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215-205
ConocoPhillips y Alaska f P.O. BOX 100360 NO V 1 0 ?016 ANCHORAGE,ALASKA 99510-0360 41/4 November 5, 2016 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501e� ty t�� ; .C U J 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 Aaron Applehans at 907-659-7506, if you have any questions. Sincerely, Aaron Applehans ConocoPhillips Well Integrity Field Supervisor • •F ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 11/8/2016 3K-24,3K-27,2V-09,2S-1,2S-2,2S-3,2S-4,2N-314 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 3K-24 50029229350000 1982490 NA NA NA NA 1.7 11/5/2016 3K-27 50029227510000 1970460 NA NA NA NA 3.4 11/5/2016 2V-09 50029213000000 1850370 NA NA NA NA 2 11/5/2016 2N-314 50103203550000 2001930 2' NA 2' NA 10.2 11/6/2016 2S-01 50103207270000 2152030 1.5' NA .98' 7/2/2016 2.55 11/6/2016 2S-02 50103207100000 2150700 2' NA 1' 7/2/2016 3.4 11/6/2016 2S-03 50103207290000 2152050 1.6' NA 1.04' 7/2/2016 3.4 11/6/2016 K.> 2S-04 50103207210000 2151590 2.3' NA 1.125' 7/2/2016 3.4 11/6/2016 • • ATO Z7z Loepp, Victoria T (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Wednesday, December 09, 2015 1:49 PM To: Loepp, Victoria T (DOA) Cc: Regg, James B (DOA); Bettis, Patricia K (DOA); Schwartz, Guy L(DOA) Subject: RE: DS-2S Diverter Exclusion Zone Waiver Request Thanks Victoria. We will keep you posted as we get closer and inform you in advance of applying for a waiver on any wells. Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska SCANNED AUG 1 9 2016 ATO 15-1564 Office: (907) 263-4180 Cell: (907) 231-2176 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday, December 09, 2015 1:37 PM To: Callahan, Mike S Cc: Regg, James B (DOA); Bettis, Patricia K (DOA); Schwartz, Guy L (DOA) Subject: [EXTERNAL]RE: DS-2S Diverter Exclusion Zone Waiver Request Mike, We will consider a waiver to allow work within 75' of the diverter discharge after drilling to surface TD, clean up and flow check with the following conditions: 1. Run mud logs on wells where a diverter waiver is desired. 2. AOGCC review of drilling records and mud log at surface TD; based on the review,the AOGGC will determine if a diverter waiver will be granted. 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.Loeppf 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.Loepp@alaska.gov 1 • s From: Callahan, Mike S [mailto:Mike.Callahanc conocophillios.com] Sent: Tuesday, December 08, 2015 3:31 PM To: Loepp, Victoria T(DOA) Subject: RE: DS-2S Diverter Exclusion Zone Waiver Request Victoria,we do have the mud log from the surface section on 2S-02,which is the well right next to 2S-03. Would that be sufficient for this well? If not,we are open to running mud loggers on the wells where we would like this waiver. Thanks, Mike From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@ialaska.gov] Sent: Tuesday, December 08, 2015 2:27 PM To: Callahan, Mike S Subject: [EXTERNAL]RE: DS-2S Diverter Exclusion Zone Waiver Request Would you be amenable to running a mud log to surface TD? From: Callahan, Mike S [mailto:Mike.CallahanOconocophillips.com] Sent: Monday, December 07, 2015 3:43 PM To: Loepp, Victoria T(DOA) Subject: RE: DS-2S Diverter Exclusion Zone Waiver Request Yes,we will have to have ignition sources within the zone to get the work done. From: Loepp, Victoria T(DOA) [mailto:victoria.loeppC@alaska.gov] Sent: Monday, December 07, 2015 3:09 PM To: Callahan, Mike S Subject: [EXTERNAL]RE: DS-2S Diverter Exclusion Zone Waiver Request Will there be any ignition sources within the exclusion zone during the requested work period? From: Callahan, Mike S [mailto:Mike.CallahanOconocophillips.com] Sent: Monday, December 07, 2015 2:33 PM To: Loepp, Victoria T(DOA) Subject: DS-2S Diverter Exclusion Zone Waiver Request Victoria, as we discussed on the phone this afternoon, we would like a waiver to work within the 75 foot exclusion zone around the end of the diverter after drilling to TD of the surface section on 2S pad. This is to allow well work and frac operations to commence on adjacent wells sooner to reduce the time to put the wells on production. On 2S-01 (and a couple of subsequent wells),we have a very limited time window to complete all of the frac and well work before the slot is covered up by the rig, preventing the well from being put on production for an additional 30-60 days. Our proposed order of operations would be as follows: 1. Move rig from 2S-01 to 2S-03 and rig up diverter as usual. 2. Drill 2S-03 surface hole to TD, maintaining 75' exclusion zone around the end of the diverter as usual. 3. At TD, circulate to clean the well and confirm no presence of gas. Perform 30 minute no flow check to confirm well is static. 4. Once the well is confirmed static and we are sure there is no presence of gas in the surface section,we would like to allow work to occur within the 75' exclusion zone around the end of the diverter. We will keep the 2 • diverter rigged up while we go through our operations of tripping out of hole, running surface casing, and cementing. This would be roughly a three day period where we traditionally maintain the exclusion zone around the diverter that we would like to allow work in. If there is any sign of over-pressure or gas present in the surface section while drilling or at TD,we will scrap the plan and maintain the exclusion zone the entire time the diverter is rigged up. I have attached a rough pad map showing the layout with Doyon 25 on 25-03 and attempting to frac on 25-01. There will be a couple more similar scenarios on subsequent wells,so we would like the waiver to apply to the remainder of the wells on the pad (7 more wells to be drilled after 25-01). Please let me know if you have any questions or would like any further information. Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907) 231-2176 3 • • o o 0 o I I N O a) • 1 O NO \ -. O (0 in N °) o ---\! 1 C 10 16 16 N N •m 1 U) . co fn Cn• Cn• co '-+ C U NI 2 'NIJ NI< NI< N_I< N1 • . • • ca r 5 > co Q I Q I Q I Q I Q a) a) a) a) a) a• O. g o co ag ag ag ag a a a a a cr. a w o in ❑ ow ow ow ow U 0 0 0o 0o o O a) a) a)r1 6"1 a) MI a)vI 456 wI °I'o co u) cI v) oI a �I Z Z Eo E0 Eo Eo E < M M M — M• — co I I ❑ E. 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I C c U 0 J t a.) .` U IT:). o o a 0. m E a E 0 E o O 2 E o ai E E d a 2 0 EL a)0 0 0 ° � 0 • . Guhl, Meredith D (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Tuesday,June 07, 2016 1:17 PM To: Guhl, Meredith D (DOA) Cc: Bettis, Patricia K (DOA) Subject: RE: KRU 2S-03 and PB1, PTD 215-205, Logs Obtained? Attachments: 20160607130153.pdf Good afternoon Meredith, Attached is the 10-407 cover page with the GR/Res/Neu/Den logs listed. The Periscope is just the logging tool used to capture the resistivity logs, not a separate log itself. We did not have sample catchers with the mud loggers,the mud loggers were just used to help us identify our casing setting depth, so there is no lithology track with the mud log. Please let me know if this answers your questions and is sufficient documentation, or if you would like more information or a revised form to be submitted. Thank you, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 1716 Office: (907) 263-4180 Cell: (907) 231-2176 From:Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent:Tuesday,June 07, 2016 10:54 AM To:Callahan, Mike S<Mike.Callahan@conocophillips.com> Cc: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject: [EXTERNAL]KRU 2S-03 and PB1, PTD 215-205, Logs Obtained? Hello Mike, I'm completing the compliance check on KRU 2S-03 and PB1 and there is an inconsistency between what logging was planned in the proposed drilling program,what was listed on the 10-407 well completion form,and what has been received at the AOGCC. In the proposed drilling program the following data is listed: 1. 13.5" hole: MWD/GR/Res/Gyro 2. 9-7/8" hole: MWD/LWD/GR/Res 3. 6-3/4" hole: MWD/LWD/GR/Res/Neu/Den/Periscope In the 10-407 the following data is listed:GR/Res To date the AOGCC has received: 1. GR/Res/Neu/Den for 2S-03 and 2S-03 PB1 2. Mudlogs(no lithology)for KRU 2S-03 1 • • Please provide a new list of logs obtained for Box 22 on the 10-407 form. Please confirm whether or not a Periscope log was completed, and if so, provide the digital and paper data required. Please provide the new list by 6/10/2016 and any missing data by 6/17/2016. If you have any questions please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100,Anchorage,AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 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 Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 2 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil El Gas❑ SPLUG❑ Other ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development I] Exploratory 0 I• GINJ ❑ WINJ❑ WAGE] WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 6.Date Comp.,Susp.,or 14.Permit to Drill Number I Sundry: ConocoPhillips Alaska, Inc. Abend.: 3/1/2016 215-205/ 3.Address: 7.Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 1/31/2016 50-103-20729-00 4a.Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 3024'FNL, 1320'FEL,Sec 17,T1ON,R8E,UM 2/22/2016 KRU 2S-03/25-03PB1 Top of Productive Interval: 9.Ref Elevations: KB:159 17.Field/Pool(s): 163 FNL,2653 FEL,Sec 21,T1ON,R8E,UM GL: 120 BF: Kuparuk River Field/Kuparuk River Oil Pool Total Depth: 10.Plug Back Depth MD/TVD: 18.Property Designation: 2216'FNL,4560 FEL,Sec 28,T1ON,R8E,UM n/a ADL 25604,25607,25603 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19.Land Use Permit: Surface: x- 481250 y- 5930023 Zone- 4 16,760/6,488 2677,2678 TPI: x- 485198 y- 5927596 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MDITVD: Total Depth: x- 483295 y- 5920268 Zone- 4 n/a 1469/1449 5. Directional or Inclination Survey: Yes 0 (attached) No El 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 r Ai v E O GR/Res/Neu/Den ,S .2 rt � 1 lb' � r "`.C‹ bil (0(1/11C' 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD r AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 62.5 H-40 39.5 118 39.5 118 24 Pre-Driven 10.75 45.5 L-80 39.5 2859 39.5 2662 13.5 1269 sx DeepCrete Class G, 192 sx DeenCrete Class G 7.625 29.7 L-80 39.5 9035 39.5 5290 9.875 Stage 1:654 sx 15.8 ppg, Class G,Stage 2:298 sx 15.8 non Class G 4.5 12.6 L-80 8885 16543 6255 6440 6.75 n/a 24.Open to production or injection? Yes I] No ❑ 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MDITVD) Size and Number): 3.5 8715 n/a FRAC PORT @9463MD,6364TVD,FRAC PORT @ 10205MD,6354TVD FRAC PORT 10766MD,6376TVD,FRAC PORT @ 11502MD,6384TVD 26.ACID,FRACTURE,CEMENT SQUEEZE,ETC. FRAC PORT 12104MD,6396TVD,FRAC PORT @ 12824MD,6399TVD Was hydraulic fracturing used during completion? Yes❑ No FRAC PORT 13542MD,6401TVD,FRAC PORT @ 14303,MD,6411TVD FRAC PORT I5064MD,6431 TVD,FRAC PORT @ I5823MD,6437 TVD Per 20 AAC 25.283(i)(2)attach electronic and printed information FRAC SLEEVE @ 16582MD,6423TVD DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): Waiting on Facility Hookup Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: 'Gas-Oil Ratio: Test Period —0.- Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): pass. 24-Hour Rate .....11o.Form 10-407 Rev sed 11/2015 CONTINUED tW PAGE 2 Submit ORIGINIAL only 2 7 1 5 5 STATE OF ALASKA ANCA OIL AND GAS CONSERVATION COMIDSION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Plug Perforations E Fracture Stimulate Pull Tubing r Operations Shutdown r" Performed: Suspend E Perforate E Other Stimulate pAlter Casing r Change Approved Program Plug for Redrill E Perforate New Pool E Repair Well r Re-enter Susp Well E 1- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number ConocoPhillips Alaska, Inc. Development 1 Exploratory r 215-205 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-103-20729-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25604,25607,25603 KRU 2S-03 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 16760 feet Plugs(measured) None true vertical 6586 feet Junk(measured) None Effective Depth measured 16728 feet Packer(measured) 8569 true vertical 6585 feet (true vertical) 6177 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 120 120 SURFACE 2741 10 3/4 2782 2593 INTERMEDIATE 8788 7 5/8 8827 6251 LINER 8077 41/2 16729 6483 RECEIVE . . MAY 0 2 2116 Perforation depth: Measured depth: 9463-16582 True Vertical Depth: 6366-6462 AOG CC Tubing(size,grade,MD,and TVD) 3.5, L-80,8715 MD,6220 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER Premier Production Packer @ 8569 MD,6177 TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9463-16582 Treatment descriptions including volumes used and final pressure: Total Well- 11 stages 1,030,400Ibs 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 1000 1600 Subsequent to operation unknown unknown unknown 300 1000 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations P- Exploratory E Development F Service r Stratigraphic E Copies of Logs and Surveys Run r 16.Well Status after work: Oil F Gas r WDSPL Printed and Electronic Fracture Stimulation Data F GSTOR E WINJ E WAG EGINJ E SUSP E SPLUG 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: 316-134 Contact Adam Klem(a,263-4529 Email Adam.Klem anconocophillips.com Printed Name dam Klem Title Completions Engineer Signatures Phone:263-4529 Date 1/71-- ///l/6, Form 10-404 Revised 5/2015 ,,,e,- 4 RBDMS 1,k, MAY 0 3 2016 Submit Original Only Caw j//,2oiL • • 2S-03 DTTMS.JOBTYP SUMMARYOPS 3/30 FRACTURING Attempt to pressure test surface lines to 9700psi. Could not get a good test initially. Wellhead leaking. Re-attempt pressure test to 9700psi, it looked good. Using the cement pump, open the Alpha sleeve at—6500psi (surface pressure). Discovered ground valve to frac pumps leaking. Suspended job for re-start tomorrow. 3/31 FRACTURING Pumped Stages 1-6. Placed 451,700 lbs of 16/20 proppant. 4/3 FRACTURING Pumped Stages 7-11. Placed 578000 lbs of 16/20 proppant. 4/16 TEMPORARY BRUSHED & FLUSHED TBG, UNABLE TO PASS 8513' SLM (72 DEG). DRIFTED NETWORK TO D-NIPPLE @ 8596' RKB WITH 2.78". ATTEMPTED SET 2.75" CA-2 PLUG AT ONLY SAME. IN PROGRESS. 4/17 TEMPORARY BRUSHED & FLUSHED D-NIPPLE @ 8596' RKB. SET 2.75" CA-2 PLUG AT SAME. NETWORK MIT TBG 3000 PSI; PASSED. NFT PASSED. DEPLOYED BAITED P/T. PULLED DV ONLY @ 3985' RKB. READY FOR DHD. 4/19 FRACTURING (SEC) : POT-T PASSED, PPPOT-T PASSED, INTERMEDIATE POT-T PASSED, INTERMEDIATE PPPOT-T PASSED, POT-IC PASSED, PPPOT-IC PASSED, BPV TEST PASSED TO 1020 PSI, DDT-T/IA PASSED. KUP P OD 2S-03 ConocoPhillips ►r"1, Well Attribu Max AnglS TD Alaska,Inc< Wellbore APUUWI Field Name Wellbore Status ncl C) MD(ft B) Act Btm(ftKB) Lora<W9uilfy. 501032072900 KUPARUK RIVER UNIT PROD 92.57 9,801.77 16,760.0 .-. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 20-03,4/20/20169:44:27 AM. SSSV: NONE Last WO: 39.64 3/1/2016 Vernal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;37 3 -- Last Tag: Rev Reason:ADD FRAC INFO lehallf 4/5/2016 .....1.1, '` "'""c-Casing n. x 3 using rings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread • . CONDUCTOR 16 15.250 40.4 120.4 120.4 62.50 H-40 Welded XO Reducing;81.8 Mr Casing Description 'OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len 02 Grade Top Thread it SURFACE 10 3/4 9.950 40.4 2,781.7 2,593.3 45.50 L-80 TSH 563 -"S s.CONDUCTOR;40.4-120.4- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread I INTERMEDIATE 7 5/8 6.875 39.2 8,826.9 6,250.6 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 SURFACE;40.4-2,781.7 LINER 41/2 3.958 8,652.1 16,728.7 6,482.8 12.60 L-80 Hyd 563 GAS LIFT;3,984.8 Liner Details iii[i Nominal ID Top(1tKB) Top(ND)(ftKB) Top Incl C) Item Des Com (in) 8,676.9 6,209.1 73.09 NIPPLE Baker 5.5""RS"Packoff Seal Nipple 17#L-80 4.240 GAS LIFT;7,481.9 x.. Hyd 563 box x box 8,679.2 6,209.7-73.11 Hanger Baker 5.5"x 7.63"Flex-Lock Liner hanger P110 4.800 GAS LIFT;8,484.3 �; Hyd 563 pin x pin �- 8,689.0 6,212.6 73.15 XO Reducing 5.5"Hyd 563 15.5#box x 5"15#H521 box 4.420 V Crossover Coupling GAUGE;9,5435 -- 8,700.5 6,215.9 73.21 SBE Seal Bore Extension 80-40 5" pin Hyd 521u x 4W 3.990 XO Threads;8,559.2- y p PACKER;8,5680- XO Threads;8,575.7 9,201.0 6,343.4 79.51 SWELL Baker-"Swell Packer-"I" SN:50494-001-44 3.958 . PACKER ?K 9,463.1 6,366.6 90.19'FRAC Port Baker 4-1/2"Frac Sleeve#10-(2.5"Bag,Drift w/ 2.448 at LOCATOR;8,648.1 2.438")PN:10437086 LOCATOR;8,849.1 10,205.2 6,354.0 88.75 FRAC Port Baker 4-1/2"Frac Sleeve#9-(2.438"Bag,Drift w/ 2.385 2.375")PN:10437085 [ '' 10,462.8 6,362.1 87.42 SWELL Baker-"Swell Packer"-"H" SN:50494-001-48 3.958 PACKER ( -I 10,766.2 6,375.7 86.53 FRAC Port Baker 4-1/2"Frac Sleeve#8-(2.375"Ball,Drift w/ 2.323 ( 2.313")PN:10437084 11,502.8 6,383.7. 89.25 FRAC Port Baker 4-1/2"Frac Sleeve#7-(2.313"Ball,Drift w/ 2.260 SHOE;8,7140 2.25")PN:10437083 11,800.8 6,386.6 88.39 SWELL Baker-"Swell Packer"-"G" SN:50494-001-20 3.958 PACKER 12,104.7 6,396.4 87.83 FRAC Port Baker 4-1/2"Frac Sleeve#6-(2.25"Ball,Drift w/ 2.198 INTERMEDIATE;39.2-8,826.9 2.188")PN:10437082 imiiir 12,400.4 6,403.2 89.11 SWELL Baker-"Swell Packer"-"F" SN:50494-001-37 3.958 PACKER 12,8242 6,399.1 91.52 FRAC Port Baker 4-1/2"Frac Sleeve#5-(2.188"Ball,Drift w/ 2.135 MB 2.125")PN:10437081 cx 13,160.7 6,390.5 89.08 SWELL Baker-"Swell Packer"-"E" SN:50494-001-42 3.958 PACKER l18=M 13,542.8 6,401.1 88.34 FRAC Port Baker 4-1/2"Frac Sleeve#4-(2.125"Ball,Drift w/ 2.073 2.063")PN:10437070 13,919.3 6,403.3 90.80 SWELL Baker-"Swell Packer"-"D" SN:50494-001-39 3.958 2.010 3.958 PACKER • ■ 14,303.4 6,410.9 87.43 FRAC Port Baker 4-1/2"Frac Sleeve#3-(2.063"Ball,Drift w/ Hydraulic Fracture 9,463.0 2.00")PN:H810-09-0416 14,680.6 6,425.3 88.82 SWELL • PACKER Baker-"Swell Packer"-"C" SN: 50494-001-4 i I 15,064.3 6,431.3 89.31 FRAC Port Baker 4-1/2"Frac Sleeve#2-(2"Ball,Drift w/1.938") 1.948 PN:H810-09-0417 15,439.8 6,436.0 89.67 SWELL Baker-"Swell Packer"-"B" SN:50494-001-36 3.958 iiPACKER 15,823.3 6,437.0 89.83 FRAC Port Baker 4-1/2"Frac Sleeve#1-(1.938"Ball,Drift w/ 1.885 (.875")PN:H810-09-0418 16,199.3 6,443.8 89.35 SWELL Baker-"Swell Packer"-"A" SN:50494-001-11 3.958 PACKER 16,582.4 6,462.6 84.66 FRAC SLEEVE Baker 4-1/2"Alpha Sleeve PN 10487898 3.000 16,595.9 6,463.8 84.47 VALVE Baker 4-1/2"Wellbore Isolation Valve(WIV)PN 1.000 10488946 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 37.3 8,715.0 6,220.1 9.30 L-80 EUE 8rd-M Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl r) Item Des Com (in) 37.3 373 0.00 HANGER Cameron 11"x 4-1/2"Tubing Hanger 3.900 81.8 81.8 0.48 XO Reducing XO,4-1/2"12.60 L-80 IBTM box x 3-1/2"9.30 L-80 EUE- 3.000 Mod pin Hydraulic Fracture;12,824.0 8,543.5 6,169.5 72.36 GAUGE Schlumberger Gauge Carrier 3-1/2"EUE P X P 2.913 (measured w/collar on top) - 8,569.0 6,177.2 72.52 PACKER Baker Premier Production Packer 2.870 8,596.1 6,185.3 72.69 NIPPLE Camco 2.75 D nipple 4.5"OD w/RHC plug body 2812 8,648.1 6,200.7 72.96 LOCATOR Baker 7.625"x 3.5"Shear pinned Fluted No-Go Sub- 3010 Large OD 8,649.1 6,201.0 72.96 LOCATOR Baker 7.625"x 3.5"Shear pinned Fluted No-Go Sub- 3.010 small OD 8,714.0 6,219.8 73.48 SHOE Mule shoe WLEG 3.000 Stimulations&Treatments Piliffilil Min Top Max Btm Depth Depth Top(TVD) Btm(TVD) OM (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 12,824.0 16,582.0 6,399.1 6,462.5 Hydraulic 3/31/2016 Stagel-69.7 klbs;2-85.66 klbs;3-30.8 klbs;4- p Fracture 65klbs;5-99.1 klbs;6-105.5 klbs. 9,463.0 12,104.0- 6,366.6 6,396.4 Hydraulic 4/3/2016 Stage7-99.5klbs;8-121 klbs;9-120 klbs;10-120 k LINER;8,652.1-18,728.7- I l Fracture lbs;11-118.2 klbs of 16/20 proppant KUP P OD • 2S-03 ConocoPhillips g Alaska,Ins, Co eccp1Npipt 28-03,4/20/2016 9:44:28 AM Vertical schematic(actual) HANGER,37.3— m..n.ouuu•uunnunuw.u.uuuuueuu.�u s .... Mandrel Inserts St i XO Reducing;81.8 '� ° Top(TVD) Valve Latch Port Size TRO Run • N, Top(80KB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com -tin.CONDUCTOR,40.4-120.4- 1 3,984.8 3,502.3 Camco KBMG 1 GAS LIFT DMY BK 2 0.000 0.0 2/29/2016 2 7,481.9 5,669.7 Camco KBMG 1 GAS LIFT DMY BK 2 0.000 0.0 2/29/2016 SURFACE,40.4-2,701.7 + 3 8,484.3 6,151.4 Camco KBMG 1 GAS LIFT SOV BEK 2 0.000 0.0 2/29/2016 GAS LIFT;3,984.8 .31 GAS LIFT;7,481.9 b 1I GAS LIFT,8,484.3 a E GAUGE,8,543.5 — XO Threads;8,559.2– PACKER,8,569.015. – XO Threads;8,575.7 a LOCATOR,8,848.1 ' ' LOCATOR,8,849.1 ;L7 SHOE;8,714.0 e m I INTERMEDIATE,39.2-8,828.9 Hydraulic Fracture 9.463.0 II Lel II f Hydraulic Fracture;12,824.0 7 I i LINER;8,652.1-18,728.7 • • Hydraulic Fracturing Fluid Product Component Information Disclosure Job Start Date: 3/30/2016 Job End Date: 4/3/2016 State: Alaska =: ± County: 200 Bay Frac Focus API Number:r: 50-103-20729-00-00 Operator Name: ConocoPhillips Company/Burlington Chemical Disclosure Registry Resources Well Name and Number: 2S-03 Longitude: -150.15435800 WATER Latitude: 70.21967000 Datum: NAD83 reOr€ea ou couxe+` Oil&Gas Federal/Tribal Well: NO True Vertical Depth: 6,488 Total Base Water Volume(gal): 699,490 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 Additive HF Fluid (CAS#) (%by mass)** (%by mass)** -ea Water Operator :ase Fluid NA A 100.00001 84.29279Density=8.540 VT-200 Penreco reeze Protection NA A :E-6 MICROBIOCIDE,Halliburton additive,Biocide, L-22 UC,CL-31 :reaker,Crosslinker, ROSSLINKER, ailing Agent, OSURF-300D,MO- icrobiocide,Non- .7,OPTIFLO-II onic Surfactant,pH BELAYED RELEASE ontrol Additive :REAKER,OPTIFLO- II DELAYED 'ELEASE BREAKER, .P BREAKER,WG-36 ELLING AGENT NA A arboLite 16/20 CarboCeramics •roppant NA A I •" shown... S ... r:'•CFR' ^+ •• •• •.. •- - --lety Data Sheets(MSDS).Ingredien'.-- `> below are Non-MSDS. azardous and Non- azardous Ingredients is Ceramic materials and wares, 66402-68-4 100.0000C 14.5398C chemicals -lydrotreated Distillate,Light.C9 64742-47-8 100.0000C 0.44931 -16 3uar gum 9000-30-0 100.0000C 0.33056 Water 7732-18-5 100.0000C 0.19764 Potassium formate 590-29-4 60.0000C 0.06168 3orate salts Confidential 60.0000C 0.06168 thanol '64-17-5 60.0000C 0.04444 Sodium hydroxide 1310-73-2 30.00000 0.04145 Cxyalkylated phenolic resin Confidential 30.0000C 0.02963 Potassium metaborate 13709-94-9 60.0000C 0.02863 Ammonium persulfate 7727-54-0 100.0000C 0.02273 Heavy aromatic petroleum 64742-94-5 30.0000C 0.02222 naphtha 3entonite,benzyl(hydrogenated 121888-68-4 5.00000 0.01653 tallow alkyl)dimethylammonium stearate complex Cured acrylic resin Confidential 30.0000C 0.00682 Surfactant mixture Confidential 1.00000 0.00661 Crystalline silica,quartz 14808-60-7 30.00000 0.00642 Naphthalene 91-20-3 5.00000 0.00370 Poly(oxy-1,2-ethanediyl),alpha- 127087-87-0 5.00000 0.00370 (4-n o nyl p h e n yl)-o m e g a- hydroxy-,branched Silica gel 112926-00-8 1.00000 0.00331 Sodium chloride 7647-14-5 1.00000 0.00241 Potassium hydroxide 1310-58-3 5.00000 0.00239 2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00000 0.00178 Acrylate polymer Confidential 1.00000 0.00103Denise Tuck,Halliburton, 3000 N.Sam Houston Pkwy E., Houston,TX 77032,281- 671-6226 Sodium glycollate 2836-32-0 1.00000 0.00103 Sodium carboxymethyl cellulose 9004-32-4 1.00000 0.00103 1,2,4 Trimethylbenzene 95-63-6 1.00000 0.00074 Crystalline Silica,Quartz 14808-60-7 0.10000 0.00033 Sodium persulfate 7775-27-1 100.00000 0.00028 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) • 0 RECEIVED STATE OF ALASKA APR 01 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORANOCOG la.Well Status: Oil 0 Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1 b.Well Class: 2oanc2s.tos 2oanc25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAG❑ WDSPL❑ No. of Completions: One Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 3/1/2016 215-205 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 1/31/2016 50-103-20729-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 3024'FNL, 1320'FEL, Sec 17,T10N, R8E, UM 2/22/2016 ' KRU 2S-0312S-03PB1 Top of Productive Interval: 9. Ref Elevations: KB: 159' 17. Field/Pool(s): 163'FNL,2653'FEL,Sec 21,T10N, R8E, UM GL: 120' BF: Kuparuk River Field/Kuparuk River Oil Pool ' Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 2216'FNL,4560 FEL,Sec 28,T1 ON, R8E, UM N/A ADL 25604,25607,25603 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/T1/D: 19. Land Use Permit: Surface: x- 481250 y- 5930023 Zone- 4 16760'MD/6488'TVD 2677,2678 TPI: x- 485198 y- 5927596 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 483295 y- 5920268 Zone- 4 N/A 1469'MD/1440'TVD 5. Directional or Inclination Survey: Yes (attached) No ❑ 13.Water Depth, if offshore 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log,spontaneous potential, gamma ray,caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation, casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary COMPLETION DAT GR/Res i I6Q1 Qes/NtID°A, '5)1 l ti 'h/wd - V R.: VERIFIED Lt- 23. L23. 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 40' 120' 40' 120' 24" Pre-Driven;438 sx AS I 10.75" 45.5# L-80 40' 2782' 40' 2593' 13.5" 1269 sx DeepCrete Class G; 192 sx DeepCrete Class G Stage 1:654 sx 15.8 ppg 7.625" 29.7# L-80 39' 8827' 39' 6251' 9.875"x 11" Class G; Stage 2:298 sx 15.8 ppg Class G 4.5" 12.6# L-80 8652' 16729' 6202' 6483' 6.75" Uncemented Liner 24.Open to production or injection? Yes ❑✓ No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5" 8715'MD 8569'MD/6177'TVD FRAC PORT @ 9463'MD/6367'TVD, FRAC PORT @ 10205'MD/6354'TVD FRAC PORT @ 10766'MD/6376'TVD, FRAC PORT @ 11502'MD/6384'TVD 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. FRAC PORT @ 12104'MD/6396'TVD, FRAC PORT @ 12824'MD/6399'TVD Was hydraulic fracturing used during completion? Yes ❑ No ❑✓ FRAC PORT @ 13543'MD/6401'TVD, FRAC PORT @ 14303'MD/6411'TVD FRAC PORT @ 15064'MD/6431'TVD, FRAC PORT @ 15823'MD/6437'TVD Per 20 AAC 25.283(i)(2)attach electronic and printed information FRAC SLEEVE @ 16582'MD/6463'TVD DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A Waiting on Facility Hook-up Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period -4 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. 24-Hour Rate -I. Form 10-407 Revised 11/2015 VTL 4/73//(, 0�1//�UE' 41iFiira& RBDMS L-" APR 0 4 201(Pubmit ORIGINIAL onlN - l • • 28. CORE DATA Conventional Core(s): Yes ❑ No RI Sidewall Cores: Yes ❑ No 0 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 RI Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1469 1449 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 9151 6333 information, including reports, per 20 AAC 25.071. WEST SAK SAND 1948 1867 WEST SAK BASE 2718 C-80 3219 2944 C-37 6117 4849 Top HRL 8093 6014 Top Kalubik Base 8430 6133 Kuparuk C 9069 6314 Kuparuk A5 9095 6320 Kuparuk A4 9151 6333 TD(Kuparuk A4) 16760 6491 2S-03PB1 Total Depth 13728 6533 Formation at total depth: Kuparuk A4 31. List of Attachments: Definitive Survey, Summary of Daily Operations, 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: Mike Callahan A 263-4180 Email: Mike.Callahan(a)cop.com kvi (�,,,.A, AA. C t;:///r (, Printed Name: G.L.Alvord Title: Alaska Drilling Manager Signature: J.i a - Phone: 265-6120 Date: 9 (t (2'"r 6 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 1b: Well Class-Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection, Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 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 8 KUP P OD 2S-03 ConocoPhillips Z Well Attrib Max AngIOD TD >'dli.k<3.II''i Wellbore APUUWI Field Name Wellbore Status ncl("i MD(ft ) Act Btm(ftKB) C.arlgco'hl8rps ' 501032072900 KUPARUK RIVER UNIT PROD 92.57 9,801 77 16,760.