru MPD manifold. 8,434.0 8,434.0 22:00 00:00 Displace well to 10.5 ppg FloPro while rot and recip f/8480'to 8428'MD. Pump 40 BBL hi-vis spacer followed by mud. Follow MPD rate/pressure schedule. 3/18/2016 3/18/2016 0.50 PROD1 DRILL DISP P Cont.displacing well to 10.5 ppg 8,434.0 8,434.0 00:00 00:30 FloPro mud. Rot and recip while pumping @ 230 gpm,2060 psi and 60 rpm. Pumped 440 BBL. 3/18/2016 3/18/2016 0.50 PROD1 DRILL SMPD P Strip in hole f/8434'to 8529.MD. B/D 8,434.0 8,529.0 00:30 01:00 topdrive. PU wt=169k,SO wt=100k, ROT wt=115k,with 8k off bottom TQ. 3/18/2016 3/18/2016 3.25 PROD1 DRILL SMPD P Strip in hole f/8529'tp 8563'MD and 8,529.0 9,092.0 01:00 04:15 sat down taking 25k Dn Wt. Made up top drive and rotate while stripping in hole per MPD schedule(440 psi when RIH&480 psi in slips)w/10 RPM,8- 12k TQ f/8529'to 9092'MD. 3/18/2016 3/18/2016 0.75 PROD1 DRILL CIRC P Circulate BU while rotate and recip f/ 9,092.0 9,185.0 04:15 05:00 9092'to 9185'MD staging pumps up to 250 GPM,2627 psi, 17%flow out, 130 RPM, 10k TQ, Pumped a total of 340 BBLS. MW In=10.3PPG, MW out= 10.3+, PU wt=163k,SO wt=101 k,ROT wt=123k. Page 23/38 Report Printed: 4/5/2016 s • Operations Summary (with Timelog Depths) 3 2S-11 dlY ConocoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End.Depth MKS) 3/18/2016 3/18/2016 7.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 9185' 9,185.0 9,805.0 05:00 12:00 to 9805'MD,6302'TVD with 250 GPM,2270 psi,20%flow out, 130 RPM, 12k TQ,8k WOB, ECD 11.82 PPG. Off bottom=2485 psi. PU wt=156k,SO wt=101 k,ROT wt=126k,with 10k off bottom TQ. ART/ADT=4.49,Total bit hrs=4.49 Total Jar hrs= 13.6 3/18/2016 3/18/2016 6.25 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 9805' 9,805.0 10,609.0 12:00 18:15 to 10609'MD,6299'TVD with 260 GPM,2500 psi,20%flow out, 130 RPM, 13k TQ, 11k WOB, ECD 11.94 PPG. Off bottom=2480 psi. PU wt=179k,SO wt=96k,ROT wt=129k,with 10k off bottom TQ. ART/ADT=4.17,Total bit hrs=8.76 Total Jar hrs=17.77 3/18/2016 3/19/2016 5.75 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 10,609.0 11,364.0 18:15 00:00 10609'to 11364'MD,6339'TVD with 260 GPM,2619 psi,20%flow out, 140 RPM, 13k TQ,9k WOB,ECD 112.0 PPG. Off bottom=2598 psi. PU wt=200k,SO wt=89k,ROT wt=131k,with 11k off bottom TQ. ART/ADT=7.61,Total bit hrs=12.46 Total Jar hrs=21.47 3/19/2016 3/19/2016 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 11,364.0 11,966.0 00:00 06:00 11364'to 11966'MD,6351'TVD with 270 GPM,2985 psi, 18%flow out, 140 RPM, 12k TQ, 11k WOB,ECD 11.98 PPG. Off bottom=2874 psi. PU wt=194k,SO wt=84k,ROT wt=124k,with 11k off bottom TQ. ART/ADT=3.98,Total bit hrs=16.44 Total Jar hrs=25.45 3/19/2016 3/19/2016 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 11,966.0 12,598.0 06:00 12:00 11966'to 12598'MD,6311'TVD with 270 GPM,2903 psi, 18%flow out, 130 RPM, 11k TQ, 13k WOB,ECD 12.03 PPG. Off bottom=2816 psi. PU wt=194k,SO wt=87k,ROT wt=130k,with 10k off bottom TQ. ART/ADT=3.58,Total bit hrs=20.02 Total Jar hrs=29.03 3/19/2016 3/19/2016 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 12,598.0 13,060.0 12:00 18:00 12598'to 13060'MD,6321'TVD with 262 GPM,2790 psi, 18%flow out, 140 RPM, 12.5k TQ,9k WOB,ECD 12.07 PPG. Off bottom=2760 psi. PU wt=190k,SO wt=85k,ROT wt=125k,with 11k off bottom TQ. ART/ADT=3.59,Total bit hrs=23.61 Total Jar hrs=32.62. Page 24/38 Report Printed: 4/5/2016 0C44.-V, • • Operations Summary (with Timelog Depths) sp 2S-11 ConocraPhillmps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB), 3/19/2016 3/20/2016 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from13060' 13,060.0 13,645.0 18:00 00:00 to 13645'MD,6317'TVD with 260 GPM,2950 psi, 18%flow out, 140 RPM, 12k TQ, 10.5k WOB,ECD 12.25 PPG. Off bottom=2940 psi. PU wt=184k,SO wt=86k,ROT wt=128k,with 10k off bottom TQ. ART/ADT=4.34,Total bit hrs=27.93 Total Jar hrs=36.94. 3/20/2016 3/20/2016 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 13,645.0 14,355.0 00:00 06:00 13645'to 14355'MD,6281'TVD with 260 GPM,2986 psi, 19%flow out, 130 RPM, 12k TQ, 11k WOB,ECD 12.34 PPG. Off bottom=2920 psi. PU wt=183k,SO wt=84k,ROT wt=130k,with 10k off bottom TQ. ART/ADT=3.70,Total bit hrs=31.69 Total Jar hrs=40.70. 3/20/2016 3/20/2016 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 14,355.0 15,014.0 06:00 12:00 14355'to 15014'MD,6266'TVD with 260 GPM,3214 psi, 18%flow out, 140 RPM, 11k TQ, 14k WOB,ECD 12.36 PPG. Off bottom=3150 psi. PU wt=185k,SO wt=90k, ROT wt=133k,with 10k off bottom TQ. ART/ADT=3.91,Total bit hrs=35.60 Total Jar hrs=44.61. 3/20/2016 3/20/2016 4.50 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 15,014.0 15,216.0 12:00 16:30 15014'to 15216'MD,6267'TVD with 260 GPM,3260 psi, 19%flow out, 140 RPM, 11k TQ,3k WOB, ECD 12.21 PPG. Off bottom=3240 psi. PU wt=184k,SO wt=97k,ROT wt=134k,with 10k off bottom TQ. ART/ADT=4.05,Total bit hrs=39.65 Total Jar hrs=48.66. 3/20/2016 3/20/2016 1.25 PROD1 DRILL CIRC P Circulate BU while rotate and recip f/ 15,216.0 15,216.0 16:30 17:45 15122'to 15210'MD with 260 GPM, 3230 psi, 19%flow out, 140 RPM, 11k TQ,ECD= 12.15 PPG. Pumped a total of 450 BBLS. MW In= 10.5PPG, MW out= 10.5, 3/20/2016 3/20/2016 0.75 PROD1 DRILL MPDA P Change out MPD bearing and break in 15,216.0 15,216.0 17:45 18:30 same. 3/20/2016 3/20/2016 2.25 PROD1 DRILL DDRL P Drill 6-3/4"production hole to TD from 15,216.0 15,309.0 18:30 20:45 15216'to 15309'MD,6264'TVD with 260 GPM,3225 psi, 18%flow out, 140 RPM, 11k TQ,5k WOB,ECD 12.1 PPG. Off bottom=3210 psi. PU wt=182k,SO wt=100k,ROT wt=134k,with 10k off bottom TQ. ART/ADT=2.05,Total bit hrs=41.7 Total Jar hrs=50.71. Page 25/38 Report Printed: 4/5/2016 Operations Summary (with TimelogDepths) p 0 z 2S-11 Conocalhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End',Depth(ftK13), 3/20/2016 3/20/2016 1.75 PROD1 CASING CIRC P Circulate BU while rotate and recip f/ 15,309.0 15,309.0 20:45 22:30 15304'to 15300'MD with 270 GPM, 3380 psi, 19%flow out, 140 RPM, 10k TQ,ECD=12.22 PPG. Pumped a total of 460 BBLS. MW In=10.5PPG, MW out=10.5, PU wt=180k,SO wt=102k,ROT wt=136k 3/20/2016 3/20/2016 1.00 PROD1 CASING OWFF P Perform MPD drawdown test in 2 min. 15,309.0 15,309.0 22:30 23:30 increments. Final pres=280 psi, 11.4 ppg EMW, 10 BBLs.bled back. 3/20/2016 3/21/2016 0.50 PROD1 CASING CIRC P Circulate BU while rotate and recip f/ 15,309.0 15,309.0 23:30 00:00 15304'to 15300'MD with 270 GPM, 3230 psi, 19%flow out, 140 RPM, 10k TQ,ECD= 12.01 PPG. Pumped a total of 205 BBLS. MW In= 10.5PPG, MW out= 10.5, 3/21/2016 3/21/2016 4.50 PROD1 CASING CIRC P Circulate two BU while rotate and 15,309.0 15,030.0 00:00 04:30 recip f/15304'to 15213'MD with 270 GPM,3230 psi, 15%flow out, 140 RPM, 10k TQ,ECD= 12.01 PPG. Pumped a total of 935 BBLS. Observed 3500 units of gas at 4200 strokes and mud cut to 9.4 ppg. Rack back one stand while rotate and recip f/15210'to 15120'MD with 270 GPM, 3230 psi, 15%flow out, 140 RPM, 10k TQ,ECD=12.01 PPG,Rack back one more stand while rotate and recip f/ 15120'to 15030'MD Total pumped 1,760 BBLs. (4 BU)PU=180k,SO= 88k. 3/21/2016 3/21/2016 5.50 PROD1 CASING SMPD P Strip out of hole f/15030 to 13000'MD 15,030.0 13,000.0 04:30 10:00 while pumping 3 strokes/min,pulling 1000 Feet/hr,630 PSI, 13%flow out, while holding 470 psi backpressure w/ MPD.PU=162k,SO=92k prior to overpulls. 3/21/2016 3/21/2016 4.00 PROD1 CASING SMPD P Strip out of hole f/13000 to 11137' 13,000.0 11,137.0 10:00 14:00 MD while pulling 1000 Feet/hr,while holding 470 psi backpressure w/MPD. PU= 162k,SO=92k prior to overpulls. 11770'-11750' 6-20k overpull 11406-11360 20-35k overpull. Wipe down and pull with 5k over. 11137 40k overpull 3/21/2016 3/21/2016 4.00 PROD1 CASING SMPD T RIH f/11137 to 11455 and attempted 11,137.0 11,455.0 14:00 18:00 to circulate. Well packed off. Worked pipe and stage up pumps and RPM. Unable to circ past 1.8 BPM w/o packing off. 3/21/2016 3/21/2016 4.50 PROD1 CASING SMPD T Worked pipe down f/11455 to 11740' 11,455.0 12,188.0 18:00 22:30 MD and worked tite hole @ 11740'. Attempted to circ and packed off. Finally worked down to 12188'. Page 26/38 Report Printed: 4/5/2016 0 • ' .:::'11°Ik �erations Summary (with TimelogDepths) Operations ':: la 2S-11 ConocoPl idrp$ Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/21/2016 3/22/2016 1.50 PROD1 CASING CIRC T Stage pumps up to 1.4 BPM. Start 12,188.0 12,188.0 22:30 00:00 rotating and well packed off. 3/22/2016 3/22/2016 6.00 PROD1 CASING CIRC T Attempted to gain circulation at 12,188.0 12,755.0 00:00 06:00 12188'. Able to rotate at 10k TQ. Attempt to gain circ.at 12405'. Packed off. RIH to 12585'-Attempt to gain circ. Packed off. Increase MPD pres on annulus to 650 psi and attempt to gain circ.-Packed off.Reduced pres back to 470 psi. PU=167k,SO=80k,ROT=125k RIH to 12755'-Attempt to gain circ. Able to circ up to 5 SPM/750 psi, 14%FO, 10 SPM/887 psi, 17%FO, 15 SPM/975 psi, 17%FO-then packed off. Continual pack-offs after multiple circ attempts. 3/22/2016 3/22/2016 1.00 PROD1 CASING SMPD T POOH f/12755'to 11270'MD 12,755.0 11,270.0 06:00 07:00 attempting to regain circ on every stand. Continual pack-offs. 3/22/2016 3/22/2016 6.00 PROD1 CASING SMPD T POOH f/11270'to 11130'MD. Work 11,270.0 11,146.0 07:00 13:00 thru original stuck point. Pull 40k over at 11143'and work thru w/20 RPM,8 -12k TQ. Drop to 11146'MD 3/22/2016 3/22/2016 0.75 PROD1 CASING CIRC T Circ @ 11146'while staging up pumps 11,146.0 11,146.0 13:00 13:45 to 1.6 BPM/870 psi. Pumped 58 BBLs. 3/22/2016 3/22/2016 0.75 PROD1 CASING SMPD T POOH f/11146'to 10953'MD. PU= 11,146.0 10,953.0 13:45 14:30 160 to 190k,SO=96 to 86k. 3/22/2016 3/22/2016 2.50 PROD1 CASING CIRC T Circ©10953'while staging up pumps 10,953.0 10,953.0 14:30 17:00 to f/1 BPM to 2.7 BPM,810 psi, 10 RPM,7.7k TQ. Pumped 250 BBLs. 3/22/2016 3/22/2016 1.00 PROD1 CASING SMPD T POOH f/10953' to 10746'MD. Pull 10,953.0 10,759.0 17:00 18:00 50k over©10746'and attempt to work thru w/20 RPM,8-13k TQ. Unable to work past. Drop down to 10759'MD. 3/22/2016 3/23/2016 6.00 PROD1 CASING CIRC T Circulate @ 10759'and stage up 10,759.0 10,741.0 18:00 00:00 pumps to 4.5 BPM/1650 psi over 2 hours. Well packed off. Attempt to POOH and pulled to 10743'MD w/ 50k overpull. Attempted to circulate and well packed off. Pull up to 70k over to at 10741'with no movement. Dropped down and continued to attempt to regain circulation. 3/23/2016 3/23/2016 6.00 PROD1 CASING SMPD T Attempt to establish circulation while 10,741.0 10,690.0 00:00 06:00 working string f/10759'to 10743'MD. Used various flow rates and rotation. Backreamed through tight spot to 10690'MD continuing to pack-off during circulation attempts. Holding 470 psi on annulus w/MPD. Page 27/38 Report Printed: 4/5/2016 ,t m .a Operations Summary (with Timelog Depths) 2S-11 Conoccehiiiirrs Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation {ItKB) End Depth{RKB). 3/23/2016 3/23/2016 14.50 PROD1 CASING SMPD T Continue back-reaming/lubricating out 10,690.0 9,280.0 06:00 20:30 of hole f/10690'to 9280'MD. Staged pumps f/20 to 60 GPM @ 785 psi and 60 rpm, 9—10k TQ. Back- reaming/lubricating OOH from 10 up to 180 feet/hour. Increased rate up slowly until at 176 GPM, 1360 PSI, 22%FO,60 RPM,7.5 to 10K TQ, 180 FPH. Holding 470 psi on annulus w/ MPD. PU=160K,SO=98K, ROT=129K 3/23/2016 3/23/2016 1.00 PROD1 CASING CIRC T At 9280'MD,stage pumps up from 9,280.0 9,280.0 20:30 21:30 176 to 250 GPM and RPM up to 115 RPM and hole packed off. Attempt to reestablish circulation. Unsuccessful past 80 GPM. 3/23/2016 3/23/2016 1.00 PROD1 CASING CIRC T Drop down one stand to 9340'and 9,280.0 9,280.0 21:30 22:30 attempt to reestablish circulation. Unsuccessful after 2 attempts. On second attempt,brought pump up at 2 min per stroke and still packed-off. 3/23/2016 3/24/2016 1.50 PROD1 CASING SMPD T Strip out of hole f/9280'MD to 8690' 9,280.0 8,690.0 22:30 00:00 MD pumping 3 strokes/min for displacement. Had 30-40k overpull @ 8926',8860',8846'and 8787'. PU=155K,SO=94K 3/24/2016 3/24/2016 1.50 PROD1 CASING SMPD T Continue stripping out of hole f/8690' 8,690.0 8,474.0 00:00 01:30 to 8474'MD,into shoe. 40k overpull @ 8667',8623',8573'MD. Wiped clean but couldn't run back in hole without setting down wt. PU=160k, SO=85k 3/24/2016 3/24/2016 3.25 PROD1 CASING CIRC T Establish circulation rate @ 270 GPM, 8,474.0 8,474.0 01:30 04:45 2587'MD. Circ 2 BU while recip and rotate f/8474'to 8429'MD. Pump 37 BBL hi vis sweep. Pump 2 more BU. MW in/Out=10.5 ppg. Total pumped =970 BBLs' 3/24/2016 3/24/2016 0.50 PROD1 CASING SVRG T Inspect drilling line and service blocks, 8,474.0 8,474.0 04:45 05:15 topdrive. 3/24/2016 3/24/2016 1.50 PROD1 CASING SLPC T Slip and cut drill line. Calibrate block 8,474.0 8,474.0 05:15 06:45 height. 3/24/2016 3/24/2016 1.50 PROD1 CASING SVRG T Change out saver sub. 8,474.0 8,474.0 06:45 08:15 3/24/2016 3/24/2016 2.75 PROD1 CASING SMPD T Establish parameters inside of casing. 8,474.0 9,370.0 08:15 11:00 PU=138k,SO=107k, ROT= 110k,7 -8k TQ. RIH f/8474'to 9370'MD. Tite spots @ 8580',8671'and 8764' MD. Worked thru @ 3 Ft/min w/20 RPM,7-8k TQ and wiped each clean. Open hole PU=165k,SO=90k,ROT =124k,7-8k TQ. 3/24/2016 3/24/2016 1.75 PROD1 CASING CIRC T Attempt to establish circ while recip f/ 9,370.0 9,370.0 11:00 12:45 9370'to 9280'MD,20 rpm and 8-9k TQ. Packed off. Made 2nd attempt to circ and got up to 1.5 BPM and packed off. 3/24/2016 3/24/2016 0.25 PROD1 CASING SMPD T Strip in hole f/9370'to 9565'MD 9,370.0 9,565.0 12:45 13:00 Page 28/38 Report Printed: 4/5/2016 ,t ti Operations Summary (with Timelog•pths) rpt•, ' 2S-11 OP Co cad hilllps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time = End Time Dur(hr) Phase Op Code" Activity Code.. Time P-T-X Operation (EKE) " End Depth(ftKS)'... 3/24/2016 3/24/2016 9.75 PROD1 CASING CIRC T Wipe stand f/9565'to 9466'MD. 9,565.0 9,565.0 13:00 22:45 Established circulation @ 9466'MD staging up to 270 GPM,2580 psi, 140 rpm,7.5k TQ. Brought strokes up 1 stk per 5 min and Rotary 5 RPM per 5 min.Circ 1 full BU after 270 GPM and 140 RPM achieved. PU=149k,SO= 95k. 3/24/2016 3/25/2016 1.25 PROD1 CASING SMPD T Strip in hole on elevators f/9466'to 9,565.0 11,075.0 22:45 00:00 11075'MD with no issues. I/67 3/25/2016 3/25/2016 1.50 PROD1 CASING SMPD T Cont. RIH on elevators f/2075'to 11,075.0 13,053.0 00:00 01:30 13053'MD @ 60 FPM holding 470 psi backpressure w/MPD in slips and 160 psi when RIH. PU=171k,SO=84k. 3/25/2016 3/25/2016 2.50 PROD1 CASING CIRC T Slowly stage up pumps 1 Stk/min 13,053.0 12,963.0 01:30 04:00 and increase RPM at 2 RPM/ 5 min until rate at 270 GPM,2896 psi, 17% FO, 100 RPM,8-9k TQ, 11.9 ECD. CBU while recip @ 10-50 Ft/Hr f/ 13053'to 12963'MD. 3/25/2016 3/25/2016 6.00 PROD1 CASING BKRM T Backream OOH f/12963'to 11466' 12,963.0 11,466.0 04:00 10:00 MD @ 270 GPM,2846 psi, 18%FO, 100 RPM,8-9 TQ holding 470 psi on annulus w/MPD. Encounter brief pack-off and increase in torque @ 11478'MD. Drop down to 11466'MD. 3/25/2016 3/25/2016 2.00 PROD1 CASING CIRC T Circ 2 BU while recip and rotate f/ 11,466.0 11,466.0 10:00 12:00 11561'to 11466'MD @ 270 GPM, 120 RPM,8-9k TQ, 17%FO. Pumped 770 BBLs. 3/25/2016 3/25/2016 1.00 PROD1 CASING BKRM T Continue to backream OOH f/11466' 11,466.0 11,137.0 12:00 13:00 to 11137'MD @ 270 GPM,2530 psi, 25%FO, 100 RPM,6.5k TQ holding 470 psi on annulus w/MPD. Off trouble time after this 3/25/2016 3/25/2016 5.50 PROD1 CASING BKRM P Continue to backream OOH f/11137' 11,137.0 9,281.0 13:00 18:30 to 9281'MD @ 270 GPM,2530 psi, 25%FO, 100 RPM,6.5 TQ holding 470 psi on annulus w/MPD. 3/25/2016 3/25/2016 2.00 PROD1 CASING CIRC P Circ 2 BU while recip and rotate f/ 9,281.0 9,185.0 18:30 20:30 9281'to 9185'MD @ 270 GPM,2440 psi, 120 RPM,6k TQ, 125 FO. Pumped 600 BBLs. PU= 150k,SO= 106k. 3/25/2016 3/25/2016 2.50 PROD1 CASING SMPD P Strip OOH f/9185'to 8434'MD. 9,185.0 8,434.0 20:30 23:00 Observed 22k overpull @ 8585'to 8575'MD. Wiped 2 times w/same results. PU=145k,SO=105k. 3/25/2016 3/26/2016 1.00 PROD1 CASING CIRC P Circulate 40 BBL hi-vis sweep 8,434.0 8,434.0 23:00 00:00 followed by mud. Rotate and recip f/ 8475 to 8390'MD@ 270 GPM,2380 psi,25%FO, 100 RPM,5 TQ holding 470 psi on annulus w/MPD. 3/26/2016 3/26/2016 1.00 PROD1 CASING CIRC P Continue to circulate 2 BU while rotate 8,434.0 8,434.0 00:00 01:00 and recip f/8475 to 8390'MD@ 270 GPM,2380 psi,25%FO, 100 RPM, 5K TQ holding 470 psi on annulus w/ MPD. Pumped 620 BBLs total. PU= 245k,SO= 110k. Page 29/38 Report Printed: 4/5/2016 • 1 . • ....;gA44.0 -4.,,, Operations Summary (with Timelog Depths) 2S-11 4440 Camaccehiiiips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (MKS) End,Depth(ftKE), 3/26/2016 3/26/2016 1.75 PROD1 CASING DISP P Displace well to 11.9 ppg brine by 8,434.0 8,054.0 01:00 02:45 laying in 50 BBL hi vis brine pill followed by brine. POOHf/8434'to 8054'MD @ 2400 fUhr pumping 2 BPM. Displace well to brine while recip and rotate @ 270 GPM,2084 PSI,50 RPM,6K TQ, 12.10 ECD, Reduced rate to 240 GPM and pumped total of 330 BBLS. Ran out of brine due to MPD pump being lined up on brine instead of Flo-Pro mud.. v MW In=11.9,MW out=11.1. Shut in well. Observe build-up of 60 PSI. 3/26/2016 3/26/2016 3.50 PROD1 CASING WAIT T Wait on Kill Weight brine. 8,054.0 8,054.0 02:45 06:15 3/26/2016 3/26/2016 0.50 PROD1 CASING DISP T Cont.displacing well w/11.9 ppg brine 8,054.0 8,054.0 06:15 06:45 while recip and rotate @ 204 GPM, 1258 PSI,50 RPM. Pumped 156 BBLs. MW in 11.9,MW out=11.7. Observe 36 PSI annulus pres. 3/26/2016 3/26/2016 1.00 PROD1 CASING COND T Condition brine in returns pit to 11.8+ 8,054.0 8,054.0 06:45 07:45 ppg. Observe 36 PSI annulus pres. 3/26/2016 3/26/2016 1.25 PROD1 CASING CIRC T Cont.circ 11.8+ppg brine. Total 8,054.0 8,054.0 07:45 09:00 pumped 309 BBLs. MW In/Out=11.8 ppg. 3/26/2016 3/26/2016 0.75 PROD1 CASING OWFF P Monitor well for flow. 8,054.0 8,054.0 09:00 09:45 3/26/2016 3/26/2016 0.75 PROD1 CASING MPDA P Remove MPD bearing and install trip 8,054.0 8,054.0 09:45 10:30 nipple. 3/26/2016 3/26/2016 5.50 PROD1 CASING TRIP P Pull out of hole f/8054'to 387'MD 8,054.0 387.0 10:30 16:00 standing back DP and HWDP. 3/26/2016 3/26/2016 0.50 PROD1 CASING TRIP P Monitor well static for 10 min. 387.0 203.0 16:00 16:30 Retrieve 2.38"drift and stand back remainder of HWDP to 203'MD. 3/26/2016 3/26/2016 2.00 PROD1 CASING BHAH P LD BHA f/203 to surface. Remove 203.0 0.0 16:30 18:30 RA source f/ADN. 3/26/2016 3/26/2016 0.50 PROD1 CASING BHAH P Clear and clean rig floor. 0.0 0.0 18:30 19:00 3/26/2016 3/26/2016 0.75 COMPZN WHDBOP RURD P Drain stack,pull wear bushing,install 0.0 0.0 19:00 19:45 test plug w/4"test joint. 3/26/2016 3/26/2016 1.25 COMPZN WHDBOP RURD P RU test equipment,flush and fill BOP 0.0 0.0 / 19:45 21:00 equipment,observe flow f/IA initially at 5 gal in 45 minutes,diminishing. Monitor and document rate continously. Page 30/38 Report Printed: 4/5/2016 • Operations Summary (with Timelog Depths) 2S-11 Conoc.oPhfilips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 3/26/2016 3/27/2016 3.00 COMPZN WHDBOP BOPE P Test BOPE(witness waived by 0.0 0.0 21:00 00:00 AOGCC Rep Brian Bixby):All tests 250psi low/3500psi high for 5 charted minutes with exception of manual operated and super choke(250psi low/2000psi high)for 5 charted minutes. Using 4" test joints,test annular,2-7/8"x5-1/2"UPR,2-7/8"x5- 1/2"LPR,choke Valves#1 to#15, Manual Operated and super choke, choke and kill manuals and NCR's,4" valve on kill line,4"dart,3-1/2"TIW,3 -1/2"dart and upper and lower IBOP's, Perform Koomy drawdown(Prior to: Accumulator=3000 psi,Manifold=150 Opsi,Function 3 rams and Annular, After test Accumulator=1550 psi, 19 sec for 200 psi with 2 electric pump, 115 sec to build system to full pressure with 2 electric and 2 air pumps. Closing times:Annular—23 sec; UPR—18 sec; Blind/Shears—16 sec; LPR—16 sec; Choke HCR—2 sec; Kill HCR-2 sec. 6 Bottle average 1958 psi. 3/27/2016 3/27/2016 2.00 COMPZN WHDBOP BOPE P Complete testing BOPE(witness 0.0 0.0 00:00 02:00 waived by AOGCC Rep Brian Bixby): All tests 250psi low/3500psi high for 5 charted minutes with 4-1/2"test joint,test annular,2-7/8"x5-1/2"UPR, 2-7/8"x5-1/2"LPR,manuals and HCR's choke valves,test 4"TIW. 3/27/2016 3/27/2016 1.25 COMPZN WHDBOP RURD P Rig down test equipment. Pull test 0.0 0.0 02:00 03:15 plug,drain stack and install wear ring. Cont.to RU to run liner. 3/27/2016 3/27/2016 2.75 COMPZN CASING PUTB P PJSM. Make up 4.5", 12.6#, Hydril 0.0 1,158.0 03:15 06:00 563 Liner as per tally. Torque to 3800,RIH to 156'MD and establish circ through shoe and check floats. Cont.RIH to 1158'MD filling each joint on the fly and to off every 10 joints. 3/27/2016 3/27/2016 6.50 COMPZN CASING PUTB P Cont RIH f/1158'to 6958'MD. PU= 1,158.0 6,958.0 06:00 12:30 108K,SO=88K. 3/27/2016 3/27/2016 1.25 COMPZN CASING OTHR P MU Baker Liner hanger.packer 6,958.0 7,100.0 12:30 13:45 assembly and pour in PAL mix. RIH to 7010'MD,make up first stand of 4" DP and RIH to 7100'MD. 3/27/2016 3/27/2016 0.75 COMPZN CASING CIRC P Break circ and pump liner volume 7,100.0 7,100.0 13:45 14:30 staging pumps up to 168 GPM,510 PSI for 110 BBLs. 3/27/2016 3/27/2016 1.00 COMPZN CASING RUNL P Run liner in hole on stands of 4" 7,100.0 8,425.0 14:30 15:30 drillpipe f/7710'to 8425'MD,filling on the fly. 3/27/2016 3/27/2016 1.25 COMPZN CASING MPDA P Pull trip nipple and run RCD bearing. 8,425.0 8,425.0 15:30 16:45 Page 31/38 Report Printed: 4/5/2016 • ' Operations Summary (with Timelog Depths) 2S-11 ConocoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(fir) Phase rrOp Code Activity Code Time P-T-X Operabon (MKS) End Depth(ftKB) 3/27/2016 3/27/2016 1.75 COMPZN CASING DISP P MU stand and RIH to 8475'MD. 8,425.0 8,475.0 16:45 18:30 Pump 50 BBL hi vis mud spacer while recip f/8475'to 8420'MD. Displace well to 10.5 PPG mud staging pumps up to 230 GPM maintaining pump schedule not exceeding 760 PSI @ 230 GPM. MW In=MW Out=10.6+ @ 450 BBLs into displacement 3/27/2016 3/27/2016 0.50 COMPZN CASING OTHR P Line up pump#1 on MPD skid and 8,475.0 8,475.0 18:30 19:00 maintain 470 PSI. Obtain parameters @ 8475'MD, PU=125K,SO=97K, ROT= 106K. Rotated at 5 RPM and 10 RPM w/5K TQ. 3/27/2016 3/28/2016 5.00 COMPZN CASING RUNL P Run in hole w/Liner on drillpipe f/ 8,475.0 11,840.0 19:00 00:00 8475'to 11840'MD filling on the fly and topping off every 10 stands. 3/28/2016 3/28/2016 5.50 COMPZN CASING RUNL P Run in hole w/Liner on drillpipe f/ 11,840.0 15,300.0 00:00 05:30 11840'to 15293'MD filling on the fly and topping off every 10 stands. PU 4"DP 31.65'DP single and RIH and tag bottom on depth @ 15309'MD. Pick up to 15300'MD for setting Liner Hanger. PU=183K,SO=80K. 3/28/2016 3/28/2016 0.50 COMPZN CASING CIRC P Circulate DP volume staging pumps 15,300.0 15,300.0 05:30 06:00 up to 3 BPM, 1050 PSI. Pumped 85 BBLs. 3/28/2016 3/28/2016 2.25 COMPZN CASING PACK P Drop 1.5"WIV setting ball and pump 15,300.0 8,344.0 06:00 08:15 down @ 3 BPM, 1013 PSI. Reduce rate to 1.5 BPM prior to landing the ball on seat. Pres.up to 1250 PSI and hold f/5 min. Bleed off MPD pres on annulus and pres up to 2500 PSI to set ZXP Liner Hanger. Slack off to 40k to verify the hanger is set. Continue to pres up to 3500 PSI and release f/Liner. Pick up and verify released at 162K. Cont pick up 4.5' and expose the the dogs. Slack off 50K down and get good surface indication shear. PU to 162K neutral wt. Rotate @ 140K,25 RPM,5K TQ and slack of to 80K setting the Liner top packer. PU to 162K free weight releasing f/Liner. Liner top @ 8299' MD. 3/28/2016 3/28/2016 0.25 COMPZN CASING PRTS P Close annular and pres test Liner top 8,344.0 8,344.0 08:15 08:30 packer and casing to 3000 PSI charted f/10 min. Good test. 3/28/2016 3/28/2016 0.75 COMPZN WELLPR SMPD P PU 40'to 8304'MD and rig up to 8,344.0 8,304.0 08:30 09:15 reverse circ well over to sea water. 3/28/2016 3/28/2016 2.25 COMPZN WELLPR DISP P Displace well over to 8.6 PPG 8,304.0 8,304.0 09:15 11:30 seawater by reversing a 40 BBL hi vis spacer followed by 340 BBLs 8.6 PPG sea water,staging pumps up to 12 BPM,3200 PSI. Cont to CBU until good clean sea water all around. In/ Out=8.6 PPG. Total pumped=518 BBLs. 3/28/2016 3/28/2016 0.50 COMPZN WELLPR OWFF P Monitor well for 30 minutes. Static. 8,304.0 8,304.0 11:30 12:00 Page 32/38 Report Printed: 4/5/2016 Operations Summary (with Timelog epths) orgoge 2S-11 *iv 1 N^ c«ocohitiiips Rrs;kn . Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKS)', 3/28/2016 3/28/2016 1.50 COMPZN WELLPR MPDA P Pull RCD bearing and install trip 8,304.0 8,304.0 12:00 13:30 nipple. Flush injection line and MPD skid w/H2O. 3/28/2016 3/28/2016 7.75 COMPZN WELLPR PULD P POOH and lay down 57 joints of 8,304.0 55.0 13:30 21:15 HWDP f/8304'to 6495'MD. Lay down 206 joints of drillpipe f/6495'to 3/28/2016 3/28/2016 0.50 COMPZN WELLPR PULD P Lay down baker running tool. 55.0 0.0 21:15 21:45 3/28/2016 3/29/2016 2.25 COMPZN WELLPR TRIP P MU mule shoe on drillpipe and RIH w/ 0.0 5,875.0 21:45 00:00 remainder of 4"drillpipe stands f/ derrick to 5875'MD. 3/29/2016 3/29/2016 1.00 COMPZN WELLPR TRIP P Run in hole with 4"drill pipe from 5,875.0 7,012.0 00:00 01:00 5875'MD to 7012'MD while monitoring displacement via trip tank. 3/29/2016 3/29/2016 5.00 COMPZN WELLPR PULD P Lay down 4"drill pipe singes 1x1 from 7,012.0 1,546.0 01:00 06:00 7012'MD to 1546'MD. Monitor displacment via trip tank. Concurrently,transfer Schlumberger(- Wire and spooling unit,225 4-1/2" cannon clamps, 10-4-1/2"half clamps, Schlumberger tool box,rig up 2"high pressure hoses in cellar for circulating and shear out. 3/29/2016 3/29/2016 0.50 COMPZN WELLPR SVRG P Service iron rough neck and skate. 1,546.0 1,546.0 06:00 06:30 3/29/2016 3/29/2016 2.00 COMPZN WELLPR PULD P Continue to lay down singles 1x1 from 1,546.0 0.0 06:30 08:30 1546'MD to surface while monitoring displacement via trip tank. 3/29/2016 3/29/2016 0.50 COMPZN WELLPR PULD P Break out mule shoe,make up 0.0 0.0 08:30 09:00 crossover to 4"drill pipe double and remove wear ring. 3/29/2016 3/29/2016 1.00 COMPZN RPCOMP WWWH P Flush stack at 16 BPM, 151psi,50 0.0 0.0 09:00 10:00 RPM, 1k TQ Concurrently,rig up GBR casing tongs and Schlumberger spooling unit. Blow down top drive. 3/29/2016 3/29/2016 1.00 COMPZN RPCOMP RURD P Verify order of 4-1/2"IBT upper 0.0 0.0 10:00 11:00 completion in pipe shed. Change out slip inserts,hang I-Wire in sheave from tugger. Make up 4-1/2"IBT safety cross over,finish rigging up Schlumberger Air Hammer,clamp wrench. Verify and test I-Wire. 3/29/2016 3/29/2016 1.00 COMPZN RPCOMP PUTB P PJSM for running 4-1/2"12.6ppf L80 0.0 118.0 11:00 12:00 IBTM-Mod gas lift upper completion to 118'MD. Torque all connectinos to 4000ft-lbs. Install I-Wire to gauge mandrel and test. Monitor displacement via trip tank. 3/29/2016 3/29/2016 6.00 COMPZN RPCOMP PUTB P Continue running in hole with 4-1/2" 118.0 3,230.0 12:00 18:00 12.6ppf L-80 IBTM-MD gas lift upper completion from 118'MD to 3230'MD Monitor displacement via trip tank and test I-Wire every-1000'MD. Page 33/38 Report Printed: 4/5/2016 •erations Summary (with Timelog 6epths) vEf� 2S-11 CQnoc Phiimps, Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End'..Depth(ftKB), 3/29/2016 3/30/2016 6.00 COMPZN RPCOMP PUTB P Continue running in hole with 4-1/2" 3,230.0 7,367.0 18:00 00:00 12.6ppf L-80 IBTM-MD gas lift upper completion from 3230'MD to 7367' MD Monitor displacement via trip tank and test I-Wire every—1000'MD. 3/30/2016 3/30/2016 1.75 COMPZN RPCOMP PUTB P Continue running in hole with 4-1/2" 7,367.0 8,270.0 00:00 01:45 12.6ppf L80 IBT-M completion rom 7367'MD to 8270'MD torquing all connections to 4000 ft-lbs. Install cannon clamps on every connection, test I-Wire every 1000',monitor displacement via trip tank. 3/30/2016 3/30/2016 1.00 COMPZN RPCOMP HOSO T Pick up joint#198 and run in hole to 8,270.0 8,299.0 01:45 02:45 8299'MD and attempt to enter liner top without success. Pick up to 8270' MD,lay down joint#198,make up circulation equipment on skate to joint #198. Pick up joint#198 and run in hole to 8290'and break circulation at 1BPM,47psi,5%flow out. Attempt to circulate down entering liner top at 8299'MD, no success. rotate pipe 1/2 turn and work down into liner top, no success. 