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 25-03,3/16/2016 3.45 16 PM SSSV: NONE Last WO. 39.64 3/1/2016 Vemcalschemahc(acnwq Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,373- Last Tag: Rev Reason: NEW WELL lehallf 3/15/2016 I. as . .. r__Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread CONDUCTOR 16 15.250 404 120.4 120.4 62.50 H-40 Welded x0 Reducing;81.8 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) .Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 10 3/4 9.950 40.4 2,781.7 2,593.3 45.50 L-80 TSH 563 JAI_CONDUCTOR.40.4-120.4• Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread g INTERMEDIATE 75/8 6.875 39.2 8,826.9 6,250.6 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 SURFACE;40.4-2,781.7 LINER 41/2 3.958 8,652.1 16,728.7 6,482.8 12.60 L-80 Hyd 563 lii GAS LIFT;3,984.8 Liner Details Nominal ID # Top(ftKB) Top(TVD)(ftKB) Top Incl Cl Item Des Com (M) I lit. 8,676.9 6,209.1 73.09 NIPPLE Baker 5.5""RS"Packoff Seal Nipple 17#L-80 4.240 II Hyd 563 box x box GAS LIFT,7,481.9 8,679.2 6,209.7 73.11 Hanger Baker 5.5"x 7.63"Flex-Lock Liner hanger P110 4.800 N Hyd 563 pin x pin GAS LIFT,8,484.3 8,689.0 6,212.6 73.15 XO Reducing 5.5"Hyd 563 15.5#box x 5"15#H521 box 4.420 Crossover Coupling GAUGE;8,543.5 = 8,700.5 6,215.9 73.21 SBE Seal Bore Extension 80-40 5"Hyd 521 pin up x 4%" 3.990 Zff xo Threads;8,559.z_ Hyd 521 box down PACKER;es69.0Cil9,201.0 6,343.4 79.51 SWELL Baker-"Swell Packer"-"I" SN:50494-001-44 3.958 x0 Threads;8,575.7 PACKER 111 9,463.1 6,366.6 90.19 FRAC Port Baker 4-1/2"Frac Sleeve#10-(2.5"Ball,Drift w/ 2.448 11.8 2.438")PN:10437086 LOCATOR;8,648.1_ 10,2052 6,354.0 88.75 FRAC Port Baker 4-1/2"Frac Sleeve#9-(2.438"Ball,Drift w/ 2.385 LOCATOR;8,649.12.375")PN:10437085 I! 10,462.8 6,362.1 87.42 SWELL Baker-"Swell Packer"-"H" SN: 50494-001-48 3.958 PACKER I . .1 10,766.2 6,375.7 86.53 FRAC Port Baker 4-1/2"Frac Sleeve#8-(2.375"Ball,Drift w/ 2.323 2313")PN:10437084 ' 11,502.8 6,383.7 89.25 FRAC Port Baker 4 1/2"Frac Sleeve#7-(2.313"Ball,Drift w/ 2.260 1 2.25")PN.10437083 SHOE',8,714.0 - 11,800.8 6,386.6 88.39 SWELL Baker-"Swell Packer"-"G" SN:50494-001-20 3.958 PACKER 5 1 I 12,104.7 6,396.4 87.83 FRAC Port Baker 4-1/2"Frac Sleeve#6-(2.25"Ball,Drift w/ 2.198 INTERMEDIATE,39.2-8,826.9 2.188")PN:10437082 12,400.4 6,403.2 89.11 SWELL Baker-"Swell Packer"-"F" SN:50494-001-37 3.958 PACKER _ 12,824.2 6,399.1 91.52 FRAC Port Baker 4-1/2"Frac Sleeve#5-(2.188"Ball,Drift w/ 2.135 2.125")PN:10437081 MINIM I 13,160.7 6,390.5 89.08 SWELL Baker-"Swell Packer"-"E" SN:50494-001-42 3.958 PACKER ii r 13,542.8 6,401.1 88.34 FRAC Port Baker 4-1/2"Frac Sleeve#4-(2.125"Ball,Drift w/ 2.073 2.063")PN:10437070 13,919.3 6,403.3 90.80 SWELL Baker-"Swell Packer"-"D" SN:50494-001-39 3.958 ( t PACKER r-1 1-1l 14,303.4 6,410.9 87.43 FRAC Port Baker 4-1/2"Frac Sleeve#3-(2.063"Ball,Drift w/ 2.010 1 `IS- 2.00")PN:H810-09-0416 •Eifi' 41 14,680.6 6,425.3 88.82 SWELL Baker-"Swell Packer"-"C" SN: 50494-001-4 3.958 PACKER ( 15,064.3 6,431.3 89.31 FRAC Port Baker 4-1/2"Frac Sleeve#2-(2"Ball,Drift w/1.938") 1.948 iilliilir PN:H810-09-0417 15,439.8 6,436.0 89.67 SWELL Baker-"Swell Packer"-"B" SN:50494-001-36 3.958 PACKER limo. 15,823.3 6,437.0 89.83 FRAC Port Baker 4-1/2"Frac Sleeve#1-(1.938"Ball,Drift w/ 1.885 1 875")PN:H810-09-0418 16,199.3 6,443.8 89.35 SWELL Baker-"Swell Packer"-"A" SN: 50494-001-11 3.958 PACKER O 0 16,582.4 6,462.6 84.66 FRAC SLEEVE Baker 4-1/2"Alpha Sleeve PN 10487898 3.000 liar 16,595.9 6,463.8 84.47 VALVE Baker 4-1/2"Wellbore Isolation Valve(WIV)PN 1.000 10488946 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..ISet Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 31/2 2.992 37.3 8,715.0 6,220.1 9.30 L-80 EUE 8rd-M liiir Completion Details f Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) iiiii:113 37.3 373 0.00 HANGER Cameron 11"x 4-1/2"Tubing Hanger 3.900 81.8 81.8 0.48 XO Reducing XO,4-1/2"12.68 L-80 IBTM box x 3-1/2"9.3#L-80 EUE- 3.000 Mod pin 8,543.5 6,169.5 72.36 GAUGE Schlumberger Gauge Carder 3-1/2"EUE P X P 2.913 (measured w/collar on top) 8,569.0 6,1772 72.52 PACKER Baker Premier Production Packer 2.870 8,596.1 6,185.3 72.69 NIPPLE Camco 275 D nipple 4.5"OD w/RHC plug body 2.812 iiillilr 8,648.1 6,200.7 72.96 LOCATOR Baker 7.625"0 3.5"Shear pinned Fluted No-Go Sub- 3.010 Large OD 0 ci 8,649.1 6,201.0 7296 LOCATOR Baker 7.625"x 3.5"Shear pinned Fluted No-Go Sub- 3.010 small OD 8,714.0 6,219.8 73.48 SHOE Mule shoe WLEG 3.000 Mandrel Inserts St an on Top(TVD) Valve Latch Port Size TRO Run NTop(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psil Run Date Corn 1 3,984.8 3,502.3 Camco KBMG 1 GAS LIFT DMY BK 2 0.000 0.0 2/29/2016 2 7,481.9 5,669.7 Camco KBMG 1 GAS LIFT DMY •BK 2 ' 0.000 0.0 2/29/2016 LINER;8,652.1-16,728.7 KUP 4OD • 2S-03 ConocoPhillips 2IXE Alaska,Inc, ••• 2S-03,3/16/20163:45'16 PM Vertical schema5c.Caytual) HANGER,37.3 Mandrel Inserts Sti on XO Reducing;81 8 Top(TVD) Valve Latch Port Size TRO Run N3 Top(kkaModel OD(in) Sery Type Type (in) (psi) Run Date Corn CONDUCTOR;46.4-126.4• ke 8,4843KB) (6,151KB) .4 CamMco KBMG 1 GAS LIFT SOV BEK 2 0.000 0.0 2/29/2016 i € SURFACE,40.4-2,781.7 GAS LIFT;3,984.8 -cc Is- GAS LIFT;7,481 9 GAS LIFT;8,484.3 GAUGE;9,543.5 XO Threads;8,559.2. - PACKER;8,569.0 00 Threads,8,575.7 LOCATOR;8,648.1 LOCATOR;8,649.1 �. 1 d SHOE;8,7140 ;In t Ci:, F INTERMEDIATE;39.2-8,826.9 MIIME :mot 11 0 LINER,8,652.1-16,728.7 -1 • • 0 Operations Summary (with Timelog Depths) to 2S-03 Can. tthpc ,..1,00, 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 (RKB) End Depth(ftKB) 1/29/2016 1/30/2016 12.00 MIRU MOVE MOB P Moving rig components from 2S-01 to 12:00 00:00 2S-03. Set starting head on conductor. Nipple up diverter tee and knife valve. Install diverter pipe sections. 1/30/2016 1/30/2016 12.00 MIRU MOVE MOB P Continue moving rig components from 0.0 0.0 00:00 12:00 2S-01 to 2S-03 and install diverter line. Raise derrick,skid floor,raise cattle chute,connect electrical and mud line interconnects. Shim cellar and close up cattle chute hatches. Accept rig @ 1200. 1/30/2016 1/30/2016 1.25 MIRU MOVE RURD P Cont.interconnects,lower and unpin 0.0 0.0 12:00 13:15 cellar box rams and secure. Rotate diverter line and tee. Charge steam lines,secure handrails and steps around rig. 1/30/2016 1/30/2016 1.75 MIRU MOVE RURD P Scope derrick up and secure in 0.0 0.0 13:15 15:00 cradles. 1/30/2016 1/30/2016 2.00 MIRU MOVE RURD P Begin loading,strapping and tally 5" 0.0 0.0 15:00 17:00 DP&HWDP in shed. Bring surface riser to floor,load pits w/H2O and calibrate Totco. 1/30/2016 1/30/2016 1.00 MIRU MOVE SEQP P Energize CIW seals on starting head 0.0 0.0 17:00 18:00 1/30/2016 1/30/2016 4.00 MIRU MOVE NUND P Lower surface riser to cellar and NU. 0.0 0.0 18:00 22:00 NU surface annular,flow box,flow line and all jet and hole fill lines. 1/30/2016 1/30/2016 0.50 MIRU MOVE RURD P Install 5"Elevators and slips. Function 0.0 0.0 22:00 22:30 test annular&knife valve. 1/30/2016 1/31/2016 1.50 MIRU MOVE BOPE P Diverter test witnessed by Guy Cook 0.0 0.0 22:30 00:00 w/AOGCC. Perform diverter test and Accumulator drawdown. Initial= 3000psi,function diverter, After=2100 psi.200psi recovery with 2 electric pumps=13 sec,full recovery at 58 sec with 2 electric and 2 air pumps, 6 bottle average=1904 psi. Annular closing time=30 sec.Knife valve opening time=14 sec. Witnessed all LEL and H2S detector Low and High alarm. 1/31/2016 1/31/2016 1.00 MIRU MOVE RURD P Cont.strapping 5"DP in pipeshed. 0.0 0.0 00:00 01:00 1/31/2016 1/31/2016 3.50 MIRU MOVE PULD P PU 1 stand of 5"DP w/mule shoe and 0.0 0.0 01:00 04:30 RIH to 45'. Tag up on ice, Install mouse hole,PU and rack back 26 stands of 5"DP and 6 stands of HWDP in derrick. 1/31/2016 1/31/2016 1.25 MIRU MOVE COND P Cont.to build 8.6 PPG spud mud. 0.0 0.0 04:30 05:45 1/31/2016 1/31/2016 1.75 MIRU MOVE RURD P C/O saver sub to 4.5"IF 0.0 0.0 05:45 07:30 1/31/2016 1/31/2016 1.00 MIRU MOVE RURD P Clean floor, PU master bushings w/ 0.0 0.0 07:30 08:30 inserts and install. 1/31/2016 1/31/2016 0.50 MIRU MOVE SFTY P Hold Pre-spud meeting 0.0 0.0 08:30 09:00 1/31/2016 1/31/2016 1.00 MIRU MOVE BHAH P PU BHA#1 per SLB. RIH to 39'MD. 0.0 39.0 09:00 10:00 Page 1/37 Report Printed: 3/14/2016 • • Operations Summary (with Timelog Depths) 2S-03 CcnocoPhillips .3 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) 1/31/2016 1/31/2016 0.75 MIRU MOVE SEQP P Fill stack and conductor w/H2O. Pres 39.0 39.0 10:00 10:45 test mud lines to 3500 PSI. Good. 1/31/2016 1/31/2016 1.25 SURFAC DRILL DDRL P Drill out ice in conductor w/water to 39.0 223.0 10:45 12:00 118'MD. Swap to 8.6 PPG spud mud and drill 10.75"hole to 223'MD @ 400 GPM,350 PSI,38%F/O,50 RPM, 1- 2K TQ,PU=54K,SO=50K,ROT= 52K. 1/31/2016 1/31/2016 1.00 SURFAC DRILL TRIP P POOH f/223'to 36'MD. 223.0 36.0 12:00 13:00 1/31/2016 1/31/2016 2.00 SURFAC DRILL BHAH P PU BHA#2 f/36'to 156'MD. Orient 36.0 156.0 13:00 15:00 and scribe BHA. 1/31/2016 1/31/2016 0.75 SURFAC DRILL RURD P RU Halliburton hoisting unit for 156.0 156.0 15:00 15:45 running Gyro. 1/31/2016 1/31/2016 0.75 SURFAC DRILL BHAH P Cont.MU BHA#2 f/156'to 194'MD. 156.0 220.0 15:45 16:30 Wash down to 220'MD. 1/31/2016 1/31/2016 0.50 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 220' 220.0 259.0 16:30 17:00 MD to 259'MD/259'TVD with 453 GPM,675 psi,42%flow out,40 RPM, 3k TQ, 18k WOB,Off Bottom pressure 550 psi. PU wt=64k,SO wt=70k,ROT wt=68k, with 1k off bottom TQ. 1/31/2016 1/31/2016 0.50 SURFAC DRILL WAIT T Troubleshoot MWD 259.0 259.0 17:00 17:30 1/31/2016 1/31/2016 0.50 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 259' 259.0 284.0 17:30 18:00 MD to 284'MD/284'TVD with 451 GPM,620 psi,39%flow out,50 RPM, 3k TQ, 18k WOB,Off Bottom pressure 550 psi. PU wt=65k,SO wt=72k, ROT wt=70k, with 2k off bottom TQ. 1/31/2016 2/1/2016 6.00 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 284' 284.0 752.0 18:00 00:00 MD to 752'MD/751'TVD with 600 GPM, 1160 psi,42%flow out,70 RPM,4k TQ,20k WOB,Off Bottom pressure 1000 psi. Run Gyro every stand. PU wt=93k,SO wt=85k,ROT wt=88k, with 1k off bottom TQ. AST=1.66,ART=1.96,ADT=3.62, Total bit hrs=4.65 Total Jar hrs= 3.62 2/1/2016 2/1/2016 6.00 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 752' 752.0 1,150.0 00:00 06:00 MD to 1150'MD/1124'TVD with 600 GPM, 1230 psi,42%flow out,70 RPM,4k TQ,22k WOB,Off Bottom pressure 1109 psi. Last Gyro at 1031' MD. PU wt=95k,SO wt=91 k,ROT wt=93k, with 2k off bottom TQ. AST=1.78,ART=1.05,ADT=2.83, Total bit hrs=7.48 Total Jar hrs= 6.45 Page 2/37 Report Printed: 3/14/2016 Operations Summary (with Timelog Depths) 0 2. 2S-03 Genoa:Ohlflips Atoka 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) 2/1/2016 2/1/2016 6.00 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 1150' 1,150.0 1,613.0 06:00 12:00 MD to 1613'MD/1586'TVD with 600 GPM, 1450 psi,48%flow out,70 RPM,6k TQ,35k WOB,Off Bottom pressure 1236 psi. PU wt=107k,SO wt=101 k,ROT wt=105k,with 4k off bottom TQ. AST=2.56,ART=1.19,ADT=3.75, Total bit hrs=11.23 Total Jar hrs= 10.2 2/1/2016 2/1/2016 6.00 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 1613' 1,613.0 2,266.0 12:00 18:00 MD to 2266'MD/2154'TVD with 700 GPM, 1930 psi,48%flow out,70 RPM,6k TQ,27k WOB,Off Bottom pressure 1690 psi. PU wt=120k,SO wt=113k, ROT wt=117k,with 3k off bottom TQ. AST=1.99,ART=1.15,ADT=3.14, Total bit hrs=14.21 Total Jar hrs= 13.18 2/1/2016 2/2/2016 6.00 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 2266' 2,266.0 2,738.0 18:00 00:00 MD to 2738'MD/2557'TVD with 700 GPM,2050 psi,45%flow out,70 RPM,7k TQ,30k WOB,Off Bottom pressure 1800 psi. PU wt=126k,SO wt=115k,ROT wt=121k,with 3.5k off bottom TQ. AST=1.79,ART=2.13,ADT=3.92, Total bit hrs=14.21 Total Jar hrs= 13.18 2/2/2016 2/2/2016 0.50 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 2738' 2,738.0 2,790.0 00:00 00:30 MD to 2790'MD/2600'TVD with 700 GPM,2205 psi,47%flow out,70 RPM,6-7k TQ,35k WOB,Off Bottom pressure 1850 psi. PU wt=126k,SO wt=115k,ROT wt=121k,with 3.5k off bottom TQ. ART=0.27,ADT=0.27,Total bit hrs= 18.4 Total Jar hrs=17.37 2/2/2016 2/2/2016 1.00 SURFAC CASING CIRC P Obtain on bottom survey from 2,790.0 2,790.0 00:30 01:30 Schlumberger.CBU x2 while reciprocating from 2788'MD to 2734' MD @ 750 GPM,2070psi,47%flow out, 100 RPM,4k TQ. 2/2/2016 2/2/2016 0.25 SURFAC CASING OWFF P Monitor well for 10 minutes.(Static) 2,790.0 2,790.0 01:30 01:45 2/2/2016 2/2/2016 4.75 SURFAC CASING BKRM P Back ream out of hole from 2790'MD 2,790.0 1,400.0 01:45 06:30 to 1400'MD @ 700 GPM, 1700psi, 47%flow out, 100 RPM,3-4k TQ. Monitor displacement via pits 1 through 5. Note: From 1700'MD to 1400'MD,on each stand,a bottoms up was circulated at same parameters as above prior to racking back stand. 2/2/2016 2/2/2016 1.50 SURFAC CASING TRIP P Pull out of hole on elevators from 1,400.0 194.0 06:30 08:00 1400'MD to 194'MD while monitoring displacement via trip tank. Page 3/37 Report Printed: 3/14/2016 • Operations Summary (with Timelog Depths) 0; 2S-03 annoceObinips Masks 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) 2/2/2016 2/2/2016 2.50 SURFAC CASING BHAH P Lay down surface BHA as per 194.0 0.0 08:00 10:30 Schlumberger Directional Driller. 2/2/2016 2/2/2016 3.50 SURFAC CASING RURD P Clean and clear rig floor. Rig up to 0.0 0.0 10:30 14:00 run 10-3/4"45.5#L-80 Surface Casing (Connection: Hydril563-Dopeless):Rig up bail extensions,volant casing running tool,side door elevators,and slip inserts. Concurrently,mobilize and secure well head to BOP deck via rig floor and verify casing count. 2/2/2016 2/2/2016 1.00 SURFAC CASING PUTB P Make up 10-3/4"shoe track to 160' 0.0 160.0 14:00 15:00 MD torquing to 20 kft-lbs. Fill pipe and check floats(Good). Note:Baker-Lok connection to pin on 4th joint. 2/2/2016 2/2/2016 3.50 SURFAC CASING PUTB P Run 10-3/4"45.5#,L-80 Hydril 563 160.0 1,592.0 15:00 18:30 Dopeless casing from 160'MD to 1592'MD using volant casing running tool filling on the fly and topping off every 10 joints. Monitoring displacement via pits#2,#3,and#4. SO wt=56k. 2/2/2016 2/2/2016 0.50 SURFAC CASING CIRC P Circulate bottoms up from 1592'MD to 1,592.0 1,632.0 18:30 19:00 1632'MD while staging up pumps: lbbl/min=210psi,23%flow out; 2bbl/min=220 psi,26%flow out; 3bbl/min=200psi,30%; 4bbl/min=185psi,33%; 5bbl/min=200psi,33%; 6bbl/min=214psi/34%. SO wt=85k 2/2/2016 2/2/2016 2.25 SURFAC CASING PUTB P Run 10-3/4"45.5#,L-80 Hydril 563 1,632.0 2,696.0 19:00 21:15 Dopeless casing from 1632'MD to 2696'MD using volant casing running tool filling on the fly and topping off every 10 joints. Monitoring displacement via pits#2,#3,and#4. 2/2/2016 2/2/2016 0.75 SURFAC CASING CIRC P Circulate bottoms up from 2696'MD to 2,696.0 2,738.0 21:15 22:00 2738'MD while staging up pumps: 1 bbl/min=180psi,24%flow out; 2bbl/min=195 psi,25%flow out; 3bbl/min=204psi,28%; 4bbl/min=218psi,30%; 5bbl/min=230psi,31%; 6bbl/min=240psi/34%. SO wt=124k 2/2/2016 2/2/2016 0.50 SURFAC CASING HOSO P Make up hanger and landing joint. 2,738.0 2,781.0 22:00 22:30 Wash down @ 1 BPM, 145psi,landing hanger at 22:30. Page 4/37 Report Printed: 3/14/2016 0 • 0::, -,,,-4,4-2---..,,,„0 f 1, L,,,- Operations Summary (with Timelog Depths) 2S-03 CcnocoPhiUlips - A Mb Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activfy Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/2/2016 2/3/2016 1.50 SURFAC CEMENT CIRC P Circulate and reciprocate from 2781' 2,781.0 2,781.0 22:30 00:00 MD to 2761'MD to conditioning mud. Stage pumps to 8 BPM,336psi,36% flow out. PU wt=140k,SO wt=120k. Concurrently,rig down un-needed casing handling equipment and build black water pills. 2/3/2016 2/3/2016 1.00 SURFAC CEMENT CIRC P Circulate and reciprocate from 2781' 2,781.0 2,781.0 00:00 01:00 MD to 2761'MD while conditioning mud. Staging pump up to 8 BPM, 336psi,36%flow out. PU wt=140k,SO wt=120k. Concurrently,Rig down un-needed handling equipment and build black water pills. Blow down top drive,rig up to circulate through cement hose. 2/3/2016 2/3/2016 2.00 SURFAC CEMENT CIRC P Circulate through cement hose staging 2,781.0 2,781.0 01:00 03:00 up to 8 BPM,360psi,20%flow out. Reciprocate and circulate from 2781' MD to 2761'MD while loading vac trucks with contamination pills and spotting trucks for cement job. Blow air through cement line to Schlumberger cementers. 2/3/2016 2/3/2016 4.00 SURFAC CEMENT CMNT P PJSM for cementing 10-3/4"surface 2,781.0 0.0 03:00 07:00 casing as per plan. Line up to Schlumberger,pump 5 bbls of CW100 and pressure test cement lines to 4000psi.Bleed off pressure and pump 35 bbls of CW100 @ 6 BPM., 170psi, 14%flow out,followed by 75bbls of 10.5ppg Mud Push II with red dye @ 4.7 BPM, 160psi, 15%flow out,shut down and bleed off pressure.Drop bottom plug.Batch up and pump 431bbls of 11 ppg Cement @ 7 BPM, 275psi, 18%flow out and 56bbl of 12ppg cement @ 4.8 BPM,200psi, 15%flow out. (Cement returns diverted to cellar @ 36bbls into pumping of 12ppg tail cement) Shut down,drop top plug,and kick out with 4bbls of 12ppg cement and 1 Obbls of water from cement unit. Swap over to rig and continue displacement @ 3.5 BPM,310psi. At 2371stks,reduce rate to 1 BPM,270psi,bump plug @ 2425strokes. Pressure up to 760psi and hold for 5 minutes. Bleed off pressure and check floats(Good). Page 5/37 Report Printed: 3/14/2016 • • Operations Summary (with Timelog Depths) 2S-03 CcnocaPhill ps 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) 2/3/2016 2/3/2016 2.00 SURFAC CEMENT RURD P Rig down and blow down volant 0.0 0.0 07:00 09:00 casing running tool.Pull landing joint, flush stack with black water pill. Function annular and clean,remove PS-21 inserts. Pressure wash inside of Joe's Box,rig down circulation equipment in cellar and clean 4" DEMCO's on cement line. 2/3/2016 2/3/2016 3.00 SURFAC CEMENT NUND P Nipple down surface annular,riser, 0.0 0.0 09:00 12:00 diverter T,diverter line,slide out Joe's Box 2/3/2016 2/3/2016 3.00 SURFAC WHDBOP NUND P Nipple down Cameron starting head 0.0 12 00 15:00 and clean atop hanger.Pull diverter T to rig floor and lower and nipple up wellhead. Lower and nipple up 11"x 13-5/8"cross-over spool,2'riser extension,and 14'riser. 2/3/2016 2/3/2016 3.50 SURFAC WHDBOP NUND P Nipple up BOP stack to riser and raise 15:00 18:30 riser with stack. Remove 2'extension in cellar to allow for flow box clearance.Re-insert 2'extension and continue to nipple up and torque all flanged connections.Nipple up flow box,flow line,and choke and kill lines. Pressure test Cameron wellhead seals to 5000 psi for 15 minutes witnessed b CPAI.SIMOPS change out drawworks gear oil and swap to hi-line power. 2/3/2016 2/3/2016 2.00 SURFAC WHDBOP MPDA P Install RCD clamp and trip nipple.Rig 18.30 20:30 up MPD choke manifold and all associated lines. 2/3/2016 2/3/2016 1.00 SURFAC WHDBOP NUND P Clean and clear rig floor.Lower 20:30 21:30 diverter T,Cameron starting head, and oil drums from floor.Pick up Cameron wear bushing and test plug to rig floor.Install PS-21 slips and 5" elevators. 2/3/2016 2/3/2016 0.50 SURFAC CEMENT PULD P Pick up 5"drillpipe double from pipe 21:30 22:00 shed,make up running tool and set wear bushing. 2/3/2016 2/4/2016 2.00 SURFAC CEMENT PULD P Make up mule shoe and run in hole 22:00 00:00 with 5"drillpipe doubles and singles to 1577'MD.Monitor via trip tank. 2/4/2016 2/4/2016 9.50 SURFAC CEMENT PULD P Run in hole picking up 5"drill pipe 1,577.0 0.0 00:00 09:30 singles from 1577'MD to 2179'MD. Pull out of hole racking back 23 stds of 5"drill pipe.Run in hole picking up 5" drill pipe singles to 2179'MD.Pull out of hole racking back 23 more stds of 5"drill pipe. Run in hole picking up 5" drill pipe to 1705'MD.Pull out of hole racking back 18 more stds of 5"drill pipe. Monitored displacement via trip tank. 2/4/2016 2/4/2016 1.00 SURFAC WHDBOP RURD P Drain stack and pull wear bushing. 0.0 0.0 09:30 10:30 Install BOPE test plug.Rig up to test BOPE system with 5"test joint. Fill stack and purge lines with water. Perform shell test. Page 6/37 Report Printed: 3/14/2016 i i tit 0 Operations Summary (with Timelog Depths) a 2S-03 c«,och'Mips 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) 2/4/2016 2/4/2016 3.50 SURFAC WHDBOP BOPE P Test BOPE(witness waived by 0.0 0.0 10:30 14:00 AOGCC Rep Guy Cook):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 5"test joint,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 HCR'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= 1775psi,35sec for 200psi with 1 electric pump, 129sec to build system to full pressure with 2 electric and 2 air pumps).Closing times:Annular- 23sec;UPR-18sec;Blind/Shears- 16sec;LPR-16sec;Choke HCR- 2sec;Kill HCR-2 sec. 2/4/2016 2/4/2016 0.50 SURFAC WHDBOP MPDA P Blow down kill and choke,pull PS-21 0.0 0.0 14:00 14:30 slips,pull trip nipple,install RCD test cap 2/4/2016 2/4/2016 2.50 SURFAC WHDBOP MPDA T Test MPD skid and RCD as per 0.0 0.0 14:30 17:00 ConocoPhillips test procedure.Test failure on Choke A 2/4/2016 2/4/2016 0.25 SURFAC WHDBOP MPDA P Blow down test equipment and MPD 0.0 0.0 17:00 17:15 skid.pull RCD test cap,install trip nipple 2/4/2016 2/4/2016 0.75 SURFAC WHDBOP RURD P Pull test plug and install wear bushing 0.0 0.0 17:15 18:00 and run in lock down screws.Lay down 5"test joint. 2/4/2016 2/4/2016 3.50 SURFAC CEMENT BHAH P PJSM.Make up BHA#3 as per 0.0 734.0 18:00 21:30 Directional Driller to 56'MD. Install radioactive source in ECO-scope. Continue to make up to 734'MD.Lay down last joint of HWDP. 2/4/2016 2/4/2016 0.50 SURFAC CEMENT TRIP P Continue to run in hole on 5"drill pipe 734.0 1,206.0 21:30 22:00 from 734'MD to 1206'MD while monitoring displacement via pits#2 and#3. 2/4/2016 2/4/2016 0.75 SURFAC CEMENT DHEQ P Shallow pulse test MWD with 602 1,206.0 1,206.0 22:00 22:45 GPM, 1415psi,30%flow out.(Good Test).Blow down top drive 2/4/2016 2/4/2016 0.75 SURFAC CEMENT TRIP P Continue to run in hole on 5"drill pipe 1,206.0 2,531.0 22:45 23:30 from 1206'MD to 2531'MD while monitoring displacement via pits#2 and#3. 2/4/2016 2/5/2016 0.50 SURFAC CEMENT SLPC P Rig up to slip and cut drill line. 2,531.0 2,531.0 23:30 00:00 Concurrently,circulate and condition wellbore at 2 BPM in preparation for casing test. 2/5/2016 2/5/2016 1.50 SURFAC CEMENT SLPC P Continue Slip and Cut of drilling line 2,531.0 2,531.0 00:00 01:30 (1 lwraps,86.35'). Calibrate block height,amphion and Totco. Concurrently,circulate at 2.5BPM, 75psi,12%flow out Page 7/37 Report Printed: 3/14/2016 • • 0 0 Operations Summary (with Timelog Depths) 2S-03 CcnocoF�hilGps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End lime Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/5/2016 2/5/2016 1.00 SURFAC CEMENT COCF P Establish parameters:PU wt=125k, 2,531.0 2,625.0 01:30 02:30 SO wt=106k,ROT wt=109k,7k TQ, 600 GPM, 1600psi,31%flow out. Wash down from 2625'MD to tag cement @ 2650'MD.Pull back to 2625'MD. 2/5/2016 2/5/2016 1.00 SURFAC CEMENT PRTS P Blow down top drive.Rig up to 2,625.0 2,625.0 02:30 03:30 pressure test casing. Establish circulation through Kill Line and drill pipe. Shut in annular and pressure up to 3500psi for 30 charted minutes (Good Test) Bleed of pressure with 3bbls bled back.Rig down and blow down pressure testing equipment. 2/5/2016 2/5/2016 0.75 SURFAC CEMENT COCF P Pick up Stand#21 and establish 2,625.0 2,697.0 03:30 04:15 circulation rate.Wash down to top of cement @ 2650'MD.Drill out cement @ 600 GPM, 1612psi,31%flow out, 80 RPM,7k TQ. Tag plugs on depth at 2697'MD. 2/5/2016 2/5/2016 2.00 SURFAC CEMENT DRLG P Drill out plugs,float collar,shoe track, 2,697.0 2,790.0 04:15 06:15 and rathole. 2/5/2016 2/5/2016 0.25 SURFAC CEMENT DDRL P 20'of new formation to 2810'MD 2,790.0 2,810.0 06:15 06:30 using 400-600 GPM,800-1600psi, 25%flow out,40-60 RPM,6-12k TQ, and 10-15k WOB. PU wt=125k,SO wt=106k,ROT wt= 109k,off bottom TQ=7k 2/5/2016 2/5/2016 1.00 SURFAC CEMENT CIRC P Circulate bottoms up twice to condition 2,810.0 2,716.0 06:30 07:30 mud while reciprocating from 2808' MD to 2713'MD at 600 GPM, 1656psi, 30%flow out,60 RPM,6-7k TQ, 9.6ppg MW In/Out. Pull inside 10-3/4" casing to 2716'MD. 2/5/2016 2/5/2016 1.00 SURFAC CEMENT FIT P Rack back stand#22.Blow down top 2,716.0 2,716.0 07:30 08:30 drive,rig up to perform Formation Integrity Test. Establish circulation through drill pipe and kill line.Shut annular and perform FIT to 16ppg equivalent mud weight,860psi.Rig down and blow down circulation equipment. 2/5/2016 2/5/2016 0.50 INTRM1 DRILL REAM P Pick up stand#22 and wash down to 2,716.0 2,810.0 08:30 09:00 2810'MD at 600 GPM,1650psi,30% flow out,60 RPM,and 6-7k TQ. 2/5/2016 2/5/2016 1.00 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate 2,810.0 2,916.0 09:00 10:00 hole from 2810'MD to 2916'MD/ 2694'TVD with 700 GPM, 1564psi, 34%flow out,80 RPM,7-8k TQ,6k WOB PU wt=130k,SO wt=110k,ROT wt= 116k,Off bottom TQ=7k Concurrently,displace to LSND on the fly while drilling ahead. Page 8/37 Report Printed: 3/14/2016 • • 0`i Operations Summary (with Timelog Depths) 2S-03 conocoPhinips m.o. 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) 2/5/2016 2/5/2016 1.00 INTRM1 DRILL CIRC P Drop RFID chips and pump down at 2,916.0 2,916.0 10:00 11:00 296 GPM,390psi, 19%flow out,30 RPM,5.5k TQ. Reduce pump rate to 147 GPM, 185 psi for 450 strokes over string volume. Increase to 700 GPM noting 220 psi drop(1560psi to 1340psi)confirming that the under reamer activated. 2/5/2016 2/5/2016 1.00 INTRM1 DRILL DDRL P Directional drill 11"x9-7/8" 2,916.0 2,999.0 11:00 12:00 intermediate hole from 2916'MD to 2999'MD/2770'ND,775 GPM, 1600 psi,36%flow out, 140 RPM,6- 8k TQ,4k WOB,ECD=10.54. PU wt=135k,SO wt=115k,ROT wt= 115k,Off bottom TQ=7k 2/5/2016 2/5/2016 6.00 INTRM1 DRILL DDRL P Directional drill 11"x 9-7/8" 2,999.0 3,380.0 12:00 18:00 intermediate hole from 2999'MD to 3380'MD/3067'ND with 775 GPM, 1712psi,36%flow out, 150 RPM,5- 10k TQ,and 12k WOB. PU wt=145k,SO wt=119k,ROT wt= 127k,off bottom TQ=8k 2/5/2016 2/6/2016 6.00 INTRM1 DRILL DDRL P Directional drill 9-7/8"x11" 3,380.0 3,950.0 18:00 00:00 intermediate hole from 3380'MD to 3950'MD/3479'ND with 770 GPM, 1800psi,34%flow out,150 RPM,5- 12k TQ,and 12k WOB. PU wt=145k,SO wt=119k, ROT wt= 127k,off bottom TQ=8k 2/6/2016 2/6/2016 6.00 INTRM1 DRILL DDRL P Directional drill 9-7/8"x 11" 3,950.0 4,502.0 00.00 06.00 intermediate hole with Riptide under reamer from 3950'MD to 4502'MD/ 3827'ND using 775 GPM, 1822psi, 34%flow out, 160 RPM,5-13k TQ, and 15k WOB. PU wt=169k,SO wt=125k,ROT wt= 140k,off bottom TQ=9k. Pump 25bb1 10ppb nut plug pills every 500'. 2/6/2016 2/6/2016 6.00 INTRM1 DRILL DDRL P Directional drill 9-7/8"x 11" 4,502.0 4,966.0 06:00 12:00 intermediate hole with Riptide under reamer from 4502'MD to 4966'MD/ 4122'ND using 775 GPM,2060psi, 34%flow out, 150 RPM,5-15k TQ, and 14-19k WOB. PU wt=183k,SO wt=125k,ROT wt= 142k,off bottom TQ=10k. Pump 25bbl 10ppb nut plug pills every 500' as well as pump 30bb1 H20/SAPP pill @ 4655'MD. Page 9/37 Report Printed: 3/14/2016 10_111 Operations Summary (with Timelog Depths) 0 11lo o 2S-03 conoceribi'hps Mack. 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) 2/6/2016 2/6/2016 6.00 INTRM1 DRILL DDRL P Directional drill 9-7/8"x 11" 4,966.0 5,300.0 12:00 18:00 intermediate hole with Riptide under reamer from 4966'MD to 5300'MD/ 4328'TVD using 775 GPM,2285psi, 34%flow out, 160 RPM,9-15k TQ, and 24k WOB. PU wt=220k,SO wt=130k,ROT wt= 161k,off bottom TQ=11k. Pump 25bb1 10ppb nut plug pills every 500'. 2/6/2016 2/7/2016 6.00 INTRM1 DRILL DDRL P Directional drill 9-7/8"x 11" 5,300.0 5,839.0 18:00 00:00 intermediate hole with Riptide under reamer from 5300'MD to 5839'MD/ 4671'TVD using 775 GPM,2475psi, 36%flow out, 175 RPM,8-18k TQ, and 20k WOB. PU wt=220k,SO wt=130k, ROT wt= 161k,off bottom TQ=13k. Pump 25bb1 10ppb nut plug pills every 500'. Total Bit Hrs=28.12,Total Jars Hrs= 96.96,ART/ADT for 24hrs=17.77 2/7/2016 2/7/2016 2.00 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"intermediate hole 5,839.0 6,029.0 00:00 02:00 with Riptide under reamer from 5839' MD to 6029'MD/4792'TVD using 775 GPM,2640psi,35%flow out, 175 RPM,8-18k TQ,and 14k WOB. PU wt=219k,SO wt=130k, ROT wt= 161k,off bottom TQ=13k 2/7/2016 2/7/2016 1.50 INTRM1 DRILL CIRC T PWD indicated poor hole cleaning, 6,029.0— 5,993.0 02:00 03:30 rotate and reciprocate from 6029'MD to 5993'MD while pumping a 50bbI 11.1 ppg weighted nut plug sweep at 775 GPM,2598psi,35%flow out, 100 RPM,and off bottom TQ=9-14k. Initial ECD-11.01ppg Final ECD- 10.75ppg. PU wt=196k,SO wt=140k,Rot wt= 163k 2/7/2016 2/7/2016 1.00 INTRM1 DRILL MPDA P PJSM,blow down top drive,remove 5,993.0 6,029.0 03:30 04:30 PS-21 slips,remove trip nipple,install MPD bearing,install PS-21 slips and calibrate MPD chokes. 2/7/2016 2/7/2016 7.50 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"intermediate hole 6,029.0 6,660.0 04:30 12:00 with Riptide under reamer from 6029' MD to 6660'MD/5182'TVD using 775 GPM,2670psi,32%flow out, 140 RPM, 10-22k TQ,and 20k WOB. PU wt=220k,SO wt=139k, ROT wt= 163k,off bottom TQ=13k Page 10/37 Report Printed: 3/14/2016 • • 4 of t Operations Summary (with Timelog Depths) sk a 2S-03 conoceilhillips Akaka 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(EKE) 2/7/2016 2/7/2016 6.00 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"intermediate hole 6,660.0 7,164.0 12:00 18:00 with Riptide under reamer from 6660' MD to 7164'MD/5479'TVD using 775 GPM,2560psi,36%flow out, 150 RPM, 12-20k TQ,and 22k WOB. PU wt=215,SO wt=150k, ROT wt= 171k,off bottom TQ=12k 2/7/2016 2/7/2016 4.50 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"intermediate hole 7,164.0 7,516.0 18:00 22:30 with Riptide under reamer from 7164' MD to 7516'MD/5685'TVD using 775 GPM,2640psi,35%flow out, 175 RPM,8-18k TQ,and 14k WOB. PU wt=219,SO wt=130k,ROT wt= 161k,off bottom TQ=13k Concurrently,make up 4"doubles in pipe shed. 2/7/2016 2/7/2016 0.75 INTRM1 DRILL CIRC T RCD bearing leaking. Circulate and 7,516.0 7,448.0 22:30 23:15 condition wellbore prior to pulling/replacing RCD bearing racking back one stand.Blow down top drive. Concurrently,make up 4"doubles in pipe shed 2/7/2016 2/7/2016 0.50 INTRM1 DRILL MPDA T Pull and replace RCD bearing. 7,448.0 7,448.0 23:15 23:45 Concurrently,make up 4"doubles in pipe shed 2/7/2016 2/8/2016 0.25 INTRM1 DRILL CIRC T Estableish circulation and break in 7,448.0 7,513.0 23:45 00:00 new bearing while washing down from 7448'MD to 7513'MD. Total Bit Hrs=43.26,Total Jars Hrs= 112.10,ART/ADT for 24hrs=15.14 2/8/2016 2/8/2016 6.00 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole with Riptide 7,513.0 8,015.0 00:00 06:00 under reamer from 7513'MD to 8015' MD at 775 GPM,2815 psi,34%flow out,140 RPM, 15-22k TQ,20k WOB, Off bottom pressure=2798 psi, PU wt=236k,SO wt=156k,ROT wt= 180k,and off bottom TQ=13k. 2/8/2016 2/8/2016 6.00 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole with Riptide 8,015.0 8,540.0 06:00 12:00 Underreamer from 8015'MD to 8540' MD at 775 GPM,2930 psi,34%flow out, 140 RPM, 16-22k TQ,22k WOB, Off bottom pressure=2925 psi, PU wt=240k,SO wt=144k,ROT wt= 170k,and off bottom TQ=13k. Page 11/37 Report Printed: 3/14/2016 III . I 0 Operations Summary (with Timelog Depths) 1 t0 ry 2S-03 ConocoPhitliips e[cxkz 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) 2/8/2016 2/8/2016 6.75 INTRMI DRILL DDRL P Drill 9-7/8"x 11"hole with Riptide 8,540.0 8,830.0 12:00 18:45 Underreamer from 8540'MD to TD of intermediate hole section(8830' MD/6250'TVD)at 775 GPM,2585 psi, 36%flow out, 140 RPM, 12-20k TQ, 6k WOB,Off bottom pressure=2600 psi, PU wt=275k,SO wt=134k,ROT wt= 180k,and off bottom TQ=20k. Total Bit Hrs=56.73,Total Jar Hrs= 125.57,ART/ADT for 24hrs=13.47 2/8/2016 2/8/2016 1.75 INTRM1 CASING CIRC P Circulate bottoms up while rotating 8,830.0 8,830.0 18:45 20:30 and reciprocating from 8830'MD to 8766'MD using 775 GPM,2560psi, 36%flow out, 140 RPM, 14-24k TQ. Concurrently,started 2nd dump and dilute and take slow pump rates 2/8/2016 2/8/2016 1.25 INTRM1 CASING CIRC P Drop RFID chips required to close 8,830.0 8,830.0 20:30 21:45 Riptide under reamer. Pump down at 775 GPM,2350psi for 1150 stks. Reduce rate to 200 GPM for additional 700 stks(1850 total). Bleed pressure and rotate at 5 RPM for 10 minutes as per Weatherford under reamer rep. Establish circulation at 775 GPM noting a 390 psi increase to 2740psi (Good indication that Riptide under reamer is in closed position). 2/8/2016 2/8/2016 0.75 INTRM1 CASING PMPO P Pump out of the hole from 8830'MD to 8,830.0 8,556.0 21:45 22:30 8535'MD at 650 GPM,2100psi,32% flow out,and an up weight of 240k. Observed a 300psi increase at 8535' MD,start rotation at 50 RPM and pack off cleared. Leak identified at saver sub of top drive and tool joint of drill pipe. Break out top drive check for wash out.(Confirmed-Washout on saver sub and top single of stand#83) 2/8/2016 2/8/2016 0.50 INTRMI CASING WAIT T While waiting on replacement saver 8,556.0 8,556.0 22:30 23:00 sub from shop,make up top drive to stand#83 and circulate while reciprocating from 8586'MD to 8556' MD with 272 GPM(ma>dmum flow without leaking through washout), 765psi,and 20%flow out. 2/8/2016 2/8/2016 0.50 INTRM1 CASING SVRG T Service and inspect top drive and 8,556.0 8,556.0 23:00 23:30 blocks while lining up injection line to MPD skid 2/8/2016 2/9/2016 0.50 INTRM1 CASING RGRP T Blow down top drive,change out 8,556.0 8,556.0 23:30 00:00 saver sub while maintaining 260 to 300psi on annulus. 2/9/2016 2/9/2016 2.50 INTRM1 CASING SMPD P Strip out of hole from 8535'MD to 8,535.0 7,920.0 00:00 02:30 7920'MD with 650 GPM,2154 psi, and 32%flow out. Holding 290psi on MPD choke during connections and monitoring displacement via Pits#2,3, and 4. PU wt=225k,SO wt=130k. Page 12/37 Report Printed: 3/14/2016 • i Operations Summary (with Timelog Depths) 0-i 2S-03 CenocoPhitlips 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) 2/9/2016 2/9/2016 2.25 INTRM1 CASING CIRC P Rotate and reciprocate from 7920'MD 7,920.0 7,920.0 02:30 04:45 to 7735'MD while conditioning mud for MPD drawdown test.using 640 GPM,2063 psi,35%flow out,and 100 RPM, PU wt=225k,SO wt=130k,Rot wt=178k,and off bottom TQ=13-17k. 2/9/2016 2/9/2016 0.25 INTRM1 CASING OWFF P Conduct MPD drawdown test @ 7920' 7,920.0 7,920.0 04:45 05:00 MD. Well found to be static with 9.7PPg. 2/9/2016 2/9/2016 1.00 INTRM1 CASING CIRC P Rotate and reciprocate from 7920'MD 7,920.0 7,920.0 05:00 06:00 to 7884'MD spotting new 9.7ppg LSND with 589 GPM, 1714psi,30% flow out, 100 RPM. PU wt=225,SO wt=130k, Rot wt=178, Off bottom TQ=13-16k. 2/9/2016 2/9/2016 0.75 INTRM1 CASING OWFF P Blow down top drive and observe well 7,920.0 7,920.0 06:00 06:45 for flow for 30 min. (Static) 2/9/2016 2/9/2016 4.25 INTRM1 CASING SMPD P Line up MPD equipment and strip out 7,920.0 2,775.0 06:45 11:00 of the hole from 7920'MD to 2775'MD following MPD pressure schedule. PU wt=117k,SO wt=110k. 2/9/2016 2/9/2016 1.00 INTRMI CASING CIRC P Rotate and reciprocate from 2775' 2,775.0 2,775.0 11:00 12:00 MD to 2717'MD while conditioning mud at the shoe using 700 GPM, 1775 psi,33%flow out,and 80 RPM, PU wt=117k,SO wt=110k,and off bottom TQ=13-17k. 2/9/2016 2/9/2016 1.00 INTRMI 'CASING OWFF P Monitor well for 45min via 2"hole fill 2,717.0 2,717.0 12:00 13:00 port observing initial minimal flow decreasing to static. Blow down top drive,make up top drive to stump. 2/9/2016 2/9/2016 0.75 INTRM1 -CASING MPDA P Pull RCD bearing and install trip nipple 2,717.0 2,717.0 13:00 13:45 2/9/2016 2/9/2016 0.50 INTRM1 CASING SVRG P Service and inspect PS-21 slips 2,717.0 2,717.0 13:45 14:15 2/9/2016 2/9/2016 1.25 INTRM1 CASING TRIP P Pull out of hole from 2775'MD to 2,775.0 1,300.0 14:15 15:30 1300'MD while monitoring displacement via trip tank. Concurrenity,blow down injection line and MPD skid. PU wt=114k,SO wt=114k. 2/9/2016 2/9/2016 1.75 INTRM1 CASING PULD P Pull out of hole laying down singles of 1,300.0 172.0 15:30 17:15 5"drill pipe from 1300'MD to 172'MD while monitoring well via trip tank and changing out slip inserts at HWDP and jars. 2/9/2016 2/9/2016 0.75 INTRM1 CASING BHAH P Lay down BHA from 172'MD to 127' 172.0 127.0 17:15 18:00 MD.Inspect and take pictures of Weatherford Riptide under reamer. Page 13/37 Report Printed: 3/14/2016 i 0 Operations Summary (with Timelog Depths) 2S-03 conoo:Phitlips $F ska ! 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) 2/9/2016 2/9/2016 0.50 INTRM1 CASING BHAH P PJSM for pulling radioactive source 127.0 127.0 18:00 18:30 from MWD. Pull and secure radioactive source and monitor well via trip tank. 2/9/2016 2/9/2016 1.25 INTRM1 CASING BHAH P Lay down BHA from 127'MD while 127.0 0.0 18:30 19:45 monitoring well via trip tank. 2/9/2016 2/9/2016 0.50 INTRM1 CASING RURD P Make up running tool and pull wear 0.0 0.0 19:45 20:15 bushing. 2/9/2016 2/9/2016 0.75 INTRMI CASING WWWH P Make up flushing sub and flush stack 0.0 0.0 20:15 21:00 at 832 GPM,lay down flushing sub, and blow down top drive. 2/9/2016 2/9/2016 0.50 INTRM1 CASING RURD P Clear and clean rig floor 0.0 0.0 21:00 21:30 2/9/2016 2/9/2016 0.75 INTRM1 CASING BOPE P Drain stack and pick up 7-5/8"test 0.0 0.0 21:30 22:15 joint. Install test plug and change out UPR's to 7-5/8"casing rams. 2/9/2016 2/9/2016 0.75 INTRMI CASING BOPE P Flush and fill stack. Test 7-5/8"UPR's 0.0 0.0 22:15 23:00 to 250psi low and 3500psi high for 5 charted minutes. Rig down and blow down test equipment. 2/9/2016 2/10/2016 1.00 INTRM1 CASING RURD P Rig up 7-5/8"casing handling 0.0 0.0 23:00 00:00 equipment and verify pipe count. Concurrently,load shoe joint to skate and pick up. 2/10/2016 2/10/2016 1.00 INTRM1 CASING PUTB P PJSM.Make up 7-5/8"29.7#Hydril 0.0 175.0 00:00 01:00 563 dopeless shoe track to 175'MD (Jts 1-4: BakerLoc'd).Check floats (Good),fill each joint on the fly and top off every 10 joints via casing Volant tool. Monitor displacement via pits#2 and#3. Make up connections to 12,400 ftlbs. 2/10/2016 2/10/2016 4.00 INTRM1 CASING PUTB P Run 7-5/8"29.7#,Hydril 563 dopeless 175.0 2,764.0 01:00 05:00 casing as per tally from 175'MD to 2764'MD. Install and BakerLoc two stage cementing collar between joints #65 and#66. Make up connection=12400 ftlbs. 2/10/2016 2/10/2016 1.50 INTRM1 CASING CIRC P Circulate bottoms up at 2764'MD. 2,764.0 2,764.0 05:00 06:30 Stage pumps up from 2BPM=37psi, 3 BPM=123psi,4 BPM=138psi,5 BPM=158psi,6 BPM=170psi.Flow out=17%. Rot TQ @ 10 RPM and 20 RPM=3k. PU wt=108k,SO wt=107k, ROT wt=108k 2/10/2016 2/10/2016 5.50 INTRM1 CASING PUTB P Run 7-5/8"29.7#, Hydril 563 dopeless 2,764.0 6,695.0 06:30 12:00 casing as per tally from 2764'MD to 6695'MD. Fill each joint on the fly and top off every 10 joints via casing Volant tool. Monitor displacement via pits#2 and#3. PU wt=210k SO wt=137k,Make up connection=12400 ftlbs. 2/10/2016 2/10/2016 0.50 INTRM1 CASING CIRC P Circulate from 6695'MD to 6735'MD 6,695.0 6,735.0 12:00 12:30 staging to 147 GPM,360 psi and 21% flow out. Page 14/37 Report Printed: 3/14/2016 i • • 0 Operations Summary (with Timelog Depths) 0 2S-03 CtinOCci'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) 2/10/2016 2/10/2016 0.50 INTRM1 CASING PUTB P Run 7-5/8"29.7#, Hydril 563 dopeless 6,695.0 7,018.0 12:30 13:00 casing as per tally from 6695'MD to 7018'MD. Fill each joint on the fly and top off every 10 joints via casing Volant tool. Monitor displacement via pits#2 and#3. PU wt=210k SO wt=137k,Makeup connection=12400 ftlbs. 2/10/2016 2/10/2016 1.25 INTRM1 CASING CIRC T Error found in tally/strap,change out 7,018.0 7,018.0 13:00 14:15 joints and confirm strap in casing shed while circulating and reciprocating from 6981'MD to 7018'MD using 5.5 BPM,295psi,and 17%flow out. PU wt=220k, SO wt= 147k 2/10/2016 2/10/2016 1.00 INTRM1 CASING PUTB P Run 7-5/8"29.7#, Hydril 563 dopeless 7,018.0 7,705.0 14:15 15:15 casing as per tally from 7018'MD to 7705'MD. Fill each joint on the fly and top off every 10 joints via casing Volant tool. PU wt=240k,SO wt=151k.Make up connection= 12400 ftlbs. 2/10/2016 2/10/2016 1.00 INTRM1 CASING PUTB P Wash down casing from 7679'MD to 7,679.0 7,803.0 15:15 16:15 7803'MD staging pump to 4BPM,340 psi, 17%flow out. PU wt=216k,SO wt=151 k 2/10/2016 2/10/2016 2.00 INTRM1 CASING PUTB P Run 7-5/8"29.7#, Hydril 563 dopeless 7,803.0 8,785.0 16:15 18:15 casing as per tally from 7803'MD to 8744'MD. Fill each joint on the fly and top off every 10 joints via casing Volant tool.Wash down to 8785'MD at 65GPM,400 psi, 13%flow out. Monitor displacement via pits#2 and #3. PU wt=240k,SO wt=151k.Make up connection=12400 ftlbs. 2/10/2016 2/10/2016 0.50 INTRM1 CASING HOSO P Make up hanger and landing joint. 8,785.0 8,825.0 18:15 18:45 Wash down from 8785'MD and land at 8825'MD at 1 BPM,350 psi,6% flow out. SO wt=142K. 2/10/2016 2/10/2016 3.25 INTRM1 CEMENT CIRC P Circulate and condition mud for 8,825.0 8,825.0 18:45 22:00 cement job. Reciprocate between 8825'MD and 8810'MD staging pump up to 1 BPM,350 psi,4%flow out. PU wt=242K,SO wt=149K. FCP= 350 psi, 17%flow out. 2/10/2016 2/10/2016 1.25 INTRM1 CEMENT CIRC P Blow down topdrive,rig up cement 8,825.0 8,825.0 22:00 23:15 hose,and establish circulation. Reciprocate between 8825'MD to 8810'MD,staging pump up to 6BPM, 380 psi, 17%flow out. PU wt=255K,SO wt=150K. Page 15/37 Report Printed: 3/14/2016 • • "' , ' Operations Summary (with Timelog Depths) 2S-03 ConocoPhillips ' _ h 4 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) 2/10/2016 2/10/2016 0.50 INTRM1 CEMENT SFTY P PJSM for cement job.SLB pump 5 bbl 8,825.0 8,825.0 23:15 23:45 water and pressure test lines to 3500 psi. 2/10/2016 2/11/2016 0.25 INTRM1 CEMENT CMNT P SLB batch Mud Push II. 8,825.0 8,825.0 23:45 00.00 2/11/2016 2/11/2016 2.75 INTRM1 CEMENT CMNT P Using Schlumberger,pump 40bbls of 8,825.0 8,825.0 00:00 02:45 11.5ppg Mud Push II @ 6 BPM, 400psi, 18%flow out. Shut down and drop bypass plug.Chase plug with 136.1 bbls of 15.8ppg Lead cement at 6.3 BPM,300psi,20%flow out.Shut down and drop 754 shut-off plug chased with 3bbls(1.5bbls in lines+ 1.5bbls additional)of 15 8ppg Lead cement followed by l Obbls of water at 5 BPM, 100psi,7%flow out. Switch to rig pumps and pump 384bb1s of 9 7ppg LSND mud at 6 BPM. (ICP=131psi, FCP=354psi, 15%flow out). Reduce pump rate to 3 BPM at 3674stks resulting in 500psi and 15% flow out. Bump plug at 3813stks and pressure up to 1075psi and hold for 5min. Bleed off and check floats (Good). Notes: -No indication that the bypass plug landed and fins flipped. -Bleedback= 1.6bbl. 2/11/2016 2/11/2016 0.25 INTRM1 CEMENT CIRC P Pressure up on casing to 2711psi at 8,825.0 8,825.0 02:45 03:00 1 BPM to open stage tool. 2/11/2016 2/11/2016 1.25 INTRM1 CEMENT CIRC P Establish circulationg through stage 8,825.0 8,825.0 03:00 04:15 tool. Stage pumps up to 6 BPM, ICP=140psi,FCP=272psi,20%flow out 2/11/2016 2/11/2016 0.50 INTRM1 CEMENT CMNT T Ensure cement line is cleared with air 8,825.0 8,825.0 04:15 04:45 through Schlumberger. Ice plug found. Remove hard line(chiksan)to thaw.Reinstall chiksan.Pressure test charted to 250 low and 3500psi. (Good). Note: Required additional pressure test due to breaking of chiksan line. In addition,pressure test was repeated 3x due to a leaking valve on the rig floor. 2/11/2016 2/11/2016 0.25 INTRM1 CEMENT CMNT P Batch up Mud Push II 8,825.0 8,825.0 04:45 05:00 Page 16/37 Report Printed: 3/14/2016 • • Operations Summary (with Timelog Depths) 2S-03 OanocoPhillips azsska 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) 2/11/2016 2/11/2016 1.75 INTRM1 CEMENT CMNT P Using Schlumberger,pump 40bbls of 8,825.0 8,825.0 05:00 06:45 11.5ppg Mud Push II @ 4.7 BPM, 170psi, 19%flow out. Pump 62bbls of 15.8ppg Tail cement at 5.3 BPM, ICP=265psi,FCP=235psi, 19%flow out.Drop closing plug and chase with 10bbls of water from Schlumberger at 5.3BPM,60psi, 13%flow out. Switch over to rig pumps and pump 272bb1s of 9.7ppg LSND at 6 BPM. (ICP=105psi, FCP=605psi, 16%flow out). Reduce pump rate to 3 BPM at 2550stks resulting in 490psi and 16% flow out. Plug on seat @ 2704stks. Pressure up to 1400psi and observe stage tool close. Continue to pressure up to 1500psi as per PESI rep and hold for 5min. Bleed off pressure and check for flow(static). Notes: -Bleedback=1.7bbl. 2/11/2016 2/11/2016 3.25 INTRM1 CEMENT RURD P Break down circulating lines and rig 0.0 0.0 06:45 10:00 down casing volant tool and landing joint,remove elevators and 6'bale extentions. Expidite volant tool and bale extensions off the rig fllor. Concurrently,flush cement valves and rig down Schlumberger Cementing Services. 2/11/2016 2/11/2016 1.00 INTRM1 CEMENT RURD P Install 5"elevators.Pick up 5"test 0.0 0.0 10:00 11:00 joint and Johnny Whacker. Flush the stack. Break down circulation lines. 2/11/2016 2/11/2016 1.25 INTRM1 CEMENT WWSP P Lay down 5"test joint and Johnny 0.0 0.0 11:00 12:15 Whacker. Remove 5"elevators and install 7-5/8"elevators.Pick up 7-5/8" landing joint and make up to pack off. Install 10-3/4"x 7-5/8"packoff and run in lock down screws as per Cameron wellhead rep. 2/11/2016 2/11/2016 0.50 INTRM1 CEMENT WWSP P Pressure test 10.75"x 7-5/8"packoff 0.0 0.0 12:15 12:45 to 5000psi for 10min. Test witnessed by CPAI rep. 2/11/2016 2/11/2016 0.25 INTRM1 CEMENT BOPE P Pull running tool and set test plug to 0.0 0.0 12:45 13:00 test UPR. 2/11/2016 2/11/2016 0.75 INTRM1 CEMENT BOPE P Change out UPR's from 7-5/8"casing - 0.0 0.0 13:00 13:45 rams to 2-7/8"x 5-1/2"VPR's. Concurrently,load and strap 3-1/2" EUE tubing into casing shed. 2/11/2016 2/11/2016 1.50 INTRM1 CEMENT BOPE P Rig up test equipment,flush and fill 0.0 0.0 13:45 15:15 stack.Using 4"test joint,test annular, 2-7/8"x 5-1/2"UPR's,2-7/8"x 5-1/2" LPR's,HCR choke,HCR kill,and Upper and Lowser IBOPs. Break down and rig down test equipment. 2/11/2016 2/11/2016 0.25 INTRM1 CEMENT BOPE P Pull test plug and install wear bushing. 0.0 0.0 15:15 15:30 Run in lock down screws and lay down test joint. Page 17/37 Report Printed: 3/14/2016 • • Operations Summary (with Timelog Depths) 2S-03 ConocaPhillips A nkx 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) 2/11/2016 2/11/2016 1.25'INTRM1 CEMENT RURD P Change out saver sub on top drive 0.0 0.0 15:30 16:45 from 4-1/2"IF to XT-39 Concurrently,load and strap 3-1/2" EUE tubing into casing shed.(290jts in shed, 10 outside) 2/11/2016 2/11/2016 0.50 INTRM1 CEMENT SVRG P Service and inspect PS-21 slips 0.0 0.0 16:45 17:15 2/11/2016 2/11/2016 0.75 INTRM1 CEMENT RURD P Install 9-5/8"slip inserts and 5" 0.0 0.0 17:15 18:00 elevators. PU and set mousehole. 2/11/2016 2/12/2016 6.00 INTRM1 CEMENT PULD P Lay down 36 stands of 5"drill pipe in 0.0 0.0 18:00 00:00 singles via mousehole. Concurrently,perform injectivity test with water,observing break over at 950psi.Continue injecting an additional 121 bbls of water staging up to 4BPM (1 BPM=470psi, 2BPM=580psi,3BPM=680psi,4BPM= 765psi ICP,685psi FCP). Sut in OA, bleed pressure and break down injection line. Concurrenity,load and strap 4-1/2" liner in pipe shed. 2/12/2016 2/12/2016 2.50 INTRM1 CEMENT PULD P Lay down 15 stands of 5"drill pipe in 0.0 0.0 00:00 02:30 singles via mousehole. 2/12/2016 2/12/2016 0.50 INTRM1 CEMENT RURD P Lay down mousehole,change out 0.0 0.0 02:30 03:00 elevators and PS-21 inserts for 4"drill pipe. 2/12/2016 2/12/2016 0.50 INTRM1 CEMENT SVRG P Service top drive and blocks. 0.0 0.0 03:00 03:30 2/12/2016 2/12/2016 0.50 INTRM1 CEMENT OTHR P Verify pipe count in casing shed and 0.0 0.0 03:30 04:00 stage 4"drill pipe into pipeshed. 2/12/2016 2/12/2016 7.25 INTRM1 CEMENT PULD P Pick up XT-39 15.99 ppf 4"drill pipe to 0.0 5,742.0 04:00 11:15 5742'MD while monitoring displacement via Pit#3. Concurrently,perform freeze protect with Little Red Oilfield Services. Injected 91 bbls of Isotherm NT into OA at 0.5BPM to 1.9 BPM. ICP= 550psi and FCP=650psi. 2/12/2016 2/12/2016 0.25 INTRMI CEMENT PULD P Circulate string volume at 5742'MD to 5,742.0 5,742.0 11:15 11:30 5640'MD with 338 GPM, 1222psi, 19%flow out.Blow down top drive. 2/12/2016 2/12/2016 4.00 INTRMI CEMENT PULD P Pull out of hole with 4"drill pipe on 5,742.0 0.0 11:30 15:30 elevators from 5742'MD to surface while racking back in derrick. Monitor displacement via Pit#3. PU wt=140k,SO wt=103k. Note: Rig lost power from High Line at 12:00. Running on Generators 2/12/2016 2/12/2016 0.50 INTRM1 CEMENT SVRG P Perform top drive preventative 0.0 0.0 15:30 16:00 maintenance as per Doyon Mechanic. Page 18/37 Report Printed: 3/14/2016 • • ' 3 Operations Summary (with Timelog Depths) 2S-03 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(EKE) 2/12/2016 2/12/2016 4.50 INTRM1 CEMENT PULD P Pick up XT-39 15.99 ppf 4"drill pipe in 0.0 5,786.0 16:00 20:30 doubles and run in hole to 5786'MD while monitoring displacement via Pit #3. Concurrently,load casing shed with 4- 1/2"liner,additional drill pipe,and 6- 3/4"production BHA. 2/12/2016 2/12/2016 0.75 INTRM1 CEMENT PULD P Circulate liner volume at 5BPM,2030 5,786.0 5,786.0 20:30 21:15 stks,while inspecting drilling line. 2/12/2016 2/12/2016 2.00 INTRM1 CEMENT SLPC P Blow down top drive,PJSM for slip 5,786.0 5,786.0 21:15 23:15 and cut of drilling line. Slip and cut 485'of 6x19 Extra Improved Plow Steel drilling line.Calibrate block height. 2/12/2016 2/13/2016 0.75 INTRM1 CEMENT PULD P Pull out of hole from 5786'MD to 5,786.0 3,792.0 23:15 00:00 3792'MD,racking back 4"drill pipe in derrick. 2/13/2016 2/13/2016 1.50 INTRM1 CEMENT PULD P Pull out of hole from 3792'MD to 0' 3,792.0 0.0 00:00 01:30 MD,racking back 4"drill pipe in derrick. 2/13/2016 2/13/2016 0.25 INTRM1 CEMENT RURD P Clean and clear floor. 0.0 0.0 01:30 01:45 2/13/2016 2/13/2016 1.00 INTRM1 WHDBOP BOPE P Pull Cameron wear bushing,install 0.0 0.0 01:45 02:45 Cameron upper test plug.Rig up to perform Bi-Weekly BOPE test.Flood lines and body test BOPE. 2/13/2016 2/13/2016 4.75 INTRM1 WHDBOP BOPE P Perform Bi-weekly BOPE.Witness of 0.0 0.0 02:45 07:30 test waived by AOGCC inspector Bob Noble.All tests to 250 psi low and 3500 psi high,held f/5 minutes, charted.Tested annular and both rams w/both 3-1/2"and 4-1/2"test joints.Electrician tested gas alarms. Top and bottom pipe rams have 2-7/8" x 5-1/2"variable.Tested choke manifold, IBOP's,kill and choke line valves,and all valves in the choke manifold,plus demco valve isolating mud pumps on the kill line.Checked Pit volume totals-OK. Koomey test:Accumulator 3000 psi, manifold 1475 psi, 1550 psi after closing.200 psi build up in 20 seconds,full charge 127 seconds. Closing times:Annular 23 seconds, upper pipe rams 18 seconds, Blind/shear rams 16 seconds,Lower pipe rams 16 seconds,choke HCR 2 seconds,Kill HCR 2 seconds.6 nitrogen bottles average pressure= 1795 psi. ConocoPhillips Koomey test:operate 2 rams, 1 HCR after isolating bottles--- Electric pumps 57 seconds,air pumps 148 seconds. 2/13/2016 2/13/2016 1.00 INTRM1 WHDBOP BOPE P Pull test plug,blow down choke 0.0 0.0 07:30 08:30 maifold,kill line and choke line.Install Cameron 10"ID wear bushing.Run in (2)lockdown screws. Page 19/37 Report Printed: 3/14/2016 • • 11110 toOperations Summary (with Timelog Depths) 0 2S-03 Cano ittips n..k. 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) 2/13/2016 2/13/2016 1.00 INTRM1 CEMENT RURD P Rig up to test the 7-5/8"29.7 ppf L-80 0.0 0.0 08:30 09:30 Hyd 563 casing to 6142.49'(Weatherford stage tool). 2/13/2016 2/13/2016 1.00 INTRM1 CEMENT PRTS P Test 7-5/8"29.7 ppf L-80 Hyd 563 0.0 0.0 09:30 10:30 casing to 3500 psi w/blind rams and both NCR's for 10 minutes.Charted test.Tested twice. First test lost 140 psi in 10 minutes.Tried to bled air from system.Repeated test w/65 psi loss in 10 minutes.Volume to pump both times was 3.6 bbls.Blow down the kill line. 2/13/2016 2/13/2016 0.25 INTRM1 CEMENT SFTY P Pre job safety meeting w/ 0.0 0.0 10:30 10:45 Schlumberger Directional Driller and Measurement While Drilling personal on picking up and making up 6-3/4"x 7.5" BHA#4. 2/13/2016 2/13/2016 1.25 INTRM1 CEMENT BHAH P Make up Halliburton 6-3/4"MM55 616 0.0 81.0 10:45 12:00 PDC bit, jetted w/(4)12's and(1) 11 for TFA of.535.Schlumberger 4-3/4" PowerDrive, PD receiver sub,4-3/4" PeriScope,4-3/4"ImPulse to 81'. 2/13/2016 2/13/2016 0.25 INTRM1 CEMENT SVRG P Swap from rig engines to highline 81.0 81.0 12:00 12:15 power @ 1200 hrs. Note: High line power was lost at noon on 2/12/2016.Rig went to generators. High Line electricians came out today to get us back on High Line. 2/13/2016 2/13/2016 0.25 INTRM1 CEMENT SFTY P Pre job safety meeting on installing 81.0 81.0 12:15 12:30 radioactive sources. 2/13/2016 2/13/2016 0.25 INTRM1 CEMENT BHAH P Install Radioacitve sources in the 81.0 81.0 12:30 12:45 BHA. 2/13/2016 2/13/2016 1.50 INTRM1 CEMENT BHAH P Continue to work bottom hole 81.0 395.0 12:45 14:15 assembly from 81'to 395'.Monitor displacment via pit#3. 4-3/4"adnvision w/6"stabilizer,float sub,(non-ported),6-5/8"Non mag stabilizer,6-1/8"Smith Rhino Reamer w/7.5"cutter blocks and(1)8/32",(1) 10/32"nozzle),Float sub(non ported), 4-3/4"non mag drill collar,6-5/8"non mag stabilizer,MI/Swaco 5"well commander and ball catcher,4-3/4" non-mag drill collar,saver sub, crossover,(3)joints 4"Heavy weight drill pipe,Weatherford 4-3/4"jars,(2) 4"heavy weight drill pipe 2/13/2016 2/13/2016 2.25 INTRM1 CEMENT PULD P Pick up/make up 4"drill pipe from the 395.0 2,283.0 14:15 16:30 pipe shed f/395'to 2283'.Monitor displacment via pit#3. Note: Field went to Phase 3 @ 1600 hrs. 2/13/2016 2/13/2016 0.50 INTRM1 CEMENT DHEQ P Fill pipe,then shallow hole test 2,283.0 2,283.0 16:30 17:00 downhole tools.Pumping 220 gpm w/ 1140 psi, 15%flow out.Good test. Blow down the top drive. Page 20/37 Report Printed: 3/14/2016 • • Operations Summary (with Timelog Depths) .. `_ . 