3/30/2016 3/30/2016 0.50 COMPZN RPCOMP HOSO P Attempt to turn additional 1/4 turn, 8,299.0 8,308.0 02:45 03:15 worked down into liner after initiating additional turn. locate on depth at 8308'MD,Slack off weight 20k to 78k, fully located at 8309'MD. Note: There was no indication of shear. PU wt=112k,SO wt=98k 3/30/2016 3/30/2016 0.75 COMPZN RPCOMP CRIH P Spot 15bbls of corrosion inhibited 8,308.0 8,308.0 03:15 04:00 seawater followed by 110bbIs of seatwater at 3bpm,190psi,9%flow out. Rig down circuation equipment. 3/30/2016 3/30/2016 1.50 COMPZN RPCOMP HOSO P Pull out of hole to 8188'MD,laying 8,308.0 8,260.0 04:00 05:30 down joints#198,#197,and#196. Pick up space out pups(7.81',7.82', 9.83',and 9.82'),Joint#196,and run in hole to 8260'MD.Pick up landing joint and make up hanger. Terminate I-Wire through hanger,test swagelok fitting ports to 5000psi,drain stack. Concurrently,clean and clear rig floor, rig down GBR casing equipment, Schlumberger spooling unit. Note: 203- 4-1/2"cannon camps and 6- 4-1/2"half clamps installed. 3/30/2016 3/30/2016 1.50 COMPZN RPCOMP THGR P Run in hole with hanger and land out. 8,260.0 8,260.0 05:30 07:00 Run in lock down screws and torque gland nuts to 250ft-lbs. Test upper/lower hanger seals to 5000psi for 10min. (Witnessed by CPAI Rep: Kurt Alexa) Page 34/38 Report Printed: 4/5/2016 0,5 Operations Summary (with Timelog ftpths) qtfr .9b14,44,* 2S-11 Cor coPhilgps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Tome End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operabon (ftKB) End Depth(ftKB) 3/30/2016 3/30/2016 2.00 COMPZN RPCOMP PRTS P Drop 1.3125"ball and rod as per 8,260.0 0.0 07:00 09:00 Baker Oil Tools rep. Rig up circulation equipment. Test tubing to 4000psi for 30min(charted,good test),bleed tubing down to 2000psi,pressure up annulus and test to 4000psi for 30min (charted,good test),bleed tubing rapidly to Opsi and shear SOV,pump down annulus to verify shear at 1.5bpm,290psi,4%flow out. Rig down circulation equipment. 3/30/2016 3/30/2016 1.00 COMPZN WHDBOP MPSP P OWFF for 30 minutes static,Pull 4- 0.0 0.0 09:00 10:00 1/2"landing joint and dry rod in back pressure valve(BPV). Pressure test to 2500psi for 10min and bleed pressure. 3/30/2016 3/30/2016 1.00 COMPZN WHDBOP WWWH P Pick up a joint of 5"drill pipe and 0.0 0.0 10:00 11:00 make up crossover and stack flushing tool. Flush stack with citric and fresh water pill at 14bpm,87psi,27%flow out,through both mud pumps. rig down and blow down top drive. 3/30/2016 3/30/2016 1.00 COMPZN WHDBOP WWWH P Close blind rams and flush with citric 0.0 0.0 11:00 12:00 and fresh water pill through kill line and choke manifold to poorboy @ 5bpm,66psi,while working each leg of choke manifold. Blow down choke and kill lines,choke manifold and drain stack. 3/30/2016 3/30/2016 3.00 COMPZN WHDBOP NUND P Flush and blow down hole fill line, 0.0 0.0 12:00 15:00 drain stack,nipple down MPD equipment and mobilize to rig floor. Break all flanged connections on riser, • extension and adapter in cellar. Concurrently,clean pits. 3/30/2016 3/30/2016 2.50 COMPZN WHDBOP NUND P Pull 2ft extension in cellar. Pull flow 0.0 0.0 15:00 17:30 box and re-install extension. Nipple down and pul RCD head to rig floor. Nipple down BOPE equipment. 3/30/2016 3/30/2016 0.75 COMPZN WHDBOP NUND P Clear rig floor of MPD equipment,pull 0.0 0.0 17:30 18:15 riser and spools to rig floor 3/30/2016 3/30/2016 2.00 COMPZN WHDBOP NUND P Cameron and Schlumberger terminate 0.0 0.0 18:15 20:15 I-Wire through Cameron tree adaptor. Nipple up same. Concurrently,prep and lower all drilling spools and riser from rig floor. Page 35/38 Report Printed: 4/5/2016 Operations Summary (with Timelogftpths) &Wens 2S-11 ConocoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (MKB) End Depth(ftKB) 3/30/2016 3/30/2016 1.75 COMPZN WHDBOP PRTS P Fill tree adaptor with diesel.Cameron 0.0 0.0 20:15 22:00 Test SRL seal to 10000psi for 15min. Test hanger void to 250/5000psi for 10/15min. Both tests witnessed by CPAI rep Kurt Alexa. Attach port block on top of tree and position for lowering to cellar. Concurrently,continue cleaning in pits,remove koomey lines from BOP stack,and begin breaking connections on stack and open up rams. 3/30/2016 3/31/2016 2.00 COMPZN WHDBOP NUND P Lower wing valve to cellar,lower and 0.0 0.0 22:00 00:00 nipple up tree.Hoist MPD PLC and accumulator and remove from floor. 3/31/2016 3/31/2016 0.50 COMPZN WHDBOP NUND P Continue to nipple up tree. 0.0 0.0 00:00 00:30 3/31/2016 3/31/2016 1.50 COMPZN WHDBOP PRTS P Fill tree with diesel.Rig up test tree, 0.0 0.0 00:30 02:00 test to 250/5000psi for 15/15 charted min. Shut in and swap over to Cameron and test tree to 10000psi for 15min. (Witnessed by CPAI Rep Kurt Alexa-Good Test).Rig down all test equipment and blow down test pump. Concurrently,continue removing all rams from BOP's,clean and grease rams and store in BOP deck.Send out RCD head,air accuator panel,and transformer. 3/31/2016 3/31/2016 1.00 COMPZN WHDBOP FRZP P Verify no pressure on annulus.Dry rod 0.0 0.0 02:00 03:00 out BPV as per Cameron.Rig up to freeze protect well. 3/31/2016 3/31/2016 1.50 COMPZN WHDBOP FRZP P Freeze protect well with 87bb1 of 0.0 0.0 03:00 04:30 80deg heated diesel @ 1.5 BPM using injector pump. ICP= 1312psi, Injection pump FCP-1572psi, IA ICP-1452psi. Shut down and bleed off injector pump.Open up IA to tubing allowing u -tubing for 30min. IA ICP-200psi,IA final U-tube pressure-Opsi.Open annulus and verify no pressure. Concurrently,pressure wash BOP's and carrier,clean BOP deck,and nipple up flow line to Joe's Box. 3/31/2016 3/31/2016 1.00 COMPZN WHDBOP MPSP P Dry rod in BPV as per Cameron 0.0 0.0 04:30 05:30 3/31/2016 3/31/2016 2.00 DEMOB MOVE RURD P Rig down and break down all freeze 0.0 0.0 05:30 07:30 protect equipment. Install flange on IA/OA,clean and clear cellar.Suck out cellar box. Well Secure:07:30. Page 36/38 Report Printed: 4/5/2016 z4 Operations Summary (with Timelog Depths) 2S-11 • ConocoPhildps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur Mr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(MKS)' 3/31/2016 3/31/2016 4.50 DEMOB MOVE DMOB P Remove all tools from cellar,clean PS 0.0 0.0 07:30 12:00 -21 air slips,nipple up jet lines to hole fill,remove rotary table cover,clean rotary table,clean drip pan,clean out cellar box,locate and separate out all CPAI 1502 unions,clean pits,clean pump suction POD/Discharge screens/sumps/rod wash tanks and BOP's 3/31/2016 3/31/2016 6.00 DEMOB MOVE DMOB P Clean remainder of mud from rotary 0.0 0.0 12:00 18:00 table cavity,service rotary table,re- install rotary table cover and wipe down. Grease and close rams, service and prepar PS-21 slips for storage and re-install in rotary table. Clean suction manifolds and discharge on mud pumps. Continue cleaning pits and casing shed. 3/31/2016 4/1/2016 6.00 DEMOB MOVE DMOB P Blow down,drain,and inspect gas 0.0 0.0 18:00 00:00 buster,remove choke and kill hoses in BoP deck and mobilize to and from rig floor. Open gat on BOP carrier and un -pin rotation cylinders. Break nuts on BOP double gate to mud cross, remove kelly hose from derrick and secure in casing shed. 4/1/2016 4/1/2016 6.00 DEMOB MOVE DMOB P R/D 50'slings. Nipple up Joes box and 0.0 0.0 00:00 06:00 flow line,pressure wash and clean top drive.Continue cleaning pump suction pods,continue cleaning pit module. Remove hydraulic fittings from BOP stack,remove rotating braces form annular.R/U slings on surface annular. Nipple down Joes box, Flow line,Hang annular from blocks,prep MPD skid for removal.Remove subs from rack-clean and send off rig floor. 4/1/2016 4/1/2016 4.00 DEMOB MOVE DMOB P Continue sending out subs,cleaning 0.0 0.0 06:00 10:00 in pits,prep cattle chute for retraction. Prep BOP stack and lifting ring for removal,lower cattle chute for crane pick.Secure MPD skid to cradle. 4/1/2016 4/1/2016 2.00 DEMOB MOVE DMOB P PJSM with crane crew,Pick MPD skid 0.0 0.0' 10:00 12:00 from BOP deck,remove support beam from BOP carrier, Pick BOP stack. 4/1/2016 4/1/2016 3.50 DEMOB MOVE DMOB P Separate BOP sections on mat, 0.0 0.0 12:00 15:30 remove BOP carrier fork plate from stack.Crane fork plate back into position on carrier.Set surface annular on carrier and pick with crane, raise cattle chute,re-assemble BOP and Hydril carriers,prep and transfer Hydril and BPOP sections to trucks for transport. 4/1/2016 4/1/2016 2.50 DEMOB MOVE DMOB P Remove saver sub,upper and lower 0.0 0.0 15:30 18:00 IBOP's and bails from topdrive,begin cleaning BOP carrier and BOP deck. Page 37/38 Report Printed: 4/5/2016 • • Operations Summary (with Timelog Depths) pi2S-11 Conocoehithps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End.Depth(ftKB) 4/1/2016 4/2/2016 6.00 DEMOB MOVE DMOB P Continue cleaning in BOP deck,clean 0.0 0.0 18:00 00:00 and reassemble top drive compression clamps and equipment, put away.Lower strip o matic,clean and re-install on rails.Remove topdrive torque foot.N/U flow box and flow line,begin cleaning and remove die blocks from ST-80.Grease and wrap topdrive swivel packing. Continue cleaning in pits and sucking lines, pull all swabs,liners,valves and seats on#2 Mud pump,begin same on#2 mud pump.Service topdrive and blocks.Remove all rope,angle descent and SRL's from derrick board and shack.Expedite equipment from derrick and rig floor to casing shed. 4/2/2016 4/2/2016 6.00 DEMOB MOVE DMOB P Continue clean and clear rig floor, 0.0 0.0 00:00 06:00 remove tools,clean ST-80,clean pits and clear lines.Cleaning under shakers and troughs in pits.Clean out MP#1 and#2.Remove wear plates, remove and clean liners and swabs. Gather oily waste and secure SAA's for pickup. 4/2/2016 4/2/2016 6.00 DEMOB MOVE DMOB P Continue cleaning rig floor,pull pipe 0.0 0.0 06:00 12:00 rack mats,place Tioga heater in cellar and open hatches on rig floor. Remove line tar from draw works. P/U plate for surface annular.Continue cleaning in pits and cellar,suction and discharge pumps. Remove oily waste, empty SAA's,haul off used oil/glycol. Rig released @ 12:00 hrs. Page 38/38 Report Printed: 4/5/2016 • 0 NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-11 2S-11 Definitive Survey Report 28 March, 2016 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-11 Project: Kuparuk River Unit TVD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Site: Kuparuk 2S Pad MD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Well: 2S-11 North Reference: True Wellbore: 2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11 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 2S-11 Well Position +N/-S 0.00 usft Northing: 5,929,973.68 usfl Latitude: 70°13'11.436 N +E/-W 0.00 usft Easting: 481,015.40 usfl Longitude: 150°9'11.362 W Position Uncertainty 0.00 usft Wellhead Elevation: 118.97 usfl Ground Level: 120.00 usfl Wellbore 2S-11 Magnetics Model Name Sample Date Declination Dip''Angle Field Strength (°) (°) (nT) BGGM2015 3/10/2016 18.31 80.86 57,484 Design 2S-11 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.65 Vertical Section: Depth From(TVD) +NI-S +EI-W Direction (usft) (usft) (u ) (0) 39.65 0.00 0.00 15.00 Survey Program Date 3/28/2016 From To (uSft) (usf() ', Survey(Wellbore) Tool Name Description Survey Date 95.00 843.50 2S-11 Srvy 1 SLB_NSG+SSHOT(2S-11;GYD-GC-SS Gyrodata gyro single shots 3/3/2016 10:22 868.42 2,797.08 2S-11 Srvy 2 SLB_MWD+GMAG(2S-11)MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/3/2016 10:24 2,861.69 2,861.69 2S-11 Srvy 3 SLB_MWD-INC_Only-Filler INC+TREND Inclinometer+known azi trend 3/7/2016 9:50 2,953.67 8,420.90 2S-11 Srvy 4 SLB_MWD+GMAG(2S-11)MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/7/2016 9:52 8,516.63 8,516.63 2S-11 Srvy 5 SLB_INC+TREND(2S-11) INC+TREND Inclinometer+known azi trend 3/16/2016 9:11 8,568.17 9,040.05 2S-11 Srvy 6 SLB_MWD+GMAG(2S-11)MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/16/2016 9:1. 9,106.77 15,226.25 2S-11 Srvy 7 SLB_MWD+GMAG(2S-11)MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/18/2016 9:Z Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft)', (ft) (°/100') (ft) Survey Tool Name 39.65 0.00 0.00 39.65 -120.00 0.00 0.00 5,929,973.68 481,015.40 0.00 0.00 UNDEFINED 95.00 0.16 135.12 95.00 -64.65 -0.05 0.05 5,929,973.63 481,015.45 0.29 -0.04 GYD-GC-SS(1) 187.50 0.41 70.28 187.50 27.85 -0.03 0.46 5,929,973.64 481,015.86 0.40 0.08 GYD-GC-SS(1) 280.50 0.51 125.46 280.50 120.85 -0.16 1.11 5,929,973.51 481,016.51 0.47 0.13 GYD-GC-SS(1) 373.50 2.22 163.14 373.47 213.82 -2.13 1.97 5,929,971.55 481,017.36 1.98 -1.54 GYD-GC-SS(1) 468.50 4.11 177.23 468.32 308.67 -7.29 2.67 5,929,966.39 481,018.05 2.14 -6.35 GYD-GC-SS(1) 561.50 5.25 182.80 561.01 401.36 -14.87 2.62 5,929,958.81 481,017.98 1.32 -13.68 GYD-GC-SS(1) 654.50 7.47 185.76 653.43 493.78 -25.13 1.80 5,929,948.54 481,017.14 2.41 -23.81 GYD-GC-SS(1) 749.50 9.83 189.46 747.34 587.69 -39.28 -0.15 5,929,934.41 481,015.15 2.55 -37.98 GYD-GC-SS(1) 3/28/2016 1:18:09PM Page 2 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-11 Project: Kuparuk River Unit TVD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Site: Kuparuk 2S Pad MD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Well: 2S-11 North Reference: True Wellbore: 2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11 Database: OAKEDMP2 Map Map Vertical MD . Inc 4Zi TVD TVDSS +NI-S +E/-W Northing Easting 01-S Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (011001 (ft) Survey Tool Name 843.50 11.45 189.24 839.72 680.07 -56.40 -2.97 5,929,917.29 481,012.29 1.72 -55.25 GYD-GC-SS(1) 868.42 11.95 190.15 864.13 704.48 -61.38 -3.82 5,929,912.31 481,011.43 2.14 -60.28 MWD+IFR-AK-CAZ-SC(2) 963.14 12.69 191.70 956.67 797.02 -81.23 -7.66 5,929,892.48 481,007.54 0.86 -80.44 MWD+IFR-AK-CAZ-SC(2) 1,058.00 13.91 192.54 1,048.98 889.33 -102.56 -12.24 5,929,871.16 481,002.90 1.30 -102.23 MWD+IFR-AK-CAZ-SC(2) 1,153.39 16.63 195.74 1,140.99 981.34 -126.89 -18.44 5,929,846.85 480,996.64 2.98 -127.34 MWD+IFR-AK-CAZ-SC(2) 1,247.48 19.41 196.13 1,230.46 1,070.81 -154.88 -26.44 5,929,818.88 480,988.58 2.96 -156.44 MWD+IFR-AK-CAZ-SC(2) 1,341.78 21.08 194.81 1,318.93 1,159.28 -186.33 -35.12 5,929,787.46 480,979.81 1.84 -189.07 MWD+IFR-AK-CAZ-SC(2) 1,436.76 24.26 192.74 1,406.56 1,246.91 -221.88 -43.80 5,929,751.93 480,971.05 3.45 -225.66 MWD+IFR-AK-CAZ-SC(2) 1,531.73 25.11 195.81 1,492.86 1,333.21 -260.30 -53.59 5,929,713.54 480,961.16 1.62 -265.30 MWD+IFR-AK-CAZ-SC(2) 1,625.03 26.05 202.72 1,577.03 1,417.38 -298.26 -66.90 5,929,675.62 480,947.76 3.35 -305.41 MWD+IFR-AK-CAZ-SC(2) 1,720.90 26.39 208.91 1,663.05 1,503.40 -336.33 -85.33 5,929,637.60 480,929.23 2.87 -346.96 MWD+IFR-AK-CAZ-SC(2) 1,815.09 26.20 216.67 1,747.52 1,587.87 -371.35 -107.88 5,929,602.64 480,906.60 3.65 -386.61 MWD+IFR-AK-CAZ-SC(2) 1,909.97 26.40 220.61 1,832.59 1,672.94 -404.16 -134.12 5,929,569.90 480,880.28 1.85 -425.10 MWD+IFR-AK-CAZ-SC(2) 2,003.79 27.56 224.75 1,916.20 1,756.55 -435.41 -162.98 5,929,538.72 480,851.34 2.35 -462.76 MWD+IFR-AK-CAZ-SC(2) 2,098.60 29.24 230.28 1,999.61 1,839.96 -465.79 -196.24 5,929,508.43 480,818.01 3.29 -500.71 MWD+IFR-AK-CAZ-SC(2) 2,193.38 32.14 231.75 2,081.11 1,921.46 -496.20 -233.85 5,929,478.12 480,780.33 3.16 -539.82 MWD+IFR-AK-CAZ-SC(2) 2,287.97 35.75 232.17 2,159.57 1,999.92 -528.74 -275.45 5,929,445.69 480,738.65 3.82 -582.01 MWD+IFR-AK-CAZ-SC(2) 2,381.57 38.74 232.68 2,234.07 2,074.42 -563.27 -320.34 5,929,411.27 480,693.67 3.21 -626.99 MWD+IFR-AK-CAZ-SC(2) 2,476.61 40.40 236.70 2,307.34 2,147.69 -598.22 -369.75 5,929,376.45 480,644 19 3.21 -673.53 MWD+IFR-AK-CAZ-SC(2) 2,570.83 42.74 240.21 2,377.84 2,218.19 -630.87 -423.03 5,929,343.94 480,590.83 3.50 -718.87 MWD+IFR-AK-CAZ-SC(2) 2,667.07 46.96 242.12 2,446.05 2,286.40 -663.56 -482.49 5,929,311.40 480,531.29 4.60 -765.83 MWD+IFR-AK-CAZ-SC(2) 2,761.21 48.85 244.05 2,509.16 2,349.51 -695.16 -544.78 5,929,279.96 480,468.93 2.52 -812.47 MWD+IFR-AK-CAZ-SC(2) 2,797.08 48.83 244.01 2,532.77 2,373.12 -706.99 -569.05 5,929,268.20 480,444.63 0.10 -830.18 MWD+IFR-AK-CAZ-SC(2) 2,859.20 48.75 243.74 2,573.70 2,414.05 -727.57 -611.01 5,929,247.73 480,402.62 0.35 -860.92 INC+TREND(3) 10 314"x 13-412" 2,861.69 48.75 243.73 2,575.34 2,415.69 -728.39 -612.69 5,929,246.90 480,400.94 0.35 -862.15 INC+TREND(3) 2,953.67 49.09 243.78 2,635.78 2,476.13 -759.05 -674.88 5,929,216.40 480,338.68 0.37 -907.86 MWD+IFR-AK-CAZ-SC(4) 3,050.81 49.13 243.07 2,699.37 2,539.72 -791.91 -740.55 5,929,183.72 480,272.93 0.55 -956.59 MWD+IFR-AK-CAZ-SC(4) 3,146.04 48.65 242.80 2,761.98 2,602.33 -824.55 -804.45 5,929,151.24 480,208.96 0.55 -1,004.66 MWD+IFR-AK-CAZ-SC(4) 3,240.73 48.66 242.53 2,824.53 2,664.88 -857.20 -867.60 5,929,118.75 480,145.74 0.21 -1,052.54 MWD+IFR-AK-CAZ-SC(4) 3,334.60 48.62 242.78 2,886.56 2,726.91 -889.56 -930.18 5,929,086.55 480,083.08 0.20 -1,100.00 MWD+IFR-AK-CAZ-SC(4) 3,428.84 48.52 242.46 2,948.92 2,789.27 -922.05 -992.92 5,929,054.22 480,020.26 0.28 -1,147.62 MWD+IFR-AK-CAZ-SC(4) 3,525.14 48.54 243.35 3,012.69 2,853.04 -954.92 -1,057.16 5,929,021.52 479,955.95 0.69 -1,195.99 MWD+IFR-AK-CAZ-SC(4) 3,619.94 48.57 242.46 3,075.44 2,915.79 -987.28 -1,120.42 5,928,989.31 479,892.61 0.70 -1,243.63 MWD+IFR-AK-CAZ-SC(4) 3,713.22 48.50 243.54 3,137.21 2,977.56 -1,019.02 -1,182.70 5,928,957.74 479,830.26 0.87 -1,290.40 MWD+IFR-AK-CAZ-SC(4) 3,808.42 48.13 242.50 3,200.52 3,040.87 -1,051.27 -1,246.06 5,928,925.65 479,766.82 0.90 -1,337.95 MWD+IFR-AK-CAZ-SC(4) 3,903.51 48.06 244.61 3,264.04 3,104.39 -1,082.79 -1,309.42 5,928,894.30 479,703.39 1.65 -1,384.79 MWD+IFR-AK-CAZ-SC(4) 3,996.52 48.56 246.68 3,325.90 3,166.25 -1,111.42 -1,372.69 5,928,865.83 479,640.06 1.75 -1,428.83 MWD+IFR-AK-CAZ-SC(4) 4,091.62 49.01 251.13 3,388.58 3,228.93 -1,137.15 -1,439.40 5,928,840.27 479,573.28 3.55 -1,470.95 MWD+IFR-AK-CAZ-SC(4) 4,187.35 49.15 251.78 3,451.28 3,291.63 -1,160.15 -1,507.98 5,928,817.44 479,504.65 0.53 -1,510.92 MWD+IFR-AK-CAZ-SC(4) 3/28/2016 1:18:09PM Page 3 COMPASS 5000.1 Build 74 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-11 Project: Kuparuk River Unit TVD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Site: Kuparuk 2S Pad MD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Well: 2S-11 North Reference: True Wellbore: 2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11 Database: OAKEDMP2 Survey , Map Map Verticai,. MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Sectiott (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey-Teel Nettle 4,281.19 48.96 251.37 3,512.78 3,353.13 -1,182.56 -1,575.23 5,928,795.21 479,437.36 0.39 -1,549.96 MWD+IFR-AK-CAZ-SC(4) 4,375.29 49.00 248.75 3,574.55 3,414.90 -1,206.76 -1,641.96 5,928,771.17 479,370.57 2.10 -1,590.62 MWD+IFR-AK-CAZ-SC(4) 4,469.90 49.08 246.21 3,636.57 3,476.92 -1,234.13 -1,707.95 5,928,743.98 479,304.52 2.03 -1,634.12 MWD+IFR-AK-CAZ-SC(4) 4,566.21 49.27 246.36 3,699.53 3,539.88 -1,263.44 -1,774.67 5,928,714.84 479,237.73 0.23 -1,679.70 MWD+IFR-AK-CAZ-SC(4) 4,659.65 49.12 244.93 3,760.60 3,600.95 -1,292.60 -1,839.10 5,928,685.84 479,173.23 1.17 -1,724.55 MWD+IFR-AK-CAZ-SC(4) 4,754.40 49.11 244.64 3,822.62 3,662.97 -1,323.12 -1,903.91 5,928,655.49 479,108.36 0.23 -1,770.80 MWD+IFR-AK-CAZ-SC(4) 4,849.12 49.11 244.37 3,884.62 3,724.97 -1,353.94 -1,968.54 5,928,624.83 479,043.65 0.22 -1,817.30 MWD+IFR-AK-CAZ-SC(4) 4,945.41 49.12 243.49 3,947.65 3,788.00 -1,385.93 -2,033.93 5,928,593.01 478,978.19 0.69 -1,865.13 MWD+IFR-AK-CAZ-SC(4) 5,039.47 49.10 241.93 4,009.22 3,849.57 -1,418.53 -2,097.12 5,928,560.57 478,914.92 1.25 -1,912.97 MWD+IFR-AK-CAZ-SC(4) 5,134.17 49.13 244.01 4,071.21 3,911.56 -1,451.06 -2,160.89 5,928,528.20 478,851.08 1.66 -1,960.90 MWD+IFR-AK-CAZ-SC(4) 5,228.65 48.62 244.00 4,133.35 3,973.70 -1,482.26 -2,224.86 5,928,497.17 478,787.04 0.54 -2,007.59 MWD+IFR-AK-CAZ-SC(4) 5,322.94 47.31 247.20 4,196.49 4,036.84 -1,511.20 -2,288.61 5,928,468.39 478,723.22 2.88 -2,052.04 MWD+IFR-AK-CAZ-SC(4) 5,417.46 45.96 248.90 4,261.40 4,101.75 -1,536.89 -2,352.34 5,928,442.86 478,659.44 1.94 -2,093.35 MWD+IFR-AK-CAZ-SC(4) 5,512.69 45.04 251.26 4,328.15 4,168.50 -1,560.04 -2,416.18 5,928,419.88 478,595.54 2.01 -2,132.24 MWD+IFR-AK-CAZ-SC(4) 5,607.68 44.14 252.83 4,395.80 4,236.15 -1,580.60 -2,479.61 5,928,399.47 478,532.07 1.50 -2,168.52 MWD+IFR-AK-CAZ-SC(4) 5,701.07 43.76 255.38 4,463.04 4,303.39 -1,598.36 -2,541.94 5,928,381.88 478,469.70 1.94 -2,201.80 MWD+IFR-AK-CAZ-SC(4) 5,797.14 43.48 258.77 4,532.59 4,372.94 -1,613.18 -2,606.52 5,928,367.22 478,405.10 2.45 -2,232.83 MWD+IFR-AK-CAZ-SC(4) 5,891.89 44.13 265.83 4,601.02 4,441.37 -1,621.93 -2,671.43 5,928,358.63 478,340.17 5.20 -2,258.09 MWD+IFR-AK-CAZ-SC(4) 5,986.61 42.65 273.91 4,669.90 4,510.25 -1,622.14 -2,736.39 5,928,358.58 478,275.22 6.06 -2,275.10 MWD+IFR-AK-CAZ-SC(4) 6,080.16 41.51 280.26 4,739.37 4,579.72 -1,614.46 -2,798.54 5,928,366.43 478,213.09 4.71 -2,283.76 MWD+IFR-AK-CAZ-SC(4) 6,174.45 41.52 285.09 4,809.99 4,650.34 -1,600.75 -2,859.47 5,928,380.28 478,152.19 3.39 -2,286.30 MWD+IFR-AK-CAZ-SC(4) 6,270.03 42.46 291.01 4,881.05 4,721.40 -1,580.93 -2,920.20 5,928,400.26 478,091.52 4.26 -2,282.87 MWD+IFR-AK-CAZ-SC(4) 6,363.58 42.42 297.34 4,950.13 4,790.48 -1,555.11 -2,977.73 5,928,426.22 478,034.06 4.57 -2,272.81 MWD+IFR-AK-CAZ-SC(4) 6,459.84 41.77 300.56 5,021.56 4,861.91 -1,523.89 -3,034.19 5,928,457.58 477,977.69 2.34 -2,257.27 MWD+IFR-AK-CAZ-SC(4) 6,553.79 41.99 303.70 5,091.52 4,931.87 -1,490.54 -3,087.29 5,928,491.06 477,924.68 2.24 -2,238.80 MWD+IFR-AK-CAZ-SC(4) 6,648.29 42.37 306.84 5,161.56 5,001.91 -1,453.90 -3,139.07 5,928,527.82 477,872.99 2.27 -2,216.82 MWD+IFR-AK-CAZ-SC(4) 6,742.89 42.07 307.93 5,231.61 5,071.96 -1,415.31 -3,189.58 5,928,566.54 477,822.58 0.84 -2,192.61 MWD+IFR-AK-CAZ-SC(4) 6,836.15 42.14 308.78 5,300.81 5,141.16 -1,376.51 -3,238.62 5,928,605.46 477,773.65 0.62 -2,167.82 MWD+IFR-AK-CAZ-SC(4) 6,931.74 43.41 311.70 5,370.98 5,211.33 -1,334.57 -3,288.15 5,928,647.52 477,724.23 2.46 -2,140.13 MWD+IFR-AK-CAZ-SC(4) 7,026.63 44.55 315.32 5,439.27 5,279.62 -1,289.20 -3,335.90 5,928,693.00 477,676.60 2.91 -2,108.67 MWD+IFR-AK-CAZ-SC(4) 7,121.73 46.38 318.32 5,505.97 5,346.32 -1,239.76 -3,382.26 5,928,742.55 477,630.37 2.96 -2,072.91 MWD+IFR-AK-CAZ-SC(4) 7,216.68 49.43 321.36 5,569.62 5,409.97 -1,185.91 -3,427.65 5,928,796.51 477,585.12 3.99 -2,032.64 MWD+IFR-AK-CAZ-SC(4) 7,310.97 52.39 323.75 5,629.07 5,469.42 -1,127.80 -3,472.11 5,928,854.73 477,540.81 3.70 -1,988.02 MWD+IFR-AK-CAZ-SC(4) 7,405.20 53.38 326.76 5,685.94 5,526.29 -1,066.06 -3,514.91 5,928,916.57 477,498.17 2.76 -1,939.46 MWD+IFR-AK-CAZ-SC(4) 7,500.00 54.40 330.77 5,741.83 5,582.18 -1,000.59 -3,554.60 5,928,982.13 477,458.65 3.58 -1,886.49 MWD+IFR-AK-CAZ-SC(4) 7,595.01 55.72 335.53 5,796.26 5,636.61 -931.12 -3,589.74 5,929,051.68 477,423.69 4.34 -1,828.49 MWD+IFR-AK-CAZ-SC(4) 7,689.27 56.32 338.95 5,848.95 5,689.30 -859.06 -3,619.96 5,929,123.81 477,393.65 3.08 -1,766.70 MWD+IFR-AK-CAZ-SC(4) 7,784.20 57.05 342.22 5,901.10 5,741.45 -784.26 -3,646.31 5,929,198.67 477,367.49 2.98 -1,701.27 MWD+IFR-AK-CAZ-SC(4) 7,879.48 59.11 344.06 5,951.48 5,791.83 -706.87 -3,669.75 5,929,276.12 477,344.25 2.71 -1,632.58 MWD+IFR-AK-CAZ-SC(4) 7,972.72 61.74 346.63 5,997.50 5,837.85 -628.42 -3,690.24 5,929,354.60 477,323.96 3.70 -1,562.12 MWD+IFR-AK-CAZ-SC(4) 3/282016 1:18:09PM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-11 Project: Kuparuk River Unit TVD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Site: Kuparuk 2S Pad MD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Well: 2S-11 North Reference: True Wellbore: 2S-11 slit calculation Method: Minimum Curvature Design: 2S-11 OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DSS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,066.87 63.05 349.04 6,041.13 5,881.48 -546.87 -3,707.81 5,929,436.19 477,306.59 2.66 -1,487.89 MWD+IFR-AK-CAZ-SC(4) 8,162.01 64.56 350.53 6,083.13 5,923.48 -462.86 -3,722.94 5,929,520.23 477,291.68 2.12 -1,410.66 MWD+IFR-AK-CAZ-SC(4) 8,257.15 67.28 352.51 6,121.95 5,962.30 -376.96 -3,735.73 5,929,606.15 477,279.10 3.43 -1,331.00 MWD+IFR-AK-CAZ-SC(4) 8,350.47 71.04 355.64 6,155.15 5,995.50 -290.24 -3,744.70 5,929,692.89 477,270.35 5.10 -1,249.55 MWD+IFR-AK-CAZ-SC(4) 8,420.90 74.19 357.85 6,176.19 6,016.54 -223.15 -3,748.51 5,929,759.98 477,266.72 5.38 -1,185.73 MWD+IFR-AK-CAZ-SC(4) 8,485.30 75.19 358.82 6,193.20 6,033.55 -161.06 -3,750.31 5,929,822.07 477,265.07 2.13 -1,126.22 INC+TREND(5) 7-5/8"x'9-7/8 by 11" 8,516.63 75.68 359.29 6,201.07 6,041.42 -130.74 -3,750.81 5,929,852.39 477,264.65 2.13 -1,097.07 INC+TREND(5) 8,568.17 76.52 0.62 6,213.46 6,053.81 -80.71 -3,750.85 5,929,902.41 477,264.73 2.99 -1,048.75 MWD+IFR-AK-CAZ-SC(6) 8,663.03 77.55 1.63 6,234.74 6,075.09 11.71 -3,749.03 5,929,994.82 477,266.78 1.50 -959.01 MWD+IFR-AK-CAZ-SC(6) 8,757.35 78.56 2.48 6,254.26 6,094.61 103.92 -3,745.72 5,930,087.02 477,270.32 1.39 -869.08 MWD+IFR-AK-CAZ-SC(6) 8,852.10 79.30 2.79 6,272.45 6,112.80 196.81 -3,741.45 5,930,179.88 477,274.83 0.84 -778.25 MWD+IFR-AK-CAZ-SC(6) 8,946.12 80.93 5.59 6,288.60 6,128.95 289.18 -3,734.67 5,930,272.22 477,281.84 3.41 -687.28 MWD+IFR-AK-CAZ-SC(6) 9,040.05 83.41 8.14 6,301.39 6,141.74 381.55 -3,723.55 5,930,364.55 477,293.19 3.77 -595.18 MWD+IFR-AK-CAZ-SC(6) 9,106.77 86.39 9.74 6,307.32 6,147.67 447.19 -3,713.22 5,930,430.16 477,303.69 5.06 -529.10 MWD+IFR-AK-CAZ-SC(7) 9,201.10 89.40 10.93 6,310.79 6,151.14 539.91 -3,696.31 5,930,522.83 477,320.83 3.43 -435.16 MWD+IFR-AK-CAZ-SC(7) 9,296.00 90.38 13.68 6,310.97 6,151.32 632.62 -3,676.09 5,930,615.48 477,341.28 3.08 -340.38 MWD+IFR-AK-CAZ-SC(7) 9,391.36 91.54 14.73 6,309.37 6,149.72 725.05 -3,652.69 5,930,707.84 477,364.91 1.64 -245.04 MWD+IFR-AK-CAZ-SC(7) 9,486.30 91.58 15.29 6,306.79 6,147.14 816.72 -3,628.11 5,930,799.44 477,389.72 0.59 -150.14 MWD+IFR-AK-CAZ-SC(7) 9,580.29 90.89 15.43 6,304.76 6,145.11 907.33 -3,603.22 5,930,889.98 477,414.83 0.75 -56.17 MWD+IFR-AK-CAZ-SC(7) 9,675.59 90.62 15.46 6,303.51 6,143.86 999.18 -3,577.84 5,930,981.75 477,440.44 0.29 39.12 MWD+IFR-AK-CAZ-SC(7) 9,769.63 89.52 15.92 6,303.39 6,143.74 1,089.71 -3,552.41 5,931,072.21 477,466.09 1.27 133.15 MWD+IFR-AK-CAZ-SC(7) 9,864.95 89.14 15.57 6,304.51 6,144.86 1,181.45 -3,526.55 5,931,163.88 477,492.19 0.54 228.45 MWD+IFR-AK-CAZ-SC(7) 9,959.87 88.87 16.60 6,306.16 6,146.51 1,272.64 -3,500.25 5,931,254.99 477,518.71 1.12 323.34 MWD+IFR-AK-CAZ-SC(7) 10,054.12 89.59 16.56 6,307.42 6,147.77 1,362.96 -3,473.36 5,931,345.24 477,545.82 0.77 417.55 MWD+IFR-AK-CAZ-SC(7) 10,149.64 90.41 16.05 6,307.42 6,147.77 1,454.64 -3,446.55 5,931,436.84 477,572.87 1.01 513.04 MWD+IFR-AK-CAZ-SC(7) 10,243.97 90.48 16.29 6,306.69 6,147.04 1,545.23 -3,420.28 5,931,527.36 