2S-03 C ,coPhillips its 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 (ftKB) End Depth(ftKB) 2/13/2016 2/13/2016 2.75 INTRM1 CEMENT PULD P Continue to pick up/make up 4"drill 2,283.0 5,116.0 17:00 19:45 pipe from the pipe shed f/2283'to 5116'.Fill pipe every 2000'.Monitor displacment via pit#3. 2/13/2016 2/14/2016 4.25 INTRM1 CEMENT WAIT T Phase 3 weather.Work on PM's and 5,116.0 5,116.0 19:45 00:00 rig inventories. Perform maintenance on flush mounted slips,install new gun line in Pit#8. OA pressure 120 psi. 2/14/2016 2/14/2016 6.00 INTRM1 CEMENT WAIT T Waiting on Phase 3 weather 5,116.0 5,116.0 00:00 06:00 conditions to clear. Concurrently,circulate to surface at 3 BPM, 128 GPM,550psi, 17%flow out. PU wt=125k,SO wt=89k. Total Strokes pumped=2191. Work PM's (pipe skate weekly,mud pump weeklys). Rebuild trash pump and housekeeping. Install Gun lines in pits. 2/14/2016 2/14/2016 6.00 INTRM1 CEMENT WAIT T Waiting on Phase 3 weather 5,116.0 5,116.0 06:00 12:00 conditions to clear. Concurrently,circulate to surface at 3 BPM, 128 GPM,550psi, 17%flow out. PU wt=125k,SO wt=89k. Total Strokes pumped=2191. Work PM's (mud pump quarterly,degasser weekly). Change out valve to transfer pump and housekeeping. Remove snow and ice from outside stairs. 2/14/2016 2/14/2016 6.00 INTRM1 CEMENT WAIT T Waiting on Phase 3 weather 5,116.0 5,116.0 12.00 18:00 conditions to clear. Concurrently,circulate to surface at 4.5 BPM, 190 GPM,990psi, 14%flow out.PU wt=125k,SO wt=89k. Work PM's(top drive,tongs). Rig cleaning, Fuel equipment, 1700 hrs:Swap camp on 2A pad back to Higj Line after CPF-2 electricians came out to energize breaker. 2/14/2016 2/15/2016 6.00 INTRM1 CEMENT WAIT T Waiting on Phase 3 weather 5,116.0 5,116.0 18:00 00:00 conditions to clear. Concurrently,circulate to surface at 4.5 BPM, 190 GPM,990psi,14%flow out.PU wt=125k,SO wt=89k. Work PM's(Elevators,shakers)and rig cleaning,Test MPD manifold to 1200psi for 5 min.(Good Test) Page 21/37 Report Printed: 3/14/2016 • • 0:i` Operations Summary (with Timelog Depths) 0 0._ 2S-03 ConocoPhillips Atka 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) 2/15/2016 2/15/2016 5.50 INTRM1 CEMENT WAIT T Waiting on Phase 3 weather 5,116.0 5,116.0 00:00 05:30 conditions to clear. Concurrently,circulate to surface at 4.5 BPM, 190 GPM,990psi, 14%flow out.PU wt=119k,SO wt=94k. Work PM's(shackels and valves)and rig cleaning,Blow down top drive. 2/15/2016 2/15/2016 0.50 INTRM1 CEMENT SFTY T PJSM prior to getting back to normal 5,116.0 5,116.0 05:30 06:00 operations on performing derrick inspection after storm,upcoming operations(tripping,drilling out stage collar). 2/15/2016 2/15/2016 0.50 INTRMI CEMENT SFTY T Inspect derrick and clear derrick of ice. 5,116.0 5,116.0 06:00 06:30 2/15/2016 2/15/2016 0.75 INTRMI CEMENT TRIP P Run in hole on elevators from 5116' 5,116.0 5,974.0 06:30 07:15 MD to 5974'MD. PU wt=140k,SO wt=94k 2/15/2016 2/15/2016 0.50 INTRM1 CEMENT WASH P Wash down from 5974'MD with 210 5,974.0 6,108.0 07:15 07:45 GPM, 1260psi, 14%flow out. Tag top of cement at 6108'MD with 4k down weight. 2/15/2016 2/15/2016 0.50 INTRM1 CEMENT COCF P Drill cement from 6108'MD to top of 6,108.0 6,141.0 07:45 08:15 closing plug at 6141'MD using 220 GPM, 1460psi, 14%flow out,40 RPM, 3-5k WOB,and 7-8k TQ. 2/15/2016 2/15/2016 0.75 INTRM1 CEMENT DRLG P Drill closing plug from 6141'MD to 6,141.0 6,160.0 08:15 09:00 6148'MD with 225-240 GPM, 1500- 1600psi, 15%flow out,40 RPM,3-5k WOB,and 7-10k TQ. 2/15/2016 2/15/2016 0.75 INTRM1 CEMENT CIRC P Work string(x5)through stage collar 6,160.0 6,160.0 09:00 09:45 from 6160'MD to 6139 MD while circulating a bottoms up at 230 GPM, 1490psi, 15%flow out,70 RPM,and 7k TQ. Blow down top drive. PU wt=149k,SO wt=95k. 2/15/2016 2/15/2016 0.50 INTRM1 CEMENT TRIP P Run in hole on elevators from 6160' 6,160.0 6,790.0 09:45 10:15 MD to 6790'MD while monitoring displacement via Pit#3.Started to take weight(15k)at 6790'MD. 2/15/2016 2/15/2016 2.25 INTRM1 CEMENT REAM T Kelly up and wash and ream from 6,780.0 7,583.0 10:15 12:30 6780'MD to 7583'MD with 200-220 GPM, 1290-1480psi,14%flow out,30 -40 RPM,7-8.5k TQ. PU wt=171k,SO wt=112k. 2/15/2016 2/15/2016 0.50 INTRM1 CEMENT CIRC T Circulate bottoms up while rotating 7,583.0 7,583.0 12:30 13:00 and reciprocating from 7492'MD to 7583'MD at 235 GPM, 1670psi, 16% flow out,40 RPM,7.5k TQ. PU wt=180k,SO wt=98k. 2/15/2016 2/15/2016 0.75 INTRM1 CEMENT TRIP P Trip in hole from 7583'MD to 7631' 7,583.0 7,631.0 13:00 13:45 MD while monitoring displacement via Pit#3. PU wt=196k,SO wt=97k Page 22/37 Report Printed: 3/14/2016 • S 0:1 Operations Summary (with Timelog Depths) 0 0 2S-03 ililips Alaska 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) 2/15/2016 2/15/2016 0.25 INTRM1 CEMENT WASH P Wash down from 7631'MD to 8608' 7,631.0 8,608.0 13:45 14:00 MD with 200 GPM, 15%flow out. Tag top of cement at 8608'MD with 10k down weight at 13:53hrs. 2/15/2016 2/15/2016 0.25 INTRM1 CEMENT COCF P Drill cement from 8608'MD to 8628' 8,608.0 8,628.0 14:00 14:15 MD using 240 GPM,1880psi, 16% flow out,40 RPM,3k WOB,10-13k WOB. 2/15/2016 2/15/2016 1.00 INTRM1 CEMENT CIRC P Circulate while reciprocating and 8,628.0 8,628.0 14:15 15:15 rotating from 8628'MD to 8535'MD using 240 GPM, 1870psi, 16%flow out,40 RPM,and 11 k TQ. Total Strokes=3648.MW in/out=9.7ppg. 2/15/2016 2/15/2016 1.25 INTRM1 CEMENT -PRTS P Rig up and flood lines to pressure test 8,628.0 8,628.0 15:15 16:30 casing. Test casing to 3500psi from 30min(Good Test).Rig down test equipment. Note:43stks to pressure up to 3500psi,4.1 bbls bled back 2/15/2016 2/15/2016 3.00 INTRM1 CEMENT COCF P Drill cement to float equipment from 8,628.0 8,736.0 16:30 19:30 8628'MD to 8736'MD. 2/15/2016 2/15/2016 4.00 INTRM1 CEMENT DRLG P Drill float equipment amd cement from 8,736.0 8,830.0 19:30 23:30 8736'MD to 8830'MD with 240 GPM, 1810psi,15%flow out,50 RPM,3-15k WOB,and 11-13k TQ. PU wt=203k,SO wt=99k, ROT wt= 153k,off bottom TQ=12k. Note:Top of Plugs=8688'MD,Top of Float Collar=8736'MD,Top of shoe= 8824'MD. 2/15/2016 2/16/2016 0.50 INTRM1 CEMENT DDRL P Drill new hole from 8830'MD to 8840' 8,830.0 8,840.0 23:30 00:00 MD with 240 GPM, 1920psi, 17%flow out,60 RPM, 13.5k WOB,and 11k TQ. 2/16/2016 2/16/2016 0.50 INTRM1 CEMENT DDRL P Continue to drill new hole from 8840' 8,840.0 8,850.0 00:00 00:30 to 8850'MD with 236 GPM, 1840psi, 15%flow out,60 RPM,13.5k WOB, and 11 k TQ. Took SPR's. 2/16/2016 2/16/2016 3.75 INTRM1 CEMENT DISP P Circulate while rotate and recip f/ 8,850.0 8,850.0 00:30 04:15 8850'to 8865'MD @ 636 GPM, 1800 psi, 15%FO,60 RPM, Pump 75 BBL Hi vis spacer. Displace well to 10.3 PPG Flo-Thru mud @ 223 GPM, 1604 PSI to 1820 PSI, 16%FO and 60 RPM,7K TQ,PU=162K,SO=106K, ROT=122K,7K TQ. Total pumped= 4949 STKS. 2/16/2016 2/16/2016 1.00 INTRM1 CEMENT FIT P RU to obtain FIT at 8817'MD. Pump 8,850.0 8,850.0 04:15 05:15 at.5 BPM and obtain 14.5 PPG EMW test. Total pumped 50 Stks. Bled back 1.2 Bbl. 2/16/2016 2/16/2016 0.75 PROD1 DRILL SVRG P Changed out swivel packing on top 8,850.0 8,850.0 05:15 06:00 drive. PT to 3500 PSI. 2/16/2016 2/16/2016 1.25 PROD1 DRILL MPDA P Pull trip nipple. Install MPD bearing. 8,850.0 8,850.0 06:00 07:15 Calibrate MPD chokes. Page 23/37 Report Printed: 3/14/2016 • • i= Operations Summary (with Timelog Depths) 2S-03 ConocoPhitlips S kx 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) 2/16/2016 2/16/2016 4.75 PROD1 DRILL DDRL P RIH f/8817'to 8850'MD. Drill 6-3/4" 8,850.0 9,198.0 07:15 12:00 production hole from 8850'to 9198' MD/6346'TVD with 261 GPM,2427 psi, 18%flow out, 100 RPM, 9k TQ, 6k WOB,Off Bottom pressure 2440 psi. PU wt=155k,SO wt=105k, ROT wt=123k,with 8k off bottom TQ. ART/ADT=4.45,Total bit hrs=4.45 Total Jar hrs=4.45 2/16/2016 2/16/2016 2.50 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 9198 9,198.0 9,388.0 12:00 14.30 to 9388'MD/6364'TVD with 263 GPM,2500 psi, 19%flow out, 100 RPM, 10.5k TQ,6k WOB,ECD= 11.61 PPG,Off Bottom pressure 2580 psi. Follow ramp up/dn schedule on connections holding 420 PSI backpressure. Took SPR's. PU wt=159k,SO wt=107k, ROT wt=119k,with 9k off bottom TQ. ART/ADT=1.84,Total bit hrs=6.29 Total Jar hrs=6.29 2/16/2016 2/16/2016 0.75 PROD1 DRILL CIRC P CBU to even out MW prior to MPD 9,388.0 9,388.0 14:30 15:15 drawdown test @ 263 GPM,2460 PSI. MW IN/OUT=10.2 PPG. 2/16/2016 2/16/2016 0.75 PROD1 DRILL OWFF P Performed MPD drawdown test. No 9,388.0 9,388.0 15:15 16:00 pressure build-up observed. 2/16/2016 2/16/2016 0.50 PROD1 DRILL CIRC P CBU to verify no gas influx. None 9,388.0 9,388.0 16:00 16:30 Observed. MW IN/OUT= 10.2 PPG. 2/16/2016 2/17/2016 7.50 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 9388 9,388.0 10,052.0 16:30 00:00 to 10052'MD/6360'TVD with 261 GPM,2530 psi, 19%flow out, 130 RPM, 12.5k TQ, 10k WOB, ECD= 11.70 PPG,Off Bottom pressure 2510 psi. Follow ramp up/dn schedule on connections holding 420 PSI backpressure. PU wt=169k,SO wt=97k,ROT wt=127k,with 10k off bottom TQ. ART/ADT=5.13,Total bit hrs= 11.42 Total Jar hrs= 11.42 2/17/2016 2/17/2016 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 10,052.0 10,665.0 00:00 06:00 10052'to 10665'MD/6373'TVD with 261 GPM,2547 psi, 19%flow out, 130 RPM, 13k TQ, 10-15k WOB, ECD= 11.87 PPG, Off Bottom pressure 2527 psi. Took SPR's. PU wt=172k,SO wt=130k, ROT wt=130k,with 10k off bottom TQ. Page 24/37 Report Printed: 3/14/2016 • • 111 0 Operations Summary (with Timelog Depths) a 2S -03 "" `tins Masks Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Tme Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE) 2/17/2016 2/17/2016 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 10,665.0 11,286.0 06:00 12:00 10665'to 11286'MD/6373'TVD with 261 GPM,2585 psi, 19%flow out, 130 RPM, 13k TQ,7-11k WOB,ECD= 11.84 PPG,Off Bottom pressure 2570 psi. Took SPR's. PU wt=185k,SO wt=93k,ROT wt=124k,with 11k off bottom TQ. ART/ADT=8.45,Total bit hrs=19.87 Total Jar hrs=19.87 2/17/2016 2/17/2016 6.00 PROD1 DRILL DDRL -.P Drill 6-3/4"production hole from 11,286.0 11,949.0 12:00 18:00 11286'to 11949'MD/6394'TVD with 261 GPM,2730 psi,20%flow out, 130 RPM, 13.5k TQ,7k WOB,ECD= 11.90 PPG,Off Bottom pressure 2720 psi. Took SPR's. PU wt=194k,SO wt=89k,ROT wt=133k,with 12k off bottom TQ. ART/ADT=4.47,Total bit hrs=24.34 Total Jar hrs=24.34 2/17/2016 2/17/2016 4.50 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 11,949.0 12,442.0 18:00 22:30 11949'to 12442'MD/6403'TVD with 261 GPM,2800 psi,20%flow out, 130 RPM, 13k TQ, 10k WOB,ECD= 11.94 PPG,Off Bottom pressure 2790 psi. PU wt=177k,SO wt=93k,ROT wt=131k,with 10k off bottom TQ. ART/ADT=3.3,Total bit hrs=27.64 Total Jar hrs=27.64 2/17/2016 2/18/2016 1.50 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 12,442.0 12,602.0 22:30 00:00 12442'to 12602'MD/6409'TVD with 261 GPM,2800 psi,20%flow out, 130 RPM, 13k TQ, 10k WOB,ECD= 11.94 PPG,Off Bottom pressure 2790 psi. Took SPR's. Follow ramp up/dn schedule on connections holding 420 PSI backpressure for past 24 hrs. Incr.lube concentration which reduced PU&TQ. PU wt=177k,SO wt=93k,ROT wt=131k,with 10k off bottom TQ. ART/ADT=1.1,Total bit hrs=28.74 Total Jar hrs=28.74 2/18/2016 2/18/2016 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 12,602.0 13,087.0 00:00 06:00 12602'to 13087'MD/6450'TVD with 261 GPM,3000 psi,20%flow out, 130 RPM, 14k TQ,8-15k WOB,ECD= 12.07 PPG,Off Bottom pressure 2970 psi. PU wt=195k,SO wt=86k,ROT wt=130k,with 11k off bottom TQ. ART/ADT=3.57,Total bit hrs=32.32, Total Jar hrs=32.32 Page 25/37 Report Printed: 3/14/2016 • • 0:i Operations Summary (with Timelog Depths) 0 0 2S-03 CcnocoPhillips Afx.ka 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) 2/18/2016 2/18/2016 2.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 13,087.0 13,277.0 06:00 08:00 13087'to 13277'MD/6474'TVD with 261 GPM,3065 psi, 19%flow out, 130 RPM, 13k TQ,8-15k WOB,ECD= 12.07 PPG,Off Bottom pressure 2980 psi. Took SPR's. PU wt=191 k,SO wt=86k,ROT wt=135k,with 11 k off bottom TQ. ART/ADT=1.46,Total bit hrs=33.78 Total Jar hrs=33.78 SPR's @ 13178'MD(6461'TVD):#1 mp:20/30=690/960 psi @ 0700 hrs SPR's @ 13178'MD(6461'TVD):#2 mp:20/30=720/1030 psi @ 0700 hrs 2/18/2016 2/18/2016 0.50 PROD1 DRILL CIRC P Circulate while rotating and recip f/ 13277.0 13,277.0 08:00 08:30 13277'to 13261'. Pumping 262 gpm w/3000 psi, 19%flow out.Rotate 130 rpm w/12k torque.PU wt 191k,SO wt 86k,Rot wt 135k,rot torque 1l k ft lbs. Pumped 186 bbls.Take survey and obtain slow pump rates. SPR's @ 13277'MD(6474'TVD):#1 mp:20/30=690/960 psi @ 0700 hrs SPR's @ 13277'MD(6474'TVD):#2 mp:20/30=720/1030 psi @ 0700 hrs 2/18/2016 2/18/2016 3.50 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 13,277.0 13,580.0 08:30 12:00 13277'to 13580'MD/6530'TVD with 261 GPM,3008 psi, 19%flow out, 100 RPM, 1l k TQ,8-15k WOB,ECD= 12.03 PPG,Off Bottom pressure 3000 psi. PU wt=200k,SO wt=89k,ROT wt=138k,with 11k off bottom TQ. ART/ADT=2.43,Total bit hrs=36.21 Total Jar hrs=36.21 2/18/2016 2/18/2016 1.75 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 13,580.0 13,728.0 12:00 13:45 13580'to 13728'MD/6536'TVD with 261 GPM,3050 psi, 19%flow out,90 RPM, 13k TQ, 15k WOB,ECD= 12.01 PPG,Off Bottom pressure 3030 psi. Follow ramp up/dn schedule on connections holding 420 PSI backpressure for all drilling today. PU wt=200k,SO wt=89k,ROT wt=135k,with 11 k off bottom TQ. ART/ADT=1.54,Total bit hrs=37.75 Total Jar hrs=37.75 2/18/2016 2/18/2016 1.25 PROD1 DRILL CIRC T Circulate while rotating and recip f/ 13,728.0 13,728.0 13:45 15:00 13727'to 13652'. Pumping 260 gpm w/2960 psi,20%flow out.Rotate 120 rpm w/10k torque.PU wt 195k,SO wt 88k,Rot wt 133k,rot torque 10k ft lbs. Pumped 433 bbls.Take survey and obtain slow pump rates. MW In/Out= 10.3 PPG. Page 26/37 Report Printed: 3/14/2016 • • 0 Operations Summary (with Timelog Depths) 2S-03 ConocoPhi ll ips Ask 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) 2/18/2016 2/18/2016 1.50 PROD1 DRILL SMPD T Strip OOH f/13728'to 12572'MD 13,728.0 12,572.0 15:00 16:30 holding 600 PSI backpressure while pulling and 420 PSI in slips. 2/18/2016 2/18/2016 1.50 PROD1 DRILL REAM T Worked tight hole at 12572'MD. Work 12,572.0 12,587.0 16:30 18:00 pipe down to 12587'MD to free up. Staged pump up to 235 GPM,2360 PSI and attempted to jar down while working 10K TQ down until free. 2/18/2016 2/18/2016 0.50 PROD1 DRILL CIRC T Circulate while rotating and recip f/ 12,587.0 12,613.0 18:00 18:30 12700'to 12613'MD.Pumping 261 gpm w/2980 psi, 19%flow out.Rotate 120 rpm w/10k torque.ECD=11.89. Pumped 151 bbls. 2/18/2016 2/18/2016 0.75 PROD1 DRILL BKRM T Backream OOH f/12613' to 12423' 12,613.0 12,423.0 18:30 19:15 MD @ 260 GPM,2760 PSI, 18%flow out, 120 RPM,9.5K TQ. 2/18/2016 2/18/2016 1.25 PROD1 DRILL OWFF T Perform MPD build-up. Bled off in 50 12,423.0 12,423.0 19:15 20:30 PSI nicrements and observed pressure build-up to 60 PSI w/10.3 PPG mud. 2/18/2016 2/18/2016 1.00 PROD1 DRILL CIRC T Circulate while rotating and recip f/ 12,423.0 12,423.0 20:30 21:30 12420'to 12335'MD.Pumping 261 gpm w/2790 psi, 18%flow out.Rotate 120 rpm,9K TQ, PU=169K,SO= 91K,ROT=120K,9.5K TQ,Total pumped=393 BBLS,MW IN/OUT= 10.3 PPG. 2/18/2016 2/19/2016 2.50 PROD1 DRILL BKRM T Backream OOH f/12423'to 10720' 12,423.0 10,720.0 21:30 00:00 MD @ 260 GPM,2700 PSI, 120 RPM, 9K TQ, 18%flow out. 2/19/2016 2/19/2016 0.50 PROD1 DRILL BKRM T Backream OOH f/10720'to 10625' 10,720.0 10,625.0 00:00 00:30 MD @ 260 GPM,2700 PSI, 120 RPM, 9K TQ, 18%flow out.,PU=160 K,SO =90K,ROT=130K, 10K TQ. 2/19/2016 2/19/2016 0.50 PROD1 DRILL PULD T PU two 10'DP pups for spaceout& 10,625.0 10,644.0 00:30 01:00 RIH f/10625'-10644'MD. 2/19/2016 2/19/2016 0.75 PROD1 DRILL CIRC T Make up stand#109,rotate and recip 10,644.0 10,640.0 01:00 01:45 f/10640'to 10635'MD @ 261 GPM, 2560 PSI, 140 RPM,8K TQ, 18%flow out,while pumping commands to powerdrive. 2/19/2016 2/19/2016 6.75 PROD1 DRILL REAM T Begin troughing for sidetrack from 10,640.0 10,670.0 01:45 08:30 10640'to 10670'MD @ 261 GPM, 2560 PSI, 140 RPM,8K TQ, 18%flow out. 2/19/2016 2/19/2016 1.25 PROD1 DRILL REAM T Set bit at 10670'MD and drill ledge w/ 10,670.0 10,670.0 08:30 09:45 261 GPM,2433 PSI,90 RPM,6K TQ, 18%flow out. 2/19/2016 2/19/2016 2.25 PROD1 DRILL DRLG T Timedrill f/10670'-10671.22 @.5 10,670.0 10,671.0 09:45 12:00 feet/hour w/261 GPM,2430 PSI,90 RPM,6.5K TQ, 18%flow out. 2/19/2016 2/20/2016 12.00 PROD1 DRILL DDRL T Timedrill f/10671'-10711 @ up to 6 10,671.0 10,711.0 12:00 00:00 feet/hour w/261 GPM,2420 PSI,80 RPM,5K WOB,8.5K TQ, 11.29 PPG ECD, 16%flow out. 2/20/2016 2/20/2016 4.00 PROD1 DRILL DDRL T Continue to timedrill f/10711'-10730 10,711.0 10,730.0 00:00 04:00 @ up to 10 feet/hour w/261 GPM, 2420 PSI,80-140 RPM,5 K WOB, 8.5K TQ, 11.40 PPG ECD, 16%flow out. Page 27/37 Report Printed: 3/14/2016 • • Operations Summary (with Timelog Depths) Pik 2S-03 ConocoPhillips itups 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) 2/20/2016 2/20/2016 2.00 PROD1 DRILL DDRL T Drill 6-3/4"sidetracked production hole 10,730.0 10,815.0 04:00 06:00 from 10730'to 10815'MD/6378'TVD with 260 GPM,2500 psi, 19%flow out,90 RPM, 10k TQ, 10k WOB, ECD =11.40 PPG,Off Bottom pressure 2489 psi. PU wt=165k,SO wt=84k,ROT wt=128k,with 8k off bottom TQ. ART/ADT=1.96,Total bit hrs=39.71 Total Jar hrs=39.71 2/20/2016 2/20/2016 1.50 PROD1 DRILL DDRL T Drill 6-3/4"sidetracked production hole 10,815.0 10,924.0 06:00 07:30 from 10815'to 10924'MD with 260 GPM,2571 psi, 19%flow out, 120 RPM, 11k TQ,10k WOB,ECD= 11.40 PPG,Off Bottom pressure 2568 psi. PU wt=165k,SO wt=84k,ROT wt=127k,with 10k off bottom TQ. 2/20/2016 2/20/2016 1.00 PROD1 DRILL MPDA T Close Annular and change out MPD 10,924.0 10,924.0 07:30 08:30 bearing. 2/20/2016 2/20/2016 3.50 PROD1 DRILL DDRL T Drill 6-3/4"production hole from 10,924.0 11,220.0 08:30 12:00 10924'to 11220'MD/6378'TVD with 260 GPM,2589 psi,20%flow out, 120 RPM, 12k TQ, 10k WOB,ECD= 11.93 PPG,Off Bottom pressure 2568 psi. PU wt=165k,SO wt=85k,ROT wt=128k,with 10k off bottom TQ. ART/ADT=3.28,Total bit hrs=42.99 Total Jar hrs=42.99 2/20/2016 2/20/2016 6.00 PROD1 DRILL DDRL T Drill 6-3/4"production hole from 11,220.0 11,874.0 12:00 18:00 11220'to 11874'MD/6389'TVD with 260 GPM,2760 psi,20%flow out, 130 RPM,12.5k TQ,9.5k WOB, ECD= 12.01 PPG,Off Bottom pressure 2740 psi. PU wt=170k,SO wt=94k,ROT wt=127k,with 10k off bottom TQ. ART/ADT=4.28,Total bit hrs=47.27 Total Jar hrs=47.27 2/20/2016 2/21/2016 6.00 PROD1 DRILL DDRL T Drill 6-3/4"production hole from 11,874.0 12,459.0 18:00 00:00 11874'to 12549'MD/6404'TVD with 260 GPM,2900 psi,20%flow out, 130 RPM, 13.5k TQ, 12k WOB,ECD= 12.23 PPG,Off Bottom pressure 2880 psi. Took Slow pump rates. PU wt=173k,SO wt=91 k,ROT wt=131k,with 10k off bottom TQ. ART/ADT=4.2,Total bit hrs=51.45 Total Jar hrs=51.45 Page 28/37 Report Printed: 3/14/2016 • • Operations Summary (with Timelog Depths) r 0. 2S-03 Corso oPhitlips Mme 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) 2/21/2016 2/21/2016 6.00 PROD1 DRILL DDRL T Drill 6-3/4"production hole from 12,459.0 13,095.0 00:00 06:00 12549'to 13095'MD/6360'TVD with 260 GPM,2919 psi,20%flow out, 140 -150 RPM, 12-13k TQ,5-10k WOB, ECD=12.29 PPG,Off Bottom pressure 2896 psi. Took slow pump rates. PU wt=176k,SO wt=86k,ROT wt=131k,with 10k off bottom TQ. ART/ADT=3.48,Total bit hrs=54.85 Total Jar hrs=54.85 2/21/2016 2/21/2016 5.75 PROD1 DRILL DDRL T Drill 6-3/4"production hole from 13,095.0 13,728.0 06:00 11:45 13095'to 13728'MD/6406'TVD with 260 GPM,3007 psi,20%flow out, 150 RPM,13-14k TQ,9k WOB,ECD= 12.24 PPG,Off Bottom pressure 3001 psi. PU wt=173k,SO wt=93k,ROT wt=132k,with 10k off bottom TQ. 2/21/2016 2/21/2016 0.25 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 13,728.0 13,772.0 11:45 12:00 13728'to 13772'MD/6406'ND with same parameters. Now off Trouble Time. PU wt=173k,SO wt=93k,ROT wt=132k,with 10k off bottom TQ. ART/ADT=4.17,Total bit hrs=58.75 Total Jar hrs=58.75 2/21/2016 2/21/2016 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 13,772.0 14,436.0 12:00 18:00 13772'to 14436'MD/6416'TVD with 260 GPM,3060 psi,20%flow out, 150 RPM, 13-14k TQ,10k WOB,ECD= 12.34 PPG,Off Bottom pressure 3050 psi. PU wt=176k,SO wt=92k,ROT wt=132k,with 10k off bottom TQ. ART/ADT=3.58,Total bit hrs=62.33 Total Jar hrs=62.33 2/21/2016 2/22/2016 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 14,436.0 15,068.0 18:00 00:00 14436'to 15068'MD/6432'TVD with 260 GPM,3090 psi,20%flow out, 150 RPM, 14k TQ, 11k WOB,ECD= 12.24 PPG,Off Bottom pressure 3050 psi. Follow ramp up/dn schedule on connections holding 420 PSI backpressure for past 24 hrs. PU wt=183k,SO wt=88k,ROT wt=130k,with 11k off bottom TQ. ART/ADT=3.81,Total bit hrs=66.14 Total Jar hrs=66.14 2/22/2016 2/22/2016 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 15,068.0 15,795.0 00:00 06:00 15068'to 15795'MD/6437'TVD with 260 GPM,3119 psi,20%flow out, 150 RPM, 15-16k TQ, 10-11 WOB,ECD= 12.28 PPG,Off Bottom pressure 3095 psi. PU wt=199k,SO wt=88k,ROT wt=131 k,with 12k off bottom TQ. ART/ADT=4.11,Total bit hrs=70.25 Total Jar hrs=70.25 Page 29/37 Report Printed: 3/14/2016 0,z Operations Summary (with Timelog Depths) 0 a ConocoPhitlips at.xka 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) 2/22/2016 2/22/2016 6.00 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 15,795.0 16,485.0 06:00 12:00 15795'to 16485'MD/6450'TVD with 260 GPM,3119 psi, 19%flow out, 150 RPM, 16k TQ, 10k WOB,ECD= 12.28 PPG,Off Bottom pressure 3095 psi. Took slow pump rates. PU wt=200k,SO wt=94k,ROT wt=134k,with 12k off bottom TQ. ART/ADT=3.52,Total bit hrs=73.77 Total Jar hrs=73.77 2/22/2016 2/22/2016 0.50 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 16,485.0 16,576.0 12:00 12:30 16485'to 16576'MD/6462'TVD with 260 GPM,3119 psi, 19%flow out, 140 RPM, 15k TQ, 11k WOB,ECD= 12.24 PPG,Off Bottom pressure 3350 psi. Took slow pump rates. PU wt=200k,SO wt=98k,ROT wt=140k,with 12k off bottom TQ. 2/22/2016 2/22/2016 1.75 PROD1 DRILL CIRC P Circulate BU while rotate and recip f/ 16,576.0 16,576.0 12:30 14:15 16576'to 16481'MD with 260 GPM, 3250 psi, 19%flow out, 140 RPM, 12k TQ,ECD=12.02 PPG 2/22/2016 2/22/2016 1.50 PROD1 DRILL OWFF P Perform MPD drawdown test to 218 16,576.0 16,576.0 14:15 15:45 PSI,11.05 PPG,bled back.6 BBLS. 2/22/2016 2/22/2016 1.75 PROD1 DRILL DDRL P Drill 6-3/4"production hole from 16,576.0 16,760.0 15:45 17:30 16481'to 16760'MD/6487'TVD with 260 GPM,3365 psi, 17%flow out, 140 RPM, 14.5k TQ, 12 WOB,ECD= 12.17 PPG,Off Bottom pressure 3345 psi. PU wt=202k,SO wt=98k,ROT wt=143k,with 11 k off bottom TQ. ART/ADT=1.44 Total bit hrs=75.21 Total Jar hrs=75.21 2/22/2016 2/22/2016 1.50 PROD1 CASING CIRC P Circulate BU while rotate and recip f/ 16,760.0 16,760.0 17:30 19:00 16760'to 16660'MD with 260 GPM, 3350 psi, 17%flow out, 140 RPM, 12k TQ,ECD=12.02 PPG. Pumped a total of 539 BBLS. MW In=10.3PPG, MW out=10.3+,PU wt=201k,SO wt=99k,ROT wt=144k. Obtain slow pump rates. 2/22/2016 2/22/2016 0.75 PROD1 CASING MPDA P Change out Managed Pressure 16,760.0 16,760.0 19:00 19:45 Drilling pack-off bearing. 2/22/2016 2/22/2016 3.25 PROD1 CASING BKRM P Backream OOH f/16760'to 15190' 16,760.0 15,190.0 19:45 23:00 MD with 260 GPM,2890 psi,22%flow out,140 RPM, 11 k TQ,ECD=11.72 PPG. Holding 420 PSI backpressure during connections. 2/22/2016 2/22/2016 0.50 PROD1 CASING SVRG P Service Rig. Greasewashpipe. 15,190.0 15,190.0 23:00 23:30 2/22/2016 2/23/2016 0.50 PROD1 CASING RGRP T Both mudpumps went down. Line up 15,190.0 15,190.0 23:30 00:00 test pump on annulus and maintain pres of 400 PSI while troubleshooting pump. 2/23/2016 2/23/2016 0.50 PROD1 CASING RGRP T Both mudpumps went down. Lineup 15,190.0 15,190.0 00:00 00:30 test pump on annulus and maintain pres of 400 PSI while troubleshooting pump. Page 30/37 Report Printed: 3/14/2016 i • .# Operations Summary (with Timelog Depths) 2S-03 Concte6Phillips Alaska Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Tme Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/23/2016 2/23/2016 12.00 PROD1 CASING BKRM P Backream OOH f/15190'to 10635' 15,190.0 10,635.0 00:30 12:30 MD with 260 GPM,2560 psi,21%flow out, 140 RPM,7k TQ,ECD=11.71 PPG. Obtain survey at 10,830'MD. Holding 420 PSI backpressure during connections. PU wt=149k,SO wt=101 k, ROT wt=123k 2/23/2016 2/23/2016 0.25 PROD1 CASING TRIP P Drop back thru sidetrack w/o pump or 10,635.0 10,830.0 12:30 12:45 rotary f/10635'to 10830'MD. Survey at 10830'MD and confirmed in sidetrack hole. Took 5K at 10714'and 9K at 10888'MD. PU wt=149k,SO wt=99k 2/23/2016 2/23/2016 3.75 PROD1 CASING BKRM P Backream OOH f/10830'to 9578'MD 10,830.0 9,578.0 12:45 16:30 with 260 GPM,2210 psi,22%flow out, 140 RPM,6k TQ,ECD=11.23 PPG. 2/23/2016 2/23/2016 1.00 PROD1 CASING CIRC P Circulate BU while rotate and recip f/ 9,578.0 9,480.0 16:30 17:30 9578'to 9480'MD with 260 GPM, 2420 psi, 17%flow out, 140 RPM,6k TQ, 2/23/2016 2/23/2016 0.75 PROD1 CASING SMPD P Strip OOH f/9480'to 8816'MD. 9,480.0 8,816.0 17:30 18:15 2/23/2016 2/23/2016 1.75 PROD1 CASING CIRC P Circulate BU while rotate and recip f/ 8,816.0 8,816.0 18:15 20:00 8816'to 8722'MD with 260 GPM, 2350 psi, 17%flow out, 120 RPM, 5k TQ,Pumped 540 BBLS. 2/23/2016 2/23/2016 1.75 PROD1 CASING SLPC P Slip and cut drill line. Calibrate wt. 8,816.0 8,816.0 20:00 21:45 sensors. 2/23/2016 2/23/2016 0.50 PROD1 CASING SVRG P Service topdrive,blocks and crown. 8,816.0 8,816.0 21:45 22:15 2/23/2016 2/23/2016 0.75 PROD1 CASING REAM T Wash down f/8816'to 8913'MD. 8,816.0 8,825.0 22:15 23:00 Attempted to ream f/8913'to 8918' MD and well packed off at 8919'. Pull back to 8825'MD w/o pump or rotary. 2/23/2016 2/23/2016 0.25 PROD1 CASING CIRC P Circ inside casing w/ 260 GPM,2350 8,825.0 8,825.0 23:00 23:15 psi, 16%flow out, 120 RPM, 6K TQ, 11.25 ECD. 2/23/2016 2/24/2016 0.75 PROD1 CASING REAM P Ream down f/8825'to 8965'MD with 8,825.0 8,965.0 23:15 00:00 125 GPM, 160 psi, 15%flow out,60 RPM,6k 300 FPH,PU wt=140k,SO wt=109k 2/24/2016 2/24/2016 0.50 PROD1 CASING REAM T Ream down f/8965'to 9068'MD with 8,965.0 9,068.0 00:00 00:30 125 GPM,970 psi, 15%flow out,60 RPM,6k 275 FPH,PU wt=140k,SO wt=109k. Staging pumps up to 190 GPM and 970 PSI. Stalled rotary and packed off. 2/24/2016 2/24/2016 1.75 PROD1 CASING SMPD T POOH to shoe at 8825'MD. 9,068.0 8,825.0 00:30 02:15 2/24/2016 2/24/2016 1.00 PROD1 CASING CIRC T Circ BU @ 260 GPM and 2350 PSI, 8,825.0 8,825.0 02:15 03:15 90 RPM,7K TQ. Page 31/37 Report Printed: 3/14/2016 i ! 41;.,..,e Z•° 4:,, Operations Summary (with Timelog Depths) c. 7i 4 `1-, 2S-03 ccnocoPhillips a'.ska 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) 2/24/2016 2/24/2016 1.75 PROD1 CASING REAM T Ream down f/8821'to 8916'MD with 8,825.0 8,821.0 03:15 05:00 125 GPM,930 psi, 15%flow out,60 RPM,6k 275 FPH, Incr rate to 168 GPM and ream do to 8930'MD. Packed off and stalled rotary. PU to 8900'and regain circ and rotation. RIH w/o circ or rot to 8940'. Could not go any further. Pull back to shoe at 8821'MD. 2/24/2016 2/24/2016 1.50 PROD1 CASING CIRC T Circ BU @ 250 GPM and 2567 down 8,821.0 8,821.0 05:00 06:30 to 2297 PSI,90 RPM,7K TQ. Pumped 600 BBLS. 2/24/2016 2/24/2016 2.50 PROD1 CASING REAM T Ream down f/8821'to 8920'MD with 8,821.0 8,821.0 06:30 09:00 200 GPM, 1566 psi,20%flow out,80 RPM,6k. Packed off and torqued up. Regained circ and pull back into the shoe @ 8821'MD. 2/24/2016 2/24/2016 0.50 PROD1 CASING CIRC T Establish full circ rate @ 250 GPM, 8,821.0 8,821.0 09:00 09:30 20%flow out, 90 RPM,6K TQ, Recip &Rotate, pumped 150 BBLS. 2/24/2016 2/24/2016 2.50 PROD1 CASING REAM T Ream down f/8821'to 8944'MD with 8,821.0 8,944.0 09:30 12:00 200 GPM, 1600 psi,21%flow out,80 RPM,6k,50 FPH. PU wt=155k,SO wt=101 k 2/24/2016 2/24/2016 1.00 PROD1 CASING SMPD T POOH w/o pump to 8817. MD into 8,944.0 8,817.0 12:00 13:00 shoe 2/24/2016 2/24/2016 1.25 PROD1 CASING CIRC T Circ BU @ 300 GPM and 2567 PSI 8,817.0 8,817.0 13:00 14:15 down to 2297 PSI, 120 RPM,6K TQ. Pumped 280 BBLS. 2/24/2016 2/24/2016 4.50 PROD1 CASING REAM T RIH f/8817'-8890'MD and sat down. 8,817.0 8,950.0 14:15 18:45 Attempt to wash down with 126 GPM &940 PSI. Would not go. Increase rate to 200 GPM, 1640 PSI and ream down to 8960'MD at 25 RPM,8K TO. Stalled out and packed off. 2/24/2016 2/24/2016 1.50 PROD1 CASING SMPD T RIH f/8950'to 9385'MD w/o pumps 8,950.0 9,385.0 18:45 20:15 or rotary. 2/24/2016 2/25/2016 3.75 PROD1 CASING CIRC T Stage pumps up to 4.5 BPM&1620 9,385.0 9,475.0 20:15 00:00 PSI and had pack-off. Work pipe with and without rotary and attempt to pump. RIH to 9475'MD stage pumps to 4 BPM @ 1250 PSI. Well packed off. 2/25/2016 2/25/2016 3.25 PROD1 CASING CIRC T Cont.to attempt circ at 9475'MD, 9,475.0 9,380.0 00:00 03:15 rotating @ 35 RPM&9.5 K TQ while staging pumps up to 126 GPM. At 126 GPM,well packed off and pipe stalled at 10K TO. Stripped up to 9380'and tried to get circ again with no luck. 2/25/2016 2/25/2016 1.25 PROD1 CASING SMPD T Strip OOH from 9380'to 8815'MD, 9,380.0 8,815.0 03.15 04:30 while holding 420 PSI backpressure on the annulus. PU wt=166k,SO wt=101k ROT wt=123k. Had 40K overpull @ 9366',9035',8968&8938' MD. Dropped back down and wipped thru at 10-15K overpull. 2/25/2016 2/25/2016 2.50 PROD1 CASING CIRC T Circ BU while recip&rotate @ 300 8,815.0 8,815.0 04:30 07:00 GPM and 2924 PSI,90 RPM,6K TQ. PU wt=145k,SO wt=105k. Pumped 970 BBLS. Page 32/37 Report Printed: 3/14/2016 • 646, Operations Summary (with Timelog Depths) 2S-03 66, ConocoPhillips .5_:xka Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Tme Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/25/2016 2/25/2016 0.75 PROD1 CASING SMPD T Strip in hole on elevators f/8815 to 8,815.0 9,286.0 07:00 07:45 9286'MD. PU wt=145k,SO wt=108k 2/25/2016 2/25/2016 0.75 PROD1 CASING SMPD T Strip OOH from 9286'to 8812'MD. 9,286.0 8,812.0 07:45 08:30 40K overpull @ 9055'MD. Wiped clean. 2/25/2016 2/25/2016 2.00 PROD1 CASING CIRC P Circ BU while recip&rotate @ 300 8,812.0 8,812.0 08:30 10:30 GPM and 2876 PSI,90 RPM,6K TQ. PU wt=145k,SO wt=105k. Pumped 960 BBLS. 2/25/2016 2/25/2016 1.25 PROD1 CASING CIRC P Pumped 36 BBLS of 11.9 Hi Vis brine 8,812.0 8,326.0 10:30 11:45 spacer followed by 44 BBLS of 11.9 PPG brine.POOH f/8812 to 8326'MD while pumping 2 BPM and 530 PSI. Pump 5 BBLS per stand laying spacer inside casing while pulling stands. 2/25/2016 2/25/2016 1.00 PROD1 CASING DISP P Displace well to 11.9 PPG NaBr @ 8,326.0 8,326.0 11:45 12.45 300 GPM and 2471 PSI. MW In/Out= 11.9 PPG. 2/25/2016 2/25/2016 0.75 PROD1 CASING OWFF P Blowdown topdrive and monitor well 8,306.0 8,306.0 12:45 13.30 for flow. 2/25/2016 2/25/2016 0.50 PROD1 CASING MPDA P Remove MPD bearing&install trip 8,306.0 8,306.0 13:30 14:00 nipple. 2/25/2016 2/25/2016 3.00 PROD1 CASING TRIP P POOH f/8306'to 397'MD. 8,306.0 397.0 14:00 17:00 2/25/2016 2/25/2016 0.25 PROD1 CASING OWFF P Monitor well for flow. Static 397.0 397.0 17:00 17:15 2/25/2016 2/25/2016 2.25 PROD1 CASING BHAH P Lay down BHA#4. Remove RA 397.0 0.0 17:15 19:30 Source 2/25/2016 2/25/2016 0.50 PROD1 CASING BHAH P Clean&Clear Floor 0.0 0.0 19:30 20:00 2/25/2016 2/25/2016 1.00 COMPZN WHDBOP BOPE P Pull wear ring&install test plug. RU 0.0 0.0 20:00 21:00 test equipment 2/25/2016 2/26/2016 3.00 COMPZN WHDBOP BOPE P Perform Bi-weekly BOPE.Witnessed 0.0 0.0 21.00 00:00 by AOGCC inspector Lou Grimaldi.All BOPE tests to 250 psi low and 3500 psi high with exception of manual operated&superchoke tested to 250/2000 psi, held f/5 minutes, charted.Tested annular and both rams w/both 3-1/2"and 4-1/2"test joints.Electrician tested gas alarms. Top and bottom pipe rams have 2-7/8" x 5-1/2"variable.Tested choke manifold, IBOP's,kill and choke line valves,and all valves in the choke manifold,plus Demco valve isolating mud pumps on the kill line.Checked Pit volume totals-OK. Koomey test:Accumulator 3000 psi, manifold 1500 psi, 1600 psi after closing.200 psi build up in 20 seconds,full charge 121 seconds. Closing times:Annular 28 seconds, upper pipe rams 18 seconds, Blind/shear rams 24 seconds,Lower pipe rams 18 seconds,choke HCR 2 seconds,Kill HCR 2 seconds.6 nitrogen bottles average pressure= 1795 psi. Page 33/37 Report Printed: 3/14/2016 • • . ,66. _ ,, Operations Summary (with Timelog Depths) r:'613.L.,,.4,,,,: .:,".,....:.1:!:, : 2S-03 ConacoPhillips tLxka 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) 2/26/2016 2/26/2016 2.00 COMPZN WHDBOP BOPE P Continue testing BOPE. 0.0 0.0 00:00 02:00 2/26/2016 2/26/2016 1.00 COMPZN WHDBOP BOPE P RD Testing equipment,pull test plug 0.0 0.0 02:00 03:00 and run wear ring. 2/26/2016 2/26/2016 1.50 COMPZN CASING RURD P Rig up liner running wquipment. 0.0 0.0 03:00 04:30 2/26/2016 2/26/2016 9.00 COMPZN CASING RUNL P RIH with shoe track. Check floats/OK. 0.0 8,086.0 04:30 13:30 Continue to 8086'MD making up 4- 1/2"Hydril 363 connections to 3.8K TQ.Fill pipe on the ply and top off every 10 joints. 2/26/2016 2/26/2016 1.25 COMPZN CASING OTHR P Make up Baker liner hanger and seal 8,086.0 8,086.0 13:30 14:45 bore assembly 2/26/2016 2/26/2016 0.25 COMPZN CASING CIRC P Pick up 1 stand of DP and break 8,086.0 8,086.0 14:45 15:00 circulation. 2/26/2016 2/26/2016 0.50 COMPZN CASING RUNL P Run in hole with liner of 4"drillpipe f/ 8,086.0 8,807.0 15:00 15:30 8086'to 8807'MD. 2/26/2016 2/26/2016 0.75 COMPZN CASING MPDA P Remove trip nipple and install MPD 8,807.0 8,807.0 15:30 16:15 bearing. 2/26/2016 2/26/2016 2.25 COMPZN CASING DISP P Displace well to 10.3 PPG FlowThru 8,807.0 8,807.0 16:15 18:30 mud by pumping 50 BBL high vis spacer @ 5 BPM followed by 393 BBLS mud. 2/26/2016 2/26/2016 0.50 COMPZN CASING CIRC P Establish circulation below RCD and 8,807.0 8,838.0 18:30 19:00 get well parameters. 5 RPM,5.5K TQ. PU wt=125k,SO wt=89k. ROT= 100k. 10 RPM,6K TO. RIH to 8838' MD. 2/26/2016 2/27/2016 5.00 COMPZN CASING RUNL P RIH w/4-1/2"liner on drillpipe 8,838.0 11,298.0 19:00 00:00 stripping thru RCD maintiaining 420 PSI f/8838'-11298'MD. 2/27/2016 2/27/2016 10.25 COMPZN CASING RUNL P Continue to RIH w/4-1/2"liner on 11,298.0 16,733.0 00:00 10:15 drillpipe stripping thru RCD maintiaining 420 PSI f/11298'-16745' MD. Pull up to setting depth of 16733' MD. PU= 195K,SO=80K. 2/27/2016 2/27/2016 3.75 COMPZN CASING CIRC P Establish circulation rate staging 16,733.0 8,731.0 10:15 14:00 from.5 BPM @ 736 PSI, 1 BPM @ 801 PSI, 1.5 BPM @ 840 PSI,2 BPM @ 816 PSI. Drop 1.5"WIV ball and circ down @ 2.5 BPM @ 750 PSI. With ball on seat pres up to 1250 PSI for 4 min,increase to 2500 PSI and set Baker Liner hanger. Slack off to 70 K hook load and verify hanger set. Increase pressure to 4300 PSI for 5 minutes. Bleed pres and PU to 165K free wt and pull running tool dogs out. Rotate @ 15 RPM,5.5K TQ, 140K ROT wt and slack off setting down 35K. Saw surface indication of shear. PU to 165K free wt and release from liner top. 2/27/2016 2/27/2016 0.25 COMPZN CASING PRTS P Close annular and PT annulus and 8,731.0 8,731.0 14:00 14:15 liner top packer to 3000 PSI for 10 min,charted. 2/27/2016 2/27/2016 0.75 COMPZN WELLPR STRP P POOH to 8637 and rack back 1 stand. 8,731.0 8,637.0 14:15 15:00 RU to circulate. Page 34/37 Report Printed: 3/14/2016 • • , • ,., 4046 .7„, , .. ':t1i,N614 L,,' ,n.4:.:- 1:,,1?..„ Operations Summary (with Timelog Depths) 4,,,,-,44:7.- 2S-03 Canoc hiitIips 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) 2/27/2016 2/27/2016 2.00 COMPZN WELLPR DISP P Displace well to seawater by pumping 8,637.0 8,637.0 15:00 17:00 a 50 BBL.High Vis spacer ahead. Pumped 362 BBLs of seawater. 2/27/2016 2/27/2016 0.50 COMPZN WELLPR OWFF P Monitor well for 30 minutes. 8,637.0 8,637.0 17:00 17:30 2/27/2016 2/27/2016 0.75 COMPZN WELLPR MPDA P Pull MPD bearing and install trip 8,637.0 8,637.0 17:30 18:15 nipple. 2/27/2016 2/27/2016 0.50 COMPZN WELLPR SVRG P Service topdrive and blocks. 8,637.0 8,637.0 18:15 18:45 2/27/2016 2/28/2016 5.25 COMPZN WELLPR PULD P POOH laying down 54 joints of 4" 8,637.0 3,410.0 18:45 00:00 heavyweight DP. Lay down 114 joints of 4"drillpipe. 2/28/2016 2/28/2016 3.75 COMPZN WELLPR PULD P Cont.POOH laying down 108 joints of 3,410.0 0.0 00:00 03:45 4"DP. Lay down Liner running tool. 2/28/2016 2/28/2016 3.75 COMPZN WELLPR 'TRIP P RIH w/82 stands of 4"drillpipe. 0.0 7,750.0 03:45 07:30 2/28/2016 2/28/2016 1.50 COMPZN WELLPR PULD P POOH w/4"drillpipe laying down 7,750.0 5,505.0 07:30 09:00 doubles. 72 joints total. 2/28/2016 2/28/2016 0.50 COMPZN WELLPR SVRG P Service topdrive,blocks and skate. 5,505.0 5,505.0 09:00 09:30 2/28/2016 2/28/2016 4.75 COMPZN RPCOMP PULD P POOH w/4"drillpipe laying down 5,505.0 0.0 09:30 14:15 doubles and singles. 177 joints total. SIMOPS on expediting 3-1/2" completion handling equipment. 2/28/2016 2/28/2016 0.75 COMPZN RPCOMP PULD P Lay down mule shoe. Pull wear 0.0 0.0 14:15 15:00 bushing.PU stack flushing tool. SIMOPS on expediting 3-1/2" completion handling equipment. 2/28/2016 2/28/2016 0.50 COMPZN RPCOMP RURD P Flush stack w/seawater. 0.0 0.0 15:00 15:30 2/28/2016 2/28/2016 0.50 COMPZN RPCOMP RURD P RU remainder handling equipment 0.0 0.0 15:30 16:00 and control line spool. Verify pipe count and jewelry alignment in shed. 2/28/2016 2/28/2016 1.00 COMPZN RPCOMP PUTB P PJSM. RU and run 3-1/2".L-80, EUE, 0.0 171.0 16:00 17:00 8RD-MOD Upper Completion to 171' MD. 2/28/2016 2/28/2016 1.00 COMPZN RPCOMP PUTB P Install SLB guage and TEC wire. Test 171.0 171.0 17:00 18:00 connections. 2/28/2016 2/28/2016 0.50 COMPZN RPCOMP RURD P Pull PS-21 slips and install master 171.0 171.0 18:00 18:30 bushing. 2/28/2016 2/29/2016 5.50 COMPZN RPCOMP PUTB P Cont.to run 3-1/2". L-80, EUE,8RD- 171.0 3,450.0 18:30 00:00 MOD Upper Completion from 171'MD to 3450'MD. Testing TEC wire every 1000'MD. 2/29/2016 2/29/2016 7.50 COMPZN RPCOMP PUTB P Cont.to run 3-1/2". L-80, EUE,8RD- 3,450.0 8,717.0 00:00 07:30 MOD Upper Completion from 3450' MD to 8717'MD. Testing i-wire every 1000'MD. SIMOPS-Installing diverter knife valve on 2S-11. 2/29/2016 2/29/2016 0.50 COMPZN RPCOMP PUTB P Locate into liner top @ 8718'MD and 8,717.0 8,713.0 07:30 08:00 observed shear of locator sub. PU= 100K,SO=81K. Pull up to 8718'MD and lay down JT#270. RU to circ inhibited brine. SIMOPS-Cont, installing diverter on 2S-11. Page 35/37 Report Printed: 3/14/2016 • Operations Summary (with Timelog Depths) 2S-03 ccnocnPhilhps l 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) 2/29/2016 2/29/2016 2.25 COMPZN RPCOMP CIRC P Establish circulation @ 3 BPM,305 8,713.0 8,713.0 08:00 10:15 PSI and pump 15 BBL's of corrosion inhibited brine followed by 75 BBLs of 8.5 PPG seawater. U-tube back 7 BBLs. 2/29/2016 2/29/2016 2.00 COMPZN RPCOMP HOSO P POOH and LD joints#269,#268 and 8,713.0 8,715.0 10:15 12:15 #267. PU 6.16'and 6.25'pups,x- over,4-1/2"IBT joint and make up to hanger. Terminate i-wire to hanger. Land hanger into tubing head w/SO= 85K. Run in lock down screws and torque same. 2/29/2016 2/29/2016 1.00 COMPZN RPCOMP PRTS P Pressure test upper and lower hanger 8,715.0 8,715.0 12:15 13:15 seals to 5000 PSI,witnessed. 2/29/2016 2/29/2016 2.25 COMPZN WHDBOP THGR P Drop ball and rod. Pump down tubing 8,715.0 8,715.0 13:15 15:30 and set packer. Test tubing to 3500 PSI for 30 min charted. Pump down IA and test to 3500 for 30 min charted. Bleed IA then tubing pres to zero. Pump down IA to 2000 PSI and shear SOV. Circulate©1.5 BPM, 130 PSI to verify. 2/29/2016 2/29/2016 1.25 COMPZN WHDBOP PRTS P Rig down circ equipment,pull landing 8,715.0 8,715.0 15:30 16:45 jt,install BPV w/dry rod, PT BPV f/ below to 2500 PSI f/10 min charted. Bleed pres. 2/29/2016 2/29/2016 0.50 COMPZN WHDBOP OWFF P Blow down injection line while 8,715.0 8,715.0 16:45 17:15 monitoring static well open at IA for 30 min. 2/29/2016 2/29/2016 2.50 COMPZN WHDBOP NUND P ND BOP's. Remove spacer spool& 8,715.0 8,715.0 17:15 19:45 adapter spool. 2/29/2016 2/29/2016 1.00 COMPZN WHDBOP NUND P Clean well head. Run i-wire thru 8,715.0 8,715.0 19:45 20:45 adapter flange and NU adapter flange to tubing head. Install test sub on adapter flange. 2/29/2016 2/29/2016 2.25 COMPZN WHDBOP PRTS P ClWperformed pre-test adapter flange 8,715.0 8,715.0 20:45 23:00 connection to 10000 PSI. Test upper tubing hanger seals and i-wire seals to 250/5000 PSI for 15 minutes, witnessed. 2/29/2016 3/1/2016 1.00 COMPZN WHDBOP NUND P Nipple up 10K CIW tree. 8,715.0 8,715.0 23:00 00:00 3/1/2016 3/1/2016 2.00 COMPZN WHDBOP NUND P Continue nippling up Cameron 10K 8,715.0 00:00 02:00 frac tree. 3/1/2016 3/1/2016 1.25 COMPZN WHDBOP PRTS P Fill tree with diesel,fluid pack all lines. 0.0 0.0 02:00 03:15 Test tree to 250/5000 psi for 15 minutes charted. Isolate rig equipment and Cameron continued to test tree above adapter to 10k psi for 15 minutes witnessed. 3/1/2016 3/1/2016 1.25 COMPZN WHDBOP MPSP P Rig down test equipment,Open 0.0 0.0 03:15 04:30 annulus to verify no pressure,dry rod out TWC(Type'HP'BPV with plug tool) SIMOPS-Off load pits,blow down mud pumps,prep to scope derrick, disconnect pump/pit innerconnects. R/U to pump freeze protect. Page 36/37 Report Printed: 3/14/2016 • • µ Operations Summary (with Timelog Depths) 0 2S-03 Conihps k.x4a Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Tme Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/1/2016 3/1/2016 1.50 COMPZN WHDBOP FRZP P Freeze protect well with 75 bbl LEPD 0.0 0.0 04:30 06:00 with rig injection pump @ 1.5 bpm,0- 1%flow out, 1425 psi.Pumping down annulus 1230 psi,taking returns out tubing 110 psi.FCP=1530 psi.Shut in and bleed off injection pump,allow diesel to U-tube for 1 hr. Bleed tubing to 0-psi,rig down hoses. SIMOPS-Bridle up to scope and scope derrick. 3/1/2016 3/1/2016 0.25 COMPZN WHDBOP MPSP P Dry rod in type'H'BPV as per 0.0 0.0 06:00 06:15 Cameron. SIMOPS-Blow down steam to rig floor. 3/1/2016 3/1/2016 1.25 DEMOB MOVE RURD P Bridle down, pin blocks to top drive 0.0 0.0 06:15 07.30 and secure for layover.Unspool 10 wraps from drawworks,pull excess line from deadman side of blocks. Swap power from to moving generators. SIMOPS -Install blank flanges on IA/ OA,install tree gauges. 3/1/2016 3/1/2016 1.50 DEMOB MOVE RURD P Prep and secure derrick for layover, lift 0.0 0.0 07:30 09:00 C-section, lower cattle shute,unplug electrical innerconnects. Rig Release @ 09:00 hrs. Page 37/37 Report Printed: 3/14/2016 • • NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-03 2S-03 Definitive Survey Report 24 February, 2016 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: 120+39.64 @ 159.64usft(D25) Well: 2S-03 North Reference: True Wellbore: 2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03 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-03 Well Position +N/-S 0.00 usft Northing: 5,930,023.62 usfl Latitude: 70° 13'11.933 N +E/-W 0.00 usft Easting: 481,250.32 usfl Longitude: 150°9'4.542 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 120.00 usft Wellbore 2S-03 Magnetics Model Name Sample Date Declination Dip Angie Field Strength; BGGM2015 2/1/2016 18.37 80.86 57,485 Design 2S-03 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 10,561.36 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft)' (usft)'. (usft)'' (°)', 39.64 0.00 0.00 143.35 Survey Program Date 2/2 412 0 1 6 From To (usft) (usft)" Survey(Wellbore) Tool Name Description' ` Survey Date 99.00 1,031.00 2S-03 Srvy#1 -GYD-GC-SS(2S-03PB1 GYD-GC-SS Gyrodata gyro single shots 1/31/2016 10:2 1,058.15 2,718.88 2S-03 Srvy#2-GMAG(2S-03PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/31/2016 10:::. 2,740.81 2,740.81 2S-03 Srvy#3-Inc+Trend(2S-03PB1) INC+TREND Inclinometer+known azi trend 2/5/2016 9:34. 2,835.17 8,756.84 2S-03 Srvy#4-GMAG(2S-03PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/5/2016 9:38. 8,852.56 8,852.56 2S-03 Srvy#5-Inc+Trend(2S-03PB1) INC+TREND Inclinometer+known azi trend 2/16/2016 9:1, 8,947.89 10,561.36 2S-03 Srvy#6-GMAG(2S-03PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/16/2016 9:11 10,656.01 16,696.12 2S-03 Srvy#7-SLB_MWD+GMAG(2S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/19/2016 1:4; : Map Map Vertical MD Inc Azi TVD TVDSS +N1-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 39.64 0.00 0.00 39.64 -120.00 0.00 0.00 5,930,023.62 481,250.32 0.00 0.00 UNDEFINED 99.00 0.68 307.59 99.00 -60.64 0.21 -0.28 5,930,023.84 481,250.04 1.15 -0.34 GYD-GC-SS(1) 120.40 0.76 307.84 120.40 -39.24 0.38 -0.49 5,930,024.00 481,249.83 0.35 -0.60 GYD-GC-SS(1) 16"x20" 187.00 0.99 308.38 186.99 27.35 1.01 -1.29 5,930,024.63 481,249.04 0.35 -1.58 GYD-GC-SS(1) 279.00 1.43 323.75 278.97 119.33 2.42 -2.59 5,930,026.05 481,247.74 0.59 -3.49 GYD-GC-SS(1) 373.00 2.73 352.26 372.91 213.27 5.59 -3.59 5,930,029.22 481,246.75 1.73 -6.62 GYD-GC-SS(1) 467.00 4.05 3.66 466.74 307.10 11.12 -3.68 5,930,034.75 481,246.68 1.57 -11.12 GYD-GC-SS(1) 560.00 4.75 8.02 559.47 399.83 18.21 -2.93 5,930,041.84 481,247.44 0.83 -16.36 GYD-GC-SS(1) 2124/2018 9:44:05AM Page 2 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: 120+39.64 @ 159.64usft(D25) Well: ;2S-03 North Reference: True Wellbore: 2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03 Database: OAKEDMP2 Map', Map Vertical MD Inc Ali TVD 1VDSS' +N1-S +E►-W Northing Easting DI-8 Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 654.00 5.88 10.82 653.06 493.42 26.79 -1.48 5,930,050.41 481,248.91 1.23 -22.38 GYD-GC-SS(1) 748.00 7.82 21.67 746.39 586.75 37.47 1.78 5,930,061.08 481,252.20 2.47 -29.00 GYD-GC-SS(1) 843.00 9.53 23.20 840.30 680.66 50.70 7.27 5,930,074.30 481,257.72 1.82 -36.34 GYD-GC-SS(1) 937.00 10.63 22.72 932.85 773.21 65.85 13.68 5,930,089.43 481,264.17 1.17 -44.67 GYD-GC-SS(1) 1,031.00 12.43 22.65 1,024.95 865.31 83.19 20.93 5,930,106.75 481,271.46 1.91 -54.25 GYD-GC-SS(1) 1,058.15 13.24 22.22 1,051.42 891.78 88.76 23.23 5,930,112.32 481,273.77 3.00 -57.35 MWD+IFR-AK-CAZ-SC(2) 1,152.92 15.04 22.94 1,143.31 983.67 110.14 32.13 5,930,133.66 481,282.72 1.91 -69.19 MWD+IFR-AK-CAZ-SC(2) 1,247.26 17.39 24.50 1,233.89 1,074.25 134.24 42.75 5,930,157.74 481,293.40 2.53 -82.19 MWD+IFR-AK-CAZ-SC(2) 1,340.99 21.22 26.16 1,322.34 1,162.70 162.22 56.04 5,930,185.68 481,306.76 4.13 -96.71 MWD+IFR-AK-CAZ-SC(2) 1,435.66 24.72 24.77 1,409.49 1,249.85 195.58 71.89 5,930,219.00 481,322.69 3.74 -114.02 MWD+IFR-AK-CAZ-SC(2) 1,530.79 25.79 26.03 1,495.53 1,335.89 232.24 89.31 5,930,255.61 481,340.20 1.26 -133.03 MWD+IFR-AK-CAZ-SC(2) 1,626.16 26.71 26.08 1,581.06 1,421 42 270.13 107.83 5,930,293.46 481,358.82 0.96 -152.38 MWD+IFR-AK-CAZ-SC(2) 1,721.19 27.14 25.69 1,665.79 1,506.15 308.85 126.62 5,930,332.12 481,377.70 0.49 -172.23 MWD+IFR-AK-CAZ-SC(2) 1,815.71 27.42 33.73 1,749.82 1,590.18 346.39 148.06 5,930,369.61 481,399.22 3.91 -189.55 MWD+IFR-AK-CAZ-SC(2) 1,909.84 27.44 39.74 1,833.39 1,673.75 381.10 173.96 5,930,404.25 481,425.21 2.94 -201.94 MWD+IFR-AK-CAZ-SC(2) 2,004.80 25.17 44.51 1,918.52 1,758.88 412.33 202.11 5,930,435.41 481,453.44 3.26 -210.20 MWD+IFR-AK-CAZ-SC(2) 2,099.72 24.63 50.47 2,004.63 1,844.99 439.32 231.52 5,930,462.32 481,482.91 2.70 -214.30 MWD+IFR-AK-CAZ-SC(2) 2,194.87 25.45 63.12 2,090.90 1,931 26 461.20 265.08 5,930,484.11 481,516.52 5.68 -211.83 MWD+IFR-AK-CAZ-SC(2) 2,289.33 27.45 75.16 2,175.53 2,015.89 475.96 304.26 5,930,498.78 481,555.73 6.05 -200.29 MWD+IFR-AK-CAZ-SC(2) 2,383.45 30.15 81.07 2,258.01 2,098.37 485.19 348.59 5,930,507.90 481,600.09 4.17 -181.23 MWD+IFR-AK-CAZ-SC(2) 2,476.89 32.78 84.16 2,337.71 2,178.07 491.41 396.95 5,930,513.99 481,648.45 3.30 -157.36 MWD+IFR-AK-CAZ-SC(2) 2,572.22 32.39 83.70 2,418.04 2,258.40 496.84 448.00 5,930,519.29 481,699.51 0.48 -131.24 MWD+IFR-AK-CAZ-SC(2) 2,666.25 33.43 89.38 2,497.00 2,337.36 499.88 498.95 5,930,522.21 481,750.46 3.46 -103.27 MWD+IFR-AK-CAZ-SC(2) 2,718.88 33.57 90.10 2,540.88 2,381.24 500.01 528.00 5,930,522.27 481,779.51 0.80 -86.04 MWD+IFR-AK-CAZ-SC(2) 2,740.81 33.44 88.91 2,559.17 2,399.53 500.12 540.10 5,930,522.35 481,791.61 3.05 -78.90 INC+TREND(3) 2,781.70 33.89 89.13 2,593.20 2,433.56 500.51 562.77 5,930,522.68 481,814.28 1.15 -65.69 MWD+IFR-AK-CAZ-SC(4) 10 314"x 13-1/2" 2,835.17 34.49 89.40 2,637.43 2,477.79 500.89 592.81 5,930,522.99 481,844.32 1.15 -48.06 MWD+IFR-AK-CAZ-SC(4) 2,929.75 36.21 90.65 2,714.57 2,554.93 500.86 647.53 5,930,522.82 481,899.03 1.97 -15.37 MWD+IFR-AK-CAZ-SC(4) 3,024.24 37.57 93.01 2,790.14 2,630.50 499.03 704.21 5,930,520.85 481,955.70 2.08 19.92 MWD+IFR-AK-CAZ-SC(4) 3,123.14 38.70 94.95 2,867.94 2,708.30 494.78 765.13 5,930,516.44 482,016.60 1.67 59.69 MWD+IFR-AK-CAZ-SC(4) 3,214.24 39.66 97.87 2,938.56 2,778.92 488.34 822.30 5,930,509 86 482,073.76 2.28 98.99 MWD+IFR-AK-CAZ-SC(4) 3,309.20 39.94 100.70 3,011.52 2,851.88 478.53 882.28 5,930,499.91 482,133.70 1.93 142.65 MWD+IFR-AK-CAZ-SC(4) 3,404.39 40.64 103.86 3,084.14 2,924.50 465.43 942.41 5,930,486.66 482,193.79 2.27 189.05 MWD+IFR-AK-CAZ-SC(4) 3,498.42 41.50 108.17 3,155.04 2,995.40 448.37 1,001.75 5,930,469.46 482,253.08 3.15 238.15 MWD+IFR-AK-CAZ-SC(4) 3,593.22 42.17 111.43 3,225.68 3,066.04 426.95 1,061.22 5,930,447.89 482,312.49 2.40 290.84 MWD+IFR-AK-CAZ-SC(4) 3,687.80 42.71 112.59 3,295.48 3,135.84 403.03 1,120.39 5,930,423.82 482,371.60 1.01 345.35 MWD+IFR-AK-CAZ-SC(4) 3,782.58 44.52 112.00 3,364.10 3,204.46 378.23 1,180.88 5,930,398.88 482,432.02 1.96 401.35 MWD+IFR-AK-CAZ-SC(4) 3,876.02 46.63 112.03 3,429.50 3,269.86 353.22 1,242.74 5,930,373.71 482,493.82 2.26 458.34 MWD+IFR-AK-CAZ-SC(4) 3,970.37 49.13 112.04 3,492.77 3,333.13 326.96 1,307.61 5,930,347.30 482,558.61 2.65 518.12 MWD+IFR-AK-CAZ-SC(4) 2/24/2016 9:44:05AM Page 3 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: 120+39.64 @ 159.64usft(D25) Site: " Kuparuk 2S Pad MD Reference: 120+39.64 @ 159.64usft(D25) Well: 2S-03 North Reference: True Wellbore: 2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°!100'), (ft) Survey Tool Name 4,064.96 50.96 111.78 3,553.52 3,393.88 299.91 1,374.88 5,930,320.08 482,625.80 1.95 579.98 MWD+IFR-AK-CAZ-SC(4) 4,159.92 51.08 111.85 3,613.25 3,453.61 272.48 1,443.41 5,930,292.49 482,694.26 0.14 642.89 MWD+IFR-AK-CAZ-SC(4) 4,254.49 51.03 111.77 3,672.70 3,513.06 245.15 1,511.70 5,930,264.99 482,762.47 0.08 705.58 MWD+IFR-AK-CAZ-SC(4) 4,349.76 51.11 111.87 3,732.56 3,572.92 217.61 1,580.50 5,930,237.28 482,831.20 0.12 768.74 MWD+IFR-AK-CAZ-SC(4) 4,444.28 51.03 110.84 3,791.95 3,632.31 190.83 1,648.98 5,930,210.33 482,899.61 0.85 831.10 MWD+IFR-AK-CAZ-SC(4) 4,537.03 51.10 110.83 3,850.24 3,690.60 165.17 1,716.41 5,930,184.51 482,966.96 0.08 891.93 MWD+IFR-AK-CAZ-SC(4) 4,632 40 51.17 109.61 3,910.09 3,750.45 139.51 1,786.08 5,930,158.67 483,036.57 1.00 954.11 MWD+IFR-AK-CAZ-SC(4) 4,726.93 51.25 108.73 3,969.31 3,809.67 115.31 1,855.68 5,930,134.31 483,106.10 0.73 1,015.06 MWD+IFR-AK-CAZ-SC(4) 4,820.81 51.07 107.98 4,028.18 3,868.54 92.28 1,925.08 5,930,111.11 483,175.44 0.65 1,074.96 MWD+IFR-AK-CAZ-SC(4) 4,916.59 51.13 106.93 4,088.33 3,928.69 69.93 1,996.19 5,930,088.58 483,246.48 0.86 1,135.34 MWD+IFR-AK-CAZ-SC(4) 5,010.86 51.21 106.99 4,147.44 3,987.80 48.50 2,066.43 5,930,066.99 483,316.66 0.10 1,194.45 MWD+IFR-AK-CAZ-SC(4) 5,104.99 51.11 108.41 4,206.48 4,046.84 26.22 2,136.27 5,930,044.53 483,386.44 1.18 1,254.03 MWD+IFR-AK-CAZ-SC(4) 5,199.04 51.12 109.40 4,265.52 4,105.88 2.50 2,205.53 5,930,020.64 483,455.64 0.82 1,314.39 MWD+IFR-AK-CAZ-SC(4) 5,294.20 50.66 110.68 4,325.55 4,165.91 -22.80 2,274.90 5,929,995.17 483,524.93 1.15 1,376.09 MWD+IFR-AK-CAZ-SC(4) 5,389.44 50.33 110.32 4,386.13 4,226.49 -48.54 2,343.73 5,929,969.26 483,593.69 0.45 1,437.82 MWD+IFR-AK-CAZ-SC(4) 5,483.64 50.61 110.40 4,446.09 4,286.45 -73.82 2,411.85 5,929,943.82 483,661.74 0.30 1,498.76 MWD+IFR-AK-CAZ-SC(4) 5,578.33 50.43 110.44 4,506.29 4,346.65 -99.32 2,480.34 5,929,918.15 483,730.16 0.19 1,560.10 MWD+IFR-AK-CAZ-SC(4) 5,673.16 50.65 110.27 4,566.56 4,406.92 -124.78 2,548.98 5,929,892.52 483,798.73 0.27 1,621.51 MWD+IFR-AK-CAZ-SC(4) 5,768.21 50.23 110.52 4,627.10 4,467 46 -150.32 2,617.67 5,929,866.81 483,867.35 0.49 1,682.99 MWD+IFR-AK-CAZ-SC(4) 5,862.27 50.51 111.83 4,687.09 4,527.45 -176.49 2,685.22 5,929,840.48 483,934.83 1.11 1,744.30 MWD+IFR-AK-CAZ-SC(4) 5,957.06 50.54 112.78 4,747.36 4,587.72 -204.26 2,752.91 5,929,812.54 484,002.44 0.77 1,806.99 MWD+IFR-AK-CAZ-SC(4) 6,052.13 50.63 112.23 4,807.72 4,648.08 -232.37 2,820.76 5,929,784.27 484,070.22 0.46 1,870.04 MWD+IFR-AK-CAZ-SC(4) 6,146.51 50.47 113.62 4,867.69 4,708.05 -260.76 2,887.88 5,929,755.72 484,137.26 1.15 1,932.88 MWD+IFR-AK-CAZ-SC(4) 6,240.39 50.88 115.73 4,927.19 4,767.55 -291.07 2,953.86 5,929,725.24 484,203.16 1.79 1,996.59 MWD+IFR-AK-CAZ-SC(4) 6,335.37 51.43 118.56 4,986.77 4,827.13 -324.82 3,019.68 5,929,691.33 484,268.88 2.39 2,062.95 MWD+IFR-AK-CAZ-SC(4) 6,430.02 52.39 121.19 5,045.16 4,885.52 -361.93 3,084.25 5,929,654.06 484,333.36 2.41 2,131.27 MWD+IFR-AK-CAZ-SC(4) 6,524.27 52.99 124.07 5,102.30 4,942.66 -402.35 3,147.37 5,929,613.49 484,396.37 2.51 2,201.37 MWD+IFR-AK-CAZ-SC(4) 6,619.02 53.30 126.46 5,159.13 4,999.49 -446.12 3,209.26 5,929,569.57 484,458.15 2.04 2,273.43 MWD+IFR-AK-CAZ-SC(4) 6,714.34 53.81 129.69 5,215.77 5,056.13 -493.40 3,269.61 5,929,522.14 484,518.37 2.78 2,347.38 MWD+IFR-AK-CAZ-SC(4) 6,807.69 54.01 131.52 5,270.76 5,111.12 -542.50 3,326.87 5,929,472.91 484,575.51 1.60 2,420.95 MWD+IFR-AK-CAZ-SC(4) 6,903.31 54.07 133.10 5,326.91 5,167.27 -594.60 3,384.11 5,929,420.68 484,632.60 1.34 2,496.91 MWD+IFR-AK-CAZ-SC(4) 6,998.16 54.04 134.47 5,382.59 5,222.95 -647.73 3,439.54 5,929,367.41 484,687.90 1.17 2,572.63 MWD+IFR-AK-CAZ-SC(4) 7,092.00 53.65 137.03 5,437.96 5,278.32 -701.99 3,492.41 5,929,313.03 484,740.63 2.24 2,647.72 MWD+IFR-AK-CAZ-SC(4) 7,187.22 53.65 139.87 5,494.41 5,334.77 -759.37 3,543.26 5,929,255.52 484,791.34 2.40 2,724.12 MWD+IFR-AK-CAZ-SC(4) 7,281.99 53.38 143.30 5,550.77 5,391.13 -819.06 3,590.60 5,929,195.73 484,838.52 2.92 2,800.26 MWD+IFR-AK-CAZ-SC(4) 7,376.46 53.33 146.73 5,607.16 5,447.52 -881.14 3,634.05 5,929,133.54 484,881.81 2.91 2,876.00 MWD+IFR-AK-CAZ-SC(4) 7,470.40 54.01 150.28 5,662.83 5,503.19 -945.66 3,673.57 5,929,068.93 484,921.16 3.13 2,951.36 MWD+IFR-AK-CAZ-SC(4) 7,565.20 54.64 153.51 5,718.12 5,558.48 -1,013.58 3,709.83 5,929,000.93 484,957.25 2.85 3,027.49 MWD+IFR-AK-CAZ-SC(4) 7,659.92 54.58 156.32 5,772.99 5,613.35 -1,083.50 3,742.56 5,928,930.93 484,989.81 2.42 3,103.13 MWD+IFR-AK-CAZ-SC(4) 7,755.31 54.76 158.29 5,828.15 5,668.51 -1,155.29 3,772.58 5,928,859.07 485,019.65 1.70 3,178.65 MWD+IFR-AK-CAZ-SC(4) 