477,599.36 0.27 607.35 MWD+IFR-AK-CAZ-SC(7) 10,338.37 90.75 17.28 6,305.68 6,146.03 1,635.60 -3,393.02 5,931,617.65 477,626.84 1.09 701.69 MWD+IFR-AK-CAZ-SC(7) 10,433.81 91.49 16.83 6,303.81 6,144.16 1,726.83 -3,365.03 5,931,708.79 477,655.06 0.91 797.05 MWD+IFR-AK-CAZ-SC(7) 10,529.84 90.72 16.28 6,301.96 6,142.31 1,818.86 -3,337.67 5,931,800.75 477,682.64 0.99 893.03 MWD+IFR-AK-CAZ-SC(7) 10,624.69 89.71 15.32 6,301.60 6,141 95 1,910.12 -3,311.85 5,931,891.94 477,708.69 1.47 987.87 MWD+IFR-AK-CAZ-SC(7) 10,719.49 90.10 13.79 6,301.76 6,142.11 2,001.88 -3,288.03 5,931,983.62 477,732.75 1.67 1,082.66 MWD+IFR-AK-CAZ-SC(7) 10,813.18 90.17 13.43 6,301.54 6,141.89 2,092.94 -3,265.98 5,932,074.62 477,755.02 0.39 1,176.32 MWD+IFR-AK-CAZ-SC(7) 10,909.52 89.52 13.68 6,301.80 6,142.15 2,186.59 -3,243.40 5,932,168.20 477,777.83 0.72 1,272.63 MWD+IFR-AK-CAZ-SC(7) 11,004.94 87.90 14.20 6,303.95 6,144.30 2,279.17 -3,220.42 5,932,260.72 477,801.04 1.78 1,368.01 MWD+IFR-AK-CAZ-SC(7) 11,099.66 85.64 15.14 6,309.28 6,149.63 2,370.65 -3,196.47 5,932,352.13 477,825.22 2.58 1,462.57 MWD+IFR-AK-CAZ-SC(7) 11,194.61 83.06 16.14 6,318.63 6,158.98 2,461.64 -3,171.00 5,932,443.04 477,850.91 2.91 1,557.04 MWD+IFR-AK-CAZ-SC(7) 11,290.45 83.88 15.56 6,329.53 6,169.88 2,553.23 -3,145.00 5,932,534.56 477,877.15 1.05 1,652.25 MWD+IFR-AK-CAZ-SC(7) 11,384.08 84.12 15.30 6,339.32 6,179.67 2,642.99 -3,120.22 5,932,624.25 477,902.14 0.38 1,745.36 MWD+IFR-AK-CAZ-SC(7) 11,479.00 84.05 15.25 6,349.10 6,189.45 2,734.07 -3,095.35 5,932,715.26 477,927.24 0.09 1,839.78 MWD+IFR-AK-CAZ-SC(7) 3/28,2016 i:18:09PM Page 5 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-11 Project: Kuparuk River Unit TVD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Site: Kuparuk 2S Pad MD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Well: 2S-11 North Reference: True Wellbore: 2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11 Database: OAKEDMP2 Survey Map Map= Vertical MD Inc Azi TVD 1VDSS 114 +E►W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) fusft) (usft) (ft) (ft) ('1100');, (ft) Survey Tool Name 11,574.24 84.15 14.44 6,358.89 6,199.24 2,825.65 -3,071.08 5,932,806.76 477,951.74 0.85 1,934.51 MWD+IFR-AK-CAZ-SC(7) 11,668.50 89.69 13.69 6,363.95 6,204.30 2,916.91 -3,048.21 5,932,897.96 477,974.84 5.93 2,028.58 MWD+IFR-AK-CAZ-SC(7) 11,763.42 91.34 13.51 6,363.10 6,203.45 3,009.16 -3,025.90 5,932,990.14 477,997.38 1.75 2,123.47 MWD+IFR-AK-CAZ-SC(7) 11,858.44 93.19 13.01 6,359.34 6,199.69 3,101.57 -3,004.12 5,933,082.49 478,019.39 2.02 2,218.37 MWD+IFR-AK-CAZ-SC(7) 11,953.35 95.17 12.80 6,352.43 6,192 78 3,193.84 -2,982.98 5,933,174.69 478,040.76 2.10 2,312.96 MWD+IFR-AK-CAZ-SC(7) 12,047.90 94.59 13.42 6,344.38 6,184.73 3,285.59 -2,961.61 5,933,266.38 478,062.36 0.90 2,407.11 MWD+IFR-AK-CAZ-SC(7) 12,143.18 95.47 14.19 6,336.03 6,176.38 3,377.76 -2,938.96 5,933,358.48 478,085.23 1.23 2,502.00 MWD+IFR-AK-CAZ-SC(7) 12,238.17 91.96 16.01 6,329.88 6,170.23 3,469.25 -2,914.27 5,933,449.91 478,110.15 4.16 2,596.77 MWD+IFR-AK-CAZ-SC(7) 12,332.19 92.61 15.96 6,326.13 6,166.48 3,559.57 -2,888.40 5,933,540.15 478,136.25 0.69 2,690.70 MWD+IFR-AK-CAZ-SC(7) 12,427.18 93.12 15.71 6,321.38 6,161.73 3,650.84 -2,862.52 5,933,631.34 478,162.36 0.60 2,785.57 MWD+IFR-AK-CAZ-SC(7) 12,522.73 93.05 16.20 6,316.24 6,156.59 3,742.57 -2,836.29 5,933,723.00 478,188.82 0.52 2,880.96 MWD+IFR-AK-CAZ-SC(7) 12,616.68 91.89 15.87 6,312.19 6,152.54 3,832.78 -2,810.36 5,933,813.14 478,214.97 1.28 2,974.81 MWD+IFR-AK-CAZ-SC(7) 12,711.02 89.42 13.86 6,311.11 6,151.46 3,923.95 -2,786.16 5,933,904.23 478,239.39 3.38 3,069.13 MWD+IFR-AK-CAZ-SC(7) 12,806.01 88.21 14.16 6,313.07 6,153.42 4,016.09 -2,763.17 5,933,996.31 478,262.61 1.31 3,164.08 MWD+IFR-AK-CAZ-SC(7) 12,900.27 88.21 13.80 6,316.02 6,156.37 4,107.51 -2,740.41 5,934,087.66 478,285.60 0.38 3,258.28 MWD+IFR-AK-CAZ-SC(7) 12,996.81 88.56 15.26 6,318.74 6,159.09 4,200.93 -2,716.20 5,934,181.01 478,310.04 1.55 3,354.78 MWD+IFR-AK-CAZ-SC(7) 13,090.31 89.55 16.56 6,320.28 6,160.63 4,290.83 -2,690.58 5,934,270.84 478,335.89 1.75 3,448.25 MWD+IFR-AK-CAZ-SC(7) 13,186.52 89.69 17.29 6,320.92 6,161.27 4,382.87 -2,662.57 5,934,362.80 478,364.13 0.77 3,544.40 MWD+IFR-AK-CAZ-SC(7) 13,281 45 90.41 17.81 6,320.84 6,161.19 4,473.38 -2,633.94 5,934,453.23 478,392.98 0.94 3,639.24 MWD+IFR-AK-CAZ-SC(7) 13,376.39 90.07 18.31 6,320.44 6,160.79 4,563.64 -2,604.51 5,934,543.40 478,422.63 0.64 3,734.04 MWD+IFR-AK-CAZ-SC(7) 13,470.95 90.68 17.91 6,319.82 6,160.17 4,653.51 -2,575.12 5,934,633.19 478,452.25 0.77 3,828.46 MWD+IFR-AK-CAZ-SC(7) 13,565.85 91.08 16.45 6,318.36 6,158.71 4,744.17 -2,547.09 5,934,723.77 478,480.50 1.59 3,923.28 MWD+IFR-AK-CAZ-SC(7) 13,660.43 94.07 14.55 6,314.11 6,154.46 4,835.20 -2,521.84 5,934,814.73 478,505.98 3.74 4,017.74 MWD+IFR-AK-CAZ-SC(7) 13,755.21 94.19 14.47 6,307.29 6,147.64 4,926.72 -2,498.16 5,934,906.18 478,529.89 0.15 4,112.27 MWD+IFR-AK-CAZ-SC(7) 13,846.76 93.43 13.55 6,301.20 6,141.55 5,015.35 -2,476.05 5,934,994.74 478,552.22 1.30 4,203.61 MWD+IFR-AK-CAZ-SC(7) 13,939.31 91.77 14.41 6,297.01 6,137.36 5,105.06 -2,453.71 5,935,084.39 478,574.78 2.02 4,296.04 MWD+IFR-AK-CAZ-SC(7) 14,030.75 91.61 13.89 6,294.31 6,134.66 5,193.69 -2,431.37 5,935,172.95 478,597.35 0.59 4,387.43 MWD+IFR-AK-CAZ-SC(7) 14,123.09 91.75 9.24 6,291.60 6,131.95 5,284.09 -2,412.87 5,935,263.29 478,616.07 5.04 4,479.54 MWD+IFR-AK-CAZ-SC(7) 14,215.34 92.40 11.25 6,288.26 6,128.61 5,374.80 -2,396.47 5,935,353.96 478,632.69 2.29 4,571.41 MWD+IFR-AK-CAZ-SC(7) 14,307.14 93.12 12.23 6,283.84 6,124.19 5,464.58 -2,377.82 5,935,443.68 478,651.57 1.32 4,662.95 MWD+IFR-AK-CAZ-SC(7) 14,397.14 92.64 12.73 6,279.32 6,119.67 5,552.34 -2,358.39 5,935,531.38 478,671.22 0.77 4,752.75 MWD+IFR-AK-CAZ-SC(7) 14,489.23 92.93 13.86 6,274.84 6,115.19 5,641.85 -2,337.24 5,935,620.83 478,692.59 1.27 4,844.69 MWD+IFR-AK-CAZ-SC(7) 14,583.28 91.12 13.07 6,271.52 6,111.87 5,733.26 -2,315.35 5,935,712.17 478,714.70 2.10 4,938.64 MWD+1FR-AK-CAZ-SC(7) 14,675.75 91.44 13.86 6,269.45 6,109.80 5,823.16 -2,293.83 5,935,802.01 478,736.45 0.92 5,031.05 MWD+IFR-AK-CAZ-SC(7) 14,767.70 90.58 14.04 6,267.83 6,108.18 5,912.38 -2,271.67 5,935,891.17 478,758.84 0.96 5,122.97 MWD+IFR-AK-CAZ-SC(7) 14,860.87 90.14 13.93 6,267.25 6,107.60 6,002.79 -2,249.15 5,935,981.51 478,781.58 0.49 5,216.13 MWD+IFR-AK-CAZ-SC(7) 14,952.76 90.00 13.59 6,267.13 6,107.48 6,092.04 -2,227.29 5,936,070.70 478,803.66 0.40 5,308.00 MWD+IFR-AK-CAZ-SC(7) 15,043.78 90.07 14.28 6,267.08 6,107.43 6,180.38 -2,205.37 5,936,158.98 478,825.80 0.76 5,399.00 MWD+IFR-AK-CAZ-SC(7) 15,136.69 90.58 15.86 6,266.55 6,106.90 6,270.09 -2,181.22 5,936,248.62 478,850.18 1.79 5,491.90 MWD+IFR-AK-CAZ-SC(7) 15,226.25 90.68 17.08 6,265.57 6,105.92 6,355.97 -2,155.83 5,936,334.42 478,875.78 1.37 5,581.43 MWD+IFR-AK-CAZ-SC(7) 3/28!2016 1:18:09PM Page 6 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-11 Project: Kuparuk River Unit TVD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Site: Kuparuk 2S Pad MD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Well: 2S-11 North Reference: True Wellbore: 2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +Ei-W Northing Easting DLS Section (usft) (*) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 15,309 00 90.68 17.08 6,264 59 6,104 94 6,43507 -2,131.53 5,936,413.45 478,900.28 0.00 5,664 12 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. L. Yes L No have checked to the best of my ability that the following data is correct: Suriace Coordinates LI Declination & Convergence El GRS Survey Corrections Survey Tool Codes Vincent SLB DE Osara Scott Brunswick Chent Representative: 28-Mar-2016 Date 3128/2016 1.18:09PM Page 7 COMPASS 5000.1 Build 74 r S Cement Detail Report &MA% 2S-11 C.onocoPhillips String: Conductor Cement Job: DRILLING ORIGINAL, 3/1/2016 09:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Conductor Cement 12/1/2014 02:46 12/6/2014 18:40 2S-11 Comment CH2MHill drilled 42"hole to 80'below ground level, set 16"62.58#APISL Grade B Insulated Conductor. SLB cemented in two stages with 15.7ppg Arctic Set 1 cement.Sealed Pan Cellar is 5'deep,6'wide. Cement Stages Stage#<Stage Number?> Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 4/18/2016 • ' s • Cement Detail Report 2S-11 ii,� hl3 ConocoPhillips Ar�.3Lk..3 String: Surface Casing Cement Job: DRILLING ORIGINAL, 3/1/2016 09:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 3/6/2016 01:00 3/6/2016 04:30 2S-11 Comment Pressure test cement lines to 500psi Low and 3500psi high(Test Charted-Good Test). Reciprocating casing,pump 40bbls of CW100 using 6.4BPM, 170psi, 18%flow out and chase with 76bbls of 10.5ppg Mud Push Il using 5BPM, 140psi, 15%flow out. Drop bottom plug. Continue to reciprocate while pumping 358bbls of 11 ppg DeepCrete Lead cement using 6BPM, 190psi, 18%flow out. Chase Lead cement with 15.8ppg Class G Tail cement using 6BPM,358psi, 15% flow out. Drop top plug and kick out using 3bbls of tail cement and 1 Obbls of water using 5BPM, 170psi, 11%flow out. Switch over to rig pumps and continue displacement of cement using 9.7ppg spud mud at 7BPM,263psi,25%flow out. Caught up to cement at 670stks and diverted to cellar at 700stks when cement returns came to surface. Reduce rate to 5 BPM,274psi and again to 4BPM,286psi to help with cellar returns. Increase rate to 5 BPM,387psi at 1600stks followed by reductin rate to 3BPM,51 psi at 2000stks and 1BPM at,515psi at 2400stks. Bump plug at 2502stks. Pressure up 500psi over circulating pressure to 1020psi and hold for 10min. Bleed off to check floats(Floats held). Cement in place at 04:30 with Note: Experienced 50k overpull after kickout of Top Plug. Displaced cement while sitting on landing ring. 182bbls of cement returned to surface 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 40.7 2,859.2 Yes 182.0 Yes Yes casing Q Pump Init(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 7 1 6 515.0 1,020.0 Yes 18.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pressure test cement lines to 500psi Low and 3500psi high(Test Charted-Good Test). Reciprocating casing,pump 40bbls of CW100 using 6.4BPM, 170psi, 18%flow out and chase with 76bbls of 10.5ppg Mud Push II using 5BPM, 140psi, 15%flow out. Drop bottom plug. Continue to reciprocate while pumping 358bbls of 11 ppg DeepCrete Lead cement using 6BPM, 190psi, 18%flow out. Chase Lead cement with 15.8ppg Class G Tail cement using 6BPM,358psi, 15% flow out. Drop top plug and kick out using 3bbls of tail cement and 10bbls of water using 5BPM, 170psi, 11%flow out. Switch over to rig pumps and continue displacement of cement using 9.7ppg spud mud at 7BPM,263psi,25%flow out. Caught up to cement at 670stks and diverted to cellar at 700stks when cement returns came to surface. Reduce rate to 5 BPM,274psi and again to 4BPM,286psi to help with cellar returns. Increase rate to 5 BPM,387psi at 1600stks followed by reductin rate to 3BPM,51 psi at 2000stks and 1BPM at,515psi at 2400stks. Bump plug at 2502stks. Pressure up 500psi over circulating pressure to 1020psi and hold for 10min. Bleed off to check floats(Floats held). Cement in place at 04:30 with Note: Experienced 50k overpull after kickout of Top Plug. Displaced cement while sitting on landing ring. 182bbls of cement returned to surface Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) CW100 40.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 8.35 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MudPush II _ 75.0 Yield(fN/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 10.55 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) 11.Oppg DeepCrete 40.7 2,358.2 1,054 G 358.3 Lead Cement Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.91 6.82 11.00 4.00 Additives Additive Type Concentration Conc Unit label D046 ANTIFOAM 0.2 %BWOB Additive Type Concentration Conc Unit label D185 DISPERSANT 0.07 gal/sx Additive Type Concentration Conc Unit label D177 RETARDER 0.02 gal/sx Page 1/2 Report Printed: 4/18/2016 • Milting Cement Detail Report tkWeIlis 2S-11 tai€rps At. String: Surface Casing Cement Job: DRILLING ORIGINAL, 3/1/2016 09:00 Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) 15.8ppg Class G Tail 2,358.2 2,858.2 303 G 63.0 Cement Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1 (psi) 1.17 5.14 15.80 3.00 Additives Additive Type Concentration Conc Unit label D186 ACCELERATOR 0.13 gal/sx Additive Type Concentration Conc Unit label D046 ANTIFOAM 0.2 %BWOB Additive Type Concentration Conc Unit label D065 DISPERSANT 0.3 %BWOC Additive Type Concentration Conc Unit label D167 FLUID LOSS 0.4 %BWOC Page 2/2 Report Printed: 4/18/2016 • Cement Detail Report • 2S-11 ConacoPhimlips String: Intermediate Casing Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 3/12/2016 16:45 3/12/2016 23:30 2S-11 Comment 1st Stage Cement 7-5/8"casing: Pump 5 bbl water,test trips on cement unit and pressure test cement lines to 3500psi(Good Test). Pump 40bbI of 11.5ppg Mud Push II at 4.7 BPM,285psi,drop bottom plug and chase with 134bbls of 15.8ppg cement @ 5.7 BPM,250psi. Drop shut off plug and pump 2bbls of cement on top and chase with 10bbls of H2O from cement unit. Swap to rig pumps and continue displacment using drill mud(9.9+ppg)at 7 BPM, 160psi. Final circulating pressure was 3 BPM,725psi. Plug bumped at 3660stk and pressured up to 1225psi for 5min. Bleed off 3.5bbls and check floats(Floats holding). Pressure up to shear stage tool. Shearted out at 2740psi. Verified open with 3 BPM,290psi, 12%flow out. Cement in place at 19:15hrs,3/12/2016. 2nd Stage Cement 7-5/8"casing(Stage Tool): Pump Sbbl of H2O.Test trips on cement unit and pressure test cement lines to 3500psi(Good Test). Pump 43.3bbl of 11.5ppg Mud Push II at 5.0 BPM,212psi. Chase with 90.1bbls of 15.8ppg cement at 5.2 BPM,200 psi. Drop closing plug and pump 2bbls of cement on top of plug followed by 10bbls of H2O from cement unit. Swap over to rig pumps and continue displacing cement with initial circulating rate of 7BPM, 160 psi and a final circulating rate of 3 BPM,710psi. Bump plug at 2790stks and pressure up to 1770psi,observe stage tool close,hold pressure for 5min. Bleed off 3 bbls and check floats.(Floats holding).Cement in place at 23:18,3/12/2016. Note:35 bbls lost during 2nd stage cement job. Cement Stages Stage# Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing Cement to top of Cairn 7,000.0 8,492.0 Yes Yes Yes Cement Q Pump[nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 3 6 710.0 1,215.0 Yes 18.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 8,280.0 Drill Bit 8,492.0 6 3/4 Comment 1st Stage Cement 7-5/8"casing: Pump 5 bbl water,test trips on cement unit and pressure test cement lines to 3500psi(Good Test). Pump 40bbl of 11.5ppg Mud Push II at 4.7 BPM,285psi,drop bottom plug and chase with 134bbls of 15.8ppg cement @ 5.7 BPM,250psi. Drop shut off plug and pump 2bbls of cement on top and chase with 10bbls of H2O from cement unit. Swap to rig pumps and continue displacment using drill mud(9.9+ppg)at 7 BPM, 160psi. Final circulating pressure was 3 BPM,725psi. Plug bumped at 3660stk and pressured up to 1225psi for 5min. Bleed off 3.5bbls and check floats(Floats holding). Pressure up to shear stage tool. Shearted out at 2740psi. Verified open with 3 BPM,290psi, 12%flow out. Cement in place at 19:15hrs,3/12/2016. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mud Push II 6,344.0 7,000.0 40.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 11.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Cement 7,000.0 8,492.0 643 G 134.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.17 5.11 15.80 Additives Additive Type Concentration Conc Unit label D186 Accelerator 0.13 gal/sx Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 Dispersant 0.6 %BWOC Additive Type Concentration Conc Unit label D167 Fluid loss 0.8 %BWOC Page 1/2 Report Printed: 4/26/2016 �, e Cement Detail Report • 2S-11 CcoPhitlipir s �. .� String: Intermediate Casing Cement Job: Cement Stages Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing Cement 500'above C37 5,300.0 6,330.0 No Yes No Cement Q Pump mit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 4 5 720.0 1,770.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 6,237.0 Drill Bit 6,469.0 6 3/4 Comment 2nd Stage Cement 7-5/8"casing(Stage Tool): Pump 5bbl of H2O.Test trips on cement unit and pressure test cement lines to 3500psi(Good Test). Pump 43.3bbl of 11.5ppg Mud Push II at 5.0 BPM,212psi. Chase with 90.1 bbls of 15.8ppg cement at 5.2 BPM,200 psi. Drop closing plug and pump 2bbls of cement on top of plug followed by 10bbls of H2O from cement unit. Swap over to rig pumps and continue displacing cement with initial circulating rate of 7BPM, 160 psi and a final circulating rate of 3 BPM,710psi. Bump plug at 2790stks and pressure up to 1770psi,observe stage tool close, hold pressure for 5min. Bleed off 3 bbls and check floats.(Floats holding).Cement in place at 23:18,3/12/2016. Note:35 bbls lost during cement job. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mud Push II 4,590.9 5,300.0 Yield(f/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 11.60 Additives Additive Type Concentration Conc Unit label D186 Accelerator 0.13 gal/sx Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 Dispersant 0.6 %BWOC Additive Type Concentration Conc Unit label D167 Fluid Loss 0.8 %BWOC Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Cement 5,300.0 6,330.0 433 G 90.1 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.17 5.12 15.80 3.43 Additives Additive Type Concentration Conc Unit label D186 Accelerator 0.13 gal/sx Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 Dispersant 0.6 %BWOC Additive Type Concentration Conc Unit label D167 Fluid Loss 0.8 %BWOC Page 2/2 Report Printed: 4/26/2016 21._ 52. 19 RECE.Er • 27064 APR 27 201 ScblumbergerA°GGTransmittal#: 21APR16-SP02 Drilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery M./GENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2S-11 Date Dispatched: 21-Apr-16 Job#: 14AKA0067 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 5 Contents on CD N/A VISION*Service 2" MD x x VISION*Service 2'TVD x x VISION*Service 5'MD x x VISION*Service 5'TVD x x VISION*Service MicroScope Resistivity Image x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Tom.Osterkamp c(Dconocophillips.com AlaskaPTSPrintCenter(a�slb.com Tom Osterkamp Attn:Stephanie Pacillo 907-263-4795pr) i/3 Received By: ,,�v 6,...4 / AIMED 21 52 1 9 ® 27064 APR 27 2010 AOGCC FINAL NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-11 2S-11 Definitive Survey Report 28 March, 2016 NAD 27 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-11 Project: Kuparuk River Unit TVD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Site: Kuparuk 2S Pad MD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Well: 2S-11 North Reference: True Wellbore: 2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11 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 2S-11 Well Position +NI-S 0.00 usft Northing: 5,929,973.68 usft Latitude: 70°13'11.436 N +E/-W 0.00 usft Easting: 481,015.40 usft Longitude: 150°9'11.362 W Position Uncertainty 0.00 usft Wellhead Elevation: 118.97 usfl Ground Level: 120.O0usft Wellbore 2S-11 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2015 3/10/2016 18.31 80.86 57,484 Design 2S-11 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.65 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (usft) (usft) (usft) (°) 39.65 0.00 0.00 15.00 Survey Program Date 3/28/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 95.00 843.50 2S-11 Srvy 1 SLB_NSG+SSHOT(2S-11 GYD-GC-SS Gyrodata gyro single shots 3/3/2016 10:22 868.42 2,797.08 2S-11 Srvy 2 SLB_MWD+GMAG(2S-11;MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/3/2016 10:24 2,861.69 2,861.69 2S-11 Srvy 3 SLB_MWD-INC_Only-Filler INC+TREND Inclinometer+known azi trend 3/7/2016 9:50 2,953.67 8,420.90 2S-11 Srvy 4 SLB_MWD+GMAG(2S-11;MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/7/2016 9:52 8,516.63 8,516.63 2S-11 Srvy 5 SLB_INC+TREND(2S-11) INC+TREND Inclinometer+known azi trend 3/16/2016 9:11 8,568.17 9,040.05 2S-11 Srvy 6 SLB_MWD+GMAG(2S-11;MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/16/2016 9:1. 9,106.77 15,226.25 2S-11 Srvy 7 SLB_MWD+GMAG(2S-11;MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/18/2016 9:2, Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) 0100) (ft) Survey Tool Name 39.65 0.00 0.00 39.65 -120.00 0.00 0.00 5,929,973.68 481,015.40 0.00 0.00 UNDEFINED 95.00 0.16 135.12 95.00 -64.65 -0.05 0.05 5,929,973.63 481,015.45 0.29 -0.04 GYD-GC-SS(1) 187.50 0.41 70.28 187.50 27.85 -0.03 0.46 5,929,973.64 481,015.86 0.40 0.08 GYD-GC-SS(1) 280.50 0.51 125.46 280.50 120.85 -0.16 1.11 5,929,973.51 481,016.51 0.47 0.13 GYD-GC-SS(1) 373.50 2.22 163.14 373.47 213.82 -2.13 1.97 5,929,971.55 481,017.36 1.98 -1.54 GYD-GC-SS(1) 468.50 4.11 177.23 468.32 308.67 -7.29 2.67 5,929,966.39 481,018.05 2.14 -6.35 GYD-GC-SS(1) 561.50 5.25 182.80 561.01 401.36 -14.87 2.62 5,929,958.81 481,017.98 1.32 -13.68 GYD-GC-SS(1) 654.50 7.47 185.76 653.43 493.78 -25.13 1.80 5,929,948.54 481,017.14 2.41 -23.81 GYD-GC-SS(1) 749.50 9.83 189.46 747.34 587.69 -39.28 -0.15 5,929,934.41 481,015.15 2.55 -37.98 GYD-GC-SS(1) 3/28/2016 1:18.:09PM Page 2 COMPASS 5000.1 Build 74 • 0 . Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-11 Project: Kuparuk River Unit TVD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Site: Kuparuk 2S Pad MD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Well: 2S-11 North Reference: True Wellbore: 2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°l100') (ft) Survey Tool Name 843.50 11.45 189.24 839.72 680.07 -56.40 -2.97 5,929,917.29 481,012.29 1.72 -55.25 GYD-GC-SS(1) 868.42 11.95 190.15 864.13 704.48 -61.38 -3.82 5,929,912.31 481,011.43 2.14 -60.28 MWD+IFR-AK-CAZ-SC(2) 963.14 12.69 191.70 956.67 797.02 -81.23 -7.66 5,929,892.48 481,007.54 0.86 -80.44 MWD+IFR-AK-CAZ-SC(2) 1,058.00 13.91 192.54 1,048.98 889.33 -102.56 -12.24 5,929,871.16 481,002.90 1.30 -102.23 MWD+IFR-AK-CAZ-SC(2) 1,153.39 16.63 195.74 1,140.99 981.34 -126.89 -18.44 5,929,846.85 480,996.64 2.98 -127.34 MWD+IFR-AK-CAZ-SC(2) 1,247.48 19.41 196.13 1,230.46 1,070.81 -154.88 -26.44 5,929,818.88 480,988.58 2.96 -156.44 MWD+IFR-AK-CAZ-SC(2) 1,341.78 21.08 194.81 1,318.93 1,159.28 -186.33 -35.12 5,929,787.46 480,979.81 1.84 -189.07 MWD+IFR-AK-CAZ-SC(2) 1,436.76 24.26 192.74 1,406.56 1,246.91 -221.88 -43.80 5,929,751.93 480,971.05 3.45 -225.66 MWD+IFR-AK-CAZ-SC(2) 1,531.73 25.11 195.81 1,492.86 1,333.21 -260.30 -53.59 5,929,713.54 480,961.16 1.62 -265.30 MWD+IFR-AK-CAZ-SC(2) 1,625.03 26.05 202.72 1,577.03 1,417.38 -298.26 -66.90 5,929,675.62 480,947.76 3.35 -305.41 MWD+IFR-AK-CAZ-SC(2) 1,720.90 26.39 208.91 1,663.05 1,503.40 -336.33 -85.33 5,929,637.60 480,929.23 2.87 -346.96 MWD+IFR-AK-CAZ-SC(2) 1,815.09 26.20 216.67 1,747.52 1,587.87 -371.35 -107.88 5,929,602.64 480,906.60 3.65 -386.61 MWD+IFR-AK-CAZ-SC(2) 1,909.97 26.40 220.61 1,832.59 1,672.94 -404.16 -134.12 5,929,569.90 480,880.28 1.85 -425.10 MWD+IFR-AK-CAZ-SC(2) 2,003.79 27.56 224.75 1,916.20 1,756.55 -435.41 -162.98 5,929,538.72 480,851.34 2.35 -462.76 MWD+IFR-AK-CAZ-SC(2) 2,098.60 29.24 230.28 1,999.61 1,839.96 -465.79 -196.24 5,929,508.43 480,818.01 3.29 -500.71 MWD+IFR-AK-CAZ-SC(2) 2,193.38 32.14 231.75 2,081.11 1,921.46 -496.20 -233.85 5,929,478.12 480,780.33 3.16 -539.82 MWD+IFR-AK-CAZ-SC(2) 2,287.97 35.75 232.17 2,159.57 1,999.92 -528.74 -275.45 5,929,445.69 480,738.65 3.82 -582.01 MWD+IFR-AK-CAZ-SC(2) 2,381.57 38.74 232.68 2,234.07 2,074.42 -563.27 -320.34 5,929,411.27 480,693.67 3.21 -626.99 MWD+IFR-AK-CAZ-SC(2) 2,476.61 40.40 236.70 2,307.34 2,147.69 -598.22 -369.75 5,929,376.45 480,644.19 3.21 -673.53 MWD+IFR-AK-CAZ-SC(2) 2,570.83 42.74 240.21 2,377.84 2,218.19 -630.87 -423.03 5,929,343.94 480,590.83 3.50 -718.87 MWD+IFR-AK-CAZ-SC(2) 2,667.07 46.96 242.12 2,446.05 2,286.40 -663.56 -482.49 5,929,311.40 480,531.29 4.60 -765.83 MWD+IFR-AK-CAZ-SC(2) 2,761.21 48.85 244.05 2,509.16 2,349.51 -695.16 -544.78 5,929,279.96 480,468.93 2.52 -812.47 MWD+IFR-AK-CAZ-SC(2) 2,797.08 48.83 244.01 2,532.77 2,373.12 -706.99 -569.05 5,929,268.20 480,444.63 0.10 -830.18 MWD+IFR-AK-CAZ-SC(2) 2,859.20 48.75 243.74 2,573.70 2,414.05 -727.57 -611.01 5,929,247.73 480,402.62 0.35 -860.92 NOT an Actual Survey 10 3/4"x 13-1/2" 2,861.69 48.75 243.73 2,575.34 2,415.69 -728.39 -612.69 5,929,246.90 480,400.94 0.35 -862.15 INC+TREND(3) 2,953.67 49.09 243.78 2,635.78 2,476.13 -759.05 -674.88 5,929,216.40 480,338.68 0.37 -907.86 MWD+IFR-AK-CAZ-SC(4) 3,050.81 49.13 243.07 2,699.37 2,539.72 -791.91 -740.55 5,929,183.72 480,272.93 0.55 -956.59 MWD+IFR-AK-CAZ-SC(4) 3,146.04 48.65 242.80 2,761.98 2,602.33 -824.55 -804.45 5,929,151.24 480,208.96 0.55 -1,004.66 MWD+IFR-AK-CAZ-SC(4) 3,240.73 48.66 242.53 2,824.53 2,664.88 -857.20 -867.60 5,929,118.75 480,145.74 0.21 -1,052.54 MWD+IFR-AK-CAZ-SC(4) 3,334.60 48.62 242.78 2,886.56 2,726.91 -889.56 -930.18 5,929,086.55 480,083.08 0.20 -1,100.00 MWD+IFR-AK-CAZ-SC(4) 3,428.84 48.52 242.46 2,948.92 2,789.27 -922.05 -992.92 5,929,054.22 480,020.26 0.28 -1,147.62 MWD+IFR-AK-CAZ-SC(4) 3,525.14 48.54 243.35 3,012.69 2,853.04 -954.92 -1,057.16 5,929,021.52 479,955.95 0.69 -1,195.99 MWD+IFR-AK-CAZ-SC(4) 3,619.94 48.57 242.46 3,075.44 2,915.79 -987.28 -1,120.42 5,928,989.31 479,892.61 0.70 -1,243.63 MWD+IFR-AK-CAZ-SC(4) 3,713.22 48.50 243.54 3,137.21 2,977.56 -1,019.02 -1,182.70 5,928,957.74 479,830.26 0.87 -1,290.40 MWD+IFR-AK-CAZ-SC(4) 3,808.42 48.13 242.50 3,200.52 3,040.87 -1,051.27 -1,246.06 5,928,925.65 479,766.82 0.90 -1,337.95 MWD+IFR-AK-CAZ-SC(4) 3,903.51 48.06 244.61 3,264.04 3,104.39 -1,082.79 -1,309.42 5,928,894.30 479,703.39 1.65 -1,384.79 MWD+IFR-AK-CAZ-SC(4) 3,996.52 48.56 246.68 3,325.90 3,166.25 -1,111.42 -1,372.69 5,928,865.83 479,640.06 1.75 -1,428.83 MWD+IFR-AK-CAZ-SC(4) 4,091.62 49.01 251.13 3,388.58 3,228.93 -1,137.15 -1,439.40 5,928,840.27 479,573.28 3.55 -1,470.95 MWD+IFR-AK-CAZ-SC(4) 4,187.35 49.15 251.78 3,451.28 3,291.63 -1,160.15 -1,507.98 5,928,817.44 479,504.65 0.53 -1,510.92 MWD+IFR-AK-CAZ-SC(4) 3/28/2016 1:18:09PM Page 3 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-11 Project: Kuparuk River Unit TVD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Site: Kuparuk 2S Pad MD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Well: 2S-11 North Reference: True Wellbore: 2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,281.19 48.96 251.37 3,512.78 3,353.13 -1,182.56 -1,575.23 5,928,795.21 479,437.36 0.39 -1,549.96 MWD+IFR-AK-CAZ-SC(4) 4,375.29 49.00 248.75 3,574.55 3,414.90 -1,206.76 -1,641.96 5,928,771.17 479,370.57 2.10 -1,590.62 MWD+IFR-AK-CAZ-SC(4) 4,469.90 49.08 246.21 3,636.57 3,476.92 -1,234.13 -1,707.95 5,928,743.98 479,304.52 2.03 -1,634.12 MWD+IFR-AK-CAZ-SC(4) 4,566.21 49.27 246.36 3,699.53 3,539.88 -1,263.44 -1,774.67 5,928,714.84 479,237.73 0.23 -1,679.70 MWD+IFR-AK-CAZ-SC(4) 4,659.65 49.12 244.93 3,760.60 3,600.95 -1,292.60 -1,839.10 5,928,685.84 479,173.23 1.17 -1,724.55 MWD+IFR-AK-CAZ-SC(4) 4,754.40 49.11 244.64 3,822.62 3,662.97 -1,323.12 -1,903.91 5,928,655.49 479,108.36 0.23 -1,770.80 MWD+IFR-AK-CAZ-SC(4) 4,849.12 49.11 244.37 3,884.62 3,724.97 -1,353.94 -1,968.54 5,928,624.83 479,043.65 0.22 -1,817.30 MWD+IFR-AK-CAZ-SC(4) 4,945.41 49.12 243.49 3,947.65 3,788.00 -1,385.93 -2,033.93 5,928,593.01 478,978.19 0.69 -1,865.13 MWD+IFR-AK-CAZ-SC(4) 5,039.47 49.10 241.93 4,009.22 3,849.57 -1,418.53 -2,097.12 5,928,560.57 478,914.92 1.25 -1,912.97 MWD+IFR-AK-CAZ-SC(4) 5,134.17 49.13 244.01 4,071.21 3,911.56 -1,451.06 -2,160.89 5,928,528.20 478,851.08 1.66 -1,960.90 MWD+IFR-AK-CAZ-SC(4) 5,228.65 48.62 244.00 4,133.35 3,973.70 -1,482.26 -2,224.86 5,928,497.17 478,787.04 0.54 -2,007.59 MWD+IFR-AK-CAZ-SC(4) 5,322.94 47.31 247.20 4,196.49 4,036.84 -1,511.20 -2,288.61 5,928,468.39 478,723.22 2.88 -2,052.04 MWD+IFR-AK-CAZ-SC(4) 5,417.46 45.96 248.90 4,261.40 4,101.75 -1,536.89 -2,352.34 5,928,442.86 478,659.44 1.94 -2,093.35 MWD+IFR-AK-CAZ-SC(4) 5,512.69 45.04 251.26 4,328.15 4,168.50 -1,560.04 -2,416.18 5,928,419.88 478,595.54 2.01 -2,132.24 MWD+IFR-AK-CAZ-SC(4) 5,607.68 44.14 252.83 4,395.80 4,236.15 -1,580.60 -2,479.61 5,928,399.47 478,532.07 1.50 -2,168.52 MWD+IFR-AK-CAZ-SC(4) 5,701.07 43.76 255.38 4,463.04 4,303.39 -1,598.36 -2,541.94 5,928,381.88 478,469.70 1.94 -2,201.80 MWD+IFR-AK-CAZ-SC(4) 5,797.14 43.48 258.77 4,532.59 4,372.94 -1,613.18 -2,606.52 5,928,367.22 478,405.10 2.45 -2,232.83 MWD+IFR-AK-CAZ-SC(4) 5,891.89 44.13 265.83 4,601.02 4,441.37 -1,621.93 -2,671.43 5,928,358.63 478,340.17 5.20 -2,258.09 MWD+IFR-AK-CAZ-SC(4) 5,986.61 42.65 273.91 4,669.90 4,510.25 -1,622.14 -2,736.39 5,928,358.58 478,275.22 6.06 -2,275.10 MWD+IFR-AK-CAZ-SC(4) 6,080.16 41.51 280.26 4,739.37 4,579.72 -1,614.46 -2,798.54 5,928,366.43 478,213.09 4.71 -2,283.76 MWD+IFR-AK-CAZ-SC(4) 6,174.45 41.52 285.09 4,809.99 4,650.34 -1,600.75 -2,859.47 5,928,380.28 478,152.19 3.39 -2,286.30 MWD+IFR-AK-CAZ-SC(4) 6,270.03 42.46 291.01 4,881.05 4,721.40 -1,580.93 -2,920.20 5,928,400.26 478,091.52 4.26 -2,282.87 MWD+IFR-AK-CAZ-SC(4) 6,363.58 42.42 297.34 4,950.13 4,790.48 -1,555.11 -2,977.73 5,928,426.22 478,034.06 4.57 -2,272.81 MWD+IFR-AK-CAZ-SC(4) 6,459.84 41.77 300.56 5,021.56 4,861.91 -1,523.89 -3,034.19 5,928,457.58 477,977.69 2.34 -2,257.27 MWD+IFR-AK-CAZ-SC(4) 6,553.79 41.99 303.70 5,091.52 4,931.87 -1,490.54 -3,087.29 5,928,491.06 477,924.68 2.24 -2,238.80 MWD+IFR-AK-CAZ-SC(4) 6,648.29 42.37 306.84 5,161.56 5,001.91 -1,453.90 -3,139.07 5,928,527.82 477,872.99 2.27 -2,216.82 MWD+IFR-AK-CAZ-SC(4) 6,742.89 42.07 307.93 5,231.61 5,071.96 -1,415.31 -3,189.58 5,928,566.54 477,822.58 0.84 -2,192.61 MWD+IFR-AK-CAZ-SC(4) 6,836.15 42.14 308.78 5,300.81 5,141.16 -1,376.51 -3,238.62 5,928,605.46 477,773.65 0.62 -2,167.82 MWD+IFR-AK-CAZ-SC(4) 6,931.74 43.41 311.70 5,370.98 5,211.33 -1,334.57 -3,288.15 5,928,647.52 477,724.23 2.46 -2,140.13 MWD+IFR-AK-CAZ-SC(4) 7,026.63 44.55 315.32 5,439.27 5,279.62 -1,289.20 -3,335.90 5,928,693.00 477,676.60 2.91 -2,108.67 MWD+IFR-AK-CAZ-SC(4) 7,121.73 46.38 318.32 5,505.97 5,346.32 -1,239.76 -3,382.26 5,928,742.55 477,630.37 2.96 -2,072.91 MWD+IFR-AK-CAZ-SC(4) 7,216.68 49.43 321.36 5,569.62 5,409.97 -1,185.91 -3,427.65 5,928,796.51 477,585.12 3.99 -2,032.64 MWD+IFR-AK-CAZ-SC(4) 7,310.97 52.39 323.75 5,629.07 5,469.42 -1,127.80 -3,472.11 5,928,854.73 477,540.81 3.70 -1,988.02 MWD+IFR-AK-CAZ-SC(4) 7,405.20 53.38 326.76 5,685.94 5,526.29 -1,066.06 -3,514.91 5,928,916.57 477,498.17 2.76 -1,939.46 MWD+IFR-AK-CAZ-SC(4) 7,500.00 54.40 330.77 5,741.83 5,582.18 -1,000.59 -3,554.60 5,928,982.13 477,458.65 3.58 -1,886.49 MWD+IFR-AK-CAZ-SC(4) 7,595.01 55.72 335.53 5,796.26 5,636.61 -931.12 -3,589.74 5,929,051.68 477,423.69 4.34 -1,828.49 MWD+IFR-AK-CAZ-SC(4) 7,689.27 56.32 338.95 5,848.95 5,689.30 -859.06 -3,619.96 5,929,123.81 477,393.65 3.08 -1,766.70 MWD+IFR-AK-CAZ-SC(4) 7,784.20 57.05 342.22 5,901.10 5,741.45 -784.26 -3,646.31 5,929,198.67 477,367.49 2.98 -1,701.27 MWD+IFR-AK-CAZ-SC(4) 7,879.48 59.11 344.06 5,951.48 5,791.83 -706.87 -3,669.75 5,929,276.12 477,344.25 2.71 -1,632.58 MWD+IFR-AK-CAZ-SC(4) 7,972.72 61.74 346.63 5,997.50 5,837.85 -628.42 -3,690.24 5,929,354.60 477,323.96 3.70 -1,562.12 MWD+IFR-AK-CAZ-SC(4) 3/28/2016 1:18:09PM Page 4 COMPASS 5000.1 Build 74 • S . Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-11 Project: Kuparuk River Unit TVD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Site: Kuparuk 2S Pad MD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Well: 2S-11 North Reference: True Wellbore: 2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100) (ft) Survey Tool Name 8,066.87 63.05 349.04 6,041.13 5,881.48 -546.87 -3,707.81 5,929,436.19 477,306.59 2.66 -1,487.89 MWD+IFR-AK-CAZ-SC(4) 8,162.01 64.56 350.53 6,083.13 5,923.48 -462.86 -3,722.94 5,929,520.23 477,291.68 2.12 -1,410.66 MWD+IFR-AK-CAZ-SC(4) 8,257.15 67.28 352.51 6,121.95 5,962.30 -376.96 -3,735.73 5,929,606.15 477,279.10 3.43 -1,331.00 MWD+IFR-AK-CAZ-SC(4) 8,350.47 71.04 355.64 6,155.15 5,995.50 -290.24 -3,744.70 5,929,692.89 477,270.35 5.10 -1,249.55 MWD+IFR-AK-CAZ-SC(4) 8,420.90 74.19 357.85 6,176.19 6,016.54 -223.15 -3,748.51 5,929,759.98 477,266.72 5.38 -1,185.73 MWD+IFR-AK-CAZ-SC(4) 8,485.30 75.19 358.82 6,193.20 6,033.55 -161.06 -3,750.31 5,929,822.07 477,265.07 2.13 -1,126.22 NOT an Actual Survey 7-5/8"x 9-7/8 by 11" 8,516.63 75.68 359.29 6,201.07 6,041.42 -130.74 -3,750.81 5,929,852.39 477,264.65 2.13 -1,097.07 INC+TREND(5) 8,568.17 76.52 0.62 6,213.46 6,053.81 -80.71 -3,750.85 5,929,902.41 477,264.73 2.99 -1,048.75 MWD+IFR-AK-CAZ-SC(6) 8,663.03 77.55 1.63 6,234.74 6,075.09 11.71 -3,749.03 5,929,994.82 477,266.78 1.50 -959.01 MWD+IFR-AK-CAZ-SC(6) 8,757.35 78.56 2.48 6,254.26 6,094.61 103.92 -3,745.72 5,930,087.02 477,270.32 1.39 -869.08 MWD+IFR-AK-CAZ-SC(6) 8,852.10 79.30 2.79 6,272.45 6,112.80 196.81 -3,741.45 5,930,179.88 477,274.83 0.84 -778.25 MWD+IFR-AK-CAZ-SC(6) 8,946.12 80.93 5.59 6,288.60 6,128.95 289.18 -3,734.67 5,930,272.22 477,281.84 3.41 -687.28 MWD+IFR-AK-CAZ-SC(6) 9,040.05 83.41 8.14 6,301.39 6,141.74 381.55 -3,723.55 5,930,364.55 477,293.19 3.77 -595.18 MWD+IFR-AK-CAZ-SC(6) 9,106.77 86.39 9.74 6,307.32 6,147.67 447.19 -3,713.22 5,930,430.16 477,303.69 5.06 -529.10 MWD+IFR-AK-CAZ-SC(7) 9,201.10 89.40 10.93 6,310.79 6,151.14 539.91 -3,696.31 5,930,522.83 477,320.83 3.43 -435.16 MWD+IFR-AK-CAZ-SC(7) 9,296.00 90.38 13.68 6,310.97 6,151.32 632.62 -3,676.09 5,930,615.48 477,341.28 3.08 -340.38 MWD+IFR-AK-CAZ-SC(7) 9,391.36 91.54 14.73 6,309.37 6,149.72 725.05 -3,652.69 5,930,707.84 477,364.91 1.64 -245.04 MWD+IFR-AK-CAZ-SC(7) 9,486.30 91.58 15.29 6,306.79 6,147.14 816.72 -3,628.11 5,930,799.44 477,389.72 0.59 -150.14 MWD+IFR-AK-CAZ-SC(7) 9,580.29 90.89 15.43 6,304.76 6,145.11 907.33 -3,603.22 5,930,889.98 477,414.83 0.75 -56.17 MWD+IFR-AK-CAZ-SC(7) 9,675.59 90.62 15.46 6,303.51 6,143.86 999.18 -3,577.84 5,930,981.75 477,440.44 0.29 39.12 MWD+IFR-AK-CAZ-SC(7) 9,769.63 89.52 15.92 6,303.39 6,143.74 1,089.71 -3,552.41 5,931,072.21 477,466.09 1.27 133.15 MWD+IFR-AK-CAZ-SC(7) 9,864.95 89.14 15.57 6,304.51 6,144.86 1,181.45 -3,526.55 5,931,163.88 477,492.19 0.54 228.45 MWD+IFR-AK-CAZ-SC(7) 9,959.87 88.87 16.60 6,306.16 6,146.51 1,272.64 -3,500.25 5,931,254.99 477,518.71 1.12 323.34 MWD+IFR-AK-CAZ-SC(7) 10,054.12 89.59 16.56 6,307.42 6,147.77 1,362.96 -3,473.36 5,931,345.24 477,545.82 0.77 417.55 MWD+IFR-AK-CAZ-SC(7) 10,149.64 90.41 16.05 6,307.42 6,147.77 1,454.64 -3,446.55 5,931,436.84 477,572.87 1.01 513.04 MWD+IFR-AK-CAZ-SC(7) 10,243.97 90.48 16.29 6,306.69 6,147.04 1,545.23 -3,420.28 5,931,527.36 477,599.36 0.27 607.35 MWD+IFR-AK-CAZ-SC(7) 10,338.37 90.75 17.28 6,305.68 6,146.03 1,635.60 -3,393.02 5,931,617.65 477,626.84 1.09 701.69 MWD+IFR-AK-CAZ-SC(7) 10,433.81 91.49 16.83 6,303.81 6,144.16 1,726.83 -3,365.03 5,931,708.79 477,655.06 0.91 797.05 MWD+IFR-AK-CAZ-SC(7) 10,529.84 90.72 16.28 6,301.96 6,142.31 1,818.86 -3,337.67 5,931,800.75 477,682.64 0.99 893.03 MWD+IFR-AK-CAZ-SC(7) 10,624.69 89.71 15.32 6,301.60 6,141.95 1,910.12 -3,311.85 5,931,891.94 477,708.69 1.47 987.87 MWD+IFR-AK-CAZ-SC(7) 10,719.49 90.10 13.79 6,301.76 6,142.11 2,001.88 -3,288.03 5,931,983.62 477,732.75 1.67 1,082.66 MWD+IFR-AK-CAZ-SC(7) 10,813.18 90.17 13.43 6,301.54 6,141.89 2,092.94 -3,265.98 5,932,074.62 477,755.02 0.39 1,176.32 MWD+IFR-AK-CAZ-SC(7) 10,909.52 89.52 13.68 6,301.80 6,142.15 2,186.59 -3,243.40 5,932,168.20 477,777.83 0.72 1,272.63 MWD+IFR-AK-CAZ-SC(7) 11,004.94 87.90 14.20 6,303.95 6,144.30 2,279.17 -3,220.42 5,932,260.72 477,801.04 1.78 1,368.01 MWD+IFR-AK-CAZ-SC(7) 11,099.66 85.64 15.14 6,309.28 6,149.63 2,370.65 -3,196.47 5,932,352.13 477,825.22 2.58 1,462.57 MWD+IFR-AK-CAZ-SC(7) 11,194.61 83.06 16.14 6,318.63 6,158.98 2,461.64 -3,171.00 5,932,443.04 477,850.91 2.91 1,557.04 MWD+IFR-AK-CAZ-SC(7) 11,290.45 83.88 15.56 6,329.53 6,169.88 2,553.23 -3,145.00 5,932,534.56 477,877.15 1.05 1,652.25 MWD+IFR-AK-CAZ-SC(7) 11,384.08 84.12 15.30 6,339.32 6,179.67 2,642.99 -3,120.22 5,932,624.25 477,902.14 0.38 1,745.36 MWD+IFR-AK-CAZ-SC(7) 11,479.00 84.05 15.25 6,349.10 6,189.45 2,734.07 -3,095.35 5,932,715.26 477,927.24 0.09 1,839.78 MWD+IFR-AK-CAZ-SC(7) 3/28/2016 1:18:09PM Page 5 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-11 Project: Kuparuk River Unit TVD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Site: Kuparuk 2S Pad MD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Well: 2S-11 North Reference: True Wellbore: 2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 11,574.24 84.15 14.44 6,358.89 6,199.24 2,825.65 -3,071.08 5,932,806.76 477,951.74 0.85 1,934.51 MWD+IFR-AK-CAZ-SC(7) 11,668.50 89.69 13.69 6,363.95 6,204.30 2,916.91 -3,048.21 5,932,897.96 477,974.84 5.93 2,028.58 MWD+IFR-AK-CAZ-SC(7) 11,763.42 91.34 13.51 6,363.10 6,203.45 3,009.16 -3,025.90 5,932,990.14 477,997.38 1.75 2,123.47 MWD+IFR-AK-CAZ-SC(7) 11,858.44 93.19 13.01 6,359.34 6,199.69 3,101.57 -3,004.12 5,933,082.49 478,019.39 2.02 2,218.37 MWD+IFR-AK-CAZ-SC(7) 11,953.35 95.17 12.80 6,352.43 6,192.78 3,193.84 -2,982.98 5,933,174.69 478,040.76 2.10 2,312.96 MWD+IFR-AK-CAZ-SC(7) 12,047.90 94.59 13.42 6,344.38 6,184.73 3,285.59 -2,961.61 5,933,266.38 478,062.36 0.90 2,407.11 MWD+IFR-AK-CAZ-SC(7) 12,143.18 95.47 14.19 6,336.03 6,176.38 3,377.76 -2,938.96 5,933,358.48 478,085.23 1.23 2,502.00 MWD+IFR-AK-CAZ-SC(7) 12,238.17 91.96 16.01 6,329.88 6,170.23 3,469.25 -2,914.27 5,933,449.91 478,110.15 4.16 2,596.77 MWD+IFR-AK-CAZ-SC(7) 12,332.19 92.61 15.96 6,326.13 6,166.48 3,559.57 -2,888.40 5,933,540.15 478,136.25 0.69 2,690.70 MWD+IFR-AK-CAZ-SC(7) 12,427.18 93.12 15.71 6,321.38 6,161.73 3,650.84 -2,862.52 5,933,631.34 478,162.36 0.60 2,785.57 MWD+IFR-AK-CAZ-SC(7) 12,522.73 93.05 16.20 6,316.24 6,156.59 3,742.57 -2,836.29 5,933,723.00 478,188.82 0.52 2,880.96 MWD+IFR-AK-CAZ-SC(7) 12,616.68 91.89 15.87 6,312.19 6,152.54 3,832.78 -2,810.36 5,933,813.14 478,214.97 1.28 2,974.81 MWD+IFR-AK-CAZ-SC(7) 12,711.02 89.42 13.86 6,311.11 6,151.46 3,923.95 -2,786.16 5,933,904.23 478,239.39 3.38 3,069.13 MWD+IFR-AK-CAZ-SC(7) 12,806.01 88.21 14.16 6,313.07 6,153.42 4,016.09 -2,763.17 5,933,996.31 478,262.61 1.31 3,164.08 MWD+IFR-AK-CAZ-SC(7) 12,900.27 88.21 13.80 6,316.02 6,156.37 4,107.51 -2,740.41 5,934,087.66 478,285.60 0.38 3,258.28 MWD+IFR-AK-CAZ-SC(7) 12,996.81 88.56 15.26 6,318.74 6,159.09 4,200.93 -2,716.20 5,934,181.01 478,310.04 1.55 3,354.78 MWD+IFR-AK-CAZ-SC(7) 13,090.31 89.55 16.56 6,320.28 6,160.63 4,290.83 -2,690.58 5,934,270.84 478,335.89 1.75 3,448.25 MWD+IFR-AK-CAZ-SC(7) 13,186.52 89.69 17.29 6,320.92 6,161.27 4,382.87 -2,662.57 5,934,362.80 478,364.13 0.77 3,544.40 MWD+IFR-AK-CAZ-SC(7) 13,281.45 90.41 17.81 6,320.84 6,161.19 4,473.38 -2,633.94 5,934,453.23 478,392.98 0.94 3,639.24 MWD+IFR-AK-CAZ-SC(7) 13,376.39 90.07 18.31 6,320.44 6,160.79 4,563.64 -2,604.51 5,934,543.40 478,422.63 0.64 3,734.04 MWD+IFR-AK-CAZ-SC(7) 13,470.95 90.68 17.91 6,319.82 6,160.17 4,653.51 -2,575.12 5,934,633.19 478,452.25 0.77 3,828.46 MWD+IFR-AK-CAZ-SC(7) 13,565.85 91.08 16.45 6,318.36 6,158.71 4,744.17 -2,547.09 5,934,723.77 478,480.50 1.59 3,923.28 MWD+IFR-AK-CAZ-SC(7) 13,660.43 94.07 14.55 6,314.11 6,154.46 4,835.20 -2,521.84 5,934,814.73 478,505.98 3.74 4,017.74 MWD+IFR-AK-CAZ-SC(7) 13,755.21 94.19 14.47 6,307.29 6,147.64 4,926.72 -2,498.16 5,934,906.18 478,529.89 0.15 4,112.27 MWD+IFR-AK-CAZ-SC(7) 13,846.76 93.43 13.55 6,301.20 6,141.55 5,015.35 -2,476.05 5,934,994.74 478,552.22 1.30 4,203.61 MWD+IFR-AK-CAZ-SC(7) 13,939.31 91.77 14.41 6,297.01 6,137.36 5,105.06 -2,453.71 5,935,084.39 478,574.78 2.02 4,296.04 MWD+IFR-AK-CAZ-SC(7) 14,030.75 91.61 13.89 6,294.31 6,134.66 5,193.69 -2,431.37 5,935,172.95 478,597.35 0.59 4,387.43 MWD+IFR-AK-CAZ-SC(7) 14,123.09 91.75 9.24 6,291.60 6,131.95 5,284.09 -2,412.87 5,935,263.29 478,616.07 5.04 4,479.54 MWD+IFR-AK-CAZ-SC(7) 14,215.34 92.40 11.25 6,288.26 6,128.61 5,374.80 -2,396.47 5,935,353.96 478,632.69 2.29 4,571.41 MWD+IFR-AK-CAZ-SC(7) 14,307.14 93.12 12.23 6,283.84 6,124.19 5,464.58 -2,377.82 5,935,443.68 478,651.57 1.32 4,662.95 MWD+IFR-AK-CAZ-SC(7) 14,397.14 92.64 12.73 6,279.32 6,119.67 5,552.34 -2,358.39 5,935,531.38 478,671.22 0.77 4,752.75 MWD+IFR-AK-CAZ-SC(7) 14,489.23 92.93 13.86 6,274.84 6,115.19 5,641.85 -2,337.24 5,935,620.83 478,692.59 1.27 4,844.69 MWD+IFR-AK-CAZ-SC(7) 14,583.28 91.12 13.07 6,271.52 6,111.87 5,733.26 -2,315.35 5,935,712.17 478,714.70 2.10 4,938.64 MWD+IFR-AK-CAZ-SC(7) 14,675.75 91.44 13.86 6,269.45 6,109.80 5,823.16 -2,293.83 5,935,802.01 478,736.45 0.92 5,031.05 MWD+IFR-AK-CAZ-SC(7) 14,767.70 90.58 14.04 6,267.83 6,108.18 5,912.38 -2,271.67 5,935,891.17 478,758.84 0.96 5,122.97 MWD+IFR-AK-CAZ-SC(7) 14,860.87 90.14 13.93 6,267.25 6,107.60 6,002.79 -2,249.15 5,935,981.51 478,781.58 0.49 5,216.13 MWD+IFR-AK-CAZ-SC(7) 14,952.76 90.00 13.59 6,267.13 6,107.48 6,092.04 -2,227.29 5,936,070.70 478,803.66 0.40 5,308.00 MWD+IFR-AK-CAZ-SC(7) 15,043.78 90.07 14.28 6,267.08 6,107.43 6,180.38 -2,205.37 5,936,158.98 478,825.80 0.76 5,399.00 MWD+IFR-AK-CAZ-SC(7) 15,136.69 90.58 15.86 6,266.55 6,106.90 6,270.09 -2,181.22 5,936,248.62 478,850.18 1.79 5,491.90 MWD+IFR-AK-CAZ-SC(7) 15,226.25 90.68 17.08 6,265.57 6,105.92 6,355.97 -2,155.83 5,936,334.42 478,875.78 1.37 5,581.43 MWD+IFR-AK-CAZ-SC(7) 3/28/2016 1:18:09PM Page 6 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-11 Project: Kuparuk River Unit TVD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Site: Kuparuk 2S Pad MD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Well: 2S-11 North Reference: True Wellbore: 2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) 0100') (ft) Survey Tool Name 15,309.00 90.68 17.08 6,264.59 6,104.94 6,435.07 -2,131.53 5,936,413.45 478,900.28 0.00 5,664.12 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. U Yes L; No I have checked to the best of my ability that the following data is correct: [s] Surface Coordinates El Declination & Convergence [] GRS Survey Corrections D Survey Tool Codes Vincent OHIF SLB DE: Osara Gent Representative: Scott Brunswick �� ew li,147n svx ax Date 28-Mar-2016 3/28/2016 1:18:09PM Page 7 COMPASS 5000.1 Build 74 • 215119 27064 RECEIVED APR 27 20111 c AOGCC FINAL ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad 2S-11 2S-11 Definitive Survey Report 28 March, 2016 NAD 83 • • . Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-11 Project: Kuparuk River Unit TVD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Site: Kuparuk 2S Pad MD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Well: 2S-11 North Reference: True Wellbore: 2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well 2S-11 Well Position +N/-S 0.00 usft Northing: 5,929,723.27 usfi Latitude: 70° 13'10.316 N +E/-W 0.00 usft Easting: 1,621,048.72 usfi Longitude: 150°9'22.511 W Position Uncertainty 0.00 usft Wellhead Elevation: 118.97 usfi Ground Level: 120.00 usft Wellbore 2S-11 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2015 3/10/2016 18.31 80.86 57,484 Design 2S-11 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.65 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) (0) 39.65 0.00 0.00 15.00 Survey Program Date 3/24/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 95.00 843.50 2S-11 Srvy 1 SLB_NSG+SSHOT(2S-11GYD-GC-SS Gyrodata gyro single shots 3/3/2016 10:22 868.42 2,797.08 2S-11 Srvy 2 SLB_MWD+GMAG(2S-11 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/3/2016 10:24 2,861.69 2,861.69 2S-11 Srvy 3 SLB_MWD-INC_Only-Filler INC+TREND Inclinometer+known azi trend 3/7/2016 9:50 I 2,953.67 8,420.90 2S-11 Srvy 4 SLB_MWD+GMAG(2S-11 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/7/2016 9:52 8,516.63 8,516.63 2S-11 Srvy 5 SLB_INC+TREND(2S-11)INC+TREND Inclinometer+known azi trend 3/16/2016 9:11 8,568.17 9,040.05 2S-11 Srvy 6 SLB_MWD+GMAG(2S-11 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/16/2016 9:1, 9,106.77 15,226.25 2S-11 Srvy 7 SLB_MWD+GMAG(2S-11 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/18/2016 9:2: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 39.65 0.00 0.00 39.65 -120.00 0.00 0.00 5,929,723.27 1,621,048.72 0.00 0.00 UNDEFINED 95.00 0.16 135.12 95.00 -64.65 -0.05 0.05 5,929,723.21 1,621,048.78 0.29 -0.04 GYD-GC-SS(1) 187.50 0.41 70.28 187.50 27.85 -0.03 0.46 5,929,723.23 1,621,049.18 0.40 0.08 GYD-GC-SS(1) 280.50 0.51 125.46 280.50 120.85 -0.16 1.11 5,929,723.10 1,621,049.83 0.47 0.13 GYD-GC-SS(1) 373.50 2.22 163.14 373.47 213.82 -2.13 1.97 5,929,721.13 1,621,050.68 1.98 -1.54 GYD-GC-SS(1) 468.50 4.11 177.23 468.32 308.67 -7.29 2.67 5,929,715.97 1,621,051.37 2.14 -6.35 GYD-GC-SS(1) 561.50 5.25 182.80 561.01 401.36 -14.87 2.62 5,929,708.39 1,621,051.30 1.32 -13.68 GYD-GC-SS(1) 654.50 7.47 185.76 653.43 493.78 -25.13 1.80 5,929,698.13 1,621,050.46 2.41 -23.81 GYD-GC-SS(1) 749.50 9.83 189.46 747.34 587.69 -39.28 -0.15 5,929,683.99 1,621,048.47 2.55 -37.98 GYD-GC-SS(1) 3/28/2016 12:54:53PM Page 2 COMPASS 5000.1 Build 74 0 • . Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-11 Project: Kuparuk River Unit TVD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Site: Kuparuk 2S Pad MD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Well: 2S-11 North Reference: True Wellbore: 2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 843.50 11.45 189.24 839.72 680.07 -56.40 -2.97 5,929,666.88 1,621,045.61 1.72 -55.25 GYD-GC-SS(1) 868.42 11.95 190.15 864.13 704.48 -61.38 -3.82 5,929,661.90 1,621,044.75 2.14 -60.28 MWD+IFR-AK-CAZ-SC(2) 963.14 12.69 191.70 956.67 797.02 -81.23 -7.66 5,929,642.07 1,621,040.86 0.86 -80.44 MWD+IFR-AK-CAZ-SC(2) 1,058.00 13.91 192.54 1,048.98 889.33 -102.56 -12.24 5,929,620.75 1,621,036.22 1.30 -102.23 MWD+IFR-AK-CAZ-SC(2) 1,153.39 16.63 195.74 1,140.99 981.34 -126.89 -18.44 5,929,596.43 1,621,029.96 2.98 -127.34 MWD+IFR-AK-CAZ-SC(2) 1,247.48 19.41 196.13 1,230.46 1,070.81 -154.88 -26.44 5,929,568.47 1,621,021.89 2.96 -156.44 MWD+IFR-AK-CAZ-SC(2) 1,341.78 21.08 194.81 1,318.93 1,159.28 -186.33 -35.12 5,929,537.05 1,621,013.12 1.84 -189.07 MWD+IFR-AK-CAZ-SC(2) 1,436.76 24.26 192.74 1,406.56 1,246.91 -221.88 -43.80 5,929,501.52 1,621,004.36 3.45 -225.66 MWD+IFR-AK-CAZ-SC(2) 1,531.73 25.11 195.81 1,492.86 1,333.21 -260.30 -53.59 5,929,463.13 1,620,994.47 1.62 -265.30 MWD+IFR-AK-CAZ-SC(2) 1,625.03 26.05 202.72 1,577.03 1,417.38 -298.26 -66.90 5,929,425.21 1,620,981.07 3.35 -305.41 MWD+IFR-AK-CAZ-SC(2) 1,720.90 26.39 208.91 1,663.05 1,503.40 -336.33 -85.33 5,929,387.19 1,620,962.54 2.87 -346.96 MWD+IFR-AK-CAZ-SC(2) 1,815.09 26.20 216.67 1,747.52 1,587.87 -371.35 -107.88 5,929,352.24 1,620,939.90 3.65 -386.61 MWD+IFR-AK-CAZ-SC(2) 1,909.97 26.40 220.61 1,832.59 1,672.94 -404.16 -134.12 5,929,319.49 1,620,913.58 1.85 -425.10 MWD+IFR-AK-CAZ-SC(2) 2,003.79 27.56 224.75 1,916.20 1,756.55 -435.41 -162.98 5,929,288.32 1,620,884.65 2.35 -462.76 MWD+IFR-AK-CAZ-SC(2) 2,098.60 29.24 230.28 1,999.61 1,839.96 -465.79 -196.24 5,929,258.02 1,620,851.31 3.29 -500.71 MWD+IFR-AK-CAZ-SC(2) 2,193.38 32.14 231.75 2,081.11 1,921.46 -496.20 -233.85 5,929,227.71 1,620,813.62 3.16 -539.82 MWD+IFR-AK-CAZ-SC(2) 2,287.97 35.75 232.17 2,159.57 1,999.92 -528.74 -275.45 5,929,195.29 1,620,771.95 3.82 -582.01 MWD+IFR-AK-CAZ-SC(2) 2,381.57 38.74 232.68 2,234.07 2,074.42 -563.27 -320.34 5,929,160.88 1,620,726.97 3.21 -626.99 MWD+IFR-AK-CAZ-SC(2) 2,476.61 40.40 236.70 2,307.34 2,147.69 -598.22 -369.75 5,929,126.06 1,620,677.48 3.21 -673.53 MWD+IFR-AK-CAZ-SC(2) 2,570.83 42.74 240.21 2,377.84 2,218.19 -630.87 -423.03 5,929,093.54 1,620,624.12 3.50 -718.87 MWD+IFR-AK-CAZ-SC(2) 2,667.07 46.96 242.12 2,446.05 2,286.40 -663.56 -482.49 5,929,061.01 1,620,564.58 4.60 -765.83 MWD+IFR-AK-CAZ-SC(2) 2,761.21 48.85 244.05 2,509.16 2,349.51 -695.16 -544.78 5,929,029.57 1,620,502.22 2.52 -812.47 MWD+IFR-AK-CAZ-SC(2) 2,797.08 48.83 244.01 2,532.77 2,373.12 -706.99 -569.05 5,929,017.81 1,620,477.91 0.10 -830.18 MWD+IFR-AK-CAZ-SC(2) 2,859.20 48.75 243.74 2,573.70 2,414.05 -727.57 -611.01 5,928,997.34 1,620,435.90 0.35 -860.92 NOT an Actual Survey 10 3/4"x 13-1/2" 2,861.69 48.75 243.73 2,575.34 2,415.69 -728.39 -612.69 5,928,996.52 1,620,434.22 0.35 -862.15 INC+TREND(3) 2,953.67 49.09 243.78 2,635.78 2,476.13 -759.05 -674.88 5,928,966.02 1,620,371.97 0.37 -907.86 MWD+IFR-AK-CAZ-SC(4) 3,050.81 49.13 243.07 2,699.37 2,539.72 -791.91 -740.55 5,928,933.34 1,620,306.21 0.55 -956.59 MWD+IFR-AK-CAZ-SC(4) 3,146.04 48.65 242.80 2,761.98 2,602.33 -824.55 -804.45 5,928,900.86 1,620,242.24 0.55 -1,004.66 MWD+IFR-AK-CAZ-SC(4) 3,240.73 48.66 242.53 2,824.53 2,664.88 -857.20 -867.60 5,928,868.38 1,620,179.01 0.21 -1,052.54 MWD+IFR-AK-CAZ-SC(4) 3,334.60 48.62 242.78 2,886.56 2,726.91 -889.56 -930.18 5,928,836.18 1,620,116.35 0.20 -1,100.00 MWD+IFR-AK-CAZ-SC(4) 3,428.84 48.52 242.46 2,948.92 2,789.27 -922.05 -992.92 5,928,803.85 1,620,053.54 0.28 -1,147.62 MWD+IFR-AK-CAZ-SC(4) 3,525.14 48.54 243.35 3,012.69 2,853.04 -954.92 -1,057.16 5,928,771.16 1,619,989.22 0.69 -1,195.99 MWD+IFR-AK-CAZ-SC(4) 3,619.94 48.57 242.46 3,075.44 2,915.79 -987.28 -1,120.42 5,928,738.96 1,619,925.88 0.70 -1,243.63 MWD+IFR-AK-CAZ-SC(4) 3,713.22 48.50 243.54 3,137.21 2,977.56 -1,019.02 -1,182.70 5,928,707.39 1,619,863.53 0.87 -1,290.40 MWD+IFR-AK-CAZ-SC(4) 3,808.42 48.13 242.50 3,200.52 3,040.87 -1,051.27 -1,246.06 5,928,675.30 1,619,800.09 0.90 -1,337.95 MWD+IFR-AK-CAZ-SC(4) 3,903.51 48.06 244.61 3,264.04 3,104.39 -1,082.79 -1,309.42 5,928,643.95 1,619,736.66 1.65 -1,384.79 MWD+IFR-AK-CAZ-SC(4) 3,996.52 48.56 246.68 3,325.90 3,166.25 -1,111.42 -1,372.69 5,928,615.48 1,619,673.32 1.75 -1,428.83 MWD+IFR-AK-CAZ-SC(4) 4,091.62 49.01 251.13 3,388.58 3,228.93 -1,137.15 -1,439.40 5,928,589.93 1,619,606.55 3.55 -1,470.95 MWD+IFR-AK-CAZ-SC(4) 4,187.35 49.15 251.78 3,451.28 3,291.63 -1,160.15 -1,507.98 5,928,567.10 1,619,537.92 0.53 -1,510.92 MWD+IFR-AK-CAZ-SC(4) 3/28/2016 12:54:53PM Page 3 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-11 Project: Kuparuk River Unit TVD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Site: Kuparuk 2S Pad MD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Well: 2S-11 North Reference: True Wellbore: 2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) 0100.) (ft) Survey Tool Name 4,281.19 48.96 251.37 3,512.78 3,353.13 -1,182.56 -1,575.23 5,928,544.87 1,619,470.62 0.39 -1,549.96 MWD+IFR-AK-CAZ-SC(4) 4,375.29 49.00 248.75 3,574.55 3,414.90 -1,206.76 -1,641.96 5,928,520.84 1,619,403.83 2.10 -1,590.62 MWD+IFR-AK-CAZ-SC(4) 4,469.90 49.08 246.21 3,636.57 3,476.92 -1,234.13 -1,707.95 5,928,493.65 1,619,337.78 2.03 -1,634.12 MWD+IFR-AK-CAZ-SC(4) 4,566.21 49.27 246.36 3,699.53 3,539.88 -1,263.44 -1,774.67 5,928,464.51 1,619,270.99 0.23 -1,679.70 MWD+IFR-AK-CAZ-SC(4) 4,659.65 49.12 244.93 3,760.60 3,600.95 -1,292.60 -1,839.10 5,928,435.52 1,619,206.49 1.17 -1,724.55 MWD+IFR-AK-CAZ-SC(4) 4,754.40 49.11 244.64 3,822.62 3,662.97 -1,323.12 -1,903.91 5,928,405.17 1,619,141.61 0.23 -1,770.80 MWD+IFR-AK-CAZ-SC(4) 4,849.12 49.11 244.37 3,884.62 3,724.97 -1,353.94 -1,968.54 5,928,374.52 1,619,076.91 0.22 -1,817.30 MWD+IFR-AK-CAZ-SC(4) 4,945.41 49.12 243.49 3,947.65 3,788.00 -1,385.93 -2,033.93 5,928,342.70 1,619,011.44 0.69 -1,865.13 MWD+IFR-AK-CAZ-SC(4) 5,039.47 49.10 241.93 4,009.22 3,849.57 -1,418.53 -2,097.12 5,928,310.26 1,618,948.18 1.25 -1,912.97 MWD+IFR-AK-CAZ-SC(4) 5,134.17 49.13 244.01 4,071.21 3,911.56 -1,451.06 -2,160.89 5,928,277.90 1,618,884.33 1.66 -1,960.90 MWD+IFR-AK-CAZ-SC(4) 5,228.65 48.62 244.00 4,133.35 3,973.70 -1,482.26 -2,224.86 5,928,246.87 1,618,820.29 0.54 -2,007.59 MWD+IFR-AK-CAZ-SC(4) 5,322.94 47.31 247.20 4,196.49 4,036.84 -1,511.20 -2,288.61 5,928,218.10 1,618,756.47 2.88 -2,052.04 MWD+IFR-AK-CAZ-SC(4) 5,417.46 45.96 248.90 4,261.40 4,101.75 -1,536.89 -2,352.34 5,928,192.57 1,618,692.68 1.94 -2,093.35 MWD+IFR-AK-CAZ-SC(4) 5,512.69 45.04 251.26 4,328.15 4,168.50 -1,560.04 -2,416.18 5,928,169.58 1,618,628.79 2.01 -2,132.24 MWD+IFR-AK-CAZ-SC(4) 5,607.68 44.14 252.83 4,395.80 4,236.15 -1,580.60 -2,479.61 5,928,149.19 1,618,565.31 1.50 -2,168.52 MWD+IFR-AK-CAZ-SC(4) 5,701.07 43.76 255.38 4,463.04 4,303.39 -1,598.36 -2,541.94 5,928,131.60 1,618,502.94 1.94 -2,201.80 MWD+IFR-AK-CAZ-SC(4) 5,797.14 43.48 258.77 4,532.59 4,372.94 -1,613.18 -2,606.52 5,928,116.94 1,618,438.34 2.45 -2,232.83 MWD+IFR-AK-CAZ-SC(4) 5,891.89 44.13 265.83 4,601.02 4,441.37 -1,621.93 -2,671.43 5,928,108.35 1,618,373.41 5.20 -2,258.09 MWD+IFR-AK-CAZ-SC(4) 5,986.61 42.65 273.91 4,669.90 4,510.25 -1,622.14 -2,736.39 5,928,108.31 1,618,308.46 6.06 -2,275.10 MWD+IFR-AK-CAZ-SC(4) 6,080.16 41.51 280.26 4,739.37 4,579.72 -1,614.46 -2,798.54 5,928,116.15 1,618,246.33 4.71 -2,283.76 MWD+IFR-AK-CAZ-SC(4) 6,174.45 41.52 285.09 4,809.99 4,650.34 -1,600.75 -2,859.47 5,928,130.01 1,618,185.44 3.39 -2,286.30 MWD+IFR-AK-CAZ-SC(4) 6,270.03 42.46 291.01 4,881.05 4,721.40 -1,580.93 -2,920.20 5,928,149.99 1,618,124.76 4.26 -2,282.87 MWD+IFR-AK-CAZ-SC(4) 6,363.58 42.42 297.34 4,950.13 4,790.48 -1,555.11 -2,977.73 5,928,175.96 1,618,067.30 4.57 -2,272.81 MWD+IFR-AK-CAZ-SC(4) 6,459.84 41.77 300.56 5,021.56 4,861.91 -1,523.89 -3,034.19 5,928,207.32 1,618,010.93 2.34 -2,257.27 MWD+IFR-AK-CAZ-SC(4) 6,553.79 41.99 303.70 5,091.52 4,931.87 -1,490.54 -3,087.29 5,928,240.80 1,617,957.93 2.24 -2,238.80 MWD+IFR-AK-CAZ-SC(4) 6,648.29 42.37 306.84 5,161.56 5,001.91 -1,453.90 -3,139.07 5,928,277.57 1,617,906.24 2.27 -2,216.82 MWD+IFR-AK-CAZ-SC(4) 6,742.89 42.07 307.93 5,231.61 5,071.96 -1,415.31 -3,189.58 5,928,316.29 1,617,855.83 0.84 -2,192.61 MWD+IFR-AK-CAZ-SC(4) 6,836.15 42.14 308.78 5,300.81 5,141.16 -1,376.51 -3,238.62 5,928,355.21 1,617,806.91 0.62 -2,167.82 MWD+IFR-AK-CAZ-SC(4) 6,931.74 43.41 311.70 5,370.98 5,211.33 -1,334.57 -3,288.15 5,928,397.27 1,617,757.49 2.46 -2,140.13 MWD+IFR-AK-CAZ-SC(4) 7,026.63 44.55 315.32 5,439.27 5,279.62 -1,289.20 -3,335.90 5,928,442.76 1,617,709.85 2.91 -2,108.67 MWD+IFR-AK-CAZ-SC(4) 7,121.73 46.38 318.32 5,505.97 5,346.32 -1,239.76 -3,382.26 5,928,492.31 1,617,663.63 2.96 -2,072.91 MWD+IFR-AK-CAZ-SC(4) 7,216.68 49.43 321.36 5,569.62 5,409.97 -1,185.91 -3,427.65 5,928,546.28 1,617,618.38 3.99 -2,032.64 MWD+IFR-AK-CAZ-SC(4) 7,310.97 52.39 323.75 5,629.07 5,469.42 -1,127.80 -3,472.11 5,928,604.49 1,617,574.08 3.70 -1,988.02 MWD+IFR-AK-CAZ-SC(4) 7,405.20 53.38 326.76 5,685.94 5,526.29 -1,066.06 -3,514.91 5,928,666.33 1,617,531.44 2.76 -1,939.46 MWD+IFR-AK-CAZ-SC(4) 7,500.00 54.40 330.77 5,741.83 5,582.18 -1,000.59 -3,554.60 5,928,731.90 1,617,491.92 3.58 -1,886.49 MWD+IFR-AK-CAZ-SC(4) 7,595.01 55.72 335.53 5,796.26 5,636.61 -931.12 -3,589.74 5,928,801.45 1,617,456.97 4.34 -1,828.49 MWD+IFR-AK-CAZ-SC(4) 7,689.27 56.32 338.95 5,848.95 5,689.30 -859.06 -3,619.96 5,928,873.58 1,617,426.93 3.08 -1,766.70 MWD+IFR-AK-CAZ-SC(4) 7,784.20 57.05 342.22 5,901.10 5,741.45 -784.26 -3,646.31 5,928,948.45 