2/24/2016 9:44:05AM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: 120+39.64 @ 159.64usft(D25) Well: 2S-03 North Reference: True Wellbore: 2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03 Database: OAKEDMP2 Survey Map, Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,851.51 54.93 159.69 5,883.55 5,723.91 -1,228.72 3,800.78 5,928,785.59 485,047.66 1.20 3,254.39 MWD+IFR-AK-CAZ-SC(4) 7,944.13 57.65 160.82 5,934.95 5,775.31 -1,301.23 3,826.80 5,928,713.02 485,073.49 3.11 3,328.10 MWD+IFR-AK-CAZ-SC(4) 8,037.87 61.20 162.16 5,982.62 5,822.98 -1,377.75 3,852.40 5,928,636.44 485,098.90 3.98 3,404.78 MWD+IFR-AK-CAZ-SC(4) 8,134.96 65.11 163.68 6,026.46 5,866.82 -1,460.54 3,877.81 5,928,553.59 485,124.11 4.26 3,486.38 MWD+IFR-AK-CAZ-SC(4) 8,227.49 67.60 165.32 6,063.57 5,903.93 -1,542.21 3,900.45 5,928,471.87 485,146.54 3.14 3,565.42 MWD+IFR-AK-CAZ-SC(4) 8,321.13 69.49 167.84 6,097.82 5,938.18 -1,626.98 3,920.66 5,928,387.07 485,166.54 3.22 3,645.49 MWD+IFR-AK-CAZ-SC(4) 8,416.49 71.30 170.93 6,129.83 5,970.19 -1,715.26 3,937.20 5,928,298.76 485,182.85 3.59 3,726.19 MWD+IFR-AK-CAZ-SC(4) 8,511.46 72.15 172.50 6,159.61 5,999.97 -1,804.49 3,950.19 5,928,209.50 485,195.62 1.81 3,805.54 MWD+IFR-AK-CAZ-SC(4) 8,606.43 72.76 174.79 6,188.24 6,028.60 -1,894.48 3,960.21 5,928,119.50 485,205.42 2.39 3,883.72 MWD+IFR-AK-CAZ-SC(4) 8,701 25 73.21 177.13 6,215.99 6,056.35 -1,984.92 3,966.59 5,928,029.05 485,211.58 2.41 3,960.09 MWD+IFR-AK-CAZ-SC(4) 8,756.84 74.39 178.49 6,231.50 6,071.86 -2,038.26 3,968.63 5,927,975.71 485,213.48 3.17 4,004.11 MWD+IFR-AK-CAZ-SC(4) 8,826.90 74.24 179.92 6,250.44 6,090.80 -2,105.70 3,969.56 5,927,908.27 485,214.25 1.98 4,058.78 INC+TREND(5) 7-5/8 x 9-7/8 by 11" 8,852.56 74.19 180.45 6,257.42 6,097.78 -2,130.39 3,969.48 5,927,883.58 485,214.11 1.98 4,078.54 INC+TREND(5) 8,947.89 75.01 181.42 6,282.74 6,123.10 -2,222.29 3,967.98 5,927,791.70 485,212.38 1.30 4,151.37 MWD+IFR-AK-CAZ-SC(6) 9,042.78 75.22 183.94 6,307.12 6,147.48 -2,313.88 3,963.69 5,927,700.13 485,207.86 2.58 4,222.31 MWD+IFR-AK-CAZ-SC(6) 9,137.59 76.65 185.80 6,330.16 6,170.52 -2,405.51 3,955.88 5,927,608.53 485,199.82 2.43 4,291.16 MWD+IFR-AK-CAZ-SC(6) 9,232.40 80.93 185.26 6,348.59 6,188.95 -2,498.06 3,946.92 5,927,516.01 485,190.64 4.55 4,360.07 MWD+IFR-AK-CAZ-SC(6) 9,326.85 84.53 184.89 6,360.54 6,200.90 -2,591.37 3,938.64 5,927,422.73 485,182.12 3.83 4,429.99 MWD+IFR-AK-CAZ-SC(6) 9,421.97 88.76 186.02 6,366.10 6,206.46 -2,685.87 3,929.61 5,927,328.26 485,172.86 4.60 4,500.43 MWD+IFR-AK-CAZ-SC(6) 9,519.33 92.15 185.87 6,365.33 6,205.69 -2,782.69 3,919.53 5,927,231.48 485,162.54 3.49 4,572.09 MWD+IFR-AK-CAZ-SC(6) 9,612.10 91.39 188.72 6,362.46 6,202.82 -2,874.65 3,907.76 5,927,139.55 485,150.54 3.18 4,638.85 MWD+IFR-AK-CAZ-SC(6) 9,707.04 92.46 191.75 6,359.27 6,199.63 -2,968.02 3,890.90 5,927,046.24 485,133.45 3.38 4,703.70 MWD+IFR-AK-CAZ-SC(6) 9,801.77 92.57 195.88 6,355.11 6,195.47 -3,059.90 3,868.31 5,926,954.42 485,110.63 4.36 4,763.94 MWD+IFR-AK-CAZ-SC(6) 9,896.56 92.10 200.03 6,351.25 6,191.61 -3,149.98 3,839.11 5,926,864.43 485,081.22 4.40 4,818.79 MWD+IFR-AK-CAZ-SC(6) 9,992.30 89.33 200.03 6,350.06 6,190.42 -3,239.91 3,806.33 5,926,774.58 485,048.21 2.89 4,871.38 MWD+IFR-AK-CAZ-SC(6) 10,086.92 88.93 198.88 6,351.49 6,191.85 -3,329.12 3,774.82 5,926,685.47 485,016.48 1.29 4,924.14 MWD+IFR-AK-CAZ-SC(6) 10,181.40 88.83 197.79 6,353.34 6,193.70 -3,418.78 3,745.10 5,926,595.88 484,986.55 1.16 4,978.35 MWD+IFR-AK-CAZ-SC(6) 10,277.03 88.49 196.66 6,355.58 6,195.94 -3,510.10 3,716.79 5,926,504.65 484,958.02 1.23 5,034.72 MWD+IFR-AK-CAZ-SC(6) 10,371.90 88.07 196.20 6,358.42 6,198.78 -3,601.05 3,689.97 5,926,413.77 484,930.97 0.66 5,091.68 MWD+IFR-AK-CAZ-SC(6) 10,466.92 87.39 196.30 6,362.19 6,202.55 -3,692.20 3,663.40 5,926,322.70 484,904.18 0.72 5,148.96 MWD+IFR-AK-CAZ-SC(6) 10,561.36 87.32 195.65 6,366.54 6,206.90 -3,782.90 3,637.44 5,926,232.07 484,877.99 0.69 5,206.23 MWD+IFR-AK-CAZ-SC(6) 10,656.01 87.63 197.44 6,370.71 6,211.07 -3,873.54 3,610.51 5,926,141.51 484,850.84 1.92 5,262.89 MWD+IFR-AK-CAZ-SC(7) 10,676.59 87.95 198.16 6,371.51 6,211.87 -3,893.12 3,604.23 5,926,121.95 484,844.51 3.83 5,274.85 MWD+IFR-AK-CAZ-SC(7) 10,731.24 87.40 197.04 6,373.73 6,214.09 -3,945.17 3,587.72 5,926,069.95 484,827.87 2.28 5,306.75 MWD+IFR-AK-CAZ-SC(7) 10,770.72 86.42 197.40 6,375.85 6,216.21 -3,982.82 3,576.05 5,926,032.32 484,816.11 2.64 5,330.00 MWD+IFR-AK-CAZ-SC(7) 10,867.03 86.22 201.11 6,382.04 6,222.40 -4,073.54 3,544.36 5,925,941.69 484,784.20 3.85 5,383.87 MWD+IFR-AK-CAZ-SC(7) 10,961.97 87.21 203.25 6,387.48 6,227.84 -4,161.30 3,508.58 5,925,854.03 484,748.20 2.48 5,432.93 MWD+IFR-AK-CAZ-SC(7) 11,055.87 90.67 205.48 6,389.22 6,229.58 -4,246.81 3,469.85 5,925,768.63 484,709.27 4.38 5,478.42 MWD+IFR-AK-CAZ-SC(7) 11,150.83 92.32 205.35 6,386.74 6,227.10 -4,332.55 3,429.11 5,925,683.00 484,668.32 1.74 5,522.90 MWD+IFR-AK-CAZ-SC(7) 2/24/2016 9:44:05AM Page 5 COMPASS 5000.1 Build 74 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: "120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: 120+39.64 @ 159.64usft(D25) Well: 2S-03 North Reference: True Wellbore: 2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03 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) (/100') (ft) Survey Tool Name 11,244.08 92.15 205.27 6,383.10 6,223.46 -4,416.78 3,389.28 5,925,598.87 484,628.28 0.20 5,566.71 MWD+IFR-AK-CAZ-SC(7) 11,338.63 89.98 204.52 6,381.34 6,221.70 -4,502.52 3,349.49 5,925,513.24 484,588.28 2.43 5,611.75 MWD+IFR-AK-CAZ-SC(7) 11,433.70 88.79 201.15 6,382.36 6,222.72 -4,590.12 3,312.60 5,925,425.74 484,551.18 3.76 5,660.02 MWD+IFR-AK-CAZ-SC(7) 11,529.43 89.43 197.69 6,383.85 6,224.21 -4,680.38 3,280.78 5,925,335.57 484,519.14 3.68 5,713.45 MWD+IFR-AK-CAZ-SC(7) 11,623.50 89.56 194.59 6,384.68 6,225.04 -4,770.73 3,254.63 5,925,245.29 484,492.77 3.30 5,770.33 MWD+IFR-AK-CAZ-SC(7) 11,718.25 89.81 192.67 6,385.20 6,225.56 -4,862.81 3,232.31 5,925,153.28 484,470.22 2.04 5,830.88 MWD+IFR-AK-CAZ-SC(7) 11,813.16 88.18 191.81 6,386.87 6,227.23 -4,955.54 3,212.19 5,925,060.61 484,449.87 1.94 5,893.28 MWD+IFR-AK-CAZ-SC(7) 11,909.04 88.36 191.70 6,389.76 6,230.12 -5,049.37 3,192.66 5,924,966.84 484,430.12 0.22 5,956.91 MWD+IFR-AK-CAZ-SC(7) 12,003.80 88.19 193.00 6,392.61 6,232.97 -5,141.89 3,172.41 5,924,874.38 484,409.63 1.38 6,019.05 MWD+IFR-AK-CAZ-SC(7) 12,096.90 87.70 194.18 6,395.95 6,236.31 -5,232.32 3,150.54 5,924,784.01 484,387.55 1.37 6,078.56 MWD+IFR-AK-CAZ-SC(7) 12,192.51 89.27 195.64 6,398.48 6,238.84 -5,324.68 3,125.95 5,924,691.73 484,362.73 2.24 6,137.99 MWD+IFR-AK-CAZ-SC(7) 12,287.54 88.32 196.32 6,400.48 6,240.84 -5,416.01 3,099.80 5,924,600.46 484,336.35 1.23 6,195.66 MWD+IFR-AK-CAZ-SC(7) 12,383.45 88.95 199.63 6,402.76 6,243.12 -5,507.20 3,070.21 5,924,509.36 484,306.54 3.51 6,251.16 MWD+IFR-AK-CAZ-SC(7) 12,478.63 89.84 199.82 6,403.77 6,244.13 -5,596.79 3,038.09 5,924,419.86 484,274.20 0.96 6,303.87 MWD+IFR-AK-CAZ-SC(7) 12,573.07 89.93 199.96 6,403.96 6,244.32 -5,685.60 3,005.96 5,924,331.14 484,241.85 0.18 6,355.95 MWD+IFR-AK-CAZ-SC(7) 12,667.82 91.24 200.21 6,402.99 6,243.35 -5,774.58 2,973.42 5,924,242.25 484,209.10 1.41 6,407.92 MWD+IFR-AK-CAZ-SC(7) 12,762.82 91.59 198.98 6,400.65 6,241.01 -5,864.05 2,941.58 5,924,152.87 484,177.03 1.35 6,460.70 MWD+IFR-AK-CAZ-SC(7) 12,857.98 91.48 198.00 6,398.10 6,238.46 -5,954.26 2,911.41 5,924,062.74 484,146.64 1.04 6,515.08 MWD+IFR-AK-CAZ-SC(7) 12,952.68 92.38 197.28 6,394.91 6,235.27 -6,044.46 2,882.73 5,923,972.62 484,117.74 1.22 6,570.32 MWD+IFR-AK-CAZ-SC(7) 13,047.58 91.94 193.03 6,391.33 6,231.69 -6,135.97 2,857.94 5,923,881.18 484,092.73 4.50 6,628.96 MWD+IFR-AK-CAZ-SC(7) 13,141.13 89.50 189.18 6,390.15 6,230.51 -6,227.74 2,839.93 5,923,789.47 484,074.49 4.87 6,691.83 MWD+IFR-AK-CAZ-SC(7) 13,236.33 87.48 186.50 6,392.66 6,233.02 -6,322.00 2,826.95 5,923,695.25 484,061.28 3.52 6,759.72 MWD+IFR-AK-CAZ-SC(7) 13,332.50 88.77 186.41 6,395.81 6,236.17 -6,417.51 2,816.14 5,923,599.78 484,050.24 1.34 6,829.90 MWD+IFR-AK-CAZ-SC(7) 13,427.95 88.67 185.98 6,397.94 6,238.30 -6,512.38 2,805.85 5,923,504.94 484,039.70 0.46 6,899.87 MWD+IFR-AK-CAZ-SC(7) 13,521.41 88.40 184.44 6,400.33 6,240.69 -6,605.42 2,797.36 5,923,411.93 484,030.99 1.67 6,969.46 MWD+IFR-AK-CAZ-SC(7) 13,616.06 88.14 184.70 6,403.19 6,243.55 -6,699.72 2,789.82 5,923,317.66 484,023.22 0.39 7,040.62 MWD+IFR-AK-CAZ-SC(7) 13,710.58 89.46 188.26 6,405.17 6,245.53 -6,793.60 2,779.16 5,923,223.81 484,012.32 4.02 7,109.58 MWD+IFR-AK-CAZ-SC(7) 13,805.91 90.70 190.81 6,405.03 6,245.39 -6,887.60 2,763.37 5,923,129.86 483,996.30 2.97 7,175.58 MWD+IFR-AK-CAZ-SC(7) 13,900.16 91.17 193.44 6,403.50 6,243.86 -6,979.73 2,743.58 5,923,037.79 483,976.28 2.83 7,237.68 MWD+IFR-AK-CAZ-SC(7) 13,995.25 89.31 189.76 6,403.10 6,243.46 -7,072.86 2,724.46 5,922,944.72 483,956.94 4.34 7,300.99 MWD+IFR-AK-CAZ-SC(7) 14,090.63 89.54 188.91 6,404.05 6,244.41 -7,166.97 2,708.99 5,922,850.66 483,941.23 0.92 7,367.27 MWD+IFR-AK-CAZ-SC(7) 14,184.95 87.80 187.34 6,406.24 6,246.60 -7,260.31 2,695.67 5,922,757.36 483,927.68 2.48 7,434.21 MWD+IFR-AK-CAZ-SC(7) 14,280.00 87.90 187.25 6,409.81 6,250.17 -7,354.52 2,683.60 5,922,663.18 483,915.38 0.14 7,502.60 MWD+IFR-AK-CAZ-SC(7) 14,376.13 85.97 190.37 6,414.95 6,255.31 -7,449.37 2,668.91 5,922,568.39 483,900.45 3.81 7,569.93 MWD+IFR-AK-CAZ-SC(7) 14,470.87 87.50 195.44 6,420.35 6,260.71 -7,541.53 2,647.79 5,922,476.28 483,879.11 5.58 7,631.27 MWD+IFR-AK-CAZ-SC(7) 14,564.13 89.21 200.48 6,423.03 6,263.39 -7,630.18 2,619.05 5,922,387.72 483,850.15 5.70 7,685.24 MWD+IFR-AK-CAZ-SC(7) 14,659.33 88.74 199.03 6,424.73 6,265.09 -7,719.76 2,586.88 5,922,298.23 483,817.76 1.60 7,737.91 MWD+IFR-AK-CAZ-SC(7) 14,754.81 89.12 197.48 6,426.52 6,266.88 -7,810.41 2,556.98 5,922,207.66 483,787.64 1.67 7,792.80 MWD+IFR-AK-CAZ-SC(7) 14,848.40 89.08 194.78 6,427.99 6,268.35 -7,900.30 2,530.98 5,922,117.84 483,761.42 2.88 7,849.41 MWD+IFR-AK-CAZ-SC(7) 14,944.18 89.08 192.03 6,429.52 6,269.88 -7,993.45 2,508.78 5,922,024.76 483,738.99 2.87 7,910.90 MWD+IFR-AK-CAZ-SC(7) 2/24/2016 9:44:05AM Page 6 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: 120+39.64 @ 159.64usft(D25) Well: 2S-03 North Reference: True Wellbore: 2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +Ni-S +Ei-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°1100) (ft) Survey Tool Name 15,040.54 89.32 190.61 6,430.87 6,271.23 -8,087.92 2,489.87 5,921,930.34 483,719.85 1.49 7,975.41 MWD+IFR-AK-CAZ-SC(7) 15,132.00 89.29 190.42 6,431.98 6,272.34 -8,177.84 2,473.18 5,921,840.47 483,702.94 0.21 8,037.59 MWD+IFR-AK-CAZ-SC(7) 15,224.25 88.98 192.17 6,433.37 6,273.73 -8,268.29 2,455.11 5,921,750.08 483,684.65 1.93 8,099.38 MWD+IFR-AK-CAZ-SC(7) 15,316.87 89.29 194.17 6,434.77 6,275.13 -8,358.46 2,434.02 5,921,659.97 483,663.33 2.18 8,159.13 MWD+IFR-AK-CAZ-SC(7) 15,409.64 89.63 196.87 6,435.64 6,276.00 -8,447.84 2,409.20 5,921,570.67 483,638.29 2.93 8,216.03 MWD+IFR-AK-CAZ-SC(7) 15,501.00 89.74 195.82 6,436.15 6,276.51 -8,535.50 2,383.49 5,921,483.08 483,612.36 1.16 8,271.02 MWD+IFR-AK-CAZ-SC(7) 15,595.47 89.53 196.59 6,436.75 6,277.11 -8,626.21 2,357.12 5,921,392.44 483,585.78 0.84 8,328.07 MWD+IFR-AK-CAZ-SC(7) 15,688.46 90.01 196.44 6,437.12 6,277.48 -8,715.37 2,330.69 5,921,303.36 483,559.12 0.54 8,383.83 MWD+IFR-AK-CAZ-SC(7) 15,778.27 90.28 196.42 6,436.89 6,277.25 -8,801.51 2,305.29 5,921,217.29 483,533.51 0.30 8,437.78 MWD+IFR-AK-CAZ-SC(7) 15,871.03 89.36 195.54 6,437.19 6,277.55 -8,890.68 2,279.75 5,921,128.19 483,507.75 1.37 8,494.09 MWD+IFR-AK-CAZ-SC(7) 15,961.10 88.98 194.67 6,438.49 6,278.85 -8,977.63 2,256.28 5,921,041.31 483,484.07 1.05 8,549.84 MWD+IFR-AK-CAZ-SC(7) 16,055.33 88.28 195.44 6,440.74 6,281.10 -9,068.60 2,231.81 5,920,950.41 483,459.38 1.10 8,608.22 MWD+IFR-AK-CAZ-SC(7) 16,147.87 88.98 195.97 6,442.96 6,283.32 -9,157.66 2,206.77 5,920,861.42 483,434.12 0.95 8,664.73 MWD+IFR-AK-CAZ-SC(7) 16,240.83 89.64 195.90 6,444.08 6,284.44 -9,247.04 2,181.25 5,920,772.11 483,408.38 0.71 8,721.22 MWD+IFR-AK-CAZ-SC(7) 16,331.08 88.54 194.28 6,445.51 6,285.87 -9,334.16 2,157.76 5,920,685.06 483,384.68 2.17 8,777.10 MWD+IFR-AK-CAZ-SC(7) 16,423.08 85.94 192.86 6,449.94 6,290.30 -9,423.48 2,136.20 5,920,595.80 483,362.90 3.22 8,835.89 MWD+IFR-AK-CAZ-SC(7) 16,514.67 85.62 193.28 6,456.68 6,297.04 -9,512.45 2,115.54 5,920,506.89 483,342.02 0.58 8,894.95 MWD+IFR-AK-CAZ-SC(7) 16,607.53 84.30 192.22 6,464.84 6,305.20 -9,602.67 2,095.13 5,920,416.73 483,321.38 1.82 8,955.15 MWD+1FR-AK-CAZ-SC(7) 16,696.12 79.93 188.81 6,476.99 6,317.35 -9,688.91 2,079.11 5,920,330.54 483,305.15 6.23 9,014.79 MWD+IFR-AK-CAZ-SC(7) 16,760.00 79.93 188.81 6,488.16 6,328.52 -9,751.07 2,069.48 5,920,268.41 483,295.36 0.00 9,058.91 PROJECTED to TD 2/24/2016 9:44:05AM Page 7 COMPASS 5000.1 Build 74 • Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. LI Yes L No I have checked to the best of my ability that the following data is correct: LI Surface Coordinates 0 Declination & Convergence GRS Survey Corrections Survey Tool Codes shped VII,:*3:‹AarZ Dti: WinCent OS.W. Vincent Osara erima-vosafays1t..71,,,L'S SLB DE. CVIV DV.*Nalrwl trf r..11.1, Mike Callahan Client Representative: 24-Feb-20]6- Date- • • NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-03PB1 2S-03 Definitive Survey Report 23 February, 2016 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: Rig: 120+39.64 @ 159.64usft(D25) Well:, 2S-03 North Reference: True Wellbore 2S-03PB1 Survey Calculation Method: Minimum Curvature Design: 2S-03PB1 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-03 Well Position +N/-S 0.00 usft Northing: 5,930,023.62 usfl Latitude: 70°13'11.933 N +EI-W 0.00 usft Easting: 481,250.32 usfl Longitude: 150°9'4.542 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 120.00 usft Wellbore 2S-03PB1 Magnetics Model Name Sample Date" Declination DIP Angie Field"Strength (o) (1 (nT) BGGM2015 2/1/2016 18.37 80.86 57,485 Design 2S-03PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.64 Vertical Section: Depth From(TVD) +NJ-S +E/-W Di tion (usft) (usft) (usft) :.. ) 39.64 0.00 0.00 195.00 Survey Program Date From To (usft) (usft) Survey'(Weiibore) Tool Name Description Survey Date 99.00 1,031.00 2S-03 Srvy#1 -GYD-GC-SS(2S-03PB1 GYD-GC-SS Gyrodata gyro single shots 1/31/2016 10:2 1,058.15 2,718.88 2S-03 Srvy#2-GMAG(2S-03PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/31/2016 10:2 2,740.81 2,740.81 2S-03 Srvy#3-Inc+Trend(2S-03PB1) INC+TREND Inclinometer+known azi trend 2/5/2016 9:34 2,835.17 8,756.84 2S-03 Srvy#4-GMAG(2S-03PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/5/2016 9:38. 8,852.56 8,852.56 2S-03 Srvy#5-Inc+Trend(2S-03PB1) INC+TREND Inclinometer+known azi trend 2/16/2016 9:1. 8,947.89 13,667.30 2S-03 Srvy#6-GMAG(2S-03PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/16/2016 9:11 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usfl) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 39.64 0.00 0.00 39.64 -120.00 0.00 0.00 5,930,023.62 481,250.32 0.00 0.00 UNDEFINED 99.00 0.68 307.59 99.00 -60.64 0.21 -0.28 5,930,023.84 481,250.04 1.15 -0.14 GYD-GC-SS(1) 120.40 0.76 307.84 120.40 -39.24 0.38 -0.49 5,930,024.00 481,249.83 0.35 -0.24 GYD-GC-SS(1) 16"x 2d" 187.00 0.99 308.38 186.99 27.35 1.01 -1.29 5,930,024.63 481,249.04 0.35 -0.64 GYD-GC-SS(1) 279.00 1.43 323.75 278.97 119.33 2.42 -2.59 5,930,026.05 481,247.74 0.59 -1.67 GYD-GC-SS(1) 373.00 2.73 352.26 372.91 213.27 5.59 -3.59 5,930,029.22 481,246.75 1.73 -4.47 GYD-GC-SS(1) 467.00 4.05 3.66 466.74 307.10 11.12 -3.68 5,930,034.75 481,246.68 1.57 -9.79 GYD-GC-SS(1) 560.00 4.75 8.02 559.47 399.83 18.21 -2.93 5,930,041.84 481,247.44 0.83 -16.83 GYD-GC-SS(1) 654.00 5.88 10.82 653.06 493.42 26.79 -1.48 5,930,050.41 481,248.91 1.23 -25.50 GYD-GC-SS(1) 2/23/2016 9:01:28AM Page 2 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: Rig: 120+39.64 @ 159.64usft(D25) Well: 2S-03 North Reference: True Wellbore: 2S-03PB1 Survey Calculation Method: Minimum Curvature Design: 2S-03PB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°{100') (ft) Survey Tool Name 748.00 7.82 21.67 746.39 586.75 37.47 1.78 5,930,061.08 481,252.20 2.47 -36.65 GYD-GC-SS(1) 843.00 9.53 23.20 840.30 680.66 50.70 7.27 5,930,074.30 481,257.72 1.82 -50.86 GYD-GC-SS(1) 937.00 10.63 22.72 932.85 773.21 65.85 13.68 5,930,089.43 481,264.17 1.17 -67.15 GYD-GC-SS(1) 1,031.00 12.43 22.65 1,024.95 865.31 83.19 20.93 5,930,106.75 481,271.46 1.91 -85.77 GYD-GC-SS(1) 1,058.15 13.24 22.22 1,051.42 891.78 88.76 23.23 5,930,112.32 481,273.77 3.00 -91.75 MWD+IFR-AK-CAZ-SC(2) 1,152.92 15.04 22.94 1,143.31 983.67 110.14 32.13 5,930,133.66 481,282.72 1.91 -114.70 MWD+IFR-AK-CAZ-SC(2) 1,247.26 17.39 24.50 1,233.89 1,074.25 134.24 42.75 5,930,157.74 481,293.40 2.53 -140.73 MWD+IFR-AK-CAZ-SC(2) 1,340.99 21.22 26.16 1,322.34 1,162.70 162.22 56.04 5,930,185.68 481,306.76 4.13 -171.20 MWD+IFR-AK-CAZ-SC(2) 1,435.66 24.72 24.77 1,409.49 1,249.85 195.58 71.89 5,930,219.00 481,322.69 3.74 -207.53 MWD+IFR-AK-CAZ-SC(2) 1,530.79 25.79 26.03 1,495.53 1,335.89 232.24 89.31 5,930,255.61 481,340.20 1.26 -247.44 MWD+IFR-AK-CAZ-SC(2) 1,626.16 26.71 26.08 1,581.06 1,421.42 270.13 107.83 5,930,293.46 481,358.82 0.96 -288.84 MWD+IFR-AK-CAZ-SC(2) 1,721.19 27.14 25.69 1,665.79 1,506.15 308.85 126.62 5,930,332.12 481,377.70 0.49 -331.10 MWD+IFR-AK-CAZ-SC(2) 1,815.71 27.42 33.73 1,749 82 1,590.18 346.39 148.06 5,930,369.61 481,399.22 3.91 -372.91 MWD+IFR-AK-CAZ-SC(2) 1,909.84 27.44 39.74 1,833.39 1,673.75 381.10 173.96 5,930,404.25 481,425.21 2.94 -413.14 MWD+IFR-AK-CAZ-SC(2) 2,004.80 25.17 44.51 1,918.52 1,758.88 412.33 202.11 5,930,435.41 481,453.44 3.26 -450.59 MWD+IFR-AK-CAZ-SC(2) 2,099.72 24.63 50.47 2,004.63 1,844.99 439.32 231.52 5,930,462.32 481,482.91 2.70 -484.27 MWD+IFR-AK-CAZ-SC(2) 2,194.87 25.45 63.12 2,090.90 1,931.26 461.20 265.08 5,930,484.11 481,516.52 5.68 -514.09 MWD+IFR-AK-CAZ-SC(2) 2,289.33 27.45 75.16 2,175.53 2,015.89 475.96 304.26 5,930,498.78 481,555.73 6.05 -538.49 MWD+IFR-AK-CAZ-SC(2) 2,383.45 30.15 81.07 2,258.01 2,098.37 485.19 348.59 5,930,507.90 481,600.09 4.17 -558.88 MWD+IFR-AK-CAZ-SC(2) 2,476.89 32.78 84.16 2,337.71 2,178.07 491.41 396.95 5,930,513.99 481,648.45 3.30 -577.40 MWD+IFR-AK-CAZ-SC(2) 2,572.22 32.39 83.70 2,418.04 2,258.40 496.84 448.00 5,930,519.29 481,699.51 0.48 -595.86 MWD+IFR-AK-CAZ-SC(2) 2,666.25 33.43 89.38 2,497.00 2,337.36 499.88 498.95 5,930,522.21 481,750.46 3.46 -611.99 MWD+IFR-AK-CAZ-SC(2) 2,718.88 33.57 90.10 2,540.88 2,381.24 500.01 528.00 5,930,522.27 481,779.51 0.80 -619.63 MWD+IFR-AK-CAZ-SC(2) 2,740.81 33.44 88.91 2,559.17 2,399.53 500.12 540.10 5,930,522.35 481,791.61 3.05 -622.87 INC+TREND(3) 2,781.70 33.89 89.13 2,593.20 2,433.56 500.51 562.77 5,930,522.68 481,814.28 1.15 -629.11 MWD+IFR-AK-CAZ-SC(4) 10 3/4"x 13-1/2" 2,835.17 34.49 89.40 2,637.43 2,477.79 500.89 592.81 5,930,522.99 481,844.32 1.15 -637.26 MWD+IFR-AK-CAZ-SC(4) 2,929.75 36.21 90.65 2,714.57 2,554.93 500.86 647.53 5,930,522.82 481,899.03 1.97 -651.38 MWD+IFR-AK-CAZ-SC(4) 3,024.24 37.57 93.01 2,790.14 2,630.50 499.03 704.21 5,930,520.85 481,955.70 2.08 -664.29 MWD+IFR-AK-CAZ-SC(4) 3,123.14 38.70 94.95 2,867.94 2,708.30 494.78 765.13 5,930,516.44 482,016.60 1.67 -675.95 MWD+IFR-AK-CAZ-SC(4) 3,214.24 39.66 97.87 2,938.56 2,778.92 488.34 822.30 5,930,509.86 482,073.76 2.28 -684.53 MWD+IFR-AK-CAZ-SC(4) 3,309.20 39.94 100.70 3,011.52 2,851.88 478.53 882.28 5,930,499.91 482,133.70 1.93 -690.57 MWD+IFR-AK-CAZ-SC(4) 3,404.39 40.64 103.86 3,084.14 2,924.50 465.43 942.41 5,930,486.66 482,193.79 2.27 -693.48 MWD+IFR-AK-CAZ-SC(4) 3,498.42 41.50 108.17 3,155.04 2,995.40 448.37 1,001.75 5,930,469.46 482,253.08 3.15 -692.37 MWD+IFR-AK-CAZ-SC(4) 3,593.22 42.17 111.43 3,225.68 3,066.04 426.95 1,061.22 5,930,447.89 482,312.49 2.40 -687.07 MWD+IFR-AK-CAZ-SC(4) 3,687.80 42.71 112.59 3,295.48 3,135.84 403.03 1,120.39 5,930,423.82 482,371.60 1.01 -679.27 MWD+IFR-AK-CAZ-SC(4) 3,782.58 44.52 112.00 3,364.10 3,204.46 378.23 1,180.88 5,930,398.88 482,432.02 1.96 -670.98 MWD+IFR-AK-CAZ-SC(4) 3,876.02 46.63 112.03 3,429.50 3,269.86 353.22 1,242.74 5,930,373.71 482,493.82 2.26 -662.83 MWD+IFR-AK-CAZ-SC(4) 3,970.37 49.13 112.04 3,492.77 3,333.13 326.96 1,307.61 5,930,347.30 482,558.61 2.65 -654.26 MWD+IFR-AK-CAZ-SC(4) 4,064.96 50.96 111.78 3,553.52 3,393.88 299.91 1,374.88 5,930,320.08 482,625.80 1.95 -645.54 MWD+IFR-AK-CAZ-SC(4) 2/23/2016 9:01:28AM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: Rig: 120+39.64 @ 159.64usft(D25) Well: 2S-03 North Reference: True Wellbore: 2S-03PB1 Survey Calculation Method: Minimum Curvature Design: 2S-03PB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD T1f +NI-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) ' Survey Tool Name 4,159.92 51.08 111.85 3,613.25 3,453.61 272.48 1,443.41 5,930,292.49 482,694.26 0.14 -636.78 MWD+IFR-AK-CAZ-SC(4) 4,254.49 51.03 111.77 3,672.70 3,513.06 245.15 1,511.70 5,930,264.99 482,762.47 0.08 -628.05 MWD+IFR-AK-CAZ-SC(4) 4,349.76 51.11 111.87 3,732.56 3,572.92 217.61 1,580.50 5,930,237.28 482,831.20 0.12 -619.25 MWD+IFR-AK-CAZ-SC(4) 4,444.28 51.03 110.84 3,791.95 3,632.31 190.83 1,648.98 5,930,210.33 482,899.61 0.85 -611.12 MWD+IFR-AK-CAZ-SC(4) 4,537.03 51.10 110.83 3,850.24 3,690.60 165.17 1,716.41 5,930,184.51 482,966.96 0.08 -603.78 MWD+IFR-AK-CAZ-SC(4) 4,632.40 51.17 109.61 3,910.09 3,750.45 139.51 1,786.08 5,930,158.67 483,036.57 1.00 -597.03 MWD+IFR-AK-CAZ-SC(4) 4,726.93 51.25 108.73 3,969.31 3,809.67 115.31 1,855.68 5,930,134.31 483,106.10 0.73 -591.67 MWD+IFR-AK-CAZ-SC(4) 4,820.81 51.07 107.98 4,028.18 3,868.54 92.28 1,925.08 5,930,111.11 483,175.44 0.65 -587.39 MWD+IFR-AK-CAZ-SC(4) 4,916.59 51.13 106.93 4,088.33 3,928.69 69.93 1,996.19 5,930,088.58 483,246.48 0.86 -584.20 MWD+IFR-AK-CAZ-SC(4) 5,010.86 51.21 106.99 4,147.44 3,987.80 48.50 2,066.43 5,930,066.99 483,316.66 0.10 -581.68 MWD+IFR-AK-CAZ-SC(4) 5,104.99 51.11 108.41 4,206.48 4,046.84 26.22 2,136.27 5,930,044.53 483,386.44 1.18 -578.23 MWD+IFR-AK-CAZ-SC(4) 5,199.04 51.12 109.40 4,265.52 4,105.88 2.50 2,205.53 5,930,020.64 483,455.64 0.82 -573.24 MWD+IFR-AK-CAZ-SC(4) 5,294.20 50.66 110.68 4,325.55 4,165.91 -22.80 2,274.90 5,929,995.17 483,524.93 1.15 -566.76 MWD+IFR-AK-CAZ-SC(4) 5,389.44 50.33 110.32 4,386.13 4,226.49 -48.54 2,343.73 5,929,969.26 483,593.69 0.45 -559.72 MWD+IFR-AK-CAZ-SC(4) 5,483.64 50.61 110.40 4,446.09 4,286.45 -73.82 2,411.85 5,929,943.82 483,661.74 0.30 -552.93 MWD+1FR-AK-CAZ-SC(4) 5,578.33 50.43 110.44 4,506.29 4,346.65 -99.32 2,480.34 5,929,918.15 483,730.16 0.19 -546.03 MWD+IFR-AK-CAZ-SC(4) 5,673.16 50.65 110.27 4,566.56 4,406.92 -124.78 2,548.98 5,929,892.52 483,798.73 0.27 -539.19 MWD+IFR-AK-CAZ-SC(4) 5,768.21 50.23 110.52 4,627.10 4,467.46 -150.32 2,617.67 5,929,866.81 483,867.35 0.49 -532.30 MWD+IFR-AK-CAZ-SC(4) 5,862.27 50.51 111.83 4,687.09 4,527.45 -176.49 2,685.22 5,929,840.48 483,934.83 1.11 -524.51 MWD+IFR-AK-CAZ-SC(4) 5,957.06 50.54 112.78 4,747.36 4,587.72 -204.26 2,752.91 5,929,812.54 484,002.44 0.77 -515.21 MWD+IFR-AK-CAZ-SC(4) 6,052.13 50.63 112.23 4,807.72 4,648.08 -232.37 2,820.76 5,929,784.27 484,070.22 0.46 -505.61 MWD+IFR-AK-CAZ-SC(4) 6,146.51 50.47 113.62 4,867.69 4,708.05 -260.76 2,887.88 5,929,755.72 484,137.26 1.15 -495.57 MWD+IFR-AK-CAZ-SC(4) 6,240.39 50.88 115.73 4,927.19 4,767.55 -291.07 2,953.86 5,929,725.24 484,203.16 1.79 -483.36 MWD+IFR-AK-CAZ-SC(4) 6,335.37 51.43 118.56 4,986.77 4,827.13 -324.82 3,019.68 5,929,691.33 484,268.88 2.39 -467.79 MWD+IFR-AK-CAZ-SC(4) 6,430.02 52.39 121.19 5,045.16 4,885.52 -361.93 3,084.25 5,929,654.06 484,333.36 2.41 -448.66 MWD+IFR-AK-CAZ-SC(4) 6,524.27 52.99 124.07 5,102.30 4,942.66 -402.35 3,147.37 5,929,613.49 484,396.37 2.51 -425.96 MWD+IFR-AK-CAZ-SC(4) 6,619.02 53.30 126.46 5,159.13 4,999.49 -446.12 3,209.26 5,929,569.57 484,458.15 2.04 -399.70 MWD+IFR-AK-CAZ-SC(4) 6,714.34 53.81 129.69 5,215.77 5,056.13 -493.40 3,269.61 5,929,522.14 484,518.37 2.78 -369.64 MWD+IFR-AK-CAZ-SC(4) 6,807.69 54.01 131.52 5,270.76 5,111.12 -542.50 3,326.87 5,929,472.91 484,575.51 1.60 -337.04 MWD+IFR-AK-CAZ-SC(4) 6,903.31 54.07 133.10 5,326.91 5,167.27 -594.60 3,384.11 5,929,420.68 484,632.60 1.34 -301.54 MWD+IFR-AK-CAZ-SC(4) 6,998.16 54.04 134.47 5,382.59 5,222.95 -647.73 3,439.54 5,929,367.41 484,687.90 1.17 -264.56 MWD+IFR-AK-CAZ-SC(4) 7,092.00 53.65 137.03 5,437.96 5,278.32 -701.99 3,492.41 5,929,313.03 484,740.63 2.24 -225.83 MWD+IFR-AK-CAZ-SC(4) 7,187.22 53.65 139.87 5,494.41 5,334.77 -759.37 3,543.26 5,929,255.52 484,791.34 2.40 -183.57 MWD+IFR-AK-CAZ-SC(4) 7,281.99 53.38 143.30 5,550.77 5,391.13 -819.06 3,590.60 5,929,195.73 484,838.52 2.92 -138.17 MWD+IFR-AK-CAZ-SC(4) 7,376.46 53.33 146.73 5,607.16 5,447.52 -881.14 3,634.05 5,929,133.54 484,881.81 2.91 -89.44 MWD+IFR-AK-CAZ-SC(4) 7,470.40 54.01 150.28 5,662.83 5,503.19 -945.66 3,673.57 5,929,068.93 484,921.16 3.13 -37.35 MWD+IFR-AK-CAZ-SC(4) 7,565.20 54.64 153.51 5,718.12 5,558.48 -1,013.58 3,709.83 5,929,000.93 484,957.25 2.85 18.87 MWD+IFR-AK-CAZ-SC(4) 7,659.92 54.58 156.32 5,772.99 5,613.35 -1,083.50 3,742.56 5,928,930.93 484,989.81 2.42 77.94 MWD+IFR-AK-CAZ-SC(4) 7,755.31 54.76 158.29 5,828.15 5,668.51 -1,155.29 3,772.58 5,928,859.07 . 