1,617,400.77 2.98 -1,701.27 MWD+IFR-AK-CAZ-SC(4) 7,879.48 59.11 344.06 5,951.48 5,791.83 -706.87 -3,669.75 5,929,025.89 1,617,377.53 2.71 -1,632.58 MWD+IFR-AK-CAZ-SC(4) 7,972.72 61.74 346.63 5,997.50 5,837.85 -628.42 -3,690.24 5,929,104.38 1,617,357.25 3.70 -1,562.12 MWD+IFR-AK-CAZ-SC(4) 3/28/2016 12:54:53PM Page 4 COMPASS 5000.1 Build 74 • . • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-11 Project: Kuparuk River Unit TVD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Site: Kuparuk 2S Pad MD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Well: 2S-11 North Reference: True Wellbore: 2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,066.87 63.05 349.04 6,041.13 5,881.48 -546.87 -3,707.81 5,929,185.96 1,617,339.89 2.66 -1,487.89 MWD+IFR-AK-CAZ-SC(4) 8,162.01 64.56 350.53 6,083.13 5,923.48 -462.86 -3,722.94 5,929,270.01 1,617,324.98 2.12 -1,410.66 MWD+IFR-AK-CAZ-SC(4) 8,257.15 67.28 352.51 6,121.95 5,962.30 -376.96 -3,735.73 5,929,355.93 1,617,312.41 3.43 -1,331.00 MWD+IFR-AK-CAZ-SC(4) 8,350.47 71.04 355.64 6,155.15 5,995.50 -290.24 -3,744.70 5,929,442.67 1,617,303.66 5.10 -1,249.55 MWD+IFR-AK-CAZ-SC(4) 8,420.90 74.19 357.85 6,176.19 6,016.54 -223.15 -3,748.51 5,929,509.76 1,617,300.03 5.38 -1,185.73 MWD+IFR-AK-CAZ-SC(4) 8,485.30 75.19 358.82 6,193.20 6,033.55 -161.06 -3,750.31 5,929,571.85 1,617,298.38 2.13 -1,126.22 NOT an Actual Survey 7-5/8"x 9-7/8 by 11" 8,516.63 75.68 359.29 6,201.07 6,041.42 -130.74 -3,750.81 5,929,602.16 1,617,297.96 2.13 -1,097.07 INC+TREND(5) 8,568.17 76.52 0.62 6,213.46 6,053.81 -80.71 -3,750.85 5,929,652.19 1,617,298.05 2.99 -1,048.75 MWD+IFR-AK-CAZ-SC(6) 8,663.03 77.55 1.63 6,234.74 6,075.09 11.71 -3,749.03 5,929,744.59 1,617,300.11 1.50 -959.01 MWD+IFR-AK-CAZ-SC(6) 8,757.35 78.56 2.48 6,254.26 6,094.61 103.92 -3,745.72 5,929,836.79 1,617,303.65 1.39 -869.08 MWD+IFR-AK-CAZ-SC(6) 8,852.10 79.30 2.79 6,272.45 6,112.80 196.81 -3,741.45 5,929,929.66 1,617,308.17 0.84 -778.25 MWD+IFR-AK-CAZ-SC(6) 8,946.12 80.93 5.59 6,288.60 6,128.95 289.18 -3,734.67 5,930,022.00 1,617,315.17 3.41 -687.28 MWD+IFR-AK-CAZ-SC(6) 9,040.05 83.41 8.14 6,301.39 6,141.74 381.55 -3,723.55 5,930,114.33 1,617,326.54 3.77 -595.18 MWD+IFR-AK-CAZ-SC(6) 9,106.77 86.39 9.74 6,307.32 6,147.67 447.19 -3,713.22 5,930,179.93 1,617,337.03 5.06 -529.10 MWD+IFR-AK-CAZ-SC(7) 9,201.10 89.40 10.93 6,310.79 6,151.14 539.91 -3,696.31 5,930,272.61 1,617,354.18 3.43 -435.16 MWD+IFR-AK-CAZ-SC(7) 9,296.00 90.38 13.68 6,310.97 6,151.32 632.62 -3,676.09 5,930,365.25 1,617,374.64 3.08 -340.38 MWD+IFR-AK-CAZ-SC(7) 9,391.36 91.54 14.73 6,309.37 6,149.72 725.05 -3,652.69 5,930,457.61 1,617,398.27 1.64 -245.04 MWD+IFR-AK-CAZ-SC(7) 9,486.30 91.58 15.29 6,306.79 6,147.14 816.72 -3,628.11 5,930,549.21 1,617,423.08 0.59 -150.14 MWD+IFR-AK-CAZ-SC(7) 9,580.29 90.89 15.43 6,304.76 6,145.11 907.33 -3,603.22 5,930,639.74 1,617,448.20 0.75 -56.17 MWD+IFR-AK-CAZ-SC(7) 9,675.59 90.62 15.46 6,303.51 6,143.86 999.18 -3,577.84 5,930,731.52 1,617,473.81 0.29 39.12 MWD+IFR-AK-CAZ-SC(7) 9,769.63 89.52 15.92 6,303.39 6,143.74 1,089.71 -3,552.41 5,930,821.98 1,617,499.47 1.27 133.15 MWD+IFR-AK-CAZ-SC(7) 9,864.95 89.14 15.57 6,304.51 6,144.86 1,181.45 -3,526.55 5,930,913.64 1,617,525.57 0.54 228.45 MWD+IFR-AK-CAZ-SC(7) 9,959.87 88.87 16.60 6,306.16 6,146.51 1,272.64 -3,500.25 5,931,004.75 1,617,552.09 1.12 323.34 MWD+IFR-AK-CAZ-SC(7) 10,054.12 89.59 16.56 6,307.42 6,147.77 1,362.96 -3,473.36 5,931,095.00 1,617,579.21 0.77 417.55 MWD+IFR-AK-CAZ-SC(7) 10,149.64 90.41 16.05 6,307.42 6,147.77 1,454.64 -3,446.55 5,931,186.60 1,617,606.26 1.01 513.04 MWD+IFR-AK-CAZ-SC(7) 10,243.97 90.48 16.29 6,306.69 6,147.04 1,545.23 -3,420.28 5,931,277.12 1,617,632.76 0.27 607.35 MWD+IFR-AK-CAZ-SC(7) 10,338.37 90.75 17.28 6,305.68 6,146.03 1,635.60 -3,393.02 5,931,367.41 1,617,660.25 1.09 701.69 MWD+IFR-AK-CAZ-SC(7) 10,433.81 91.49 16.83 6,303.81 6,144.16 1,726.83 -3,365.03 5,931,458.55 1,617,688.47 0.91 797.05 MWD+IFR-AK-CAZ-SC(7) 10,529.84 90.72 16.28 6,301.96 6,142.31 1,818.86 -3,337.67 5,931,550.50 1,617,716.06 0.99 893.03 MWD+IFR-AK-CAZ-SC(7) 10,624.69 89.71 15.32 6,301.60 6,141.95 1,910.12 -3,311.85 5,931,641.69 1,617,742.11 1.47 987.87 MWD+IFR-AK-CAZ-SC(7) 10,719.49 90.10 13.79 6,301.76 6,142.11 2,001.88 -3,288.03 5,931,733.37 1,617,766.17 1.67 1,082.66 MWD+IFR-AK-CAZ-SC(7) 10,813.18 90.17 13.43 6,301.54 6,141.89 2,092.94 -3,265.98 5,931,824.37 1,617,788.45 0.39 1,176.32 MWD+IFR-AK-CAZ-SC(7) 10,909.52 89.52 13.68 6,301.80 6,142.15 2,186.59 -3,243.40 5,931,917.96 1,617,811.27 0.72 1,272.63 MWD+IFR-AK-CAZ-SC(7) 11,004.94 87.90 14.20 6,303.95 6,144.30 2,279.17 -3,220.42 5,932,010.47 1,617,834.48 1.78 1,368.01 MWD+IFR-AK-CAZ-SC(7) 11,099.66 85.64 15.14 6,309.28 6,149.63 2,370.65 -3,196.47 5,932,101.88 1,617,858.66 2.58 1,462.57 MWD+IFR-AK-CAZ-SC(7) 11,194.61 83.06 16.14 6,318.63 6,158.98 2,461.64 -3,171.00 5,932,192.79 1,617,884.36 2.91 1,557.04 MWD+IFR-AK-CAZ-SC(7) 11,290.45 83.88 15.56 6,329.53 6,169.88 2,553.23 -3,145.00 5,932,284.31 1,617,910.60 1.05 1,652.25 MWD+IFR-AK-CAZ-SC(7) 11,384.08 84.12 15.30 6,339.32 6,179.67 2,642.99 -3,120.22 5,932,373.99 1,617,935.60 0.38 1,745.36 MWD+IFR-AK-CAZ-SC(7) 11,479.00 84.05 15.25 6,349.10 6,189.45 2,734.07 -3,095.35 5,932,465.00 1,617,960.71 0.09 1,839.78 MWD+IFR-AK-CAZ-SC(7) 3/28/2016 12:54:53PM Page 5 COMPASS 5000.1 Build 74 • . Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-11 Project: Kuparuk River Unit TVD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Site: Kuparuk 2S Pad MD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Well: 2S-11 North Reference: True Wellbore: 2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,574.24 84.15 14.44 6,358.89 6,199.24 2,825.65 -3,071.08 5,932,556.50 1,617,985.21 0.85 1,934.51 MWD+IFR-AK-CAZ-SC(7) 11,668.50 89.69 13.69 6,363.95 6,204.30 2,916.91 -3,048.21 5,932,647.70 1,618,008.31 5.93 2,028.58 MWD+IFR-AK-CAZ-SC(7) 11,763.42 91.34 13.51 6,363.10 6,203.45 3,009.16 -3,025.90 5,932,739.88 1,618,030.86 1.75 2,123.47 MWD+IFR-AK-CAZ-SC(7) 11,858.44 93.19 13.01 6,359.34 6,199.69 3,101.57 -3,004.12 5,932,832.23 1,618,052.87 2.02 2,218.37 MWD+IFR-AK-CAZ-SC(7) 11,953.35 95.17 12.80 6,352.43 6,192.78 3,193.84 -2,982.98 5,932,924.43 1,618,074.24 2.10 2,312.96 MWD+IFR-AK-CAZ-SC(7) 12,047.90 94.59 13.42 6,344.38 6,184.73 3,285.59 -2,961.61 5,933,016.11 1,618,095.85 0.90 2,407.11 MWD+IFR-AK-CAZ-SC(7) 12,143.18 95.47 14.19 6,336.03 6,176.38 3,377.76 -2,938.96 5,933,108.22 1,618,118.73 1.23 2,502.00 MWD+IFR-AK-CAZ-SC(7) 12,238.17 91.96 16.01 6,329.88 6,170.23 3,469.25 -2,914.27 5,933,199.64 1,618,143.65 4.16 2,596.77 MWD+IFR-AK-CAZ-SC(7) 12,332.19 92.61 15.96 6,326.13 6,166.48 3,559.57 -2,888.40 5,933,289.88 1,618,169.75 0.69 2,690.70 MWD+IFR-AK-CAZ-SC(7) 12,427.18 93.12 15.71 6,321.38 6,161.73 3,650.84 -2,862.52 5,933,381.07 1,618,195.87 0.60 2,785.57 MWD+IFR-AK-CAZ-SC(7) 12,522.73 93.05 16.20 6,316.24 6,156.59 3,742.57 -2,836.29 5,933,472.73 1,618,222.33 0.52 2,880.96 MWD+IFR-AK-CAZ-SC(7) 12,616.68 91.89 15.87 6,312.19 6,152.54 3,832.78 -2,810.36 5,933,562.87 1,618,248.48 1.28 2,974.81 MWD+IFR-AK-CAZ-SC(7) 12,711.02 89.42 13.86 6,311.11 6,151.46 3,923.95 -2,786.16 5,933,653.96 1,618,272.91 3.38 3,069.13 MWD+IFR-AK-CAZ-SC(7) 12,806.01 88.21 14.16 6,313.07 6,153.42 4,016.09 -2,763.17 5,933,746.03 1,618,296.14 1.31 3,164.08 MWD+IFR-AK-CAZ-SC(7) 12,900.27 88.21 13.80 6,316.02 6,156.37 4,107.51 -2,740.41 5,933,837.39 1,618,319.13 0.38 3,258.28 MWD+IFR-AK-CAZ-SC(7) 12,996.81 88.56 15.26 6,318.74 6,159.09 4,200.93 -2,716.20 5,933,930.73 1,618,343.58 1.55 3,354.78 MWD+IFR-AK-CAZ-SC(7) 13,090.31 89.55 16.56 6,320.28 6,160.63 4,290.83 -2,690.58 5,934,020.56 1,618,369.43. 1.75 3,448.25 MWD+IFR-AK-CAZ-SC(7) 13,186.52 89.69 17.29 6,320.92 6,161.27 4,382.87 -2,662.57 5,934,112.52 1,618,397.67 0.77 3,544.40 MWD+I FR-AK-CAZ-SC(7) 13,281.45 90.41 17.81 6,320.84 6,161.19 4,473.38 -2,633.94 5,934,202.94 1,618,426.53 0.94 3,639.24 MWD+I FR-AK-CAZ-SC(7) 13,376.39 90.07 18.31 6,320.44 6,160.79 4,563.64 -2,604.51 5,934,293.12 1,618,456.19 0.64 3,734.04 MWD+IFR-AK-CAZ-SC(7) 13,470.95 90.68 17.91 6,319.82 6,160.17 4,653.51 -2,575.12 5,934,382.91 1,618,485.81 0.77 3,828.46 MWD+IFR-AK-CAZ-SC(7) 13,565.85 91.08 16.45 6,318.36 6,158.71 4,744.17 -2,547.09 5,934,473.48 1,618,514.07 1.59 3,923.28 MWD+IFR-AK-CAZ-SC(7) 13,660.43 94.07 14.55 6,314.11 6,154.46 4,835.20 -2,521.84 5,934,564.44 1,618,539.54 3.74 4,017.74 MWD+I FR-AK-CAZ-SC(7) 13,755.21 94.19 14.47 6,307.29 6,147.64 4,926.72 -2,498.16 5,934,655.89 1,618,563.46 0.15 4,112.27 MWD+IFR-AK-CAZ-SC(7) 13,846.76 93.43 13.55 6,301.20 6,141.55 5,015.35 -2,476.05 5,934,744.45 1,618,585.80 1.30 4,203.61 MW D+I FR-AK-CAZ-SC(7) 13,939.31 91.77 14.41 6,297.01 6,137.36 5,105.06 -2,453.71 5,934,834.10 1,618,608.36 2.02 4,296.04 MWD+IFR-AK-CAZ-SC(7) 14,030.75 91.61 13.89 6,294.31 6,134.66 5,193.69 -2,431.37 5,934,922.66 1,618,630.93 0.59 4,387.43 MWD+IFR-AK-CAZ-SC(7) 14,123.09 91.75 9.24 6,291.60 6,131.95 5,284.09 -2,412.87 5,935,013.00 1,618,649.66 5.04 4,479.54 MWD+IFR-AK-CAZ-SC(7) 14,215.34 92.40 11.25 6,288.26 6,128.61 5,374.80 -2,396.47 5,935,103.66 1,618,666.29 2.29 4,571.41 MWD+IFR-AK-CAZ-SC(7) 14,307.14 93.12 12.23 6,283.84 6,124.19 5,464.58 -2,377.82 5,935,193.38 1,618,685.17 1.32 4,662.95 MWD+IFR-AK-CAZ-SC(7) 14,397.14 92.64 12.73 6,279.32 6,119.67 5,552.34 -2,358.39 5,935,281.08 1,618,704.82 0.77 4,752.75 MWD+IFR-AK-CAZ-SC(7) 14,489.23 92.93 13.86 6,274.84 6,115.19 5,641.85 -2,337.24 5,935,370.54 1,618,726.20 1.27 4,844.69 MWD+IFR-AK-CAZ-SC(7) 14,583.28 91.12 13.07 6,271.52 6,111.87 5,733.26 -2,315.35 5,935,461.87 1,618,748.32 2.10 4,938.64 MWD+IFR-AK-CAZ-SC(7) 14,675.75 91.44 13.86 6,269.45 6,109.80 5,823.16 -2,293.83 5,935,551.71 1,618,770.07 0.92 5,031.05 MWD+IFR-AK-CAZ-SC(7) 14,767.70 90.58 14.04 6,267.83 6,108.18 5,912.38 -2,271.67 5,935,640.87 1,618,792.46 0.96 5,122.97 MW D+I FR-AK-CAZ-SC(7) 14,860.87 90.14 13.93 6,267.25 6,107.60 6,002.79 -2,249.15 5,935,731.21 1,618,815.21 0.49 5,216.13 MWD+IFR-AK-CAZ-SC(7) 14,952.76 90.00 13.59 6,267.13 6,107.48 6,092.04 -2,227.29 5,935,820.40 1,618,837.29 0.40 5,308.00 MWD+IFR-AK-CAZ-SC(7) 15,043.78 90.07 14.28 6,267.08 6,107.43 6,180.38 -2,205.37 5,935,908.67 1,618,859.43 0.76 5,399.00 MWD+IFR-AK-CAZ-SC(7) 15,136.69 90.58 15.86 6,266.55 6,106.90 6,270.09 -2,181.22 5,935,998.31 1,618,883.82 1.79 5,491.90 MWD+IFR-AK-CAZ-SC(7) 15,226.25 90.68 17.08 6,265.57 6,105.92 6,355.97 -2,155.83 5,936,084.12 1,618,909.42 1.37 5,581.43 MWD+IFR-AK-CAZ-SC(7) 3/28/2016 12:54:53PM Page 6 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-11 Project: Kuparuk River Unit TVD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Site: Kuparuk 2S Pad MD Reference: Rig:2S-11 actual @ 159.65usft(Doyon 25) Well: 2S-11 North Reference: True Wellbore: 2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 15,309.00 90.68 17.08 6,264.59 6,104.94 6,435.07 -2,131.53 5,936,163.14 1,618,933.93 0.00 5,664.12 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. L Yes ❑ No I have checked to the best of my ability that the following data is correct: Q Surface Coordinates El Declination & Convergence C] GRS Survey Corrections D Survey Tool Codes Vincent .ge•.�,.._,� SLB DE: Osara �"'�""' Scott Brunswick 17,1171-1.::::71.,7:-,' Client Representative: Co.T,407.7.9..11 Date: 28-Mar-2016 3/28/2016 12:54:53PM Page 7 COMPASS 5000.1 Build 74 `,OF Tit • THE STATE • Alaska Oil and Gas o� JL`►1 1 ALA Conservation Commission „OM ,, 333 West Seventh Avenue /. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ,_ Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Adam Klem Completions Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2S-11 Permit to Drill Number: 215-219 Sundry Number: 316-223 Dear Mr. Klem: 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, /a4ti >4- _ Ca0)/c Foerster Chair DATED this /3y of April, 2016. RBDMS t,v APR 1 4 2016 RECEIVED 110 STATE OF ALASKA APR 0 6 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AAO //3i/(g( 6 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑✓ • Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program E Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑✓ _ 215-219 f 3.Address: ❑ 6.API Number: Stratigraphic ❑ Service P.O.Box 100360,Anchorage,Alaska 99510 50-103-20732-00-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2S-11 • Will planned perforations require a spacing exception? Yes ❑ No ❑., / 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 025590 & 025603 . 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): 15,309' . 6,264' ' 4,400 Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 119.5' 119.5' Surface 2819' 10-3/4" 2859' 2573' Intermediate 8446' 7-5/8" 8485' 6193' Production Liner 7001' 4-1/2" 15300' 6264' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See attached schematic 1 See attached schematic 4.5" L-80 8357' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): LEM Installation,no SSSV , 8257'MD,6122'TVD 12.Attachments: Proposal Summary E Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑., BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑✓ • Service ❑ 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: 13-Apr-16 OIL Q . WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Adam Klem @ 907-263-4529 Email Adam.Klem@conocophillips.com Printed Name Adam m Title: Completions Engineer Signature Phone 907-263-4529 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 2___2_� Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: /c—46, 4- RBDMS v' APR 1 4 2016 / :.:2 APPROVED BY Approved by: - / �v p. COMMISSIONER THE COMMISSION Date: T-- 5'./� /'�`� Submit Form and Form 10-403-evised 11/20151 1 o s alid for 12 months from the date of approval. Attachments in Duplicate 1/7-4 4/ie/16 O (I 1 �1 API/711c OW 4,7 2D(4 ,elf T l/� +� i Section 1 - Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1). TO THE•SKA OIL AND GAS CONSERVATION CO•SION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Garrett B. Haag Request of ConocoPhillips Alaska, Inc. for ) Hydraulic fracturing for the 2S-11 Well ) under the Provisions of 20 AAC 25.280 ) STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) Garrett B. Haag, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Garrett B. Haag. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. I 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 April 6, 2016, 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 6th day of April, 2016. -7444017 3 Garrett B. Haag STATE OF ALASKA ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 6th day of April, 2016, by Garrett B. Haag. Notary Public, State of Alaska STAT OF ALASKA NOTARY PUBLIC ' REBECCA SWENSEN I� -� My Commission Expires Aug.27,2016 • P.O.BOX 100360 ConocoPh i I I i ps ANCHORAGE,ALASKA 99510-0360 Alaska, Inc. Garrett B.Haag,Staff Landman Land Department,ATO 1480 Phone (907)265-6297 Fax (907)263-4966 Garrett.B.Haag@cop.com April 6, 2016 VIA CERTIFIED MAIL To: Operator and Owners(shown on Exhibit 2) Re: Notice of Operations pursuant to 20 AAC 25.283 (1) 2S-11 Well Kuparuk River Unit,Alaska ADL025604,KRU Tract 89;ADL025603,KRU Tract 90;ADL 025590,KRU Tract 74 Dear Operator and Owners: 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 2S-11 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about April 6, 2016. This Notice is being provided pursuant to subsection of 20 AAC 25.283. The Well has been drilled as a directional horizontal well on leases, ADL025603, KRU Tract 90; ADL 025590,KRU Tract 74 as depicted on Exhibit 1 and has locations as follows: Location FNL FEL Township Range Section Meridian Surface 3,074.87' 1,554.73' 10N 8E 17 Umiat Heel 2,521.29' 5,230.49' 10N 8E 17 Umiat Bottomhole 1,996.34' 3,688.56' 10N 8E 8 Umiat Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of record of all properties within the Notification Area. Upon your request, CPAI will provide a complete copy of the Application. If you require any additional information,please contact the undersigned. Sincerely, 4.4.8 Garrett B. Haag / Staff Landman Attachments: Exhibits 1 &2 • • Exhibit 1 `" 21Mar16 ConocoPhillips ADL025585 0 a> T11 NR8E �o25sas sa 2s-11 Alaska, Inc. Lease Plat ,^N 0 015 0.3 0.45 0.6 Miles A Southern Miluveach Unit ADL025590 ADL025589 0 75 2M-34 ADL390680 Kuparuk 1o; River Unit ...1111.7.. il lie MOW.1____. 2S-13L1 "',,, 2S-13 2S-04 17 D:• . r 2S-13PB1 ��25-04PB1 a` e \\.............., ADL....„1,001 ADL025604 _________ ® IC, T10NR8E Bs 25-08 ADL380051 o Frac Point 2S-11 Open Interval 2S-11 Trajectory —Well within Frac Point Radius Kuparuk PA ❑1/2 Mi.Frac Point Radius ADL025608 95 ADL025607 0 1/2 Mi.Trajectory Radius ss 27 ()Unit Tract Number a ❑BRPC Lease 0 CPAI Lease 1 • • 2S-1 1 ConocoPhillips Grassroots Horizontal A-Sand Producer As-Built Wellbore Schematic �� �t CAMERON Last Edited: 4--'tree,too loins iso-;,'12.e4*IBTIrI Brunswick 4-5-16 to m 16"Conductor to-119.5' n Se n m ai O C a 1J 13.5" Surface Hole Top We Sak 1,936'MD/1654'TVD = .—'z' x 1"Camco BMG GLM Surface Casing 10-3/4"45.5#L-80 Hydril 563 2,859.24'MD/2,573.7'TVD(48.75' INC) 9-7/8" x 11" Intermediate Hole a. Tubing: 4-1/2" 12.6#L-80 IBTM '4,., c a J GLMW SOV z V) $A,:,>.;, 2'S -86---0i-''14 -a-be C 37-Ferniot+co o4-5 507 MD4,389'TVD) rtn „ ,' C-37 6.030 MD/4,707 TVD I I#I {II it-- . .. . ..e Collar 6 379 98'MD Growler(Iceberg) 6,308'MD t4 910'TVD �` '' Top Cairn 7,074 MD/5474'TVD $a ) 4---1`Stage TOC: (Top of Bermuda./Cairn formation) Top Bermuda 7,216'MD/5,570'TVD `7 " Base Bermuda:7 351'MD/5.655'TVD -::IR : ip;i � t - Top HRZ:7,931'MD/5,977'TVD 4-G"x 75/8",Premier Packer / SLB DI-IG -..-$ rook. 4-'/,"3.81"DB Nipple 7' 57A1 1) * f' r , -; Upper Kalubik:8,212'MD/6,104'TVD ,- \ t6 445 IA) Lower Kalubik(K-1): 8.472'MD/6,191'TVD z co '' ,.... .. - 5.75"x 4'/:"Swett Packer ,' Kuparuk C:8,900'MD/6,282'TVD KuparukA4:9,025'MD/6,300'TVD srta. 2 7-5f3"x 5-%"Baker ZXP R ft ID u (�1 (]1 `°� Padker!Flex Lock Liner _ (]I It it (� v.ti.I• x AO'. •- Hanger ''•-. a TD:15,309'MD/6,264'TVD Intermediate Casing Production Liner: 6-3/4" Production Hole 7-5/8"29.7#L-80 Hyd563 Casing 4-1/2"12.6#L-80 IBTM with Torque Rings 8,485.26'MD/6,193.2'TVD(75.2° INC) +/-15,300'MD/6,264'TVD • • Exhibit 2 List of the names and addresses of all owners, landowners and operators of all properties within the Notification Area. Operator& Owner: ConocoPhillips Alaska,Inc. 700 G Street, Suite ATO 1226(Zip 99501) P.O. Box 100360 Anchorage,AK 99510-0360 Attention: Erik Keskula,NS Development Manager Owner(Non-Operator): BP Exploration(Alaska)Inc. P.O.Box 196612 900 E. Benson Boulevard(Zip 99508) Anchorage,AK 99519-6612 Attention: Mr. Robert Kinnear Chevron U.S.A.Inc. 310 K Street, Suite 406 Anchorage,AK 99501 Attention: Mr. Glenn Fredrick ExxonMobil Alaska Production Inc. P.O. Box 196601 3301 C Street, Suite 400(Zip 99503) Anchorage,AK 99519-6601 Attention: Mr. Gilbert Wong Landowners: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage,AK 99501-3560 Attention: Director Surface Owner: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage,AK 99501-3560 Attention: Director • 0 Section 2 — Plat 20 AAC 25.283 (a)(2) Plat 1: 2S-11 Landowners Conor©PhillipsADL02558 T E22 23 0 2S-11 Alaska.Inc. Lease Plat N % "..4 .:r �";mss j ,. % /r 3 / Southern ° f Miluveach Unit 0 i i f , i A)LA25580 ADL0255 9 • 5 9413 . 1 2Rf34 / i _ CL230eS3 0 ; �,•. 1 '`r v Kuparuk 10 River Unit 1% / r 17 . // 7 >! Irina Mt; r� fil 2S-13L1 '«Ρ, II 25-13 2S-04t. 17 tri 15 25-13Pc1 F 2S-0-PS1-r „se ++/ _ a-o RSE _ J 2S-08 ADL380051 f1 t 74 • Frac Point '2S-11 Open Interval —2S-11 Trajectory / —Well within Frac Point Radius Ku pa ruk PA 0112 Mi.Frac Point Radius ADLo2'2-08 .• ADL025007 27 01/2 Mi Trajectory Radius �1 ` 1 , )Unit Tract Number j DBRPC Lease 0CPAI Lease a • • Table 1: Wells within .5 miles API WELL NAME FLUID TYPE STATUS WELL TYPE 501032024200 2M-34 MWAG ACTIVE INJ 501032072100 2S-04 OIL ACTIVE PROD 501032072170 2S-04PB1 N/A PA EXPEND 501032072200 2S-08 OIL ACTIVE PROD 501032072000 2S-13 N/A PROP SVC 501032072060 2S-13L1 N/A PROP SVC 501032072070 2S-13PB1 N/A PA EXPEND • • SECTION 3 — FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. See conclusion of the Aquifer Exemption Title 40 CFR 147.102(b)(3)I"The portions of aquifers on the North Slope described by a 1/4 mile area beyond and lying directly below the Kuparuk River Unit oil and gas producing field" as exempt freshwater aquifers under 10 AAC 25.440" • • SECTION 4 — PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. • • SECTION 5 — DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) All casing is cemented in accordance with 20 AAC 25.52(b) and tested in accordance with 20 AAC 25.030 (g) when completed. See Wellbore schematic for casing details. . • SECTION 6 — ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(a)(6) Casing & Cement Assessments: The 10-3/4" casing cement pump report on 3/06/2016 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 11 ppg Lead Deep Crete cement and 15.8 ppg Class G tail cement. Full returns were seen throughout the job with 182bbls returned to surface. The plug bumped at 1,020 psi and the floats were checked and they held. The 7-5/8" casing cement report on 3/12/2016 shows that the job was pumped as designed with two stages, indicating competent cementing operations. The first stage was pumped with 15.8 ppg class G cement. Full returns were seen throughout the job. The plug bumped at 1,215 psi and the floats were checked and they held. The second stage was pumped with 15.8ppg class G cement. 35bbls of losses were observed during 2nd stage cementing. The closing plug bumped at 1,770 psi and the floats were checked, they held. Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. • • SECTION 7 — PRESSURE TEST INFORMATION AND PLANS TO PRESSURE-TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 3/7/2016 the 10 & 3/4" casing was pressure tested to 3500 psi. On 3/15/2016 the 7 & 5/8" casing was pressure tested to 3500 psi. The 7 & 5/8" casing will be pressure tested to 4,000 psi prior to frac'ing. The 4.5" tubing will be pressure tested to 5,000 psi prior to frac'ing. 0 • SECTION 8 — PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight Grade API Burst API Collapse 10 & 3/4" 45.5 L-80 2,090 psi 3,580 psi 7 & 5/8" 29.7 L-80 6,890 psi 4,790 psi 4.5" 12.6 L-80 8,430 psi 7,500 psi Table 2: Pressure Ratings • • Stimulation Surface Rig-Up Reed I Tattle Tale Tank 11:1 1:010 y V/747. • Minimum pressure rating on all surface ----D8111 11104 treating lines 10,000 psi • Main treating line PRV is set to 95%of max treating pressure =, C • IA parallel PRV set to 3 si ? OD f(A • Frac pump trip pressure setting are staggered and set below main treating line PRV g • Tree saver used on all fracs rated for 15,000 Ceri psi. )U1 Pop-Off Tank Pump Truck Pop-0If Tank N E- 0 o �J Frac Fhxnp - — -- Frac Purp Frac Pump -{ —£(311- Frac Pump 2 Frac Pump — mac} Frac PurIP II I 10K Frac Tree NOW Dartensional iritoltrriation ttinekrtred on this dratimni;aft,esiachated rhstaskuthmenits onlw 65 OTIS 1111111111 ,------- IL i s 9 I t I 11 - i 41002 ii."mi ne.11002 '- woo. 4-1/16' 10,00O# AP-Ik ,.n 2 C8 . 51 l3i 111 .4-1/16' 10,0,..Q4 Hydrauric Sia_c44' F11 41 -.....o. 44116" 10,000# A....-yz.. .1% liorTY I 4-11 6' 10,0001 ginimai ConocoPhillips eCAME RON Dna Site 2S-10K Frac 144 STEPHEN „..12-30-15 ,,....,_ I 1162040-.-2 • • Wellhead with 10K Frac Tree All' 'torr utmen.mal ofotft'auo reflected 6.5 OTiS ext flux dra+,.rit are mitt-melt 1 mea:urernent tank,_ . 4" i002 .1r u 4"1002 4015% 4-111 b' 10,00114 4-1/16' 10.00011 1 �"` / a1! 1; 124.08' ,, 4-1/1 11"10,000. x a' 1507 4-1/1G` 10,0011 ci 561- 18»45' 1 .le 1 =a1< ,, ,.. 1110 ' 1-0,4) 4f ...< '1.1 src i.,„ I11731' 16.13" 2-1an! , ,, ..../16'5,00(11 10.19' t ilea.. .... , 11ip.. . ,!T_. 80.1 1i ,. i 8 _. trr, ifiv 2-1/16"5,00011 19.17" 1 rr s]. 11:1-.15" -_ III 111 1487- '1 " 'I fi op at!. /.11" a a i (C 19 ti z _ 9 16 � 10-IA ConocoPhiI[Iip.7c 6.0'04) i uStelS-Producers 'CAMERON w/•10K1r STEPHEN ....12-30-15 ,. ,,.,,_ 4 1162040-0 • • 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 6,129' TVDSS (8,940' MD) and 130' TVT at the toe of the well, with the top Kuparuk A estimated at 6,060' 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 300' TVT (969' MD) and consists of HRZ and Kalubik mudstones. Top HRZ was encountered at 5,817' TVDSS (7,931' 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 6,250' TVDSS at the heel (the Miluveach interval was not penetrated in the 2S-11 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: 2S-04: The 7 & 5/8 casing cement pump report on 10/18/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg cement, followed by 16 ppg tail cement. The plug bumped at 717 psi and the floats were checked and they held. 2S-04 PB1: 2S-04 PB1 was plugged and abandoned per state regulations on 10/12/2015. 2S-08: The 7 & 5/8 casing cement pump report on 11/15/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.3 ppg cement, displaced with 10.1 ppg mud. The plug bumped at 1,400 psi and the floats were checked and they held. 2S-13: The 7 & 5/8" casing cement pump report on 12/27/17 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg cement, displaced with 11.8 ppg mud. The plug bumped at 1,200 psi and the floats were checked and they held. 2S-13 PB1: 2S-13PB1 was plugged and abandoned per state regulations on 12/17/2015 2M-34: The 7" casing cement pump report on 5/23/1996 shows that the cement job was pumped with 15.8 ppg cement, displaced with diesel and SW with no returns. The plug bumped and the floats were checked and they held. • • SECTION 11 — LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(9) CPAI has formed the opinion based on seismic, well, and other subsurface information currently available that there are 8 mapped faults that transect the Kuparuk A interval and enter the confining zone within one half mile radius of the wellbore trajectory for 2S-11. The fault to the northwest of the toe of 2S-11 terminates at the C-35. The C35 in this area consists of shales and siltstone lithologies with an estimated fracture pressure of—16ppg. The fault to the east of 2S-04 terminates at the C-37. The C37 in this area consists of shales and siltstone lithologies with an estimated fracture pressure of—'16ppg. Two faults intersect the 2S-11 wellbore and terminate within the confining layer. No losses were observed at any of the fault crossings during drilling of the 2S-11 lateral section. 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. 2S-11 Faults MD SSTVD Throw Fault#1(A4/A4) 10675 6142 5(DTS) Fault#2(A3/A3) 11885 6198 25 (DTN) One mapped fault intersects the offset 2S-13 and 2S-13L1 wellbores in the Kuparuk A sands. It also intersects the 2S-11 wellbore and corresponds to Fault#2 in 2S-11. Fault#1 terminates within the confining zone. No losses were observed at any faults during drilling of the 2S-13 or 2S-13L1 lateral sections. The 2S-11 lateral is greater than 1500' east of the 2S- 13 and 2S-13L1 wellbores. 2S-13 Fault MD SSTVD Throw Fault#1(A3/C) 14525 6090 60(DTN) 2S-13L1 Fault MD SSTVD Throw Fault#1(A3/A4) 14635 6115 60(DTN) One mapped fault intersects the offset 2S-04 wellbore in the Kuparuk A sands. Fault#1 terminates within the confining zone. No losses were observed at the fault during the drilling of the 2S-04 lateral section. The 2S-11 lateral is greater than 1500' west of the 2S-04 wellbore. 