485,019.65 1.70 139.51 MWD+IFR-AK-CAZ-SC(4) 7,851.51 54.93 159.69 5,883.55 5,723.91 -1,228.72 3,800.78 5,928,785.59 485,047.66 1.20 203.13 MWD+IFR-AK-CAZ-SC(4) 2/23120/6 9:01:28AM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: Rig: 120+39.64 @ 159.64usft(D25) Well: 2S-03 North Reference: True Wel(bore: 2S-03PB1 Survey Calculation Method: Minimum Curvature Design: 2S-03PB1 Database: OAKEDMP2 Survey Map' Map Vertical MD Inc Azi TVD TVDSS +Ni-S +E/-W Northing Easting DLS Section (usft) (0) () (usft) (usft)__ (usft) (usft) (ft) (ft) (0/100')' (ft) Survey Tool Name 7,944.13 57.65 160.82 5,934.95 5,775.31 -1,301.23 3,826.80 5,928,713.02 485,073.49 3.11 266.44 MWD+IFR-AK-CAZ-SC(4) 8,037.87 61.20 162.16 5,982.62 5,822.98 -1,377.75 3,852.40 5,928,636.44 485,098.90 3.98 333.73 MWD+IFR-AK-CAZ-SC(4) 8,134.96 65.11 163.68 6,026.46 5,866.82 -1,460.54 3,877.81 5,928,553.59 485,124.11 4.26 407.12 MWD+IFR-AK-CAZ-SC(4) 8,227.49 67.60 165.32 6,063.57 5,903.93 -1,542.21 3,900.45 5,928,471.87 485,146.54 3.14 480.15 MWD+IFR-AK-CAZ-SC(4) 8,321.13 69.49 167.84 6,097.82 5,938.18 -1,626.98 3,920.66 5,928,387.07 485,166.54 3.22 556.80 MWD+IFR-AK-CAZ-SC(4) 8,416.49 71.30 170.93 6,129.83 5,970.19 -1,715.26 3,937.20 5,928,298.76 485,182.85 3.59 637.79 MWD+IFR-AK-CAZ-SC(4) 8,511.46 72.15 172.50 6,159.61 5,999.97 -1,804.49 3,950.19 5,928,209.50 485,195.62 1.81 720.62 MWD+IFR-AK-CAZ-SC(4) 8,606.43 72.76 174.79 6,188.24 6,028.60 -1,894.48 3,960.21 5,928,119.50 485,205.42 2.39 804.95 MWD+IFR-AK-CAZ-SC(4) 8,701.25 73.21 177.13 6,215.99 6,056.35 -1,984.92 3,966.59 5,928,029.05 485,211.58 2.41 890.65 MWD+IFR-AK-CAZ-SC(4) 8,756.84 74.39 178.49 6,231.50 6,071.86 -2,038.26 3,968.63 5,927,975.71 485,213.48 3.17 941.65 MWD+IFR-AK-CAZ-SC(4) 8,826.90 74.24 179.92 6,250.44 6,090.80 -2,105.70 3,969.56 5,927,908.27 485,214.25 1.98 1,006.55 INC+TREND(5) 7-5/8 x 9-7/8 by 11" 8,852.56 74.19 180.45 6,257.42 6,097.78 -2,130.39 3,969.48 5,927,883.58 485,214.11 1.98 1,030.43 INC+TREND(5) 8,947.89 75.01 181.42 6,282.74 6,123.10 -2,222.29 3,967.98 5,927,791.70 485,212.38 1.30 1,119.58 MWD+IFR-AK-CAZ-SC(6) 9,042.78 75.22 183.94 6,307.12 6,147.48 -2,313.88 3,963.69 5,927,700.13 485,207.86 2.58 1,209.16 MWD+IFR-AK-CAZ-SC(6) 9,137.59 76.65 185.80 6,330.16 6,170.52 -2,405.51 3,955.88 5,927,608.53 485,199.82 2.43 1,299.69 MWD+IFR-AK-CAZ-SC(6) 9,232.40 80.93 185.26 6,348.59 6,188.95 -2,498.06 3,946.92 5,927,516.01 485,190.64 4.55 1,391.40 MWD+IFR-AK-CAZ-SC(6) 9,326.85 84.53 184.89 6,360.54 6,200.90 -2,591.37 3,938.64 5,927,422.73 485,182.12 3.83 1,483.67 MWD+IFR-AK-CAZ-SC(6) 9,421.97 88.76 186.02 6,366.10 6,206.46 -2,685.87 3,929.61 5,927,328.26 485,172.86 4.60 1,577.29 MWD+IFR-AK-CAZ-SC(6) 9,519.33 92.15 185.87 6,365.33 6,205.69 -2,782.69 3,919.53 5,927,231.48 485,162.54 3.49 1,673.42 MWD+IFR-AK-CAZ-SC(6) 9,612.10 91.39 188.72 6,362.46 6,202.82 -2,874.65 3,907.76 5,927,139.55 485,150.54 3.18 1,765.30 MWD+IFR-AK-CAZ-SC(6) 9,707.04 92.46 191.75 6,359.27 6,199.63 -2,968.02 3,890.90 5,927,046.24 485,133.45 3.38 1,859.85 MWD+IFR-AK-CAZ-SC(6) 9,801.77 92.57 195.88 6,355.11 6,195.47 -3,059.90 3,868.31 5,926,954.42 485,110.63 4.36 1,954.45 MWD+IFR-AK-CAZ-SC(6) 9,896.56 92.10 200.03 6,351.25 6,191.61 -3,149.98 3,839.11 5,926,864.43 485,081.22 4.40 2,049.01 MWD+IFR-AK-CAZ-SC(6) 9,992.30 89.33 200.03 6,350.06 6,190.42 -3,239.91 3,806.33 5,926,774.58 485,048.21 2.89 2,144.36 MWD+IFR-AK-CAZ-SC(6) 10,086.92 88.93 198.88 6,351.49 6,191.85 -3,329.12 3,774.82 5,926,685.47 485,016.48 1.29 2,238.69 MWD+IFR-AK-CAZ-SC(6) 10,181.40 88.83 197.79 6,353.34 6,193.70 -3,418.78 3,745.10 5,926,595.88 484,986.55 1.16 2,332.99 MWD+IFR-AK-CAZ-SC(6) 10,277.03 88.49 196.66 6,355.58 6,195.94 -3,510.10 3,716.79 5,926,504.65 484,958.02 1.23 2,428.52 MWD+IFR-AK-CAZ-SC(6) 10,371.90 88.07 196.20 6,358.42 6,198.78 -3,601.05 3,689.97 5,926,413.77 484,930.97 0.66 2,523.31 MWD+IFR-AK-CAZ-SC(6) 10,466.92 87.39 196.30 6,362.19 6,202.55 -3,692.20 3,663.40 5,926,322.70 484,904.18 0.72 2,618.24 MWD+IFR-AK-CAZ-SC(6) 10,561.36 87.32 195.65 6,366.54 6,206.90 -3,782.90 3,637.44 5,926,232.07 484,877.99 0.69 2,712.56 MWD+IFR-AK-CAZ-SC(6) 10,656.01 87.61 197.86 6,370.73 6,211.09 -3,873.44 3,610.18 5,926,141.61 484,850.51 2.35 2,807.07 MWD+IFR-AK-CAZ-SC(6) 10,750.57 89.80 195.90 6,372.87 6,213.23 -3,963.89 3,582.74 5,926,051.24 484,822.84 3.11 2,901.54 MWD+IFR-AK-CAZ-SC(6) 10,845.81 90.41 197.42 6,372.69 6,213.05 -4,055.13 3,555.43 5,925,960.08 484,795.32 1.72 2,996.74 MWD+IFR-AK-CAZ-SC(6) 10,941.49 90.34 197.54 6,372.07 6,212.43 -4,146.39 3,526.69 5,925,868.90 484,766.35 0.15 3,092.33 MWD+IFR-AK-CAZ-SC(6) 11,036.30 89.40 197.75 6,372.28 6,212.64 -4,236.74 3,497.95 5,925,778.63 484,737.39 1.02 3,187.04 MWD+IFR-AK-CAZ-SC(6) 11,130.21 89.65 197.86 6,373.06 6,213.42 -4,326.15 3,469.24 5,925,689.30 484,708.46 0.29 3,280.83 MWD+IFR-AK-CAZ-SC(6) 11,224.93 88.62 196.31 6,374.49 6,214.85 -4,416.67 3,441.42 5,925,598.85 484,680.42 1.96 3,375.47 MWD+IFR-AK-CAZ-SC(6) 11,319.09 88.00 196.62 6,377.27 6,217.63 -4,506.93 3,414.74 5,925,508.67 484,653.52 0.74 3,469.56 MWD+IFR-AK-CAZ-SC(6) 11,413.70 87.76 195.11 6,380.77 6,221.13 -4,597.87 3,388.90 5,925,417.80 484,627.45 1.61 3,564.09 MWD+IFR-AK-CAZ-SC(6) 2/23/2016 9:01:28AM Page 5 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference:, Well 2S-03 Project: Kuparuk River Unit TVD Reference: Rig:120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: Rig: 120+39.64 @ 159.64usft(D25) Well: 2S-03 North Reference: True • Wellbore: 2S-03PB1 Survey Calculation Method: Minimum Curvature Design: 2S-03PB1 Database: OAKEDMP2 Survey Map Map Vertical' MD Inc Azi TVD TVDSS +N/-S +EJIW Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 11,508.90 88.35 192.64 6,384.00 6,224.36 -4,690.23 3,366.08 5,925,325.51 484,604.41 2.67 3,659.21 MWD+IFR-AK-CAZ-SC(6) 11,604.26 88.38 191.80 6,386.72 6,227.08 -4,783.39 3,345.91 5,925,232.41 484,584.00 0.88 3,754.42 MWD+IFR-AK-CAZ-SC(6) 11,698.69 88.59 192.00 6,389.22 6,229.58 -4,875.76 3,326.44 5,925,140.10 484,564.31 0.31 3,848.68 MWD+IFR-AK-CAZ-SC(6) 11,793.62 88.59 191.14 6,391.55 6,231.91 -4,968.73 3,307.41 5,925,047.18 484,545.05 0.91 3,943.41 MWD+IFR-AK-CAZ-SC(6) 11,888.42 89.03 192.55 6,393.52 6,233.88 -5,061.49 3,287.95 5,924,954.48 484,525.36 1.56 4,038.04 MWD+IFR-AK-CAZ-SC(6) 11,984.62 89.00 192.00 6,395.18 6,235.54 -5,155.48 3,267.50 5,924,860.55 484,504.68 0.57 4,134.12 MWD+IFR-AK-CAZ-SC(6) 12,077.92 89.58 190.74 6,396.33 6,236.69 -5,246.94 3,249.11 5,924,769.15 484,486.07 1.49 4,227.22 MWD+IFR-AK-CAZ-SC(6) 12,172.68 88.78 190.34 6,397.69 6,238.05 -5,340.09 3,231.78 5,924,676.05 484,468.51 0.94 4,321.68 MWD+IFR-AK-CAZ-SC(6) 12,268.19 89.21 191.47 6,399.36 6,239.72 -5,433.86 3,213.71 5,924,582.34 484,450.21 1.27 4,416.93 MWD+IFR-AK-CAZ-SC(6) 12,363.22 88.69 192.78 6,401.11 6,241.47 -5,526.75 3,193.76 5,924,489.50 484,430.02 1.48 4,511.83 MWD+IFR-AK-CAZ-SC(6) 12,457.52 88.52 194.38 6,403.40 6,243.76 -5,618.38 3,171.62 5,924,397.93 484,407.66 1.71 4,606.07 MWD+IFR-AK-CAZ-SC(6) 12,552.96 87.20 194.32 6,406.96 6,247.32 -5,710.78 3,147.99 5,924,305.61 484,383.80 1.38 4,701.43 MWD+IFR-AK-CAZ-SC(6) 12,647.84 88.43 196.83 6,410.58 6,250.94 -5,802.10 3,122.53 5,924,214.36 484,358.12 2.94 4,796.23 MWD+IFR-AK-CAZ-SC(6) 12,743.26 86.87 197.05 6,414.50 6,254.86 -5,893.30 3,094.75 5,924,123.24 484,330.12 1.65 4,891.51 MWD+IFR-AK-CAZ-SC(6) 12,838.22 84.17 196.98 6,421.91 6,262.27 -5,983.82 3,067.05 5,924,032.80 484,302.20 2.84 4,986.11 MWD+IFR-AK-CAZ-SC(6) 12,932.91 83.12 196.47 6,432.39 6,272.75 -6,073.94 3,039.97 5,923,942.75 484,274.89 1.23 5,080.18 MWD+IFR-AK-CAZ-SC(6) 13,028.27 83.02 197.75 6,443.90 6,284.26 -6,164.41 3,012.12 5,923,852.36 484,246.82 1.34 5,174.77 MWD+IFR-AK-CAZ-SC(6) 13,121.95 82.94 196.16 6,455.35 6,295.71 -6,253.35 2,985.01 5,923,763.50 484,219.49 1.69 5,267.69 MWD+IFR-AK-CAZ-SC(6) 13,218.25 78.76 197.01 6,470.66 6,311.02 -6,344.45 2,957.88 5,923,672.48 484,192.14 4.43 5,362.71 MWD+IFR-AK-CAZ-SC(6) 13,312.58 77.33 196.63 6,490.20 6,330.56 -6,432.78 2,931.17 5,923,584.22 484,165.22 1.57 5,454.94 MWD+IFR-AK-CAZ-SC(6) 13,407.89 80.90 195.90 6,508.19 6,348.55 -6,522.62 2,904.97 5,923,494.46 484,138.79 3.82 5,548.50 MWD+IFR-AK-CAZ-SC(6) 13,502.54 83.19 195.32 6,521.29 6,361.65 -6,612.89 2,879.75 5,923,404.25 484,113.35 2.49 5,642.23 MWD+IFR-AK-CAZ-SC(6) 13,596.27 86.56 193.49 6,529.67 6,370.03 -6,703.30 2,856.53 5,923,313.92 484,089.91 4.09 5,735.56 MWD+IFR-AK-CAZ-SC(6) 13,667.30 89.00 194.05 6,532.42 6,372.78 -6,772.23 2,839.64 5,923,245.03 484,072.85 3.52 5,806.52 MWD+IFR-AK-CAZ-SC(6) 13,728.00 89.00 194.05 6,533.48 6,373.84 -6,831.10 2,824.90 5,923,186.20 484,057.97 0.00 5,867.20 PROJECTED to TD 2/232016 9:01:28AM Page 6 COMPASS 5000.1 Build 74 • • Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. Yes L N I have checked to the best of my ability that the following data is correct: Li Surface Coordinates 0 Declination & Convergence Li GRS Survey Corrections 2 Survey Tool Codes Vincent Dgitaily svoc by Vincem Gsara ISIN; ..VincebT Oar, c,StbIlyinbever zAs-Schlumbefger. SLB DE Osara eolasb,vabaYabibbcork c.tJS Date 2-016C2n09:5711 0)06 Mike Callahan Client Representative. .14:1343w.n.oplatat,m4it cAJS 23-Feb-2016 Date: • • Mir"; Cement Detail Report 2S-03 ConocoPhillips String: Conductor Job: DRILLING ORIGINAL, 1/29/2016 12:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Conductor 11/30/2014 14:00 11/30/2014 15:30 2S-03 Comment Peak drilled 42"hole to 81'below ground level,set 16"62.58#APISL Grade B Insulated Conductor. SLB cemented in two stages with 15.7ppg Arctic Set 1 cement.Topped with 5'deep,6'wide sealed pan cellar. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Conductor Cement Cement 16"conductor in 39.6 2,781.0 No No No place. 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) Yes 18.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Peak drilled 42"hole to 81'below ground level,set 16"62.58#APISL Grade B Insulated Conductor.SLB cemented in two stages with 15.7ppg Arctic Set 1 cement.Topped with 5'deep,6'wide sealed pan cellar. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Primary Cement 39.6 118.0 438 AS1 Yield(W/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: 3/14/2016 Cement Detail Report 0J -; WeIits 2S-03 ` onocoPtailgps String: Surface Casing Cement Job: DRILLING ORIGINAL, 1/29/2016 12:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 2/3/2016 03:00 2/3/2016 07:00 2S-03 Comment PJSM for cementing 10-3/4"surface casing as per plan. Line up to Schlumberger,pump 5 bbls of CW100 and pressure test cement lines to 4000psi. Bleed off pressure and pump 35 bbls of CW100 @ 6 BPM., 170psi, 14%flow out,followed by 75bbls of 10.5ppg Mud Push II with red dye @ 4.7 BPM, 160psi, 15%flow out,shut down and bleed off pressure. Drop bottom plug. Batch up and pump 431 bbls of 11 ppg Cement @ 7 BPM,275psi, 18%flow out and 56bb1 of 12ppg cement @ 4.8 BPM,200psi, 15%flow out. (Cement returns diverted to cellar @ 36bbls into pumping of 12ppg tail cement.) Shut down,drop top plug,and kick out with 4bbls of 12ppg cement and l Obbls of water from cement unit. Swap over to rig and continue displacement @ 3.5 BPM,310psi. At 2371 stks, reduce rate to 1 BPM,270psi,bump plug @ 2425strokes. Pressure up to 760psi and hold for 5 minutes. Bleed off pressure and check floats(Good). Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement Cement 10-3/4"surface 39.6 2,781.0 Yes 147.0 Yes Yes casing in place. 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) 7 1 5 257.0 257.0 Yes 18.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment PJSM for cementing 10-3/4"surface casing as per plan. Line up to Schlumberger,pump 5 bbls of CW100 and pressure test cement lines to 4000psi. Bleed off pressure and pump 35 bbls of CW100 @ 6 BPM., 170psi, 14%flow out,followed by 75bbls of 10.5ppg Mud Push II with red dye @ 4.7 BPM, 160psi, 15%flow out,shut down and bleed off pressure. Drop bottom plug.Batch up and pump 431 bbls of 11 ppg Cement @ 7 BPM,275psi, 18%flow out and 56bb1 of 12ppg cement @ 4.8 BPM,200psi, 15%flow out. (Cement returns diverted to cellar @ 36bbls into pumping of 12ppg tail cement.) Shut down,drop top plug,and kick out with 4bbls of 12ppg cement and l Obbls of water from cement unit. Swap over to rig and continue displacement @ 3.5 BPM,310psi. At 2371stks,reduce rate to 1 BPM,270psi, bump plug @ 2425strokes. Pressure up to 760psi and hold for 5 minutes. Bleed off pressure and check floats(Good). Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) CW 100 40.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1 (psi) 8.34 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mud Push II 75.0 Yield(W/sack) Mix 1120 Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead-DeepCrete 39.6 2,290.0 1,269 G 431.7 Yield(fP/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.91 6.82 11.00 0.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOB Additive Type Concentration Conc Unit label Dispersant D185 0.07 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail-DeepCrete 2,290.0 2,790.0 192 G 56.1 Yield(f/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.64 5.56 12.00 0.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOB Additive Type Concentration Conc Unit label Dispersant LT D185 0.06 gal/sx Additive Type Concentration Conc Unit label Accelerator D186 0.1 gal/sx Page 1/2 Report Printed: 3/14/2016 • • ;. Cement Detail Report { 2S-03 ConocoPhillips String: Surface Casing Cement Job: DRILLING ORIGINAL, 1/29/2016 12:00 Additives Additive Type Concentration Cone Unit label Gasblok LT D500 0.75 gal/sx Page 2/2 Report Printed: 3/14/2016 • • Cement Detail Report t , .14 &Wens 2S-03 CcnocoPhitljps String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 1/29/2016 12:00 Cement Details " Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 2/11/2016 00:16 2/11/2016 06:45 2S-03 Comment Stage 1:Using Schlumberger,pump 40bbls of 11.5ppg Mud Push II @ 6 BPM,400psi, 18%flow out. Shut down and drop bypass plug.Chase plug with 136.1 bbls of 15.8ppg Lead cement at 6.3 BPM,300psi,20%flow out.Shut down and drop 754 shut-off plug chased with 3bbls(1.5bbls in lines+1.5bbls additional)of 15.8ppg Lead cement followed by l Obbls of water at 5 BPM, 100psi,7%flow out. Switch to rig pumps and pump 384bb1s of 9.7ppg LSND mud at 6 BPM.(ICP=131 psi, FCP=354psi, 15%flow out). Reduce pump rate to 3 BPM at 3674stks resulting in 500psi and 15%flow out. Bump plug at 3813stks and pressure up to 1075psi and hold for 5min. Bleed off and check floats(Good). Stage 2:Using Schlumberger,pump 40bbls of 11.5ppg Mud Push 11 @ 4.7 BPM, 170psi, 19%flow out. Pump 62bbls of 15.8ppg Tail cement at 5.3 BPM, ICP=265psi, FCP=235psi, 19%flow out. Drop closing plug and chase with 1 Obbls of water from Schlumberger at 5.3BPM,60psi, 13%flow out. Switch over to rig pumps and pump 272bb1s of 9.7ppg LSND at 6 BPM. (ICP=105psi, FCP=605psi, 16%flow out). Reduce pump rate to 3 BPM at 2550stks resulting in 490psi and 16%flow out. Plug on seat @ 2704stks. Pressure up to 1400psi and observe stage tool close. Continue to pressure up to 1500psi as per PESI rep and hold for 5min. Bleed off pressure and check for flow(static). Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing TOC to 7308'MD(Top of 7,308.0 8,830.0 Yes Yes Yes Cement Cairn formation) 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) 3 6 630.0 1,103.0 Yes 18.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 8,608.0 Drill Bit 8,850.0 6 3/4 Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mud Push II 6,653.0 7,308.0 40.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 11.60 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Water 6,489.0 6,653.0 10.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) 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) UniSlurry Cement 7,308.0 8,830.0 654 G 135.1 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.07 15.80 0.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.6 %BWOC Additive Type Concentration Conc Unit label Fluid Loss D167 0.8 %BWOC Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing TOC to 5442 5,442.0 6,142.0 Yes Yes No Cement 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) 3 6 505.0 1,400.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 6,108.0 Drill Bit 6,146.0 6 3/4 Comment Page 1/2 Report Printed: 3/14/2016 41110 11110 Dri Cement Detail Report &Welts 2S-03 ConocoPhillips String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 1/29/2016 12:00 Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Water 4,622.0 4,786.0 10.0 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 Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mud Push II 4,786.0 5,441.0 40.1 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 11.58 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) UniSlurry Cement 5,441.0 6,141.0 298 G 62.1 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.17 5.10 15.83 0.00 Additives Additive Type Concentration Conc Unit label Page 2/2 Report Printed: 3/14/2016 • i 21 5205 ENV 16 9 7 2 • MAR 2 4 2016 ConocoPhillips AOGCC TRANSMITTAL DATA LOGGED 3 1.(/2o1m K. BENDER FROM: Sandra D. Lemke, ATO14-1412 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 Anchorage Pouch Mail Anchorage AK 99510-0360 RE: 2S-03 DATE: 02/22/2016 Transmitted: Kuparuk River Unit, Alaska 2S-03 1 CD of final report w/log images and 1 color hardcopy print each loq Halliburton Surface Data Logging- End of well report for 2S-03; 02/10/2016; ; general information, daily summary, days vs. depth, after action review, mud record, bit record, morning reports, survey reports; color log presentations, one set each for wellbore. * no lithology-mud loggers did not catch samples. Formation Evaluation log-CVE gas extraction - MD Gas ratio- CVE gas extraction - MD Drilling Engineering Log - CVE gas extraction - MD CD contains Final log files, End of well report, final LAS exports, log viewers Please promptly sign, scan and return electronically to Sandra.D.Lemke(dCOP.com CC: 2S-03 transmittal folder, production well files, eSearch Receipt: A"V 17) GIS-Technical Data Management I ConocoPhillips Anchorage, Alaska I Ph: 907.2656947 eet1V C149 L 1 0 5 MAR 14 201 � 2 6 9 3 1 AOGCC Schiumberger Transmittal#: 14MAR16-SPO1 MWD/LWD Log Product Delivery DATA LOGGED iiZi2o1C. M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2S-03 Date Dispatched: 14-Mar-16 Job#: 15AKA0039 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Contents on CD N/A Scope Services 2" MD x x Scope Services 2'TVD x x Scope Services 5'MD x x Scope Services 5"TVD 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(a�conocophillips.com AlaskaPTSPrintCenter(c�slb.com Tom Osterkamp Attn:Stephanie Pacillo 907-263-4795M y� Received By: w `k� • • 215205 15931 REceiv'ED M\R 14 2015 FINAL pOGCG NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-03 2S-03 Definitive Survey Report 24 February, 2016 NAD 27 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: 120+39.64 @ 159.64usft(D25) Well: 2S-03 North Reference: True Wellbore: 2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03 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-03 Well Position +N/-S 0.00 usft Northing: 5,930,023.62 usfl Latitude: 70° 13'11.933 N +E/-W 0.00 usft Easting: 481,250.32 usfl Longitude: 150°9'4.542 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 120.00 usft Wellbore 2S-03 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2015 2/1/2016 18.37 80.86 57,485 Design 2S-03 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 10,561.36 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) (0) 39.64 0.00 0.00 143.35 Survey Program Date 2/24/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 99.00 1,031.00 2S-03 Srvy#1 -GYD-GC-SS(2S-03PB1 GYD-GC-SS Gyrodata gyro single shots 1/31/2016 10:2 1,058.15 2,718.88 2S-03 Srvy#2-GMAG(2S-03PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/31/2016 10:2 2,740.81 2,740.81 2S-03 Srvy#3-Inc+Trend(2S-03PB1) INC+TREND Inclinometer+known azi trend 2/5/2016 9:34 2,835.17 8,756.84 2S-03 Srvy#4-GMAG(2S-03PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/5/2016 9:38 8,852.56 8,852.56 2S-03 Srvy#5-Inc+Trend(2S-03PB1) INC+TREND Inclinometer+known azi trend 2/16/2016 9:1 8,947.89 10,561.36 2S-03 Srvy#6-GMAG(2S-03PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/16/2016 9:11 10,656.01 16,696.12 2S-03 Srvy#7-SLB_MWD+GMAG(2S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/19/2016 1:4: 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 39.64 0.00 0.00 39.64 -120.00 0.00 0.00 5,930,023.62 481,250.32 0.00 0.00 UNDEFINED 99.00 0.68 307.59 99.00 -60.64 0.21 -0.28 5,930,023.84 481,250.04 1.15 -0.34 GYD-GC-SS(1) 120.40 0.76 307.84 120.40 -39.24 0.38 -0.49 5,930,024.00 481,249.83 0.35 -0.60 NOT an Actual Survey 16"x 20" 187.00 0.99 308.38 186.99 27.35 1.01 -1.29 5,930,024.63 481,249.04 0.35 -1.58 GYD-GC-SS(1) 279.00 1.43 323.75 278.97 119.33 2.42 -2.59 5,930,026.05 481,247.74 0.59 -3.49 GYD-GC-SS(1) 373.00 2.73 352.26 372.91 213.27 5.59 -3.59 5,930,029.22 481,246.75 1.73 -6.62 GYD-GC-SS(1) 467.00 4.05 3.66 466.74 307.10 11.12 -3.68 5,930,034.75 481,246.68 1.57 -11.12 GYD-GC-SS(1) 560.00 4.75 8.02 559.47 399.83 18.21 -2.93 5,930,041.84 481,247.44 0.83 -16.36 GYD-GC-SS(1) 2/24/2016 9:44:05AM Page 2 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: 120+39.64 @ 159.64usft(D25) Well: 2S-03 North Reference: True Wellbore: 2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03 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) (°1100') (ft) Survey Tool Name 654.00 5.88 10.82 653.06 493.42 26.79 -1.48 5,930,050.41 481,248.91 1.23 -22.38 GYD-GC-SS(1) 748.00 7.82 21.67 746.39 586.75 37.47 1.78 5,930,061.08 481,252.20 2.47 -29.00 GYD-GC-SS(1) 843.00 9.53 23.20 840.30 680.66 50.70 7.27 5,930,074.30 481,257.72 1.82 -36.34 GYD-GC-SS(1) 937.00 10.63 22.72 932.85 773.21 65.85 13.68 5,930,089.43 481,264.17 1.17 -44.67 GYD-GC-SS(1) 1,031.00 12.43 22.65 1,024.95 865.31 83.19 20.93 5,930,106.75 481,271.46 1.91 -54.25 GYD-GC-SS(1) 1,058.15 13.24 22.22 1,051.42 891.78 88.76 23.23 5,930,112.32 481,273.77 3.00 -57.35 MWD+IFR-AK-CAZ-SC(2) 1,152.92 15.04 22.94 1,143.31 983.67 110.14 32.13 5,930,133.66 481,282.72 1.91 -69.19 MWD+IFR-AK-CAZ-SC(2) 1,247.26 17.39 24.50 1,233.89 1,074.25 134.24 42.75 5,930,157.74 481,293.40 2.53 -82.19 MWD+IFR-AK-CAZ-SC(2) 1,340.99 21.22 26.16 1,322.34 1,162.70 162.22 56.04 5,930,185.68 481,306.76 4.13 -96.71 MWD+IFR-AK-CAZ-SC(2) 1,435.66 24.72 24.77 1,409.49 1,249.85 195.58 71.89 5,930,219.00 481,322.69 3.74 -114.02 MWD+IFR-AK-CAZ-SC(2) 1,530.79 25.79 26.03 1,495.53 1,335.89 232.24 89.31 5,930,255.61 481,340.20 1.26 -133.03 MWD+IFR-AK-CAZ-SC(2) 1,626.16 26.71 26.08 1,581.06 1,421.42 270.13 107.83 5,930,293.46 481,358.82 0.96 -152.38 MWD+IFR-AK-CAZ-SC(2) 1,721.19 27.14 25.69 1,665.79 1,506.15 308.85 126.62 5,930,332.12 481,377.70 0.49 -172.23 MWD+IFR-AK-CAZ-SC(2) 1,815.71 27.42 33.73 1,749.82 1,590.18 346.39 148.06 5,930,369.61 481,399.22 3.91 -189.55 MWD+IFR-AK-CAZ-SC(2) 1,909.84 27.44 39.74 1,833.39 1,673.75 381.10 173.96 5,930,404.25 481,425.21 2.94 -201.94 MWD+IFR-AK-CAZ-SC(2) 2,004.80 25.17 44.51 1,918.52 1,758.88 412.33 202.11 5,930,435.41 481,453.44 3.26 -210.20 MWD+IFR-AK-CAZ-SC(2) 2,099.72 24.63 50.47 2,004.63 1,844.99 439.32 231.52 5,930,462.32 481,482.91 2.70 -214.30 MWD+IFR-AK-CAZ-SC(2) 2,194.87 25.45 63.12 2,090.90 1,931.26 461.20 265.08 5,930,484.11 481,516.52 5.68 -211.83 MWD+IFR-AK-CAZ-SC(2) 2,289.33 27.45 75.16 2,175.53 2,015.89 475.96 304.26 5,930,498.78 481,555.73 6.05 -200.29 MWD+IFR-AK-CAZ-SC(2) 2,383.45 30.15 81.07 2,258.01 2,098.37 485.19 348.59 5,930,507.90 481,600.09 4.17 -181.23 MWD+IFR-AK-CAZ-SC(2) 2,476.89 32.78 84.16 2,337.71 2,178.07 491.41 396.95 5,930,513.99 481,648.45 3.30 -157.36 MWD+IFR-AK-CAZ-SC(2) 2,572.22 32.39 83.70 2,418.04 2,258.40 496.84 448.00 5,930,519.29 481,699.51 0.48 -131.24 MWD+IFR-AK-CAZ-SC(2) 2,666.25 33.43 89.38 2,497.00 2,337.36 499.88 498.95 5,930,522.21 481,750.46 3.46 -103.27 MWD+IFR-AK-CAZ-SC(2) 2,718.88 33.57 90.10 2,540.88 2,381.24 500.01 528.00 5,930,522.27 481,779.51 0.80 -86.04 MWD+IFR-AK-CAZ-SC(2) 2,740.81 33.44 88.91 2,559.17 2,399.53 500.12 540.10 5,930,522.35 481,791.61 3.05 -78.90 INC+TREND(3) 2,781.70 33.89 89.13 2,593.20 2,433.56 500.51 562.77 5,930,522.68 481,814.28 1.15 -65.69 NOT an Actual Survey'C(4) 10 314"x 13-1/2" 2,835.17 34.49 89.40 2,637.43 2,477.79 500.89 592.81 5,930,522.99 481,844.32 1.15 -48.06 MWD+IFR-AK-CAZ-SC(4) 2,929.75 36.21 90.65 2,714.57 2,554.93 500.86 647.53 5,930,522.82 481,899.03 1.97 -15.37 MWD+IFR-AK-CAZ-SC(4) 3,024.24 37.57 93.01 2,790.14 2,630.50 499.03 704.21 5,930,520.85 481,955.70 2.08 19.92 MWD+IFR-AK-CAZ-SC(4) 3,123.14 38.70 94.95 2,867.94 2,708.30 494.78 765.13 5,930,516.44 482,016.60 1.67 59.69 MWD+IFR-AK-CAZ-SC(4) 3,214.24 39.66 97.87 2,938.56 2,778.92 488.34 822.30 5,930,509.86 482,073.76 2.28 98.99 MWD+IFR-AK-CAZ-SC(4) 3,309.20 39.94 100.70 3,011.52 2,851.88 478.53 882.28 5,930,499.91 482,133.70 1.93 142.65 MWD+IFR-AK-CAZ-SC(4) 3,404.39 40.64 103.86 3,084.14 2,924.50 465.43 942.41 5,930,486.66 482,193.79 2.27 189.05 MWD+IFR-AK-CAZ-SC(4) 3,498.42 41.50 108.17 3,155.04 2,995.40 448.37 1,001.75 5,930,469.46 482,253.08 3.15 238.15 MWD+IFR-AK-CAZ-SC(4) 3,593.22 42.17 111.43 3,225.68 3,066.04 426.95 1,061.22 5,930,447.89 482,312.49 2.40 290.84 MWD+IFR-AK-CAZ-SC(4) 3,687.80 42.71 112.59 3,295.48 3,135.84 403.03 1,120.39 5,930,423.82 482,371.60 1.01 345.35 MWD+IFR-AK-CAZ-SC(4) 3,782.58 44.52 112.00 3,364.10 3,204.46 378.23 1,180.88 5,930,398.88 482,432.02 1.96 401.35 MWD+IFR-AK-CAZ-SC(4) 3,876.02 46.63 112.03 3,429.50 3,269.86 353.22 1,242.74 5,930,373.71 482,493.82 2.26 458.34 MWD+IFR-AK-CAZ-SC(4) 3,970.37 49.13 112.04 3,492.77 3,333.13 326.96 1,307.61 5,930,347.30 482,558.61 2.65 518.12 MWD+IFR-AK-CAZ-SC(4) 2/24/2016 9:44:05AM Page 3 COMPASS 5000.1 Build 74 • i Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: 120+39.64 @ 159.64usft(D25) Well: 2S-03 North Reference: True Wellbore: 2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,064.96 50.96 111.78 3,553.52 3,393.88 299.91 1,374.88 5,930,320.08 482,625.80 1.95 579.98 MWD+IFR-AK-CAZ-SC(4) 4,159.92 51.08 111.85 3,613.25 3,453.61 272.48 1,443.41 5,930,292.49 482,694.26 0.14 642.89 MWD+IFR-AK-CAZ-SC(4) 4,254.49 51.03 111.77 3,672.70 3,513.06 245.15 1,511.70 5,930,264.99 482,762.47 0.08 705.58 MWD+IFR-AK-CAZ-SC(4) 4,349.76 51.11 111.87 3,732.56 3,572.92 217.61 1,580.50 5,930,237.28 482,831.20 0.12 768.74 MWD+IFR-AK-CAZ-SC(4) 4,444.28 51.03 110.84 3,791.95 3,632.31 190.83 1,648.98 5,930,210.33 482,899.61 0.85 831.10 MW D+I FR-AK-CAZ-SC(4) 4,537.03 51.10 110.83 3,850.24 3,690.60 165.17 1,716.41 5,930,184.51 482,966.96 0.08 891.93 MWD+IFR-AK-CAZ-SC(4) 4,632.40 51.17 109.61 3,910.09 3,750.45 139.51 1,786.08 5,930,158.67 483,036.57 1.00 954.11 MWD+IFR-AK-CAZ-SC(4) 4,726.93 51.25 108.73 3,969.31 3,809.67 115.31 1,855.68 5,930,134.31 483,106.10 0.73 1,015.06 MWD+IFR-AK-CAZ-SC(4) 4,820.81 51.07 107.98 4,028.18 3,868.54 92.28 1,925.08 5,930,111.11 483,175.44 0.65 1,074.96 MW D+I FR-AK-CAZ-SC(4) 4,916.59 51.13 106.93 4,088.33 3,928.69 69.93 1,996.19 5,930,088.58 483,246.48 0.86 1,135.34 MWD+IFR-AK-CAZ-SC(4) 5,010.86 51.21 106.99 4,147.44 3,987.80 48.50 2,066.43 5,930,066.99 483,316.66 0.10 1,194.45 MW D+I FR-AK-CAZ-SC(4) 5,104.99 51.11 108.41 4,206.48 4,046.84 26.22 2,136.27 5,930,044.53 483,386.44 1.18 1,254.03 MW D+I FR-AK-CAZ-SC(4) 5,199.04 51.12 109.40 4,265.52 4,105.88 2.50 2,205.53 5,930,020.64 483,455.64 0.82 1,314.39 MWD+IFR-AK-CAZ-SC(4) 5,294.20 50.66 110.68 4,325.55 4,165.91 -22.80 2,274.90 5,929,995.17 483,524.93 1.15 1,376.09 MWD+IFR-AK-CAZ-SC(4) 5,389.44 50.33 110.32 4,386.13 4,226.49 -48.54 2,343.73 5,929,969.26 483,593.69 0.45 1,437.82 MWD+IFR-AK-CAZ-SC(4) 5,483.64 50.61 110.40 4,446.09 4,286.45 -73.82 2,411.85 5,929,943.82 483,661.74 0.30 1,498.76 MWD+IFR-AK-CAZ-SC(4) 5,578.33 50.43 110.44 4,506.29 4,346.65 -99.32 2,480.34 5,929,918.15 483,730.16 0.19 1,560.10 MWD+IFR-AK-CAZ-SC(4) 5,673.16 50.65 110.27 4,566.56 4,406.92 -124.78 2,548.98 5,929,892.52 483,798.73 0.27 1,621.51 MWD+IFR-AK-CAZ-SC(4) 5,768.21 50.23 110.52 4,627.10 4,467.46 -150.32 2,617.67 5,929,866.81 483,867.35 0.49 1,682.99 MWD+IFR-AK-CAZ-SC(4) 5,862.27 50.51 111.83 4,687.09 4,527.45 -176.49 2,685.22 5,929,840.48 483,934.83 1.11 1,744.30 MWD+IFR-AK-CAZ-SC(4) 5,957.06 50.54 112.78 4,747.36 4,587.72 -204.26 2,752.91 5,929,812.54 484,002.44 0.77 1,806.99 MWD+IFR-AK-CAZ-SC(4) 6,052.13 50.63 112.23 4,807.72 4,648.08 -232.37 2,820.76 5,929,784.27 484,070.22 0.46 1,870.04 MWD+IFR-AK-CAZ-SC(4) 6,146.51 50.47 113.62 4,867.69 4,708.05 -260.76 2,887.88 5,929,755.72 484,137.26 1.15 1,932.88 MWD+IFR-AK-CAZ-SC(4) 6,240.39 50.88 115.73 4,927.19 4,767.55 -291.07 2,953.86 5,929,725.24 484,203.16 1.79 1,996.59 MWD+IFR-AK-CAZ-SC(4) 6,335.37 51.43 118.56 4,986.77 4,827.13 -324.82 3,019.68 5,929,691.33 484,268.88 2.39 2,062.95 MWD+IFR-AK-CAZ-SC(4) 6,430.02 52.39 121.19 5,045.16 4,885.52 -361.93 3,084.25 5,929,654.06 484,333.36 2.41 2,131.27 MWD+IFR-AK-CAZ-SC(4) 6,524.27 52.99 