2S-04 Fault MD SSTVD Throw Fault#1(A4/A4) 9683 6127 14(DTS) The effective fracture length is estimated to be 560'. All of the fractures will be longitudinal, running parallel to the 2S-11 wellbore. Distance of the projected fracture wings to the nearest fault that does not intersect the 2S-11 wellbore is approximately 300'. 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 ConocoPhilips 2S-11 Sault Amalie/a FM maw.,lac. sf- :!Asirs_ 4. f` .A4.2.11 .14Z111,141b11 Southern / liiu each Un it tr . �'w Kuparuk • River Unit r 6 � 2S-TIL, ,$ _`'-1 ice+{ LN atat Frac.PIM —Fps wine ung awe —2`,,,-11 Trajechxy -1` 1s' 1 Frac F alrt Flus to AIL Frac Fdrt Ramus ❑tf�►!Trdiectury Berms MI DM Sie Aftenste MI Rad mis Kama PA BRPC Lease El CFA Lie h 2 -0E N a N Hi N C N C o N o i .Eo o H o. 000 a0 w as a. o « � a Y OJ 0 U' TJ C E co G u m l0 « r 2 m oo co C V ro M V a a O. X N co W• W C . O W N E cu N L Vil H N u a a v m CO m m m N ZO I, m O N . v o ,....7 v m m oin - c ad. U O @) C LS W m 47. fo :i5u O O ona Do eel O 03 b 0 « 1.'n' « o� O E m E C v U U U O p coU UO 12 c n a 0 0 0 !j N c c Q c a Z av _ 6 a z .9 .9 vii cC 4- 0 co « N d-,,, o o v t Q d 3 v v e °c p ti. d 0 N 12 V ie V V O F C .1--, as _-___.. • C 0zo C N n lN0 to m ao m m +-, %t 0 v vi LS kJ.; N O O N r i }-+ w m o. U E 3 0 0 `t r v p O o vi m o o03 u - 0 d .o o m ai m L. a o a n C 0 Q N O W O y O N Q ti 0 C N .p .p Z .O .D 6 6 _ O r O c N v n 4 a m v Nn m m e ti r a6 Z m of o. 6 0 a N ro ro ro ro m n 4 07! W dJ 0 Z An n n n V N m Q Z Z Z a ? a m 4 IL m oo Q a " 6 o O T. ... N N nr N N AL N • • SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) The well has an approximately 6,200 horizontal placed in the Kuparuk sand completed with a 4.5" liner with 9 ball actuated sliding sleeves, Alpha sleeve, WIV, and 11 swell packers. We will pump the first frac stage out of the Alpha sleeve. Then, we will drop a ball (progressively getting larger) after each 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: (A 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. 3. Ensure AOGCC sundry has been approved. 4. Ensure that the ConocoPhillips Stimulation manual and all relevant HES standards are complied with at all times during the fracturing operation. The ConocoPhillips representative should have either a hard copy of the well stimulation manual on hand or an electronic copy on his laptop. 5. MIRU —18 (however many required per day of frac) 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. 17,322 bbls are required for the treatment with scour stage, maximum pad, and one back up tank with 450 bbls usable volume per tank.) Stage 1-5= 1,900 bbls fluid & 125,000 lbs sand. per stage (max 6 ppa) Stages 6-10 = 1,735 bbls fluid & 125,000 lbs sand. per stage (max 8 ppa) 6. MIRU HES Frac Equipment capable of 35 BPM @ 8,500 psi, with a minimum of 1 stand- by pump, primed and pressure tested. See appendix for pumping equipment layout 7. Ensure HES has completed steps to ensure densitometer is properly calibrated. 8. Ensure SLB DHG is hooked up properly and functioning correctly. 9. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 10. Set popoff valve on OA to 1000psi and test. lA f9Of+ b00e51 11. Pressure test surface lines to 9,500 psi using a pressure test fluid. Perform the following steps for the PT. ealp PSseX kO 74-00 0' . The Halliburton representative and the COP company man will verify there was a NId't'O physical check of the GORV isolation valve to ensure it is in open position. 760ppSt 12. Pressure up and maintain 3,,750 psi on the IA. We can ramp up to 3,000 then 3 as treating pressures allow. ' 35-00 Fsi CA 14 41 V,2,61C, 300 13. Pressure up tubing to around 6125 (+/- 15%) psi to shift open Alpha-sleeve. 14. See the attached excel sheet for detailed pump schedule. • • 15. Pump the 540 bbl mini frac (30 #X-linked gel, Hybor G) according to the attached excel HES pump schedule. Bring pumps up to maximum rate of 35 BPM as quick as possible, pressure permitting. 16. Perform a hard shut down. Record ISIP, and monitor pressure (30-45 mins), and determine fluid efficiencies. 17. Pump the Frac job by following the attached schedule. Add breaker as per HES lab recommendations. Slow down to 12bpm, 20 bbls prior to each seat displacement volume. A Baker representative and the COP company will verify the correct ball is dropped for every stage. 18. At the end of the last frac stage of each pumping day, DO NOT pump the next frac ball. Displace well to frac sleeve, then shut down. We will pump the frac ball at the onset of the next frac day. 19. Monitor the surface pressure fall-off at the end of the job for 15 minutes, if the well does not screen out. 20. Bleed off any excess IA pressure, down to approx. 700 psi, or recommended. 21. Conduct Safety Meeting and Identify Hazards related to rigging down equipment. RDMO HES Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 22. 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N ro 00 b N • O Z a N - CD v, Q Q c0 O Z CD s a rts a U U 0 i • Wallace, Chris D (DOA) From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Thursday, April 07, 2016 8:42 AM To: Wallace, Chris D (DOA) Cc: Loepp, Victoria T (DOA) Subject: RE: Sundry 316-223 Well KRU 2S-11 PTD 2152190 Frac treatment Shoot,just saw for some reason the table with pressures I referred to did not get copied into my sundry template from my frac procedure template. My apologies. Here it is: Maximum Predicted Treating Pressure (MPTP) 3,650 psi Maximum planned rate 35 bpm Maximum planned sand concentration 8 ppa Annulus pressure 3,500 psi Maximum allowed working pressure (MAWP) 8,000 psi Nitrogen PRV 7,600psi Highest Pump trip 7,400 psi From: Klem, Adam Sent:Thursday, April 07, 2016 8:31 AM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Loepp,Victoria T(DOA) <victoria.loepp@alaska.gov> Subject: RE: Sundry 316-223 Well KRU 2S-11 PTD 2152190 Frac treatment Chris, see below. Let me know if this is sufficient. Sorry about the confusion, the person who had be compiling these sundries transferred and now it is all up to me and I'm still getting the hang of these.Thanks for getting to this so quickly. Adam From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent:Thursday, April 07, 2016 7:37 AM To: Klem, Adam <Adam.Klem@conocophillips.com> Cc: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: [EXTERNAL]Sundry 316-223 Well KRU 2S-11 PTD 2152190 Frac treatment Adam, We are in the process of reviewing the Sundry Application received by AOGCC on April 6, 2016, with a stated estimated date for commencing operations of April 13, 2016. 20 AAC 25.283(a)(12)(b) I read an IA backpressure will be held between 3000 to 3750 psi. I read the IA will be tested to 4000 psi. This doesn't satisfy the test to >110% requirement which would be 4125 psi. 1 Sorry,that was a carryover from thikt well. We will only hold 3500psi, not 371Psi since with the 4%"tubing we will not see as high of pressure. Max pressure is not stated as required by 20 AAC 25.283(a)(12)(E)? I read in the program the pumps can perform 35 bpm at 8500 psi. 20 AAC 25.283(a)(12)(b)Assuming 8500 psi is the max pressure and 3750 psi is max IA backpressure,the frac string would see 4750 psi and the test requirement of 110%would equate to 5225 psi. A tubing test plan of 5000 psi is stated and this would not meet the requirement. The max predicted treating pressure is 3,650psi as listed under the frac procedure. Is there a better place I should list it? So with 3500psi on the IA,the 5000psi PT on the tubing is well past the 110% required PT. We word the 8500psi and 35bpm like that for the vendors to ensure they bring enough pumps on location. In the past we planned the PT based on the max expected treating pressure, not the max capable pump pressure. 20 AAC 25.283(a)(12)(c) I read the schematic as 7 5/8" second stage TOC to be 5507' MD,first stage TOC? What are these values based on? I cannot determine the packer depth MD from the schematic? We normally don't list all those depths on the schematic.The packer depth is listed on the first page sundry form (8257'MD,6122'TVD). Is that something that has to be included on the schematic as well?The TOC was calculated as we did not run any CBL. The 7-5/8" casing cement report on 3/12/2016 shows that the job was pumped as designed with two stages, indicating competent cementing operations. The first stage was pumped with 15.8 ppg class G cement. Full returns were seen throughout the job. The plug bumped at 1,215 psi and the floats were checked and they held. The second stage was pumped with 15.8ppg class G cement. 35bbls of losses were observed during 2nd stage cementing. The closing plug bumped at 1,770 psi and the floats were checked, they held. 20 AAC 25.283(a)(12)(d) pressure relief valves. "Stimulation Surface Rig-Up" shows IA parallel PRV set to 3500 psi?What is the IA PRV to be set at? What is the GORV to be set at? The IA PRV will be set to 3600psi since we will hold 3500psi.The GORV(I think that means OA PRV?)will be set to 1000psi. Please advise of any revised numbers. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. 2 From: Klem, Adam [mailto:Adam.KliC a�conocophillips.com] • e� Sent: Tuesday, February 23, 2016 3:43 PM To: Wallace, Chris D (DOA) Cc: Loepp, Victoria T (DOA) Subject: RE: Sundry 316-155 Well KRU 2M-36 PTD 2141020 Frac treatment Chris, My apologies. We will pressure test the IA to 3800psi, and hold 3500 psi on the IA during the frac.The IA popoff will be set to 3600psi. From:Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent:Tuesday, February 23, 2016 3:36 PM To: Klem,Adam <Adam.Klem@conocophillips.com> Cc: Loepp,Victoria T(DOA) <victoria.loepp@alaska.gov> Subject: [EXTERNAL]Sundry 316-155 Well KRU 2M-36 PTD 2141020 Frac treatment Adam, We are in the process of reviewing the Sundry Application received by AOGCC on February 23, 2016, with a stated estimated date for commencing operations of March 1, 2016. I read an IA backpressure will be held between 2500 to 3500 psi. I read the IA will be tested to 3500 psi. This doesn't satisfy the test to >110% requirement. IA popoff value is not stated. Please advise of any revised numbers. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907) 276-7542(fax) chris.wallace@alaska.gov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. 3 • * PTiPZts - zty Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Thursday, January 28, 2016 11:11 AM To: 'Bearden,J Daniel' Subject: RE: KRU 2S-11 PTD#215-219 Daniel, Please submit as soon as the decision is made and we will expedite processing. 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.Loei p aC�.alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loem@alaska.gov From: Bearden, J Daniel [mailto:J.Daniel.Bearden@conocophillips.com] Sent: Thursday, January 28, 2016 10:39 AM To: Loepp, Victoria T(DOA) Subject: KRU 2S-11 PTD#215-219 Hi Victoria, ConocoPhillips has a question regarding a possible amendment to the approved PTD on KRU 2S-11 (PTD#215-219). This well is approved as a three string design (topsetting the Kuparuk sands). However, based on the difficulty of installing the planned number of swell packers in our wells,we may quickly decide to turn this well into a four string design. We are now planning for both options. Since the decision for either option will be made close to planned spud, how would the AOGCC lead us to amend this approved permit? Shall we submit an amended permit for a four string design, with the option of not pursuing the design, or wait to submit the amendment until the decision is made-and request a quick turnaround for approval? Thank you for clarification, Daniel Bearden Supervising Drilling Engineer ConocoPhillips, Alaska 907-263-4864 work 907-602-7068 cell 1 �, of ry • ywP��\��j,"s THE STATE • Alaska Oil and Gas �\ /i A ��,J►,, � of� sKA. Conservation Commission AIV----_;',1-fiFt:_...„ 333 West Seventh Avenue r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 O M907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov 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 2S-11 ConocoPhillips Alaska, Inc. Permit No: 215-219 Surface Location: 3074.7' FNL, 1554.9' FEL, SEC. 17, T1ON, R8E, UM Bottomhole Location: 1994.5' FNL, 3688.6' FEL, SEC. 8, T1ON, R8E, 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, -// CathyP. Foerster Chair DATED this day of December, 2015. RECEIVEU STATE OF ALASKA DEC 15 2015 ALA OIL AND GAS CONSERVATION COMM' ,;ION PERMIT TO DRILL AOGOrt 20 AAC 25.005 1 a.Type of Work: 1 b.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp ❑ 1 c.Specify if well is proposed for: Drill 0 Lateral ❑ Stratigraphic Test ❑ Development-Oil ❑✓ Service- Winj ❑ Single Zone ❑✓ Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry ❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 KRU 2S-11 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 15,167 • TVD: • 6,322 Kuparuk River Field 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Surface: 3074.7'FNL,1554.9'FEL,Sec 17,T1ON,R8E,UM ADL025590&ADL025603 Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2797.6'FNL, 10.8'FEL,Sec 18,T1ON,R8E,UM 931898000&931899000 1/21/2016 Total Depth: 9.Acres in Property: 14. Distance to Nearest Property: 1994.5'FNL,3688.6'FEL,Sec 8,T1ON, R8E,UM 2501 &2512 3688.15'from ADL025589 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): . 159 15.Distance to Nearest Well Open Surface: x-481015.39' y-5929973.68' Zone- 4 ' GL Elevation above MSL(ft): • 120 to Same Pool: 1835.48'to 2S-04 16.Deviated wells: Kickoff depth: . 375 feet 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: ' 90.6 degrees Downhole: 3929 , Surface: 3297 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5# H-40 Welded 80' 39.5' 39.5' 119.5' 119.5' 67 sx 15.7 ppg AS1 13.5" 10.75" 45.5# L-80 Hydril 563 2765' 39.5' 39.5' 2805' 2547' 1211 sx 11 ppg lead&193 sx 12.0 ppg tail 9.875" 7.625" 29.7# L-80 Hydril 563 8598' 39.5' 39.5' 8637' 6270' 648 sx stg 1;228 sx stg 2 15.8 ppg 6.75" 4.5" 11.6# L-80 IBTM 6717' 8450' 6210' 15167' 6322' N/A-Liner 4.5" 11.6# L-80 IBTM 8411' 39.5' 39.5' 8450' 6210' tubing 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): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program ❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch Q Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirementsy ❑✓ ts 21. Verbal Approval: Commission Representative: Date /..:-;eh--:///..'7 L/ 22.I hereby certify that the foregoing is true and the procedure approved herein will not Scott Brunswick @ 263-4249 be deviated from without prior written approval. Contact scot a.brunswick(a�cop.com Email Printed Name G.L.Alvord Title Alaska Drilling Manager t Signature . �' 't' Phone 265-6120 Date 12/14/2015 Commission Use Only Permit to Drill API Number: Permit Approval �(� See cover letter for other Number: (Q/5 a1cI 50- 1 n3-cal �3a.-oo _cJD Date: �al�� 1 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: /3 2 P tC 5 7' tO 3 57,012 S 1 Samples req'd: Yes No[' Mud log req'd:Yes II] No(> ' �},-PI rt '1Gr.v- /7 rC V7/7"7( .1,- z 570 U 1 5 1-G H2S measures: Yes Aid No❑ Directional svy req'd:Yes[.f No❑ - Spacing exception req'd: Yes ❑ No110 Inclination-only svy req'd:Yes❑ No Z Post initial injection MIT req'd:Yes❑ No❑ 0 ' APPROVED BY Approved by:rpm 1. (c,f A COMMISSIONE/estR THE COMMISSION Date:/Z-� -/J Submit Form and Form 10-401(Revised 11/2015) s p r i is li r hs from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate • • Application for Permit to Drill,Well 2S-11 Saved: 11-Dec-15 Post Office Box 100360 `y." Anchorage,Alaska 99510-0360 ConocoPhillips Phone(907)265-6935 Email: scott.a.brunswickAconocophillips.com December 14,2015 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill Well 2S-11,A Kuparuk A4 Sand Producer Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a permit to drill an onshore grassroots producer well from the 2S pad. The expected spud date for this well is January 21,2015.It is planned to use rig Doyon 25. 2S-11 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+/-2,805' MD/2,547' TVD. The intermediate section will be drilled with 9-7/8"x 11"bit/Under Reamer and run 7-5/8"casing to 8,637'MD/6,270'TVD. The production hole will be drilled with 6-3/4"bit and run 4- 1/2"slotted liner to+/- 15,167'MD/6,321'TVD.The upper completion will be run with 3-1/2"tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. A proposed completion diagram. 7. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold 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 Scott Brunswick at 263-4249 (scott.a.brunswickAconocophillips.com)or Chip Alvord at 265-6120. Sincerely, 4111 • cott Brunswick Drilling Engineer • • Application for Permit to Drill Document ; _ Aligtells Kuparuk Well 2S-11 conocoPn°i Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 2S-11 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identdying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; 30741.7 Location at Surface 39,7' FNL, 1554.9'FEL, Sec 18, T 10N,R008E,UM NGS Coordinates RKB Elevation 159.5'AMSL Northings: 5,929,973.7' Eastings: 481,015.4' Pad Elevation 120'AMSL Location at Top of 2797.6' FNL, 10.8' FEL, Sec 18,T1ON,R008E,UM Productive Interval (Kuparuk A4 Sand) NGS Coordinates Measured Depth, RKB: 8,877' Northings: 5,930,261.12' Eastings: 477,279.76' Total Vertical Depth, RKB: 6,329.5' Total Vertical Depth, SS: 6,170' Location at Total Depth 1994.5' FNL, 3688.6' FEL, Sec 8,T1ON,R008E,UM NGS Coordinates Measured Depth, RKB: 15,167' Northings: 5,936,088.6' Eastings: 478,878.83' Total Vertical Depth, RKB: 6,321.5' Total Vertical Depth, SS: 6,162' and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment: Directional Plan And (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a 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: (3)a diagram and description of the blowout prevention equipment(BOPE)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 25. • • 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 for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The maximum potential surface pressure (MPS?) while drilling 2S-11 is calculated using an estimated maximum reservoir pressure of 3,929 psi (12.0 ppg based on 2S-04 development well), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A4 sand at 6,329' TVD (WP07): A Sand Estimated. BHP = 3,929 psi A Sand estimated depth(WP07) = 6,329' TVD Gas Gradient = 0.10 psi/ft as per 20AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 632 psi (6,329' TVD * 0.10 psi/ft) MPSP =BHP—gas column =3,297 psi (3,929 psi—632psi) (B)data on potential gas zones: 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 zones,and zones that have a propensity for differential sticking; See attached 2S-11 Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.030(1); A procedure is on file with the commission for performing LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file 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 Casing and Cementing Program Csg/Tbg OD Hole Weight Length Top MD/TVD Btm MD/TVD (in) Vii) (Ib/ft) Grade Conn. (ft) (ft) f) Cement Program 16 24 62.5 H-40 Welded 80 Surf 119.5/119.5 Existing—386 sx AS1 @ 15.7 ppg Hydril Cement to Surface with 10-3/4 13-1/2 45.5 L-80 563 2,765 Surf 2,805/2,547 1,211 sx DeepCRETE Lead 11.0 ppg, 193 sx DeepCRETE Tail Slurry 12.0 ppg Stage 1: 648 sx Class G+GASBLOK at 9-7/8 Hydril 15.8 ppg w/TOC at 7,100 MD 7-5/8 X 29.7 L-80 563 8,598 Surf 8,637/6,270 Stage 2: 288 sx Class G+GASBLOK at 11 15.8 ppg w/TOC at 5,500'MD 4 1/2 6-3/4 11.6 L-80 IBTM 6,717 8,450/6,210 15,167/6,322 Uncemented Liner with Frac Sleeves • • 10.75" Surface Casing run to 2,805' MD/2,547' TVD Cement from 2805' MD to 2305'(500' of tail)with DeepCrete. @ 12 ppg,and from 2305'to surface with 11 ppg DeepCrete.Assume 250%excess annular volume in permafrost and 50%excess below the permafrost(1454' MD),zero excess in 16"conductor. Lead slurry from 2,305' MD to surface with Arctic Lite Crete @ 11 ppg Permafrost to Conductor (1,454') X 0.3634 ft3/ft X 3.5(250%excess) = 1,849 ft3 Top of Tail to Permafrost (2,305— 1,454')X 0.3634 ft3/ft X 1.5(50% excess) =464 ft3 Total Volume= 1,849+464=2,313 ft3=> 1,211 sx of 11 ppg DeepCrete @ 1.91 ft3/sk Tail slurry from 2,805' MD to 2,305' MD with 12 ppg DeepCrete Shoe to Top of Tail (2,805—2,305')X 0.3634 ft3/ft X 1.50 (50%excess) =273 ft3 Shoe Joint (80')X 0.5313 ft3/ft X 1.0 (0%excess) =43 ft3 Total Volume=273+43=316 ft3=> 193 sx of 12 ppg DeepCrete @ 1.64 ft3/sk 7.625"Intermediate Casing run to 8,637' MD/6,270 TVD 1st stage slurry designed to be at the top of Bermuda/Cairn Formation at 7,100' MD. Top of 2nd stage slurry is designed to be at 5,500' MD, which is 500' above the C-37.Assume 40%excess annular volume. 1st Stage slurry from 8,637' MD to 7,100' MD with 15.8ppg Class G+additives Shoe to Top of Cement (8,637'—7,100)X 0.3425 ft3/ft X 1.40(40%excess) =737 ft3 Shoe Joint (80')X 0.2483 ft3/ft X 1.0 (0%excess) =20 ft3 Total Volume=737+20= 757 ft3=>648 sx of 15.8 ppg Class G +GasBLOK @ 1.17 ft3/sk 2nd Stage slurry from 6,200' MD to 5,500 MD with 15.8ppg Class G +additives Stage Collar to Top of Cement (6,200'—5,500')X 0.3425 ft3/ft X 1.40(40%excess) =336 ft3 Total Volume=336 ft3=>288 sx of 15.8 ppg Class G +GasBLOK @ 1.17 ft3/sk Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); Please reference diverter schematic on file for Doyon 25. • • Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Mud Program Summary Surface Intermediate Production 9-7/8"x 11" 13-1/2" Hole Hole 6-3/4" Hole 10-3/4" Casing 7-5/8" Casing 4-1/2" Liner Spud LSND KlaySheild Mud System (WBM) (WBM) (WBM) Density 9.3- 10 9.6- 11.5 10.5-12.2 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 pH 9.0- 10.0 9.0- 10.0 9.5- 10.0 Diagram of Doyon 25 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A-Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. • • Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,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 25. Install Annular with 16"diverter line and function test. 2. Spud and directionally drill 13.5"hole to casing point at+/-2,805 MD/2,547' TVD as per directional plan (wp07). Survey with MWD,Gamma,Resistivity,Gyro. 3. Run and cement 10-3/4",45.5#,L80,Hyd-563 casing to surface. Displace cement with mud. Evacuate top 2 feet /Ud¢i- -to CL �ri`a✓ to te,p ✓ o� of cement from annulus for sealant job(post rig.) ✓' `� fiariccbfrErt .-, /3- ov l 4. In the event cement returns are not seen at surface,perform a top job. 5. Remove diverter system,install and test 13-5/8"x 5,000 psi BOP's to 3500 psi(annular preventer .to 2500 s� i) high and 250 psi low. Notify AOGCC 24 hrs before test. f 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 12.5 ppg,maximum of 16 ppg EMW leak off,recording results. 8. Open 9-5/8"x 11"Under Reamer and directionally drill to the top of the HRZ at-8,121' MD/6,075' TVD. Install RCD bearing at this time for use of MPD if necessary. 9. Directionally drill to intermediate TD of 8,637' MD/6,270' TVD, landing below the K-1 Marker. Wellsite geologist will call intermediate TD. Circulate and rotate at maximum rates until shakers are clean,minimum of 3 bottoms up. 10. POOH on elevators. Closely monitor drag and address any problem areas by dropping below and circulating/rotating to clean up. 11. Laydown intermediate BHA and rack back 5"DP 12. Run 7-5/8",29.7#L80,Hydril 563 casing from surface to TD at 8,637' MD. 13. Pump two stage cement job as per Schlumberger proposal. Top of first stage to be 7,100'MD(top of Cairn formation),top of second stage to be 5,500' MD(500' above C37). 14. Flush 10-3/4"x 7-5/8"annulus with water,followed by diesel to freeze protect. 15. Lay down 5"DP. 16. PU 4"DP,6-3/4"bit,and drilling assembly with MWD/LWD(Gamma,resistivity,Periscope,and neutron density) J 17. RIH and clean out cement to 100' above shoe. Test intermediate casing to 3500 psi for 30 minutes. 18. Drill out shoe track and 20' of new hole. Perform formation integrity test to minimum of 12.5 ppg,maximum of 14.5 ppg EMW leak off,recording results. 19. Directionally drill 6-3/4"hole geosteering though the Kuparuk A4 sand to TD-15,167' MD as per directional plan(wp07). 20. Circulate hole clean and POOH. 21. Lay down Production BHA. 22. PU and run 4-1/2", 11.6#liner. The top of liner will be placed at-12,550' MD,allowing for 150' of overlap in the 7-5/8"casing. 23. Set liner hanger. Slackoff and set liner top packer. 24. Monitor well for flow for 15 minutes • • 25. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes,chart results. 26. Flow check well for 30 minutes and POOH 27. Run 3-1/2"upper completion. 28. Nipple down BOPE,nipple up tree and test. 29. Freeze protect well with diesel and install BPV. 30. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill music be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization 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 (1R-18 or new facilities at DS1B). 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 I Well Schematic Attachment 2 Diverter Layout Diagram Attachment 3 Directional Plan Attachment 4 Drilling Hazards Summary • • 2S-1 1 ConocoPhillips Grassroots Horizontal A-Sand Producer Proposed Wellbore Schematic y, ) etCAMERON Last Edited: 4-%"tree,top joint is 4-Y"12.66 IBTM Brunswick 12-11-15 rn1 16"Conductor to-'119.5' a °I' 0 igiiiG6 z ,14.11 3 _, p GL J 13.5" Surface Hole 1 171, Top West Sak:1,881'MD/1,811'TVD GL J 3-1/2"x 1-1/2"Camco MMG GLM Surface Casing 10-3/4"45.5#L-80 Hydril 563 2,805' MD/2,547'TVD (47.7° INC) a 9-7/8" x 11" Intermediate Hole n Tubing: i 3-1/2" 9.3#L-80 EUE 8RD-MOD vi o GL J GLM wl SOV Z -J J 2od Stage TOC= 500'MD above C-37 Formation at X,XXX'MD/4,XXX'MD) 1 1 11 1 1 1 1 . herford Stage Collar:6,200'MD/4,806'TVD C-37:6,019 MD/4,671'TVD 1't Stage TOC: Top of Bermuda/Cairn formation) Growler(Iceberg):6,218'MD 14,819'TVD Baker 2.812"CMU Sliding Sleeve Cairn 7,101'MD/5,469'.TVD 1l\tl11\\ ik3-%"x 7-5/8",Premier Packer Bermuda:7,261'MD/5,579'TVD ►i r- �� 3-%"2.75"D Nipple / . +,� HRZ:8,121'MD/6,075'TVD Kalubik:8,276'MD/6,143'TVD SLB DHG �'••. 6"x 4-%"Swell Packer r Kuparuk C'8 847'MD/6 323'TVD 1 Kuparuk A4:8,877'MD/6,329'TVD—12.Oppg E 4Y.Slyer Bullet 8 ® iiiY_vv_w_v—EYY sn e 7-5/8"x 5-Y"Baker ZXP 'i Packer/Flex Lock Liner w��a�a apno Hanger ® ill ® MO • • gee:e TD:15,167'MD/6,322'TVD Intermediate Casing Production Liner: 6-3/4" Production Hole 7-5/8"29.7#L-80 Hyd563 Casing 4-1/2" 11.6#L-80 IBTM with Torque Rings 8,637' MD/6,270'TVD(73° INC) 15,167' MD/6,322'TVD 0 • ( 1 I I I I I L7Z A m a i 41 1 �] o r 0- o ® g EN g F ® m 0 ino g C o E' p----- • _0 g s C, ® *ad In V H ® >- H41/ L N ® ,,: da �0. y n -1 lili ►N b. Q Q 2 0 • ' O S _n S, t_ iTs 0 1 TX1 0 6 3 • a a Is b Z J t a 8 . 0 9 NS d < 8 .N V) . • N J J_ O gs6 • • 2S-llwpO7 [Great White] 6.808 Plan Summary N. a 5_ Y4f(JOruk C(Top C4) _5 Top Wiest€61111es Sak 04186, > - r / `s i ill j'y r r t1 I I rr / _.. C50 I - 0 far- 4" rop , 0-3/4"413-1/2' `7-5/8"x 9 /P'x 111 � \ i �+•f ` i ] 1 I I I I I Ifl D � . 0 3500 7000 10500 14000 r •• Measured Depth 141/2"x 6-3/41 0-118x3/4"x 13-1/2�' Geodetic Datum: North American Datum 1983 , •i; - :1 i p Depth ReferenceRigDloan:yo 25+120 @ 159.50usft(Doyon25) 2SOO o O ry° o 01 0 h° p° I7-5/8"x 9-7/8"x 11'1 14 1/2"x 6-3/4'' ��S , O I I I I I 1 I I I Q i i O;1 I $/ I Y 'SOT) OO qp ""- 375 0 1500 3000 4500 6000 5 7 0 O 9000 0 10900 0112000 0 375 - 560 Horizontal Departure . 560 - 750 330 3 0_ e: MEC 750 - 940 r0 60 .I k-1 • ----.I '' bio 940 - 1130 p ]k -=44c 14-.`if, 1130 - 1320 qu - _-� 300 kt�I 0 '�•; -�i 60 1320 - 1510 n q \ ._...- ' j��d�4 1.....11.;, • 1510 - 1700 cle * � ,� e.1.w_��le 1700 2260 4) 1 v / r.i s mg 23:39°0 _2260 2830 ,, - 1 v'Z$10 • !,�' 3390 U 30 (I ; ] _! 270 ���� ' ' 90 - 3950 2 '10111111' 2i-01408 Iger] v� 4x10 - x070 SC. 12wp07[B I] ' • x070 .1...- x640 U ,-• - 0 5840 - 6200 6200 - 7320 0 1 50 0 3000 4500 6000 7500 9000 10500 240 120 7320 - 6445 SURVEY PROGRAM6440 - 9560 Surface Location 9560 - 10680 Depth From Depth To Survey/Plan Tool Pad Elevation: 120.00 10680 - 11810 39.50 700.00 2S-11wp07 Great White (Plan 2S-11) INC+TREND 210 - 760 700.00 1700.00 25-11wp07 Great White Plan( 2S-11) MWD 12..-• 11810 12930 700.00 2805.03 2S-11wp07 Great White ((Plan M.SVID11)1FR-AK-CAZ-SC 180 12930 "�' 14050 39.50 700.00 2S-11wp07 Great White Plan 2S-11) GYD-GC-SS CASING DETAILS 140x0 - 15167 2805.03 4301.93 25-11wp07[Great White (Plan 2S-11) MWD 2805.03 8636.73 25-11wp07[Great White Plan I2WID54)IFR-AK-CAZ-SC ND MD Name M wpg 8636.73 10136.73 2S-11 07 Great White Plan 2S-11) MWD 2547.00 2805.03 10-3/4"x 13-1/2" Magnetic Model: BGGM2015 T 8636.73 15166.66 2S-11wp07[Great White Plan M1SVV�IFR-AK-CAZ-SC 6269.90 8636.73 7-5/8"x 9-7/8"x 11" Magnetic Model Date: 10-Mar-16 6321.50 15166.66 4 1/2"x 6-3/4" Magnetic Declination: 18.31° - To convert a Magnetic Direction to a True Direction,Add 18.31°East SECTION DETAILS g1�� r -376r% T-3 Sand Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 39.50 0.00 0.00 39.50 0.00 0.00 0.00 0.00 0.00 2 375.00 0.00 0.00 375.00 0.00 0.00 0.00 0.00 0.00 KOP:Start 1.5°/100'DLS,190°TF,for 225.13' K-15 Marker 3 600.13 3.38 190.00 600.00 -8.53 -1.15 1.50 190.00 -6.61 Start 2.5°/100'OLS,0"TF,for 799.07' 4 1399.20 23.35 190.00 1373.50 -187.52 -33.06 2.50 0.00 -189.69 Hold for 108.92' 5 1508.13 23.35 190.00 1473.50 -230.04 -40.56 0.00 0.00 -232.70 Start 3°/100'DLS,80.5°TF,for 1362.5' - 1423.5 6 2870.83 49.36 248.28 2590.45 -707.72 -591.22 3.00 80.50 -836.63 Hold for 2524.93' Base Permafrost 7 5395.55 49.36 248.28 4235.09 -1416.74 -2371.04 0.00 0.00-1982.13 Start 3°/100'DLS,119.39°TF,for 3239.79' -1811.5 8 8635.34 73.27 3.77 6269.50 44.91 -3761.50 3.00 119.39 -930.17 Hold for 30' 9 8665.34 73.27 3.77 6278.14 73.58 -3759.61 0.00 0.00 -901.99 Start 3.5°/100'DLS,43.89°TF,for 374.99' 10 9040.33 82.93 12.86 6355.52 435.73 -3706.15 3.50 43.69 -538.34 Hold for 45.94' Top West Sak 11 9086.27 82.93 12.86 6361.18 480.18 -3696.00 0.00 0.00 -492.78 Start 3.5"/100'DLS,41.73°TF,for 79.14' 12 9165.41 85.00 14.71 6369.50 556.61 -3677.24 3.50 41.73 -414.10 2S-11[Great White]1.Heel 111615 PB Start 2°/100'DLS,0°TF,for 279.42' -2551.5 13 9444.83 90.59 14.71 6380.25 826.55 -3606.35 2.00 0.00 -135.01 Hold for 5721.83' Base Wes Sak 14 15166.66 90.59 14.71 6321.50 6360.46 -2153.17 0.00 0.00 5586.48 25-11[Great White]1.Toe 111615 PB TD:15166.66'MD,6321.5'ND -2875.5 C-80 -4167.5 C-50 Permit Pack48 -0 Growler-AA iee'rmuda Base Bermuda ==lat.0042a4m47) E signing this I acknowledge that I have been informed of all risks,checked that the data is correct,ensured it's completeness,and all surrounding wells are assigned to the proper position and I approve the scan and ollision avoidance plan as set out in the audit pack.I approve it as the basis for the final well plan and wellsite drawings.I also acknowledge that,unless notified otherwise,all targets have a 100 feet lateral tolerance. 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CI Q. tm O. o ,_ _o inN- 1 13....:-14- r d r = , CoI I I I 0 0 0 o O o N o LU o in in co (uo}sn 00a) (+)upoN/C)ulnos • • - 5167 00 5000 `* 2S-11wp07 [Great White] Lr' 0) O ._ O > 4000 to `r C Oo II MIN O — m 3000 CO 0) o s'1° N w 2000 C ° 0 0 O o• o Lo r T000 0 rU U O U) — -O �� O U i 0000 O O — IO (13 o °06 _ A5 L 0006 L9o ,,,o0 0 u N o vp .- -I F . 0) X co D0O9 000 o� X O O o hco o op' o o r in I T_ O r ' co I I o OO O O o N0 0 0 O 0 Lo Ln 0 Ln Ti!/l1Sn 0090 gjdaa iea!taaco n co ti anal • • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-11 Plan: 2S-11 Plan: 2S-11wp07 [Great White] Report Permit Pack 07 December, 2015 ! i Schlumberger Comments apply to Report the line before it. Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-11 Project: Kuparuk River Unit TVD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-11 North Reference: True Wellbore: Plan:2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11wp07[Great White] 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 Kuparuk 2S Pad Site Position: Northing: usft Latitude: From: Map Easting: usft Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14° Well Plan:2S-11 rti Well Position +N/-S 0.00 usft Northing: usfi Latitude: +E/-W 0.00 usft Easting: usfl Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 120.00 usft Wellbore Plan:2S-11 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2015 3/10/2016 18.31 80.86 57,484 Design 2S-11wp07[Great White] Audit Notes: Version: Phase: PLAN Tie On Depth: 39.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.50 0.00 0.00 15.00 Survey Tool Program Date 11/17/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 39.50 700.00 2S-11wp07[Great White](Plan:2S-11) INC+TREND Inclinometer+known azi trend 700.00 1,700.00 2S-11wp07[Great White](Plan:2S-11) MWD MWD-Standard 700.00 2,805.03 2S-11wp07[Great White](Plan:2S-11) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 39.50 700.00 2S-11wp07[Great White](Plan:2S-11) GYD-GC-SS Gyrodata gyro single shots 2,805.03 4,301.93 2S-11wp07[Great White](Plan:2S-11) MWD MWD-Standard 2,805.03 8,636.73 2S-11wp07[Great White](Plan:2S-11) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,636.73 10,136.73 2S-11wp07[Great White](Plan:2S-11) MWD MWD-Standard 8,636.73 15,166.66 2S-11wp07[Great White](Plan:2S-11) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (0) (usft) (usft) (°/100usft) (0) (usft) 39.50 0.00 0.00 39.50 -120.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 -59.50 0.00 0.00 0.40 200.00 0.00 0.00 200.00 40.50 0.00 0.00 1.60 291.50 0.00 0.00 291.50 132.00 0.00 0.00 2.64 Top T-3 Sand 300.00 0.00 0.00 300.00 140.50 0.00 0.00 2.64 12/7/2015 12:40.:53PM Page 2 COMPASS 5000.1 Build 74 0 0 Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-11 Project: Kuparuk River Unit TVD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-11 North Reference: True Wellbore: Plan:2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11wp07[Great White] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (°) (usft) (usft) (°/100usft) (°) (usft) 375.00 0.00 0.00 375.00 215.50 0.00 0.00 3.38 KOP:Start 1.5°/100'DLS,190°TF,for 225.13' 376.50 0.02 190.00 376.50 217.00 1.50 190.00 3.39 K-15 Marker 400.00 0.37 190.00 400.00 240.50 1.50 0.00 3.39 500.00 1.87 190.00 499.98 340.48 1.50 0.00 2.82 600.00 3.37 190.00 599.87 440.37 1.50 0.00 3.46 600.13 3.38 190.00 600.00 440.50 1.50 0.00 3.46 Start 2.5°/100'DLS,0°TF,for 799.07' 700.00 5.87 190.00 699.54 540.04 2.50 0.00 4.34 800.00 8.37 190.00 798.76 639.26 2.50 0.00 4.35 900.00 10.87 190.00 897.34 737.84 2.50 0.00 4.38 1,000.00 13.37 190.00 995.10 835.60 2.50 0.00 4.43 1,100.00 15.87 190.00 1,091.86 932.36 2.50 0.00 4.53 1,200.00 18.37 190.00 1,187.42 1,027.92 2.50 0.00 4.68 1,300.00 20.87 190.00 1,281.60 1,122.10 2.50 0.00 4.89 1,399.20 23.35 190.00 1,373.50 1,214.00 2.50 0.00 5.18 Hold for 108.92' 1,400.00 23.35 190.00 1,374.23 1,214.73 0.00 0.00 5.18 1,453.67 23.35 190.00 1,423.50 1,264.00 0.00 0.00 5.53 Base Permafrost 1,500.00 23.35 190.00 1,466.04 1,306.54 0.00 0.00 5.53 1,508.13 23.35 190.00 1,473.50 1,314.00 0.00 0.00 5.56 Start 3°/100'DLS,80.5°TF,for 1362.5' 1,600.00 23.95 196.71 1,557.67 1,398.17 3.00 80.50 5.84 1,700.00 24.92 203.58 1,648.73 1,489.23 3.00 74.35 6.09 1,800.00 26.18 209.90 1,738.96 1,579.46 3.00 68.10 4.69 1,881.25 27.39 214.59 1,811.50 1,652.00 3.00 62.39 4.66 Top West Sak 1,900.00 27.69 215.62 1,828.13 1,668.63 3.00 58.20 4.66 2,000.00 29.41 220.77 1,915.98 1,756.48 3.00 57.29 4.65 2,100.00 31.31 225.37 2,002.27 1,842.77 3.00 52.77 4.65 2,200.00 33.35 229.47 2,086.77 1,927.27 3.00 48.80 4.69 2,300.00 35.52 233.15 2,169.25 2,009.75 3.00 45.32 4.76 2,400.00 37.79 236.44 2,249.48 2,089.98 3.00 42.29 4.88 2,500.00 40.13 239.41 2,327.24 2,167.74 3.00 39.65 5.03 2,600.00 42.55 242.10 2,402.32 2,242.82 3.00 37.34 5.23 2,700.00 45.03 244.55 2,474.51 2,315.01 3.00 35.32 5.47 2,800.00 47.55 246.80 2,543.61 2,384.11 3.00 33.55 5.75 2,805.03 47.68 246.91 2,547.00 2,387.50 3.00 32.00 6.28 10-3/4"x 13-1/2" 2,811.72 47.85 247.05 2,551.50 2,392.00 3.00 31.92 6.28 Base Wes Sak 2,870.63 49.36 248.28 2,590.45 2,430.95 3.00 31.83 6.28 Hold for 2524.93' 12/7/2015 12:40:53PM Page 3 COMPASS 5000.1 Build 74 • i Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-11 Project: Kuparuk River Unit TVD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-11 North Reference: True Wellbore: Plan:2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11wp07[Great White] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 2,900.00 49.36 248.28 2,609.59 2,450.09 0.00 -58.29 6.32 3,000.00 49.36 248.28 2,674.72 2,515.22 0.00 0.00 6.60 3,100.00 49.36 248.28 2,739.86 2,580.36 0.00 0.00 7.09 3,200.00 49.36 248.28 2,804.99 2,645.49 0.00 0.00 7.76 3,300.00 49.36 248.28 2,870.13 2,710.63 0.00 0.00 8.57 3,308.25 49.36 248.28 2,875.50 2,716.00 0.00 0.00 9.47 C-80 3,400.00 49.36 248.28 2,935.27 2,775.77 0.00 0.00 9.47 3,500.00 49.36 248.28 3,000.40 2,840.90 0.00 0.00 10.45 3,600.00 49.36 248.28 3,065.54 2,906.04 0.00 0.00 11.48 3,700.00 49.36 248.28 3,130.67 2,971.17 0.00 0.00 12.55 3,800.00 49.36 248.28 3,195.81 3,036.31 0.00 0.00 13.66 3,900.00 49.36 248.28 3,260.94 3,101.44 0.00 0.00 14.79 4,000.00 49.36 248.28 3,326.08 3,166.58 0.00 0.00 15.94 4,100.00 49.36 248.28 3,391.22 3,231.72 0.00 0.00 17.10 4,200.00 49.36 248.28 3,456.35 3,296.85 0.00 0.00 18.28 4,300.00 49.36 248.28 3,521.49 3,361.99 0.00 0.00 19.47 4,400.00 49.36 248.28 3,586.62 3,427.12 0.00 0.00 10.17 4,500.00 49.36 248.28 3,651.76 3,492.26 0.00 0.00 10.58 4,600.00 49.36 248.28 3,716.90 3,557.40 0.00 0.00 11.00 4,700.00 49.36 248.28 3,782.03 3,622.53 0.00 0.00 11.42 4,800.00 49.36 248.28 3,847.17 3,687.67 0.00 0.00 11.85 4,900.00 49.36 248.28 3,912.30 3,752.80 0.00 0.00 12.29 5,000.00 49.36 248.28 3,977.44 3,817.94 0.00 0.00 12.73 5,100.00 49.36 248.28 4,042.57 3,883.07 0.00 0.00 13.18 5,200.00 49.36 248.28 4,107.71 3,948.21 0.00 0.00 13.63 5,291.79 49.36 248.28 4,167.50 4,008.00 0.00 0.00 14.09 C-50 5,300.00 49.36 248.28 4,172.85 4,013.35 0.00 0.00 14.09 5,395.55 49.36 248.28 4,235.09 4,075.59 0.00 0.00 14.53 Start 3°/100'DLS,119.39°TF,for 3239.79' 5,400.00 49.29 248.43 4,237.98 4,078.48 3.00 119.39 14.54 5,500.00 47.88 251.96 4,304.15 4,144.65 3.00 119.29 14.59 5,600.00 46.57 255.64 4,372.07 4,212.57 3.00 116.95 14.62 5,700.00 45.40 259.48 4,441.57 4,282.07 3.00 114.45 14.59 5,800.00 44.35 263.47 4,512.45 4,352.95 3.00 111.79 14.52 5,859.92 43.79 265.92 4,555.50 4,396.00 3.00 108.96 14.39 C-40 5,900.00 43.45 267.59 4,584.52 4,425.02 3.00 107.20 14.39 6,000.00 42.70 271.85 4,657.58 4,498.08 3.00 105.99 14.20 6,018.93 42.58 272.67 4,671.50 4,512.00 3.00 102.88 13.95 C-37 6,100.00 42.12 276.21 4,731.43 4,571.93 3.00 102.28 13.95 6,200.00 41.70 280.66 4,805.87 4,646.37 3.00 99.66 13.64 12/7/2015 12:40:53PM Page 4 COMPASS 5000.1 Build 74 • i Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-11 Project: Kuparuk River Unit TVD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-11 North Reference: True Wellbore: Plan:2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11wp07[Great White] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 6,218.25 41.64 281.48 4,819.50 4,660.00 3.00 96.34 13.27 Growler-AA 6,300.00 41.45 285.17 4,880.69 4,721.19 3.00 95.73 13.27 6,400.00 41.39 289.70 4,955.70 4,796.20 3.00 92.97 12.85 2S-Helicoprion 2.Toe 6,500.00 41.50 294.23 5,030.68 4,871.18 3.00 89.57 12.39 2S-Helicoprion 1.Heel 6,600.00 41.79 298.73 5,105.43 4,945.93 3.00 86.17 11.92 6,700.00 42.25 303.16 5,179.74 5,020.24 3.00 82.81 11.44 6,800.00 42.88 307.49 5,253.41 5,093.91 3.00 79.52 10.97 6,900.00 43.66 311.72 5,326.24 5,166.74 3.00 76.33 10.53 7,000.00 44.60 315.81 5,398.02 5,238.52 3.00 73.25 10.14 7,100.00 45.68 319.76 5,468.57 5,309.07 3.00 70.31 9.81 7,101.33 45.70 319.81 5,469.50 5,310.00 3.00 67.53 9.55 Top Cairn 7,200.00 46.89 323.56 5,537.69 5,378.19 3.00 67.49 9.55 7,261.64 47.70 325.82 5,579.50 5,420.00 3.00 64.90 9.37 Top Bermuda 7,300.00 48.22 327.20 5,605.19 5,445.69 3.00 63.36 9.37 7,370.20 49.22 329.67 5,651.50 5,492.00 3.00 62.44 9.28 Base Bermuda 7,400.00 49.66 330.69 5,670.88 5,511.38 3.00 60.81 9.28 7,500.00 51.21 334.03 5,734.58 5,575.08 3.00 60.15 9.26 7,600.00 52.84 337.22 5,796.13 5,636.63 3.00 58.02 9.32 7,700.00 54.55 340.28 5,855.34 5,695.84 3.00 56.06 9.45 7,800.00 56.34 343.20 5,912.06 5,752.56 3.00 54.25 9.65 7,900.00 58.20 346.01 5,966.14 5,806.64 3.00 52.59 9.91 8,000.00 60.11 348.70 6,017.42 5,857.92 3.00 51.07 10.22 8,100.00 62.08 351.29 6,065.76 5,906.26 3.00 49.69 10.57 8,120.94 62.49 351.82 6,075.50 5,916.00 3.00 48.44 10.96 Top HRZ(K-2 Mrkr) 8,200.00 64.09 353.78 6,111.04 5,951.54 3.00 48.19 10.96 8,276.45 65.66 355.63 6,143.50 5,984.00 3.00 47.31 11.38 U.Kalubik(base HRZ) 8,300.00 66.14 356.19 6,153.12 5,993.62 3.00 46.52 11.38 8,400.00 68.23 358.53 6,191.89 6,032.39 3.00 46.29 11.83 8,500.00 70.35 0.79 6,227.25 6,067.75 3.00 45.39 12.30 8,600.00 72.50 3.00 6,259.10 6,099.60 3.00 44.59 12.80 8,601.33 72.53 3.03 6,259.50 6,100.00 3.00 43.88 12.98 L.Kalubik(K-1 Mrkr) 8,635.34 73.27 3.77 6,269.50 6,110.00 3.00 43.87 12.98 Hold for 30' 8,636.73 73.27 3.77 6,269.90 6,110.40 0.00 67.72 13.08 7-5/8"x 9-7/8"x 11" 8,665.34 73.27 3.77 6,278.14 6,118.64 0.00 0.00 13.08 Start 3.5°/100'DLS,43.69°TF,for 374.99' 12/7/2015 12:40:53PM Page 5 COMPASS 5000.1 Build 74 • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-11 Project: Kuparuk River Unit ND Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-11 North Reference: True Wellbore: Plan:2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11wp07[Great White] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (0) (usft) 8,700.00 74.15 4.64 6,287.86 6,128.36 3.50 43.69 13.15 8,800.00 76.70 7.11 6,313.02 6,153.52 3.50 43.44 13.44 8,847.73 77.93 8.27 6,323.50 6,164.00 3.50 42.82 13.86 Kuparuk C(Top C4) 8,877.35 78.70 8.99 6,329.50 6,170.00 3.50 42.56 13.86 A4 8,900.00 79.28 9.53 6,333.83 6,174.33 3.50 42.42 13.86 9,000.00 81.88 11.91 6,350.19 6,190.69 3.50 42.31 14.39 9,040.33 82.93 12.86 6,355.53 6,196.03 3.50 41.93 14.64 Hold for 45.94' 9,086.27 82.93 12.86 6,361.18 6,201.68 0.00 107.85 14.93 Start 3.5°/100'DLS,41.73°TF,for 79.14' 9,100.00 83.29 13.19 6,362.83 6,203.33 3.50 41.73 15.01 9,144.04 84.44 14.22 6,367.53 6,208.03 3.50 41.69 15.47 2S-Great WhiteLl 1.Heel 9,157.96 84.80 14.54 6,368.84 6,209.34 3.50 41.58 15.47 2S-Great White 1.Heel 9,165.41 85.00 14.71 6,369.50 6,210.00 3.50 41.55 15.47 Start 2°/100'DLS,0°TF,for 279.42'-A3-2S-11 [Great White]1.Heel 111615 PB 9,200.00 85.69 14.71 6,372.31 6,212.81 2.00 0.00 15.73 9,300.00 87.69 14.71 6,378.08 6,218.58 2.00 0.00 16.46 9,400.00 89.69 14.71 6,380.36 6,220.86 2.00 0.00 17.28 9,444.83 90.59 14.71 6,380.25 6,220.75 2.00 0.00 17.67 Hold for 5721.83' 9,500.00 90.59 14.71 6,379.68 6,220.18 0.00 175.47 18.18 9,600.00 90.59 14.71 6,378.66 6,219.16 0.00 0.00 19.16 9,700.00 90.59 14.71 6,377.63 6,218.13 0.00 0.00 20.19 9,800.00 90.59 14.71 6,376.60 6,217.10 0.00 0.00 21.28 9,900.00 90.59 14.71 6,375.58 6,216.08 0.00 0.00 22.41 10,000.00 90.59 14.71 6,374.55 6,215.05 0.00 0.00 23.58 10,100.00 90.59 14.71 6,373.52 6,214.02 0.00 0.00 24.78 10,200.00 90.59 14.71 6,372.50 6,213.00 0.00 0.00 15.93 10,300.00 90.59 14.71 6,371.47 6,211.97 0.00 0.00 16.24 10,400.00 90.59 14.71 6,370.44 6,210.94 0.00 0.00 16.57 10,500.00 90.59 14.71 6,369.42 6,209.92 0.00 0.00 16.91 10,600.00 90.59 14.71 6,368.39 6,208.89 0.00 0.00 17.26 10,700.00 90.59 14.71 6,367.36 6,207.86 0.00 0.00 17.62 10,800.00 90.59 14.71 6,366.34 6,206.84 0.00 0.00 18.00 10,900.00 90.59 14.71 6,365.31 6,205.81 0.00 0.00 18.38 11,000.00 90.59 14.71 6,364.28 6,204.78 0.00 0.00 18.78 11,100.00 90.59 14.71 6,363.26 6,203.76 0.00 0.00 19.18 11,200.00 90.59 14.71 6,362.23 6,202.73 0.00 0.00 19.60 11,300.00 90.59 14.71 6,361.20 6,201.70 0.00 0.00 20.02 11,400.00 90.59 14.71 6,360.18 6,200.68 0.00 0.00 20.45 11,500.00 90.59 14.71 6,359.15 6,199.65 0.00 0.00 20.89 12/7!2015 12:40:53PM Page 6 COMPASS 5000.1 Build 74 • • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-11 Project: Kuparuk River Unit ND Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-11 North Reference: True Wellbore: Plan:2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11wp07[Great White] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 11,600.00 90.59 14.71 6,358.12 6,198.62 0.00 0.00 21.33 11,700.00 90.59 14.71 6,357.09 6,197.59 0.00 0.00 21.78 11,800.00 90.59 14.71 6,356.07 6,196.57 0.00 0.00 22.24 11,900.00 90.59 14.71 6,355.04 6,195.54 0.00 0.00 22.70 12,000.00 90.59 14.71 6,354.01 6,194.51 0.00 0.00 23.16 12,100.00 90.59 14.71 6,352.99 6,193.49 0.00 0.00 23.64 12,200.00 90.59 14.71 6,351.96 6,192.46 0.00 0.00 24.11 12,300.00 90.59 14.71 6,350.93 6,191.43 0.00 0.00 24.59 12,400.00 90.59 14.71 6,349.91 6,190.41 0.00 0.00 25.08 12,500.00 90.59 14.71 6,348.88 6,189.38 0.00 0.00 25.57 12,600.00 90.59 14.71 6,347.85 6,188.35 0.00 0.00 26.06 12,700.00 90.59 14.71 6,346.83 6,187.33 0.00 0.00 26.56 12,800.00 90.59 14.71 6,345.80 6,186.30 0.00 0.00 27.05 12,900.00 90.59 14.71 6,344.77 6,185.27 0.00 0.00 27.56 13,000.00 90.59 14.71 6,343.75 6,184.25 0.00 0.00 28.06 13,100.00 90.59 14.71 6,342.72 6,183.22 0.00 0.00 28.57 13,200.00 90.59 14.71 6,341.69 6,182.19 0.00 0.00 29.08 13,300.00 90.59 14.71 6,340.67 6,181.17 0.00 0.00 29.60 13,400.00 90.59 14.71 6,339.64 6,180.14 0.00 0.00 30.11 13,500.00 90.59 14.71 6,338.61 6,179.11 0.00 0.00 30.63 13,600.00 90.59 14.71 6,337.59 6,178.09 0.00 0.00 31.15 13,700.00 90.59 14.71 6,336.56 6,177.06 0.00 0.00 31.67 13,800.00 90.59 14.71 6,335.53 6,176.03 0.00 0.00 32.20 13,900.00 90.59 14.71 6,334.51 6,175.01 0.00 0.00 32.72 14,000.00 90.59 14.71 6,333.48 6,173.98 0.00 0.00 33.25 14,100.00 90.59 14.71 6,332.45 6,172.95 0.00 0.00 33.78 14,200.00 90.59 14.71 6,331.43 6,171.93 0.00 0.00 34.31 14,300.00 90.59 14.71 6,330.40 6,170.90 0.00 0.00 34.84 14,400.00 90.59 14.71 6,329.37 6,169.87 0.00 0.00 35.38 14,500.00 90.59 14.71 6,328.35 6,168.85 0.00 0.00 35.91 14,600.00 90.59 14.71 6,327.32 6,167.82 0.00 0.00 36.45 14,700.00 90.59 14.71 6,326.29 6,166.79 0.00 0.00 36.99 14,800.00 90.59 14.71 6,325.26 6,165.76 0.00 0.00 37.53 14,900.00 90.59 14.71 6,324.24 6,164.74 0.00 0.00 38.07 15,000.00 90.59 14.71 6,323.21 6,163.71 0.00 0.00 38.61 15,100.00 90.59 14.71 6,322.18 6,162.68 0.00 0.00 39.15 15,166.66 90.59 14.71 6,321.50 6,162.00 0.00 0.00 39.51 TD: 15166.66'MD,6321.5'TVD-4 1/2"x 6-3/4"-2S-11 [Great White]1.Toe 111615 PB-2S-Great White 2.Toe 12/7/2015 12:40:53PM Page 7 COMPASS 5000.1 Build 74 • . Schlurnberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-11 Project: Kuparuk River Unit TVD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-11 North Reference: True Wellbore: Plan:2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11wp07[Great White] Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") ('') 2,805.03 2,547.00 10-3/4"x 13-1/2" 10-3/4 13-1/2 8,636.73 6,269.90 7-5/8"x 9-7/8"x 11" 7-5/8 9-7/8 15,166.66 6,321.50 4 1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology 1,881.25 1,811.50 Top West Sak 6,018.93 4,671.50 C-37 3,308.25 2,875.50 C-80 5,291.79 4,167.50 C-50 2,811.72 2,551.50 Base Wes Sak 291.50 291.50 Top T-3 Sand 7,261.64 5,579.50 Top Bermuda 7,101.33 5,469.50 Top Cairn 8,847.73 6,323.50 Kuparuk C(Top C4) 7,370.20 5,651.50 Base Bermuda 8,276.45 6,143.50 U.Kalubik(base HRZ) 8,877.35 6,329.50 A4 1,453.67 1,423.50 Base Permafrost 5,859.92 4,555.50 C-40 6,218.25 4,819.50 Growler-AA 8,601.33 6,259.50 L.Kalubik(K-1 Mrkr) 376.50 376.50 K-15 Marker 9,165.41 6,369.50 A3 8,120.94 6,075.50 Top HRZ(K-2 Mrkr) Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 375.00 375.00 0.00 0.00 KOP:Start 1.5°/100'DLS, 190°TF,for 225.13' 600.13 600.00 -6.53 -1.15 Start 2.5°/100'DLS,0°TF,for 799.07' 1,399.20 1,373.50 -187.52 -33.06 Hold for 108.92' 1,508.13 1,473.50 -230.04 -40.56 Start 3°/100'DLS,80.5°TF,for 1362.5' 2,870.63 2,590.45 -707.72 -591.22 Hold for 2524.93' 5,395.55 4,235.09 -1,416.74 -2,371.04 Start 3°/100'DLS, 119.39°TF,for 3239.79' 8,635.34 6,269.50 44.91 -3,761.50 Hold for 30' 8,665.34 6,278.14 73.58 -3,759.61 Start 3.5°/100'DLS,43.69°TF,for 374.99' 9,040.33 6,355.52 435.73 -3,706.15 Hold for 45.94' 9,086.27 6,361.18 480.18 -3,696.00 Start 3.5°/100'DLS,41.73°TF,for 79.14' 9,165.41 6,369.50 556.61 -3,677.24 Start 2°/100'DLS,0°TF,for 279.42' 9,444.83 6,380.25 826.55 -3,606.35 Hold for 5721.83' 15,166.66 6,321.50 6,360.46 -2,153.17 TD: 15166.66'MD,6321.5'TVD Checked By: Approved By: Date: 12!7/2015 12:40:53PM Page 8 COMPASS 5000.1 Build 74 • s N a aN o E .7 a ■ L co O a) N d d w Zs(.9 Q O — = c i. 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E d C 'O Z •p- N N N N N N O` a N al LL 0 U C m a) , a) U y re W .,d., p 01 rn rn rn rn m •o c o o N. ++ m _ • w N (tea (A U • Q (') O- in gRi (n 0 Q it cc W U u) D U 7 I 0 11:14, December 07 2015 Ladder View 2S-11wp07 [Great White] The Reference Well is along the X-axis. rror Ellipses are the Sum of the Reference and Offset Well Errors 7 E `a z- `1,3, m rn Emz= rn E !. i c'a nro n a cn n n m a 3 3 3^ u 3 a s x _ N 4`.°°').1P, N N N N N 1N i 300 III / ' 1 I r Jr / r_ ll` I I I IIII ( �) YII °Y I/ ' 01 4 i 111111--.41111111111111111, IVIli 191 111 101 1 'o ` �, " f IIl �ii , � 0- IIIIIIlllll�{I '' li IILr �llIIIa I4I , ,. en al111!:i/iii t aIilti� ( I lil P III ,/A" III t11 I Irrir ' 150— Iq III11111mY11� I I II nul I I . . . . nIIIIIpllnnl'" II ' 11 Wi, Iv IIIA 14141 !1,11101111,10'''i VIII III Rik i ll I I� U - --"1.041111111110419"aijif — .Equlvalant Magnetic Distance _. .. ...._....__.. ;......... _.....-.. .. ...-1 0 I I I I I I I I I III I I I I I I I I 1 I I—I I I I I I 0 1500 3000 4500 6000 7500 9000 10500 Displayed interval could be less than entire well:Measured Depth 39.50 To 15166.66 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.50 700.00 25-11wp07 [Great White] (Plan: 2SNIC)*TREND 2547.a805.03 10-3/4" x 13-1/211 700.00 1700.00 2S-11wp07 [Great White] (Plan: 23v1WjD 6269.91636.7/35/8"x 9-7/811 x 11" 700.00 2805.03 2S-11wp07 [Great White] (Plan: 23v1Vt J-'-IFR-AK-CAZ-SC 6321.'5E166.66 4 1/2"x 6-3/4" 39.50 700.00 25-11wp07 [Great White] (Plan: 2S31e1D-GC-SS 2805.03 4301.93 25-11wp07 [Great White] (Plan: 26\41/1/)D 2805.03 8636.73 25-11wp07 [Great White] (Plan: 23v1WJ+IFR-AK-CAZ-SC 8636.7310136.73 2S-11wp07 [Great White] (Plan: 23vr1NjD 8636 7315166 66 2S-11wo07 [Great Whitel (Plan 23V11/VD+IFR-AK-CA7-SC E▪ m o S $ F N N NV 60 ��® eY/Il' IpI , , , ,� i �� . , , : „, ._ , , , , . , . w , - , , c 30 ---""1111U o �e1slll I ;12 - 1.011111111V.114 EI I I 0 • 0 \\ 500 1000 1500 2000 2500 3000 3500 Equivelant Magnetic Distance Partial Measured Depth .1 S-11 wp07 [Great Whit-N D Inc Azi TVD Dleg TFace Target 375 560 39.-0 0.00 0.00 39.50 0.00 0.00 39.50 To 15166.6675.,0 0.00 0.00 375.00 0.00 0.00 560 750 600.13 3.38 190.00 600.00 1.50 190.00 750 940 0 23.35 190.00 1373.50 2.50 0.00 11:19,December07 2015 � 3 23.35 190.00 1473.50 0.00 0.00 940 1130 -3 49.36 248.28 2590.45 3.00 80.50 CASING DETAILS 5395. 5 49.36 248.28 4235.09 0.00 0.00 1130 1320 . 4 73.27 3.77 6269.50 3.00 119.39 TVD MD 8615m'4 73.27 3.77 6278.14 0.00 0.00 1320 1510 2597.00 2805.03 10-3/4" x10,312" 2" } 3 82.93 12.86 6355.52 3.50 43.69 1510 1700 6269.90 8636.737-5/8" x 9-7/6' 6321.50 15166.66 4 1/2" x94% 927 82.93 12.86 6361.16 0.00 0.00 9165.41 85.00 14.71 6369.50 3.50 41.73 2S-11 [Great White] 1. Heel 1116 5 P9700 2260 9499.:3 90.59 14.71 6380.25 2.00 0.00 6G261P6GG66w 6 90.59 14.71 6321.50 0.00 0.00 2S-11 [Great White] 1. Toe 11161' PB2260 2830 2830 3390 -11,07[creat 911111.1 (216.1.me�° 0.00 1700.00 2-11,07 320e00 5,1111.1 (Pl.",6026-11. 700 30.00 26°3.03 23-11,07 300ea0 NN1.1 (21.61.611.010-0.-SC 6.3° 00 28-11,07[Great w111t.1 (21.0 .63390 3950 2603.03 . 3 25-11,07[Great white] (21.07.4 3-111 331.6 0636.73 0136.73 22-113707 [Great white] 193�..5-33ys-u3-sC 8636.7313136.73 26-11,37 102eat,alter (21.0.6-11. 3950 4510 6636.73 13166.66 2s-11,0"/ [Great Mite] (P1a�w91ur6cemN6-CA2-6C 4510 5070 5070 5640 5640 6200 2S-08 6200 7320 0/360 7320 8440 ► 2S-10 2S-12wp07 [Bull] �', 4pz 8440 9560 mg,astive-` "�' - .,, 9560 10680 -30/33( �j. Il � r_!� ��'. 31 �,ii�� ®s�. ;vi,-� E- S-06wp06 [Salmon]0680 11810 l%/�� ��; �'. �4 eta�`�/°��4 'it� � 11810 12930 4L.''2..-'04;4/' �r�� alag�f�tlR� 6 12930 14050 165 `-,0 , 14050 .. ._ ._ 15167 -60/300 ���� `��es \;< � ��ir►i� �,,1.,�;�44.0 !� -y .1, , \\�\�\ ,`��\ i $�®'!t� �� '*-1/-1-44..:111 ?' mi= *sem;;• , .0&,W41&1&, �\�1 \� ,`�\h \'\ 1�� ,.,..,77"1-111,,...- V,* 11.+1,, �. '����\������� S��`����� ,�i�/.L�Ti�i ,,...e ae�a..... ,4 Qv '>t, 2S-05wp06 [Nurse Rig: 2S-132 •�� ���\� ��A,A�11���� 1�� �ikldrip� MO �•`' - 91.1 x � �,�� ��1: (, A 1A���1 �������� \� �'�►�� �� /� �� iii fi/r. �► , �a►� i i '• .s ` } � 1.�!t�,y 1.�I ��� � 'air � � < 6 .":°:',,i, 1 tn 2S-07 { 1 f 1� yt 'fiv V 1���y�w mp , . ek, q fd1 . 2S-13PB1w ^����• ,i IIlti ii�l� I N � /i►v � o..� a= � r�m . L �� 1� r�lv i,1iry]ii�����i��lll' "wilt., 4L'L� . ,F5, Y� . ,. der .- .t ,/,,,,,, �1��, �,,,, /lG +a5, +� 1 e O/ ° 1 n . 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N CO r O, Lr1 0 "0 N M d- in 1/40 00 01 0 F.. N- T- N N M m d Lr\ Lrl LO ' co 0\ 0 1,Z N 71- N- e-- 0 r—+ CT CU N � O O zvPi /o p a a 0 .4.1/4°1:1; ® .�./-_ 7 —_litio.- 0..Vii .-10 -' ) {Oo : ov33E333o � �/ s. I ” 33tipvv vvvv '' 33 -48111 \ °o o r.".s:`4,-,`,n.'°o «ggog 'R'°,,•g / �, -- u ' O I ' / aN rO 00i / O \ O M / 00 of=< \ N �// i .2 to' # •7 {il $ '' .-____________--- • ., omi''`,', O N OW '''43 1 NO1 N Ln O O o N. PO O a, G1 d' ' S. O „p V E E= Q 0 0 0 0 0 CON 00NN. N. `O `O N. N. 00 00 0 0 0 0 0 00 00 M m N NO N. O a1 01 01 d- d e- r- O 0 x- N N Z 0. • 0 0 0 rr1 0 rn rn in d d- rn N. M1/4O U1O Ln O N 7 Ln rn M M NN. 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O r,,' rm N rrl 44, _ ____\‘ TOO ,s 0 ++ O O s 1/4U O d- • __ a.n N. ry ++ O NON rQ Ln N r— a L g O .a V 'N 0 0 0 0 0 o0 00 N I\ � � E Q O O O O O N N n op CO iv a O O O O-\ O" O� d- d- Mrn „I (.1d- d- d- o e- r Z 0 O e- e- e- N N ca. 0 0 M0 M rn in d- d- rn N. _, rn °u°, 0 0 In 0 7 N 7 LO Ln M r M N CO 1/40 O rnLAOo; Cov; Lnv, O1/4oLn4 ,6 r- ® M ry m '1' op rOn �o � 0 CO dam- `fl WIi Cr , .— N Lf' CO CO Oh a1 O• O� Y 1 N • • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-11 Plan: 2S-11 Plan: 2S-11wp07 [Great White] Report - Errors rlko s: 16 November, 2015 Multiply by 2.5: • S . Schlumberger Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-11 Project: Kuparuk River Unit TVD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-11 North Reference: True Wellbore: Plan:2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11wp07[Great White] 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 Kuparuk 2S Pad Site Position: Northing: usft Latitude: From: Map Easting: usft Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14° Well Plan:2S-11 Well Position +N/-S 0.00 usft Northing: usft Latitude: +E/-W 0.00 usft Easting: usft Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 120.00 usft Wellbore Plan:2S-11 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2015 3/10/2016 18.31 80.86 57,484 Design 25-11wp07[Great White] Audit Notes: Version: Phase: PLAN Tie On Depth: 39.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 39.50 0.00 0.00 15.00 Survey Tool Program Date 11/17/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 39.50 700.00 2S-11wp07[Great White](Plan:2S-11) INC+TREND Inclinometer+known azi trend 700.00 1,700.00 2S-11wp07[Great White](Plan:2S-11) MWD MWD-Standard 700.00 2,805.03 2S-11wp07[Great White](Plan:2S-11) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 39.50 700.00 2S-11wp07[Great White](Plan:2S-11) GYD-GC-SS Gyrodata gyro single shots 2,805.03 4,301.93 2S-11wp07[Great White](Plan:2S-11) MWD MWD-Standard 2,805.03 8,636.73 2S-11wp07[Great White](Plan:2S-11) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,636.73 10,136.73 2S-11wp07[Great White](Plan:2S-11) MWD MWD-Standard 8,636.73 15,166.66 2S-11wp07[Great White](Plan:2S-11) 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) (0) (0) (usft) (usft) (usft) (usft) 39.50 0.00 0.00 0.00 -120.00 0.00 0.00 0.00 100.00 1.15 0.00 0.00 -59.50 1.15 0.40 0.40 200.00 1.15 0.00 0.00 40.50 1.15 1.60 1.60 291.50 1.15 0.00 0.00 132.00 1.15 2.64 2.64 Top T-3 Sand 300.00 1.15 0.00 0.00 140.50 1.15 2.64 2.64 11/17/2015 9:56:03AM Page 2 COMPASS 5000.1 Build 74 • Schlumberger • Comments apply to Report-Errors the line before it. Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-11 Project: Kuparuk River Unit TVD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-11 North Reference: True Wellbore: Plan:2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11wp07[Great White] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 375.00 1.15 0.00 0.00 215.50 1.15 3.38 3.38 KOP:Start 1.5°/100'DLS,190°TF,for 225.13' 376.50 1.15 0.02 45.00 217.00 1.15 3.39 3.39 K-15 Marker 400.00 1.15 0.37 45.00 240.50 1.15 3.39 3.39 500.00 1.16 1.87 10.01 340.48 1.15 2.82 2.70 600.00 1.16 3.37 10.00 440.37 1.15 3.46 2.27 600.13 1.16 3.38 10.00 440.50 1.15 3.46 2.27 Start 2.5°/100'DLS,0°TF,for 799.07' 700.00 1.18 5.87 10.01 540.04 1.16 4.34 2.15 800.00 1.20 8.37 10.01 639.26 1.15 4.35 2.15 900.00 1.23 10.87 10.01 737.84 1.15 4.38 2.15 1,000.00 1.27 13.37 10.02 835.60 1.15 4.43 2.15 1,100.00 1.31 15.87 10.03 932.36 1.14 4.53 2.16 1,200.00 1.36 18.37 10.04 1,027.92 1.14 4.68 2.18 1,300.00 1.41 20.87 10.05 1,122.10 1.14 4.89 2.21 1,399.20 1.47 23.35 10.07 1,214.00 1.14 5.18 2.25 Hold for 108.92' 1,400.00 1.47 23.35 10.07 1,214.73 1.14 5.18 2.25 1,453.67 1.47 23.35 10.08 1,264.00 1.16 5.53 2.34 Base Permafrost 1,500.00 1.47 23.35 10.08 1,306.54 1.16 5.53 2.34 1,508.13 1.47 23.35 10.08 1,314.00 1.16 5.56 2.34 Start 3°/100'DLS,80.5°TF,for 1362.5' 1,600.00 1.51 23.95 10.22 1,398.17 1.18 5.84 2.48 1,700.00 1.61 24.92 10.81 1,489.23 1.21 6.09 2.75 1,800.00 1.67 26.18 10.32 1,579.46 1.19 4.69 2.67 1,881.25 1.80 27.39 10.76 1,652.00 1.20 4.66 2.87 Top West Sak 1,900.00 1.80 27.69 10.76 1,668.63 1.20 4.66 2.87 2,000.00 1.95 29.41 11.50 1,756.48 1.22 4.65 3.07 2,100.00 2.13 31.31 12.55 1,842.77 1.24 4.65 3.24 2,200.00 2.32 33.35 13.94 1,927.27 1.27 4.69 3.38 2,300.00 2.52 35.52 15.67 2,009.75 1.30 4.76 3.50 2,400.00 2.73 37.79 17.75 2,089.98 1.34 4.88 3.60 2,500.00 2.95 40.13 20.14 2,167.74 1.38 5.03 3.68 2,600.00 3.17 42.55 22.82 2,242.82 1.43 5.23 3.74 2,700.00 3.40 45.03 25.73 2,315.01 1.49 5.47 3.78 2,800.00 3.64 47.55 28.81 2,384.11 1.55 5.75 3.80 2,805.03 3.13 47.68 39.97 2,387.50 2.35 6.28 4.43 10-3/4"x13-112" 2,811.72 3.13 47.85 39.97 2,392.00 2.35 6.28 4.43 Base Wes Sak 2,870.63 3.13 49.36 39.97 2,430.95 2.35 6.28 4.43 Hold for 2524.93' 11/17/2015 9:56:03AM Page 3 COMPASS 5000.1 Build 74 • S . Schlurnberger Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-11 Project: Kuparuk River Unit TVD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-11 North Reference: True Wellbore: Plan:2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11wp07[Great White] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (0) (usft) (usft) (usft) (usft) 2,900.00 3.13 49.36 40.32 2,450.09 2.34 6.32 4.43 3,000.00 3.14 49.36 43.03 2,515.22 2.37 6.60 4.45 3,100.00 3.14 49.36 47.17 2,580.36 2.42 7.09 4.49 3,200.00 3.15 49.36 51.49 2,645.49 2.48 7.76 4.55 3,300.00 3.15 49.36 55.20 2,710.63 2.56 8.57 4.62 3,308.25 3.16 49.36 58.07 2,716.00 2.66 9.47 4.72 C-80 3,400.00 3.16 49.36 58.07 2,775.77 2.66 9.47 4.72 3,500.00 3.17 49.36 60.20 2,840.90 2.78 10.45 4.83 3,600.00 3.17 49.36 61.78 2,906.04 2.90 11.48 4.95 3,700.00 3.18 49.36 62.95 2,971.17 3.04 12.55 5.08 3,800.00 3.19 49.36 63.84 3,036.31 3.18 13.66 5.23 3,900.00 3.19 49.36 64.52 3,101.44 3.33 14.79 5.39 4,000.00 3.20 49.36 65.05 3,166.58 3.49 15.94 5.56 4,100.00 3.21 49.36 65.48 3,231.72 3.66 17.10 5.74 4,200.00 3.21 49.36 65.82 3,296.85 3.83 18.28 5.93 4,300.00 3.22 49.36 66.10 3,361.99 4.01 19.47 6.13 4,400.00 3.23 49.36 58.60 3,427.12 3.04 10.17 5.07 4,500.00 3.24 49.36 59.33 3,492.26 3.12 10.58 5.15 4,600.00 3.24 49.36 59.98 3,557.40 3.21 11.00 5.23 4,700.00 3.25 49.36 60.55 3,622.53 3.29 11.42 5.32 4,800.00 3.26 49.36 61.06 3,687.67 3.38 11.85 5.41 4,900.00 3.27 49.36 61.51 3,752.80 3.46 12.29 5.50 5,000.00 3.28 49.36 61.92 3,817.94 3.55 12.73 5.60 5,100.00 3.28 49.36 62.28 3,883.07 3.65 13.18 5.69 5,200.00 3.29 49.36 62.60 3,948.21 3.74 13.63 5.80 5,291.79 3.30 49.36 62.90 4,008.00 3.84 14.09 5.90 C-50 5,300.00 3.30 49.36 62.90 4,013.35 3.84 14.09 5.90 5,395.55 3.31 49.36 63.15 4,075.59 3.93 14.53 6.00 Start 3°/100'DLS,119.39°TF,for 3239.79' 5,400.00 3.32 49.29 63.16 4,078.48 3.93 14.54 6.01 5,500.00 3.47 47.88 63.23 4,144.65 4.03 14.59 6.25 5,600.00 3.74 46.57 63.36 4,212.57 4.12 14.62 6.55 5,700.00 4.10 45.40 63.55 4,282.07 4.21 14.59 6.90 5,800.00 4.52 44.35 63.82 4,352.95 4.30 14.52 7.30 5,859.92 4.99 43.79 64.16 4,396.00 4.39 14.39 7.76 C-40 5,900.00 4.99 43.45 64.16 4,425.02 4.39 14.39 7.76 6,000.00 5.50 42.70 64.58 4,498.08 4.47 14.20 8.27 6,018.93 6.04 42.58 65.08 4,512.00 4.56 13.95 8.81 C-37 6,100.00 6.04 42.12 65.08 4,571.93 4.56 13.95 8.81 6,200.00 6.60 41.70 65.64 4,646.37 4.64 13.64 9.37 11/17/2015 9:56:03AM Page 4 COMPASS 5000.1 Build 74 • • Schlumberger Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-11 Project: Kuparuk River Unit TVD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-11 North Reference: True Wellbore: Plan:2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11wp07[Great White] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 6,218.25 7.16 41.64 66.28 4,660.00 4.72 13.27 9.93 Growler-AA 6,300.00 7.16 41.45 66.28 4,721.19 4.72 13.27 9.93 6,400.00 7.74 41.39 66.98 4,796.20 4.80 12.85 10.47 2S-Helicoprion 2.Toe 6,500.00 8.32 41.50 67.75 4,871.18 4.88 12.39 10.98 2S-Helicoprion 1.Heel 6,600.00 8.91 41.79 68.57 4,945.93 4.96 11.92 11.44 6,700.00 9.49 42.25 69.44 5,020.24 5.04 11.44 11.85 6,800.00 10.06 42.88 70.36 5,093.91 5.13 10.97 12.18 6,900.00 10.63 43.66 71.33 5,166.74 5.21 10.53 12.45 7,000.00 11.19 44.60 72.33 5,238.52 5.29 10.14 12.64 7,100.00 11.74 45.68 73.36 5,309.07 5.38 9.81 12.75 7,101.33 12.28 45.70 74.42 5,310.00 5.47 9.55 12.79 Top Cairn 7,200.00 12.28 46.89 74.42 5,378.19 5.47 9.55 12.79 7,261.64 12.80 47.70 75.51 5,420.00 5.56 9.37 12.76 Top Bermuda 7,300.00 12.80 48.22 75.51 5,445.69 5.56 9.37 12.76 7,370.20 13.31 49.22 76.62 5,492.00 5.65 9.28 12.67 Base Bermuda 7,400.00 13.31 49.66 76.62 5,511.38 5.65 9.28 12.67 7,500.00 13.80 51.21 77.74 5,575.08 5.75 9.26 12.52 7,600.00 14.26 52.84 78.87 5,636.63 5.85 9.32 12.32 7,700.00 14.71 54.55 80.02 5,695.84 5.95 9.45 12.07 7,800.00 15.14 56.34 81.17 5,752.56 6.06 9.65 11.79 7,900.00 15.54 58.20 82.32 5,806.64 6.18 9.91 11.48 8,000.00 15.92 60.11 83.47 5,857.92 6.29 10.22 11.14 8,100.00 16.27 62.08 84.62 5,906.26 6.41 10.57 10.79 8,120.94 16.60 62.49 85.77 5,916.00 6.54 10.96 10.43 Top HRZ(K-2 Mrkr) 8,200.00 16.60 64.09 85.77 5,951.54 6.54 10.96 10.43 8,276.45 16.90 65.66 86.91 5,984.00 6.67 11.38 10.07 U.Kalubik(base HRZ) 8,300.00 16.90 66.14 86.91 5,993.62 6.67 11.38 10.07 8,400.00 17.17 68.23 88.05 6,032.39 6.80 11.83 9.72 8,500.00 17.41 70.35 89.18 6,067.75 6.94 12.30 9.38 8,600.00 17.63 72.50 90.31 6,099.60 7.08 12.80 9.07 8,601.33 17.70 72.53 90.71 6,100.00 7.13 12.98 8.96 L.Kalubik(K-1 Mrkr) 8,635.34 17.70 73.27 90.71 6,110.00 7.13 12.98 8.96 Hold for 30' 8,636.73 17.90 73.27 92.31 6,110.40 7.09 13.08 8.98 7-5/8"x 9-7/8"x 11" 8,665.34 17.90 73.27 92.31 6,118.64 7.09 13.08 8.98 Start 3.5°/100'DLS,43.69°TF,for 374.99' 11/17/2015 9:56:03AM Page 5 COMPASS 5000.1 Build 74 • • . Schlumberger Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-11 Project: Kuparuk River Unit TVD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-11 North Reference: True Wellbore: Plan:2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11wp07[Great White] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 8,700.00 17.98 74.15 93.63 6,128.36 7.09 13.15 8.82 8,800.00 18.20 76.70 97.62 6,153.52 7.11 13.44 8.37 8,847.73 18.40 77.93 102.07 6,164.00 7.14 13.86 7.99 Kuparuk C(Top C4) 8,877.35 18.40 78.70 102.07 6,170.00 7.14 13.86 7.99 A4 8,900.00 18.40 79.28 102.07 6,174.33 7.14 13.86 7.99 9,000.00 18.57 81.88 107.24 6,190.69 7.19 14.39 7.70 9,040.33 18.63 82.93 109.61 6,196.02 7.22 14.64 7.61 Hold for 45.94' 9,086.27 18.63 82.93 112.49 6,201.68 7.25 14.93 7.64 Start 3.5°/100'DLS,41.73°TF,for 79.14' 9,100.00 18.65 83.29 113.39 6,203.33 7.26 15.01 7.61 9,144.04 18.75 84.44 118.24 6,208.03 7.32 15.47 7.52 2S-Great WhiteLl 1.Heel 9,157.96 18.75 84.80 118.24 6,209.34 7.32 15.47 7.52 2S-Great White 1.Heel 9,165.41 18.75 85.00 118.24 6,210.00 7.32 15.47 7.52 Start 2°/100'DLS,0°TF,for 279.42'-A3-2S-11 [Great White]1.Heel 111615 PB 9,200.00 18.77 85.69 120.95 6,212.81 7.35 15.73 7.50 9,300.00 18.82 87.69 129.00 6,218.58 7.45 16.46 7.51 9,400.00 18.84 89.69 137.32 6,220.86 7.58 17.28 7.58 9,444.83 18.84 90.59 140.90 6,220.75 7.63 17.67 7.63 Hold for 5721.83' 9,500.00 18.85 90.59 145.05 6,220.18 7.71 18.18 7.71 9,600.00 18.85 90.59 151.62 6,219.16 7.86 19.16 7.86 9,700.00 18.85 90.59 156.94 6,218.13 8.03 20.19 8.03 9,800.00 18.85 90.59 161.17 6,217.10 8.21 21.28 8.20 9,900.00 18.86 90.59 164.55 6,216.08 8.40 22.41 8.40 10,000.00 18.86 90.59 167.28 6,215.05 8.60 23.58 8.60 10,100.00 18.86 90.59 169.54 6,214.02 8.81 24.78 8.81 10,200.00 18.63 90.59 116.17 6,213.00 7.60 15.93 7.60 10,300.00 18.64 90.59 119.44 6,211.97 7.67 16.24 7.66 10,400.00 18.64 90.59 123.18 6,210.94 7.74 16.57 7.73 10,500.00 18.64 90.59 127.39 6,209.92 7.81 16.91 7.81 10,600.00 18.64 90.59 132.03 6,208.89 7.89 17.26 7.88 10,700.00 18.65 90.59 136.94 6,207.86 7.97 17.62 7.96 10,800.00 18.65 90.59 141.90 6,206.84 8.05 18.00 8.05 10,900.00 18.65 90.59 146.66 6,205.81 8.14 18.38 8.13 11,000.00 18.66 90.59 151.03 6,204.78 8.23 18.78 8.22 11,100.00 18.66 90.59 154.92 6,203.76 8.32 19.18 8.31 11,200.00 18.66 90.59 158.30 6,202.73 8.41 19.60 8.41 11,300.00 18.67 90.59 161.20 6,201.70 8.51 20.02 8.51 11,400.00 18.67 90.59 163.69 6,200.68 8.61 20.45 8.61 11,500.00 18.67 90.59 165.83 6,199.65 8.71 20.89 8.71 11/17/2015 9:56:03AM Page 6 COMPASS 5000.1 Build 74 • • . Schlumberger Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-11 Project: Kuparuk River Unit TVD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-11 North Reference: True Wellbore: Plan:2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11wp07[Great White] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 11,600.00 18.68 90.59 167.68 6,198.62 8.82 21.33 8.82 11,700.00 18.68 90.59 169.28 6,197.59 8.93 21.78 8.92 11,800.00 18.68 90.59 170.68 6,196.57 9.04 22.24 9.03 11,900.00 18.69 90.59 171.92 6,195.54 9.15 22.70 9.15 12,000.00 18.69 90.59 173.01 6,194.51 9.26 23.16 9.26 12,100.00 18.69 90.59 173.99 6,193.49 9.38 23.64 9.38 12,200.00 18.70 90.59 174.87 6,192.46 9.50 24.11 9.50 12,300.00 18.70 90.59 175.66 6,191.43 9.62 24.59 9.62 12,400.00 18.70 90.59 176.39 6,190.41 9.74 25.08 9.74 12,500.00 18.71 90.59 177.04 6,189.38 9.87 25.57 9.86 12,600.00 18.71 90.59 177.65 6,188.35 9.99 26.06 9.99 12,700.00 18.72 90.59 178.21 6,187.33 10.12 26.56 10.12 12,800.00 18.72 90.59 178.72 6,186.30 10.25 27.05 10.24 12,900.00 18.72 90.59 179.20 6,185.27 10.38 27.56 10.37 13,000.00 18.73 90.59 179.65 6,184.25 10.51 28.06 10.51 13,100.00 18.73 90.59 0.06 6,183.22 10.64 28.57 10.64 13,200.00 18.73 90.59 0.45 6,182.19 10.78 29.08 10.77 13,300.00 18.74 90.59 0.82 6,181.17 10.91 29.60 10.91 13,400.00 18.74 90.59 1.17 6,180.14 11.05 30.11 11.05 13,500.00 18.75 90.59 1.49 6,179.11 11.19 30.63 11.18 13,600.00 18.75 90.59 1.80 6,178.09 11.33 31.15 11.32 13,700.00 18.75 90.59 2.09 6,177.06 11.47 31.67 11.46 13,800.00 18.76 90.59 2.37 6,176.03 11.61 32.20 11.61 13,900.00 18.76 90.59 2.63 6,175.01 11.75 32.72 11.75 14,000.00 18.77 90.59 2.88 6,173.98 11.89 33.25 11.89 14,100.00 18.77 90.59 3.12 6,172.95 12.04 33.78 12.04 14,200.00 18.77 90.59 3.35 6,171.93 12.18 34.31 12.18 14,300.00 18.78 90.59 3.57 6,170.90 12.33 34.84 12.33 14,400.00 18.78 90.59 3.78 6,169.87 12.48 35.38 12.47 14,500.00 18.79 90.59 3.98 6,168.85 12.62 35.91 12.62 14,600.00 18.79 90.59 4.17 6,167.82 12.77 36.45 12.77 14,700.00 18.80 90.59 4.36 6,166.79 12.92 36.99 12.92 14,800.00 18.80 90.59 4.54 6,165.76 13.07 37.53 13.07 14,900.00 18.80 90.59 4.71 6,164.74 13.22 38.07 13.22 15,000.00 18.81 90.59 4.88 6,163.71 13.38 38.61 13.37 15,100.00 18.81 90.59 5.03 6,162.68 13.53 39.15 13.53 15,166.66 18.82 90.59 5.14 6,162.00 13.63 39.51 13.63 TD:15166.66'MD,6321.5'TVD-4 1/2"x 6-3/4"-2S-11 [Great White]1.Toe 111615 PB-2S-Great White 2.Toe 11/17/2015 9:56:03AM Page 7 COMPASS 5000.1 Build 74 • s . Schlumberger Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-11 Project: Kuparuk River Unit TVD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan:39.5+120 @ 159.50usft(Doyon25) Well: Plan:2S-11 North Reference: True Wellbore: Plan:2S-11 Survey Calculation Method: Minimum Curvature Design: 2S-11wp07[Great White] Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (0) (0) 2,805.03 2,547.00 10-3/4"x 13-1/2" 10-3/4 13-1/2 8,636.73 6,269.90 7-5/8"x 9-7/8"x 11" 7-5/8 9-7/8 15,166.66 6,321.50 4 1/2"x6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (0) 1,881.25 1,811.50 Top West Sak 6,018.93 4,671.50 C-37 3,308.25 2,875.50 C-80 5,291.79 4,167.50 C-50 2,811.72 2,551.50 Base Wes Sak 291.50 291.50 Top T-3 Sand 7,261.64 5,579.50 Top Bermuda 7,101.33 5,469.50 Top Cairn 8,847.73 6,323.50 Kuparuk C(Top C4) 7,370.20 5,651.50 Base Bermuda 8,276.45 6,143.50 U.Kalubik(base HRZ) 8,877.35 6,329.50 A4 1,453.67 1,423.50 Base Permafrost 5,859.92 4,555.50 C-40 6,218.25 4,819.50 Growler-AA 8,601.33 6,259.50 L.Kalubik(K-1 Mrkr) 376.50 376.50 K-15 Marker 9,165.41 6,369.50 A3 8,120.94 6,075.50 Top HRZ(K-2 Mrkr) Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 375.00 375.00 0.00 0.00 KOP:Start 1.5°/100'DLS, 190°TF,for 225.13' 600.13 600.00 -6.53 -1.15 Start 2.5°/100'DLS,0°TF,for 799.07' 1,399.20 1,373.50 -187.52 -33.06 Hold for 108.92' 1,508.13 1,473.50 -230.04 -40.56 Start 3°/100'DLS,80.5°TF,for 1362.5' 2,870.63 2,590.45 -707.72 -591.22 Hold for 2524.93' 5,395.55 4,235.09 -1,416.74 -2,371.04 Start 3°/100'DLS, 119.39°TF,for 3239.79' 8,635.34 6,269.50 44.91 -3,761.50 Hold for 30' 8,665.34 6,278.14 73.58 -3,759.61 Start 3.5°/100'DLS,43.69°TF,for 374.99' 9,040.33 6,355.52 435.73 -3,706.15 Hold for 45.94' 9,086.27 6,361.18 480.18 -3,696.00 Start 3.5°/100'DLS,41.73°TF,for 79.14' 9,165.41 6,369.50 556.61 -3,677.24 Start 2°/100'DLS,0°TF,for 279.42' 9,444.83 6,380.25 826.55 -3,606.35 Hold for 5721.83' 15,166.66 6,321.50 6,360.46 -2,153.17 TD: 15166.66'MD,6321.5'TVD Checked By: Approved By: Date: 11/17/2015 9:56:03AM Page 8 COMPASS 5000.1 Build 74 Pool Report • 0 O O O CO z .888,8 n re 6ii . y 0 o =_.gig. 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'''''''' It it o • a t' N • a P u �� • • ..1 N ', � .:fes • Is �� I to •• •. . * i N . ■ M O 11111111 ) (!J) N J a) L • 5 1 I '' - ‘,..T : :L.,,: I i / • • ,7"---- 1 . ,, /1/11: M a N �' . Ir� iiri , ---r--------_____ --%.A.- / / ) ...mi. L ..c ii,,7 .: . 7,,, r i .c2// 7/ 1 '''':' --'44, r ( v N 1 �� 0���-������� ��K8���eUocat'on "�� �J [P/QCoordinate[onve�er ^/ =~ , ��^��� _ ��r~ i ----- ------ -------- -^ � -- - -- From: �� - T«----- --------- - �-- � Datum: R�g�o Datum: Region: lalaska ,r| C [Decimal --- ~j i /` Degrees ` -- �� �� ,--' -� ' -~ | | ' ----- | (- UTM Zone "TrueF- South ,';'' State Plane Zone: 14-'-'--,.1 Units: ijilit- 0- State Plane Zone: IT"—Zrj Units: ti,;.F-;,j, C Legal Description(NAD27 only) r Legal Description(NAD27 only) Starting Coordinates: , Ending Coordinates: : Y: 15929723.27 [ , Y: r 5929973,68398357 1_ 2S-11wp07 Intermediate Casing From: -� - -----------` r To: Damm- Region: �l .�. `J ` � Damm Region: (a�vka .1 y`°""^ -/ r~~^~ -�/ | � ~^' � ' : -� | | (- 'Decimal �J � �~ LatitudeiLonoitude 'Decimal Degrees � . --� (` UTN Zone: �---- E South � rU7N Zone: FF��-' r- South/ / ' _ ;c State Plane Zone: Units: (i' State Plane Zone: Units: (v»Tr -1 r Legal Description LNAD27 only) 1 (- Legal Description(WAD27 only) Starting Coordinates: ------- -' - ---� Ending Coordinates: --��_�---- X: 11072870 X: | 47�5 .�8�5�8 Y: 1592977a15 `t 1583002861660823 � __ -_ Transform Quit | Help • 0 2S-11wp07 Production Horizon M CPAI Coordinate Converter . _ e3 l ., 4 ,, From: To: Datum: INAD83 Region: lalaska 1 Datum: 1NA027 ..1 Region: [alaska w 1 Latitude/Longitude Decimal Degrees ---.A, r Latitude/Longitude Decimal Degrees c LI T M Zone: f South r UTM Zone: T rue E South ri State Plane Zone: I" T1 Units: tus4t .j 4. State Plane Zone: 4 . Units: us-ft • C Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: T- Ending Coordinates: X: 11617313.16 X: 1477279.760977165 Y: 15930010.66 Y: 1 5930261.12143591 Transform Quit I Help 3 2S-11wp07 TD In, CPAI Coordinate Converter ',64.4-,',-;,:=:*1.,,,z'., From: Datum: NA0-63 1 Region: lalaska J Datum: 1NAD27 .I Region: alaska i C Latitude/Longitude Decimal Degrees . (. Latitude/LongitudeIecimDal Degrees T C' LITM Zone: f—[ South r` UTM Zone: 'True )— South State Plane Zone: 14__ Units: lus-ft �; Cr State Plane Zone: '1 4 Units: us-ft Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates:---- ; Ending Coordinates: -- - X: 1618912.10 X: 1478878.829239343 Y: 15936088.60 Y: [5936338.91043385 1 Transform Quit Help 1 O0 I- 2S-11wp07 Surface Location ,C3 , _ , , , -, ) .---ci ',' ,3 CPAI Coordinate Converter ., 1,4- .. 1 - From: To: ••• Datum: 1NAD83 ..:11 Region: Ialaska A , Datum: INAD27 ...7_1 Region: Jalaska 1 (- Latitude/Longitude 16-e-cin-Tafbegrees zi C Latitude/Longitude !Decimal Degrees ...13. ' (.. UT M Zone: 1 r- South r UTM Zone: IT r---- rue f- South t ;. State Plane Zone: ii---_1 Units: 6ir.1,. C State Plane Zone: mii---_;] Units: C Le i.,....,..,: ;;;,.•:,i:,-L „ 4- Legal Description(NAD27 only) Starting Coordinates: , Legal Description X: 11621048.72 1 Township: 010 r--- iii--,3 Range: j088 frD.P. Y: 1592972327 Meridian IU J Section:117 FFM171.7:1 13074,7091 Far-7" 11554.9085 1 Transform Quit Help I 2S-11wp07 Intermediate Casing In CPAI Coordinate Converter., From - i 1-To: Datum: f INAD 83 zi Region: lalaska II ' i Datum: I INAD27 71 Region: Ialaska ....7.1 ,7- Latitude/Longitude !Decimal Degrees , r Latitude/Longitude !Decimal Degrees .3 , I' UTM Zone: 1 I— South r UTM Zone: ITrje r South I , ro' State Plane Zone: 4 -..1 Units: [1 ;:it .,-j C State Plane Zone: F—I-„], Units: 1-us-ft ..1 i r1.f,;gal De,-,..-.1V,:q1(r 1LD 27;.= .' 4- Legal Description(NAD27 only) Starting Coordinates: Legal Description X: 11617287.82 Township: r joio iii-:1 Range: 10ra0— 8 If.11 Y: 15929779.15# —Meridian: jU ... Section:5T- 1F-NT-1.] 13029.1759 FET----;" 136.267449 Transform Quit Help I • 2S-11wp07 Production Horizon I CPAI Coordinate Converter '� " r- From: To: Datum: [NAD83 Region: Alaska .=.t Datum: [NAD27 Region: Alaska • t"' Latitude/Longitude Decimal Degrees . C Latitude/Longitude Decimal Degrees • UTM Zone: I E SouthUTM Zone: True E South 4* State Plane Zone: Ft Units: us-ft C State Plane Zone: 1-4--_-.,] Units: s-ft C 7 ,rs+tion',Cr. tom` Legal Description(NAD27 only) Starting Coordinates: - --- - -- -- ---- -Legs!Description -- X: 1617313.16 Township: Iwo rim.,--:i Range: [008 IC:j. Y: 15930010.66Meridian. U Section:118 _._W...._._..__ ___.__ __ __ FNL • 12797.5773 FEL • 110.803372 I Transform Quit I Help 1 2S-11wp07 TD t CPAI Coordinate Converter ' ' i� From: To: Datum: 1NAD83 Region: l'alaska .J Datum: NAD27 Region: [alaska j C Latitude/Longitude Decimal Degrees C Latitude/Longitude Decimal Degrees (. UTM Zone: E South r UTM Zone: ir-True E South t: State Plane Zone: 4 Units: us•ft C State Plane Zone: 17*---;1 Units: 167ii7.1 C l+, st Cr.. .r,.,tio r ir4 $T:27 on'yj < ` Legal Description(NAD27 only) Starting Coordinates: _.. ..__ ._,_ ...__. .___ Legal Description X: 11618912.10 Township: Ot Q FA„ Range: 008 E . .--. ,, i Y: ,, 59360$$.60 Meridian: lU Section:18 FNL . 11994.5490 FEL • 13688.5839 Transform Quit Help As- built REV DATE BY CK APP •DESCRIPTION REV DATE BY COAPP DESCRIPTION 1 5/28/15 SZ JAN Created Drawing Per K140173ACS w y 14 17,.. 16 ��35 i 14 , u le 4', 17 ( "°6 O NOTES: l DS2A 1 1 .. _ !Doc 1 : ==WS 14, ` Mr\\, ,,, 1. BASIS OF LOCATION AND ELEVATION IS DS2S 14 `=19 t0 2V 22 ; 23 19` 20 trefff 1 , MONUMENTATION PER LOUNSBURY & ASSOC. ' - ,� ��2. ' \2 /, 95 ��I 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, s\'D5211 ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES — •�` ' 4s2R d. ARE NAD 27. `., }1 37 ' 4 35 31 os2O 31–' 1 ... PPC' . r -'� u T11 N 4 P i w TION 3. ELEVATIONS ARE B.P.M.S.L. 111,..3-'.. JS 0,�``, �=I. '� 1 ,42c 1 22.T s; l'>S 3 '-c,\c'''-.. aP ti�,r ° W- 4s2R k ) 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED / Q.Fi„ y ; ) SECTION 17, TOWNSHIP 10 NORTH, RANGE 8 EAST, 2 fr P0a0 9 s"' 10 4,I " 11 2 4\ y';' 1\19 UMIAT MERIDIAN. - \ r—° ` if 3' le ' )S 14 is 14 a i18 ' t i 5. DATES OF SURVEY: 5-2 THRU 5-27-15 FIELD BOOKS / 1 ', I, / L15-28, L15-29, L15-32, L15-35 �..� ss ..��zs I 5. tc 4� /9;, 20 2' f -a 24 5 19 ^ 24' 21 6. ALL DISTANCES SHOWN ARE TRUE. I (, 'PROJECT .k.‘ '() �, S LOCATION ; 1.) , ,040. 1 3.,.;‘,...;.:: V2 2` 1') 2' 17, ri5 \30 29 /6 27 Nf f .1 :��} . r > 31 31 31 31. 34 1`.,3% 3y t)3 12 13 34 `. VICINITY MAP NTS 3ci' SYP• DS2S --\ 6 40 ® 0 14 12 10 8 ®®® 3 2 1 ct 5 ® ® @11 9 7 13 I LEGEND O AS—BUILT CONDUCTOR LOCATION __ 17 16 20� 21 GRAPHIC SCALE o Iiiimail00 200 400 — • LOUNSBURY SEE PAGE 2 OF 2 FOR LOCATIONS - — & ASSOCIATES, INC. 1 inch = 200 ft.. SURVEYORS ENGINEERS PLANNERS AREA:2S MODULE: XXXX UNIT: D2 i ConocoPhollo s, DS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6219d24 5/28/15 CEA—D2SX-6219D24 1 OF 2 1 l REV DATE BY CK APP ' •DESCRIPTION REV DATE DY C APP DESCRIPTION 1 5/28/15 SZ JAN Created Drawing Per K140173ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 17, T. 10 N., R. 8 E., UMIAT MERIDIAN Well NAD 27 NAD 27 Section Elev. No. ASP Coordinates Geographic Coordinates Offset. Y X Lat. Long. F.S.L F.E.L. 0.G. PAD 1 5,930,036.15 481,309.02 70' 13' 12.058" 150' 09' 02.839" 2268' 1261' 112.0' 120.0' 2 5,930,029.92 481,279.68 70' 13' 11.996" 150' 09' 03.690" 2262' 1291' 112.4' 120.0' 3 5,930,023.62 481,250.32 70' 13' 11.933" 150' 09' 04.543" 2255' 1320' 112.1' 120.0' 4 5,930,017.59 481,221.00 70' 13' 11.873" 150' 09' 05.394" 2249' 1349' 112.0' 120.0' 5 5,930,010.88 481,191.79 70' 13' 11.806" 150' 09' 06.242" 2243' 1378' 111.8' 120.0' 6 5,930,004.80 481,162.27 70' 13' 11.746" 150' 09' 07.098" 2236' 1408' 111.5' 120.0' 7 5,929,998.58 481,133.41 70' 13' 11.684" 150' 09' 07.936" 2230' 1437' 111.4' 120.0' 8 5,929,992.42 481,103.50 70' 13' 11.622" 150' 09' 08.804" 2224' 1467' 111.1' 120.0' 9 5,929,986.08 481,074.22 70' 13' 11.559" 150' 09' 09.654" 2217' 1496' 111.0' 120.0' 10 5 929.979.7? 481.044.13 70' 13' 11,496" 150' 09' 10.528" 11' 1526' 11L1' 120.0' 11 5,929,973.68 481,015.40 70' 13' 11.436" 150' 09' 11.362" 12205'11555' 111.1' 120.0' 12 5,929,968.02 480,986.10 70' 13' 11.380" 150' 09'�12.212' 2199' 1584' 110.9' 2- ' 120.0' 13 5,929,961.45 480,956.55 70' 13' 11.314" 150' 09' 13.070" 2192' 1614' 110.6' 120.0' 14 5,929,955.02 480,927.39 70' 13' 11.250" 150' 09' 13.920" 2186' 1643' 110.5' 120.0' r ;6\,/,..,♦ SURVEYOR'S CERTIFICATE r ' 49th /\ ' #, I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND • ' *••• '• LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF • r"" ✓ ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND /9("1:'.JEREMIAH F. CORNELL. ♦ A THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT ♦♦V•.•• LLSS,-12663 �! AS OF MAY 27, 2015. ,�i�o���e�•� LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA:2S MODULE: XXXX UNIT: D2 onDS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6219d24 5/28/15 CEA-D2SX--6219D24 2 OF 2 1 • 2S-11 Drilling Hazards Summary 13-1/2"Hole/10-3/4"Casing Interval Event I 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 Low Run Gyro as needed for magnetic interference.Third well on pad,so no real anti-collision risk,only with future plans. 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 Low Prevent by keeping hole clean. If losses occur-reduce pump rates and mud rheology,use LCM Unsuccessful cement job Moderate Use lower density cement slurry.Adjust the mud properties prior pump cement.Use proper pump rate. 9-7/8"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 with higher MW and proper tripping practices to avoid surging or swabbing. Minimize pressure cycling by stripping out using MPD to 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 LC decision tree. Keep ECD below known frac gradient of—13.0 ppg in Tam formations crossed in intermediate. Hole cleaning Low Use PWD and TAD to monitor hole cleaning.Control the ROP and use the best hole cleaning practice. Stuck pipe Low Good hole cleaning,stabilized BHA,proper mud weight,PWD monitor ECD. 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 higher than expected. 6-3/4"Hole/4-1/2"Liner Interval Event Risk 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 event pressure 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 prevent any 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. • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: /<RL 2S—I I PTD: tS— 1 XDevelopment Service Exploratory _Stratigraphic Test Non-Conventional FIELD: 2,1Vk✓' POOL: _ � � t tdi A.A. Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are / also required for this well: ✓/ Well Logging Requirements /Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion,suspension or abandonment of this well. Revised 2/2015 • • 0 To Op 0 0- u) N ._co _a° m 0 c 0 as. 0 , 0 a L U C : . 3. o: O ° �:P. co o co o. fA 0LC (0 GI Q . C• W E 0 a) o' ° a ry CA 2 a) o c, v, �' 3, ami: vi o a), o 3, 3. 1 a. 0C 4 W CN Q t- , O, is 2'' E .§ '2 -0 °' E c, o o' v, : Y, o L E a) 0a) a) m �COa Y a. : O v. c: a)' a Q. m ca o O' °' m' E' a N' .y0.. <cc o CD CD CD atS, : Y' c :: c u 3. as o y 3 '3 0 aa)), D °° `0 : a, CO . E 8' �: Y 8, a? 0 o- . E. Yi as i4' >, p �: 03 CO, @ a a �' y Z o Q C6 2' c: @ y ., c' a)' c. 0 o N. 2 • y y E 0 o Y' 8 -c 3: 0� 0' b 0 0� - 0 .0 � 0 0 �� v, co 0 N, . n U U 0 N 0 x O > 1' = E 0 f0 m 0, Z O. N. 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