124.07 5,102.30 4,942.66 -402.35 3,147.37 5,929,613.49 484,396.37 2.51 2,201.37 MWD+IFR-AK-CAZ-SC(4) 6,619.02 53.30 126.46 5,159.13 4,999.49 -446.12 3,209.26 5,929,569.57 484,458.15 2.04 2,273.43 MWD+IFR-AK-CAZ-SC(4) 6,714.34 53.81 129.69 5,215.77 5,056.13 -493.40 3,269.61 5,929,522.14 484,518.37 2.78 2,347.38 MWD+IFR-AK-CAZ-SC(4) 6,807.69 54.01 131.52 5,270.76 5,111.12 -542.50 3,326.87 5,929,472.91 484,575.51 1.60 2,420.95 MWD+IFR-AK-CAZ-SC(4) 6,903.31 54.07 133.10 5,326.91 5,167.27 -594.60 3,384.11 5,929,420.68 484,632.60 1.34 2,496.91 MWD+IFR-AK-CAZ-SC(4) 6,998.16 54.04 134.47 5,382.59 5,222.95 -647.73 3,439.54 5,929,367.41 484,687.90 1.17 2,572.63 MWD+IFR-AK-CAZ-SC(4) 7,092.00 53.65 137.03 5,437.96 5,278.32 -701.99 3,492.41 5,929,313.03 484,740.63 2.24 2,647.72 MWD+IFR-AK-CAZ-SC(4) 7,187.22 53.65 139.87 5,494.41 5,334.77 -759.37 3,543.26 5,929,255.52 484,791.34 2.40 2,724.12 MWD+IFR-AK-CAZ-SC(4) 7,281.99 53.38 143.30 5,550.77 5,391.13 -819.06 3,590.60 5,929,195.73 484,838.52 2.92 2,800.26 MWD+IFR-AK-CAZ-SC(4) 7,376.46 53.33 146.73 5,607.16 5,447.52 -881.14 3,634.05 5,929,133.54 484,881.81 2.91 2,876.00 MWD+IFR-AK-CAZ-SC(4) 7,470.40 54.01 150.28 5,662.83 5,503.19 -945.66 3,673.57 5,929,068.93 484,921.16 3.13 2,951.36 MWD+IFR-AK-CAZ-SC(4) 7,565.20 54.64 153.51 5,718.12 5,558.48 -1,013.58 3,709.83 5,929,000.93 484,957.25 2.85 3,027.49 MWD+IFR-AK-CAZ-SC(4) 7,659.92 54.58 156.32 5,772.99 5,613.35 -1,083.50 3,742.56 5,928,930.93 484,989.81 2.42 3,103.13 MWD+IFR-AK-CAZ-SC(4) 7,755.31 54.76 158.29 5,828.15 5,668.51 -1,155.29 3,772.58 5,928,859.07 485,019.65 1.70 3,178.65 MWD+IFR-AK-CAZ-SC(4) 2/24/2016 9:44:05AM Page 4 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: 120+39.64 @ 159.64usft(D25) Well: 2S-03 North Reference: True Wellbore: 2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03 Database: OAKEDMP2 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) (°l100') (ft) Survey Tool Name 7,851.51 54.93 159.69 5,883.55 5,723.91 -1,228.72 3,800.78 5,928,785.59 485,047.66 1.20 3,254.39 MWD+IFR-AK-CAZ-SC(4) 7,944.13 57.65 160.82 5,934.95 5,775.31 -1,301.23 3,826.80 5,928,713.02 485,073.49 3.11 3,328.10 MWD+IFR-AK-CAZ-SC(4) 8,037.87 61.20 162.16 5,982.62 5,822.98 -1,377.75 3,852.40 5,928,636.44 485,098.90 3.98 3,404.78 MWD+IFR-AK-CAZ-SC(4) 8,134.96 65.11 163.68 6,026.46 5,866.82 -1,460.54 3,877.81 5,928,553.59 485,124.11 4.26 3,486.38 MWD+IFR-AK-CAZ-SC(4) 8,227.49 67.60 165.32 6,063.57 5,903.93 -1,542.21 3,900.45 5,928,471.87 485,146.54 3.14 3,565.42 MWD+IFR-AK-CAZ-SC(4) 8,321.13 69.49 167.84 6,097.82 5,938.18 -1,626.98 3,920.66 5,928,387.07 485,166.54 3.22 3,645.49 MWD+IFR-AK-CAZ-SC(4) 8,416.49 71.30 170.93 6,129.83 5,970.19 -1,715.26 3,937.20 5,928,298.76 485,182.85 3.59 3,726.19 MWD+IFR-AK-CAZ-SC(4) 8,511.46 72.15 172.50 6,159.61 5,999.97 -1,804.49 3,950.19 5,928,209.50 485,195.62 1.81 3,805.54 MWD+IFR-AK-CAZ-SC(4) 8,606.43 72.76 174.79 6,188.24 6,028.60 -1,894.48 3,960.21 5,928,119.50 485,205.42 2.39 3,883.72 MWD+IFR-AK-CAZ-SC(4) 8,701.25 73.21 177.13 6,215.99 6,056.35 -1,984.92 3,966.59 5,928,029.05 485,211.58 2.41 3,960.09 MWD+IFR-AK-CAZ-SC(4) 8,756.84 74.39 178.49 6,231.50 6,071.86 -2,038.26 3,968.63 5,927,975.71 485,213.48 3.17 4,004.11 MWD+IFR-AK-CAZ-SC(4) 8,826.90 74.24 179.92 6,250.44 6,090.80 -2,105.70 3,969.56 5,927,908.27 485,214.25 1.98 4,058.78 NOT an Actual Survey 7-5/8 x 9-7/8 by 11" 8,852.56 74.19 180.45 6,257.42 6,097.78 -2,130.39 3,969.48 5,927,883.58 485,214.11 1.98 4,078.54 INC+TREND(5) 8,947.89 75.01 181.42 6,282.74 6,123.10 -2,222.29 3,967.98 5,927,791.70 485,212.38 1.30 4,151.37 MWD+IFR-AK-CAZ-SC(6) 9,042.78 75.22 183.94 6,307.12 6,147.48 -2,313.88 3,963.69 5,927,700.13 485,207.86 2.58 4,222.31 MWD+IFR-AK-CAZ-SC(6) 9,137.59 76.65 185.80 6,330.16 6,170.52 -2,405.51 3,955.88 5,927,608.53 485,199.82 2.43 4,291.16 MWD+IFR-AK-CAZ-SC(6) 9,232.40 80.93 185.26 6,348.59 6,188.95 -2,498.06 3,946.92 5,927,516.01 485,190.64 4.55 4,360.07 MWD+IFR-AK-CAZ-SC(6) 9,326.85 84.53 184.89 6,360.54 6,200.90 -2,591.37 3,938.64 5,927,422.73 485,182.12 3.83 4,429.99 MWD+IFR-AK-CAZ-SC(6) 9,421.97 88.76 186.02 6,366.10 6,206.46 -2,685.87 3,929.61 5,927,328.26 485,172.86 4.60 4,500.43 MWD+IFR-AK-CAZ-SC(6) 9,519.33 92.15 185.87 6,365.33 6,205.69 -2,782.69 3,919.53 5,927,231.48 485,162.54 3.49 4,572.09 MWD+IFR-AK-CAZ-SC(6) 9,612.10 91.39 188.72 6,362.46 6,202.82 -2,874.65 3,907.76 5,927,139.55 485,150.54 3.18 4,638.85 MWD+IFR-AK-CAZ-SC(6) 9,707.04 92.46 191.75 6,359.27 6,199.63 -2,968.02 3,890.90 5,927,046.24 485,133.45 3.38 4,703.70 MWD+IFR-AK-CAZ-SC(6) 9,801.77 92.57 195.88 6,355.11 6,195.47 -3,059.90 3,868.31 5,926,954.42 485,110.63 4.36 4,763.94 MWD+IFR-AK-CAZ-SC(6) 9,896.56 92.10 200.03 6,351.25 6,191.61 -3,149.98 3,839.11 5,926,864.43 485,081.22 4.40 4,818.79 MWD+IFR-AK-CAZ-SC(6) 9,992.30 89.33 200.03 6,350.06 6,190.42 -3,239.91 3,806.33 5,926,774.58 485,048.21 2.89 4,871.38 MWD+IFR-AK-CAZ-SC(6) 10,086.92 88.93 198.88 6,351.49 6,191.85 -3,329.12 3,774.82 5,926,685.47 485,016.48 1.29 4,924.14 MWD+IFR-AK-CAZ-SC(6) 10,181.40 88.83 197.79 6,353.34 6,193.70 -3,418.78 3,745.10 5,926,595.88 484,986.55 1.16 4,978.35 MWD+IFR-AK-CAZ-SC(6) 10,277.03 88.49 196.66 6,355.58 6,195.94 -3,510.10 3,716.79 5,926,504.65 484,958.02 1.23 5,034.72 MWD+IFR-AK-CAZ-SC(6) 10,371.90 88.07 196.20 6,358.42 6,198.78 -3,601.05 3,689.97 5,926,413.77 484,930.97 0.66 5,091.68 MWD+IFR-AK-CAZ-SC(6) 10,466.92 87.39 196.30 6,362.19 6,202.55 -3,692.20 3,663.40 5,926,322.70 484,904.18 0.72 5,148.96 MWD+IFR-AK-CAZ-SC(6) 10,561.36 87.32 195.65 6,366.54 6,206.90 -3,782.90 3,637.44 5,926,232.07 484,877.99 0.69 5,206.23 MWD+IFR-AK-CAZ-SC(6) 10,656.01 87.63 197.44 6,370.71 6,211.07 -3,873.54 3,610.51 5,926,141.51 484,850.84 1.92 5,262.89 MWD+IFR-AK-CAZ-SC(7) 10,676.59 87.95 198.16 6,371.51 6,211.87 -3,893.12 3,604.23 5,926,121.95 484,844.51 3.83 5,274.85 MWD+IFR-AK-CAZ-SC(7) Tie-in 10,731.24 87.40 197.04 6,373.73 6,214.09 -3,945.17 3,587.72 5,926,069.95 484,827.87 2.28 5,306.75 MWD+IFR-AK-CAZ-SC(7) Ito old 10,770.72 86.42 197.40 6,375.85 6,216.21 -3,982.82 3,576.05 5,926,032.32 484,816.11 2.64 5,330.00 MWD+IFR-AK-CAZ-SC(7) hole 10,867.03 86.22 201.11 6,382.04 6,222.40 -4,073.54 3,544.36 5,925,941.69 484,784.20 3.85 5,383.87 MWD+IFR-AK-CAZ-SC(7) 10,961.97 87.21 203.25 6,387.48 6,227.84 -4,161.30 3,508.58 5,925,854.03 484,748.20 2.48 5,432.93 MWD+IFR-AK-CAZ-SC(7) 11,055.87 90.67 205.48 6,389.22 6,229.58 -4,246.81 3,469.85 5,925,768.63 484,709.27 4.38 5,478.42 MWD+IFR-AK-CAZ-SC(7) 11,150.83 92.32 205.35 6,386.74 6,227.10 -4,332.55 3,429.11 5,925,683.00 484,668.32 1.74 5,522.90 MWD+IFR-AK-CAZ-SC(7) 2/24/2016 9:44:05AM Page 5 COMPASS 5000.1 Build 74 • Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: 120+39.64 @ 159.64usft(D25) Well: 2S-03 North Reference: True Wellbore: 2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03 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 11,244.08 92.15 205.27 6,383.10 6,223.46 -4,416.78 3,389.28 5,925,598.87 484,628.28 0.20 5,566.71 MWD+IFR-AK-CAZ-SC(7) 11,338.63 89.98 204.52 6,381.34 6,221.70 -4,502.52 3,349.49 5,925,513.24 484,588.28 2.43 5,611.75 MWD+1FR-AK-CAZ-SC(7) 11,433.70 88.79 201.15 6,382.36 6,222.72 -4,590.12 3,312.60 5,925,425.74 484,551.18 3.76 5,660.02 MW D+I FR-AK-CAZ-SC(7) 11,529.43 89.43 197.69 6,383.85 6,224.21 -4,680.38 3,280.78 5,925,335.57 484,519.14 3.68 5,713.45 MWD+IFR-AK-CAZ-SC(7) 11,623.50 89.56 194.59 6,384.68 6,225.04 -4,770.73 3,254.63 5,925,245.29 484,492.77 3.30 5,770.33 MW D+I FR-AK-CAZ-SC(7) 11,718.25 89.81 192.67 6,385.20 6,225.56 -4,862.81 3,232.31 5,925,153.28 484,470.22 2.04 5,830.88 MWD+I FR-AK-CAZ-SC(7) 11,813.16 88.18 191.81 6,386.87 6,227.23 -4,955.54 3,212.19 5,925,060.61 484,449.87 1.94 5,893.28 MWD+IFR-AK-CAZ-SC(7) 11,909.04 88.36 191.70 6,389.76 6,230.12 -5,049.37 3,192.66 5,924,966.84 484,430.12 0.22 5,956.91 MWD+I FR-AK-CAZ-SC(7) 12,003.80 88.19 193.00 6,392.61 6,232.97 -5,141.89 3,172.41 5,924,874.38 484,409.63 1.38 6,019.05 MWD+IFR-AK-CAZ-SC(7) 12,096.90 87.70 194.18 6,395.95 6,236.31 -5,232.32 3,150.54 5,924,784.01 484,387.55 1.37 6,078.56 MWD+IFR-AK-CAZ-SC(7) 12,192.51 89.27 195.64 6,398.48 6,238.84 -5,324.68 3,125.95 5,924,691.73 484,362.73 2.24 6,137.99 MW D+I FR-AK-CAZ-SC(7) 12,287.54 88.32 196.32 6,400.48 6,240.84 -5,416.01 3,099.80 5,924,600.46 484,336.35 1.23 6,195.66 MW D+I FR-AK-CAZ-SC(7) 12,383.45 88.95 199.63 6,402.76 6,243.12 -5,507.20 3,070.21 5,924,509.36 484,306.54 3.51 6,251.16 MWD+IFR-AK-CAZ-SC(7) 12,478.63 89.84 199.82 6,403.77 6,244.13 -5,596.79 3,038.09 5,924,419.86 484,274.20 0.96 6,303.87 MWD+IFR-AK-CAZ-SC(7) 12,573.07 89.93 199.96 6,403.96 6,244.32 -5,685.60 3,005.96 5,924,331.14 484,241.85 0.18 6,355.95 MWD+1FR-AK-CAZ-SC(7) 12,667.82 91.24 200.21 6,402.99 6,243.35 -5,774.58 2,973.42 5,924,242.25 484,209.10 1.41 6,407.92 MWD+IFR-AK-CAZ-SC(7) 12,762.82 91.59 198.98 6,400.65 6,241.01 -5,864.05 2,941.58 5,924,152.87 484,177.03 1.35 6,460.70 MWD+IFR-AK-CAZ-SC(7) 12,857.98 91.48 198.00 6,398.10 6,238.46 -5,954.26 2,911.41 5,924,062.74 484,146.64 1.04 6,515.08 MWD+IFR-AK-CAZ-SC(7) 12,952.68 92.38 197.28 6,394.91 6,235.27 -6,044.46 2,882.73 5,923,972.62 484,117.74 1.22 6,570.32 MWD+IFR-AK-CAZ-SC(7) 13,047.58 91.94 193.03 6,391.33 6,231.69 -6,135.97 2,857.94 5,923,881.18 484,092.73 4.50 6,628.96 MW D+I FR-AK-CAZ-SC(7) 13,141.13 89.50 189.18 6,390.15 6,230.51 -6,227.74 2,839.93 5,923,789.47 484,074.49 4.87 6,691.83 MWD+IFR-AK-CAZ-SC(7) 13,236.33 87.48 186.50 6,392.66 6,233.02 -6,322.00 2,826.95 5,923,695.25 484,061.28 3.52 6,759.72 MWD+IFR-AK-CAZ-SC(7) 13,332.50 88.77 186.41 6,395.81 6,236.17 -6,417.51 2,816.14 5,923,599.78 484,050.24 1.34 6,829.90 MW D+I FR-AK-CAZ-SC(7) 13,427.95 88.67 185.98 6,397.94 6,238.30 -6,512.38 2,805.85 5,923,504.94 484,039.70 0.46 6,899.87 MWD+IFR-AK-CAZ-SC(7) 13,521.41 88.40 184.44 6,400.33 6,240.69 -6,605.42 2,797.36 5,923,411.93 484,030.99 1.67 6,969.46 MWD+IFR-AK-CAZ-SC(7) 13,616.06 88.14 184.70 6,403.19 6,243.55 -6,699.72 2,789.82 5,923,317.66 484,023.22 0.39 7,040.62 MWD+IFR-AK-CAZ-SC(7) 13,710.58 89.46 188.26 6,405.17 6,245.53 -6,793.60 2,779.16 5,923,223.81 484,012.32 4.02 7,109.58 MWD+IFR-AK-CAZ-SC(7) 13,805.91 90.70 190.81 6,405.03 6,245.39 -6,887.60 2,763.37 5,923,129.86 483,996.30 2.97 7,175.58 MWD+IFR-AK-CAZ-SC(7) 13,900.16 91.17 193.44 6,403.50 6,243.86 -6,979.73 2,743.58 5,923,037.79 483,976.28 2.83 7,237.68 MW D+I FR-AK-CAZ-SC(7) 13,995.25 89.31 189.76 6,403.10 6,243.46 -7,072.86 2,724.46 5,922,944.72 483,956.94 4.34 7,300.99 MWD+IFR-AK-CAZ-SC(7) 14,090.63 89.54 188.91 6,404.05 6,244.41 -7,166.97 2,708.99 5,922,850.66 483,941.23 0.92 7,367.27 MW D+I FR-AK-CAZ-SC(7) 14,184.95 87.80 187.34 6,406.24 6,246.60 -7,260.31 2,695.67 5,922,757.36 483,927.68 2.48 7,434.21 MWD+IFR-AK-CAZ-SC(7) 14,280.00 87.90 187.25 6,409.81 6,250.17 -7,354.52 2,683.60 5,922,663.18 483,915.38 0.14 7,502.60 MWD+IFR-AK-CAZ-SC(7) 14,376.13 85.97 190.37 6,414.95 6,255.31 -7,449.37 2,668.91 5,922,568.39 483,900.45 3.81 7,569.93 MWD+IFR-AK-CAZ-SC(7) 14,470.87 87.50 195.44 6,420.35 6,260.71 -7,541.53 2,647.79 5,922,476.28 483,879.11 5.58 7,631.27 MWD+IFR-AK-CAZ-SC(7) 14,564.13 89.21 200.48 6,423.03 6,263.39 -7,630.18 2,619.05 5,922,387.72 483,850.15 5.70 7,685.24 MWD+IFR-AK-CAZ-SC(7) 14,659.33 88.74 199.03 6,424.73 6,265.09 -7,719.76 2,586.88 5,922,298.23 483,817.76 1.60 7,737.91 MW D+I FR-AK-CAZ-SC(7) 14,754.81 89.12 197.48 6,426.52 6,266.88 -7,810.41 2,556.98 5,922,207.66 483,787.64 1.67 7,792.80 MWD+IFR-AK-CAZ-SC(7) 14,848.40 89.08 194.78 6,427.99 6,268.35 -7,900.30 2,530.98 5,922,117.84 483,761.42 2.88 7,849.41 MW D+I FR-AK-CAZ-SC(7) 14,944.18 89.08 192.03 6,429.52 6,269.88 -7,993.45 2,508.78 5,922,024.76 483,738.99 2.87 7,910.90 MWD+IFR-AK-CAZ-SC(7) 2/24/2016 9:44:05AM Page 6 COMPASS 5000.1 Build 74 • S Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: 120+39.64 @ 159.64usft(D25) Well: 2S-03 North Reference: True Wellbore: 2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03 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 15,040.54 89.32 190.61 6,430.87 6,271.23 -8,087.92 2,489.87 5,921,930.34 483,719.85 1.49 7,975.41 MWD+IFR-AK-CAZ-SC(7) 15,132.00 89.29 190.42 6,431.98 6,272.34 -8,177.84 2,473.18 5,921,840.47 483,702.94 0.21 8,037.59 MWD+IFR-AK-CAZ-SC(7) 15,224.25 88.98 192.17 6,433.37 6,273.73 -8,268.29 2,455.11 5,921,750.08 483,684.65 1.93 8,099.38 MWD+IFR-AK-CAZ-SC(7) 15,316.87 89.29 194.17 6,434.77 6,275.13 -8,358.46 2,434.02 5,921,659.97 483,663.33 2.18 8,159.13 MWD+IFR-AK-CAZ-SC(7) 15,409.64 89.63 196.87 6,435.64 6,276.00 -8,447.84 2,409.20 5,921,570.67 483,638.29 2.93 8,216.03 MWD+IFR-AK-CAZ-SC(7) 15,501.00 89.74 195.82 6,436.15 6,276.51 -8,535.50 2,383.49 5,921,483.08 483,612.36 1.16 8,271.02 MW D+I FR-AK-CAZ-SC(7) 15,595.47 89.53 196.59 6,436.75 6,277.11 -8,626.21 2,357.12 5,921,392.44 483,585.78 0.84 8,328.07 MW D+I FR-AK-CAZ-SC(7) 15,688.46 90.01 196.44 6,437.12 6,277.48 -8,715.37 2,330.69 5,921,303.36 483,559.12 0.54 8,383.83 MWD+IFR-AK-CAZ-SC(7) 15,778.27 90.28 196.42 6,436.89 6,277.25 -8,801.51 2,305.29 5,921,217.29 483,533.51 0.30 8,437.78 MWD+IFR-AK-CAZ-SC(7) 15,871.03 89.36 195.54 6,437.19 6,277.55 -8,890.68 2,279.75 5,921,128.19 483,507.75 1.37 8,494.09 MWD+1FR-AK-CAZ-SC(7) 15,961.10 88.98 194.67 6,438.49 6,278.85 -8,977.63 2,256.28 5,921,041.31 483,484.07 1.05 8,549.84 MWD+IFR-AK-CAZ-SC(7) 16,055.33 88.28 195.44 6,440.74 6,281.10 -9,068.60 2,231.81 5,920,950.41 483,459.38 1.10 8,608.22 MW D+I FR-AK-CAZ-SC(7) 16,147.87 88.98 195.97 6,442.96 6,283.32 -9,157.66 2,206.77 5,920,861.42 483,434.12 0.95 8,664.73 MWD+IFR-AK-CAZ-SC(7) 16,240.83 89.64 195.90 6,444.08 6,284.44 -9,247.04 2,181.25 5,920,772.11 483,408.38 0.71 8,721.22 MWD+IFR-AK-CAZ-SC(7) 16,331.08 88.54 194.28 6,445.51 6,285.87 -9,334.16 2,157.76 5,920,685.06 483,384.68 2.17 8,777.10 MWD+IFR-AK-CAZ-SC(7) 16,423.08 85.94 192.86 6,449.94 6,290.30 -9,423.48 2,136.20 5,920,595.80 483,362.90 3.22 8,835.89 MWD+IFR-AK-CAZ-SC(7) 16,514.67 85.62 193.28 6,456.68 6,297.04 -9,512.45 2,115.54 5,920,506.89 483,342.02 0.58 8,894.95 MW D+I FR-AK-CAZ-SC(7) 16,607.53 84.30 192.22 6,464.84 6,305.20 -9,602.67 2,095.13 5,920,416.73 483,321.38 1.82 8,955.15 MW D+I FR-AK-CAZ-SC(7) 16,696.12 79.93 188.81 6,476.99 6,317.35 -9,688.91 2,079.11 5,920,330.54 483,305.15 6.23 9,014.79 MWD+IFR-AK-CAZ-SC(7) 16,760.00 79.93 188.81 6,488.16 6,328.52 -9,751.07 2,069.48 5,920,268.41 483,295.36 0.00 9,058.91 PROJECTED to TD 2/24/2016 9:44:05AM Page 7 COMPASS 5000.1 Build 74 • • Final Definitive Survey Verified and Signed-oft All targets and/or well position objectives have been achieved. l J Yes L No !have checked to the best of my ability that the following data is correct: Li Surface Coordinates p Declination & Convergence p GRS Survey Corrections Survey Tool Codes Digilay signed DY Oncent Osra Vincent Osara 5cmlmiM e.ou 500omoge' e ma/-vove:A rebsom, SLB DE: ° :x'a 220100923 0900' Mike Callahan°"n'"""°"""`°`"-'°`�'�"'' Client Representative:. -M+McnHlv�aroc40.1P+,,<<-U5 Date- 24-Feb-2016 • • 21 51 05 2693 1 RL46.16...A ap MAR 14 2016 AOGCC FINAL ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad 2S-03 2S-03 Definitive Survey Report 23 February, 2016 NAD 83 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: 120+39.64 @ 159.64usft(D25) Well: 2S-03 North Reference: True Wellbore: 2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03 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-03 Well Position +N/-S 0.00 usft Northing: 5,929,773.21 usfi Latitude: 70° 13'10.813 N +E/-W 0.00 usft Easting: 1,621,283.64 usfi Longitude: 150°9'15.692 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 120.00 usft Wellbore 2S-03 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2015 2/1/2016 18.37 80.86 57,485 Design 2S-03 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 10,561.36 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.64 0.00 0.00 143.35 Survey Program Date 2/23/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 99.00 1,031.00 2S-03 Srvy#1 -GYD-GC-SS(2S-03PB1 GYD-GC-SS Gyrodata gyro single shots 1/31/2016 10:2 1,058.15 2,718.88 2S-03 Srvy#2-GMAG(2S-03PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/31/2016 10:;: 2,740.81 2,740.81 2S-03 Srvy#3-Inc+Trend(2S-03PB1) INC+TREND Inclinometer+known azi trend 2/5/2016 9:34 2,835.17 8,756.84 2S-03 Srvy#4-GMAG(2S-03PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/5/2016 9:38 8,852.56 8,852.56 2S-03 Srvy#5-Inc+Trend(2S-03PB1) INC+TREND Inclinometer+known azi trend 2/16/2016 9:1. 8,947.89 10,561.36 2S-03 Srvy#6-GMAG(2S-03PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/16/2016 9:1 10,656.01 16,696.12 2S-03 Srvy#7-SLB_MWD+GMAG(2S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/19/2016 1:4: 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) (°/100') (ft) Survey Tool Name 39.64 0.00 0.00 39.64 -120.00 0.00 0.00 5,929,773.21 1,621,283.64 0.00 0.00 UNDEFINED 99.00 0.68 307.59 99.00 -60.64 0.21 -0.28 5,929,773.43 1,621,283.36 1.15 -0.34 GYD-GC-SS(1) 120.40 0.76 307.84 120.40 -39.24 0.38 -0.49 5,929,773.59 1,621,283.15 0.35 -0.60 NOT an Actual Survey 16"x 20" 187.00 0.99 308.38 186.99 27.35 1.01 -1.29 5,929,774.22 1,621,282.35 0.35 -1.58 GYD-GC-SS(1) 279.00 1.43 323.75 278.97 119.33 2.42 -2.59 5,929,775.64 1,621,281.06 0.59 -3.49 GYD-GC-SS(1) 373.00 2.73 352.26 372.91 213.27 5.59 -3.59 5,929,778.81 1,621,280.07 1.73 -6.62 GYD-GC-SS(1) 467.00 4.05 3.66 466.74 307.10 11.12 -3.68 5,929,784.34 1,621,279.99 1.57 -11.12 GYD-GC-SS(1) 560.00 4.75 8.02 559.47 399.83 18.21 -2.93 5,929,791.43 1,621,280.76 0.83 -16.36 GYD-GC-SS(1) 2/23/2016 2:58:10PM Page 2 COMPASS 5000.1 Build 74 • • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: 120+39.64 @ 159.64usft(D25) Well: 2S-03 North Reference: True Wellbore: 2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03 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) (°1100) (ft) Survey Tool Name 654.00 5.88 10.82 653.06 493.42 26.79 -1.48 5,929,800.01 1,621,282.23 1.23 -22.38 GYD-GC-SS(1) 748.00 7.82 21.67 746.39 586.75 37.47 1.78 5,929,810.67 1,621,285.52 2.47 -29.00 GYD-GC-SS(1) 843.00 9.53 23.20 840.30 680.66 50.70 7.27 5,929,823.89 1,621,291.04 1.82 -36.34 GYD-GC-SS(1) 937.00 10.63 22.72 932.85 773.21 65.85 13.68 5,929,839.02 1,621,297.49 1.17 -44.67 GYD-GC-SS(1) 1,031.00 12.43 22.65 1,024.95 865.31 83.19 20.93 5,929,856.34 1,621,304.78 1.91 -54.25 GYD-GC-SS(1) 1,058.15 13.24 22.22 1,051.42 891.78 88.76 23.23 5,929,861.91 1,621,307.09 3.00 -57.35 MWD+IFR-AK-CAZ-SC(2) 1,152.92 15.04 22.94 1,143.31 983.67 110.14 32.13 5,929,883.25 1,621,316.04 1.91 -69.19 MWD+IFR-AK-CAZ-SC(2) 1,247.26 17.39 24.50 1,233.89 1,074.25 134.24 42.75 5,929,907.33 1,621,326.72 2.53 -82.19 MWD+IFR-AK-CAZ-SC(2) 1,340.99 21.22 26.16 1,322.34 1,162.70 162.22 56.04 5,929,935.27 1,621,340.08 4.13 -96.71 MWD+IFR-AK-CAZ-SC(2) 1,435.66 24.72 24.77 1,409.49 1,249.85 195.58 71.89 5,929,968.59 1,621,356.02 3.74 -114.02 MWD+IFR-AK-CAZ-SC(2) 1,530.79 25.79 26.03 1,495.53 1,335.89 232.24 89.31 5,930,005.20 1,621,373.53 1.26 -133.03 MWD+IFR-AK-CAZ-SC(2) 1,626.16 26.71 26.08 1,581.06 1,421.42 270.13 107.83 5,930,043.04 1,621,392.15 0.96 -152.38 MWD+IFR-AK-CAZ-SC(2) 1,721.19 27.14 25.69 1,665.79 1,506.15 308.85 126.62 5,930,081.71 1,621,411.03 0.49 -172.23 MWD+IFR-AK-CAZ-SC(2) 1,815.71 27.42 33.73 1,749.82 1,590.18 346.39 148.06 5,930,119.19 1,621,432.56 3.91 -189.55 MWD+IFR-AK-CAZ-SC(2) 1,909.84 27.44 39.74 1,833.39 1,673.75 381.10 173.96 5,930,153.83 1,621,458.55 2.94 -201.94 MWD+IFR-AK-CAZ-SC(2) 2,004.80 25.17 44.51 1,918.52 1,758.88 412.33 202.11 5,930,184.99 1,621,486.78 3.26 -210.20 MWD+IFR-AK-CAZ-SC(2) 2,099.72 24.63 50.47 2,004.63 1,844.99 439.32 231.52 5,930,211.90 1,621,516.25 2.70 -214.30 MWD+IFR-AK-CAZ-SC(2) 2,194.87 25.45 63.12 2,090.90 1,931.26 461.20 265.08 5,930,233.69 1,621,549.86 5.68 -211.83 MWD+IFR-AK-CAZ-SC(2) 2,289.33 27.45 75.16 2,175.53 2,015.89 475.96 304.26 5,930,248.35 1,621,589.07 6.05 -200.29 MWD+IFR-AK-CAZ-SC(2) 2,383.45 30.15 81.07 2,258.01 2,098.37 485.19 348.59 5,930,257.47 1,621,633.43 4.17 -181.23 MWD+IFR-AK-CAZ-SC(2) 2,476.89 32.78 84.16 2,337.71 2,178.07 491.41 396.95 5,930,263.56 1,621,681.80 3.30 -157.36 MWD+IFR-AK-CAZ-SC(2) 2,572.22 32.39 83.70 2,418.04 2,258.40 496.84 448.00 5,930,268.86 1,621,732.86 0.48 -131.24 MWD+IFR-AK-CAZ-SC(2) 2,666.25 33.43 89.38 2,497.00 2,337.36 499.88 498.95 5,930,271.78 1,621,783.81 3.46 -103.27 MWD+IFR-AK-CAZ-SC(2) 2,718.88 33.57 90.10 2,540.88 2,381.24 500.01 528.00 5,930,271.83 1,621,812.85 0.80 -86.04 MWD+IFR-AK-CAZ-SC(2) 2,740.81 33.44 88.91 2,559.17 2,399.53 500.12 540.10 5,930,271.91 1,621,824.95 3.05 -78.90 INC+TREND(3) 2,781.70 33.89 89.13 2,593.20 2,433.56 500.51 562.77 5,930,272.24 1,621,847.62 1.15 -65.69 NOT an Actual Survey'(4) 10 3/4"x 13-1/2" 2,835.17 34.49 89.40 2,637.43 2,477.79 500.89 592.81 5,930,272.55 1,621,877.66 1.15 -48.06 MWD+IFR-AK-CAZ-SC(4) 2,929.75 36.21 90.65 2,714.57 2,554.93 500.86 647.53 5,930,272.37 1,621,932.37 1.97 -15.37 MWD+IFR-AK-CAZ-SC(4) 3,024.24 37.57 93.01 2,790.14 2,630.50 499.03 704.21 5,930,270.40 1,621,989.04 2.08 19.92 MWD+IFR-AK-CAZ-SC(4) 3,123.14 38.70 94.95 2,867.94 2,708.30 494.78 765.13 5,930,266.00 1,622,049.94 1.67 59.69 MWD+IFR-AK-CAZ-SC(4) 3,214.24 39.66 97.87 2,938.56 2,778.92 488.34 822.30 5,930,259.41 1,622,107.10 2.28 98.99 MWD+IFR-AK-CAZ-SC(4) 3,309.20 39.94 100.70 3,011.52 2,851.88 478.53 882.28 5,930,249.45 1,622,167.04 1.93 142.65 MWD+IFR-AK-CAZ-SC(4) 3,404.39 40.64 103.86 3,084.14 2,924.50 465.43 942.41 5,930,236.20 1,622,227.13 2.27 189.05 MWD+IFR-AK-CAZ-SC(4) 3,498.42 41.50 108.17 3,155.04 2,995.40 448.37 1,001.75 5,930,219.00 1,622,286.42 3.15 238.15 MWD+IFR-AK-CAZ-SC(4) 3,593.22 42.17 111.43 3,225.68 3,066.04 426.95 1,061.22 5,930,197.43 1,622,345.83 2.40 290.84 MWD+IFR-AK-CAZ-SC(4) 3,687.80 42.71 112.59 3,295.48 3,135.84 403.03 1,120.39 5,930,173.36 1,622,404.93 1.01 345.35 MWD+IFR-AK-CAZ-SC(4) 3,782.58 44.52 112.00 3,364.10 3,204.46 378.23 1,180.88 5,930,148.41 1,622,465.36 1.96 401.35 MWD+IFR-AK-CAZ-SC(4) 3,876.02 46.63 112.03 3,429.50 3,269.86 353.22 1,242.74 5,930,123.24 1,622,527.15 2.26 458.34 MWD+IFR-AK-CAZ-SC(4) 3,970.37 49.13 112.04 3,492.77 3,333.13 326.96 1,307.61 5,930,096.83 1,622,591.94 2.65 518.12 MWD+IFR-AK-CAZ-SC(4) 2/23/2016 2:58:10PM Page 3 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: 120+39.64 @ 159.64usft(D25) Well: 2S-03 North Reference: True Wellbore: 2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03 Database: OAKEDMP2 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) (0/100') (ft) Survey Tool Name 4,064.96 50.96 111.78 3,553.52 3,393.88 299.91 1,374.88 5,930,069.60 1,622,659.14 1.95 579.98 MWD+IFR-AK-CAZ-SC(4) 4,159.92 51.08 111.85 3,613.25 3,453.61 272.48 1,443.41 5,930,042.00 1,622,727.59 0.14 642.89 MW D+I FR-AK-CAZ-SC(4) 4,254.49 51.03 111.77 3,672.70 3,513.06 245.15 1,511.70 5,930,014.51 1,622,795.80 0.08 705.58 MWD+IFR-AK-CAZ-SC(4) 4,349.76 51.11 111.87 3,732.56 3,572.92 217.61 1,580.50 5,929,986.79 1,622,864.53 0.12 768.74 MWD+IFR-AK-CAZ-SC(4) 4,444.28 51.03 110.84 3,791.95 3,632.31 190.83 1,648.98 5,929,959.84 1,622,932.93 0.85 831.10 MWD+IFR-AK-CAZ-SC(4) 4,537.03 51.10 110.83 3,850.24 3,690.60 165.17 1,716.41 5,929,934.01 1,623,000.29 0.08 891.93 MWD+IFR-AK-CAZ-SC(4) 4,632.40 51.17 109.61 3,910.09 3,750.45 139.51 1,786.08 5,929,908.17 1,623,069.89 1.00 954.11 MWD+IFR-AK-CAZ-SC(4) 4,726.93 51.25 108.73 3,969.31 3,809.67 115.31 1,855.68 5,929,883.81 1,623,139.42 0.73 1,015.06 MWD+IFR-AK-CAZ-SC(4) 4,820.81 51.07 107.98 4,028.18 3,868.54 92.28 1,925.08 5,929,860.61 1,623,208.76 0.65 1,074.96 MWD+IFR-AK-CAZ-SC(4) 4,916.59 51.13 106.93 4,088.33 3,928.69 69.93 1,996.19 5,929,838.07 1,623,279.80 0.86 1,135.34 MWD+IFR-AK-CAZ-SC(4) 5,010.86 51.21 106.99 4,147.44 3,987.80 48.50 2,066.43 5,929,816.47 1,623,349.98 0.10 1,194.45 MWD+IFR-AK-CAZ-SC(4) 5,104.99 51.11 108.41 4,206.48 4,046.84 26.22 2,136.27 5,929,794.01 1,623,419.76 1.18 1,254.03 MWD+IFR-AK-CAZ-SC(4) 5,199.04 51.12 109.40 4,265.52 4,105.88 2.50 2,205.53 5,929,770.11 1,623,488.95 0.82 1,314.39 MWD+IFR-AK-CAZ-SC(4) 5,294.20 50.66 110.68 4,325.55 4,165.91 -22.80 2,274.90 5,929,744.64 1,623,558.25 1.15 1,376.09 MWD+IFR-AK-CAZ-SC(4) 5,389.44 50.33 110.32 4,386.13 4,226.49 -48.54 2,343.73 5,929,718.74 1,623,627.00 0.45 1,437.82 MWD+IFR-AK-CAZ-SC(4) 5,483.64 50.61 110.40 4,446.09 4,286.45 -73.82 2,411.85 5,929,693.29 1,623,695.05 0.30 1,498.76 MWD+IFR-AK-CAZ-SC(4) 5,578.33 50.43 110.44 4,506.29 4,346.65 -99.32 2,480.34 5,929,667.62 1,623,763.47 0.19 1,560.10 MWD+IFR-AK-CAZ-SC(4) 5,673.16 50.65 110.27 4,566.56 4,406.92 -124.78 2,548.98 5,929,641.98 1,623,832.04 0.27 1,621.51 MWD+IFR-AK-CAZ-SC(4) 5,768.21 50.23 110.52 4,627.10 4,467.46 -150.32 2,617.67 5,929,616.27 1,623,900.66 0.49 1,682.99 MWD+IFR-AK-CAZ-SC(4) 5,862.27 50.51 111.83 4,687.09 4,527.45 -176.49 2,685.22 5,929,589.93 1,623,968.13 1.11 1,744.30 MWD+IFR-AK-CAZ-SC(4) 5,957.06 50.54 112.78 4,747.36 4,587.72 -204.26 2,752.91 5,929,562.00 1,624,035.75 0.77 1,806.99 MWD+IFR-AK-CAZ-SC(4) 6,052.13 50.63 112.23 4,807.72 4,648.08 -232.37 2,820.76 5,929,533.71 1,624,103.52 0.46 1,870.04 MWD+IFR-AK-CAZSC(4) 6,146.51 50.47 113.62 4,867.69 4,708.05 -260.76 2,887.88 5,929,505.16 1,624,170.56 1.15 1,932.88 MWD+IFR-AK-CAZ-SC(4) 6,240.39 50.88 115.73 4,927.19 4,767.55 -291.07 2,953.86 5,929,474.68 1,624,236.46 1.79 1,996.59 MWD+IFR-AK-CAZ-SC(4) 6,335.37 51.43 118.56 4,986.77 4,827.13 -324.82 3,019.68 5,929,440.76 1,624,302.18 2.39 2,062.95 MWD+IFR-AK-CAZ-SC(4) 6,430.02 52.39 121.19 5,045.16 4,885.52 -361.93 3,084.25 5,929,403.49 1,624,366.66 2.41 2,131.27 MWD+IFR-AK-CAZ-SC(4) 6,524.27 52.99 124.07 5,102.30 4,942.66 -402.35 3,147.37 5,929,362.92 1,624,429.67 2.51 2,201.37 MWD+IFR-AK-CAZ-SC(4) 6,619.02 53.30 126.46 5,159.13 4,999.49 -446.12 3,209.26 5,929,319.00 1,624,491.44 2.04 2,273.43 MWD+IFR-AK-CAZ-SC(4) 6,714.34 53.81 129.69 5,215.77 5,056.13 -493.40 3,269.61 5,929,271.57 1,624,551.66 2.78 2,347.38 MWD+IFR-AK-CAZ-SC(4) 6,807.69 54.01 131.52 5,270.76 5,111.12 -542.50 3,326.87 5,929,222.33 1,624,608.80 1.60 2,420.95 MWD+IFR-AK-CAZSC(4) 6,903.31 54.07 133.10 5,326.91 5,167.27 -594.60 3,384.11 5,929,170.10 1,624,665.89 1.34 2,496.91 MWD+IFR-AK-CAZ-SC(4) 6,998.16 54.04 134.47 5,382.59 5,222.95 -647.73 3,439.54 5,929,116.83 1,624,721.18 1.17 2,572.63 MWD+IFR-AK-CAZSC(4) 7,092.00 53.65 137.03 5,437.96 5,278.32 -701.99 3,492.41 5,929,062.44 1,624,773.91 2.24 2,647.72 MWD+IFR-AK-CAZ-SC(4) 7,187.22 53.65 139.87 5,494.41 5,334.77 -759.37 3,543.26 5,929,004.93 1,624,824.62 2.40 2,724.12 MWD+IFR-AK-CAZ-SC(4) 7,281.99 53.38 143.30 5,550.77 5,391.13 -819.06 3,590.60 5,928,945.13 1,624,871.80 2.92 2,800.26 MWD+IFR-AK-CAZ-SC(4) 7,376.46 53.33 146.73 5,607.16 5,447.52 -881.14 3,634.05 5,928,882.94 1,624,915.08 2.91 2,876.00 MWD+IFR-AK-CAZ-SC(4) 7,470.40 54.01 150.28 5,662.83 5,503.19 -945.66 3,673.57 5,928,818.33 1,624,954.43 3.13 2,951.36 MWD+IFR-AK-CAZ-SC(4) 7,565.20 54.64 153.51 5,718.12 5,558.48 -1,013.58 3,709.83 5,928,750.33 1,624,990.52 2.85 3,027.49 MWD+IFR-AK-CAZ-SC(4) 7,659.92 54.58 156.32 5,772.99 5,613.35 -1,083.50 3,742.56 5,928,680.33 1,625,023.07 2.42 3,103.13 MWD+IFR-AK-CAZ-SC(4) 7,755.31 54.76 158.29 5,828.15 5,668.51 -1,155.29 3,772.58 5,928,608.47 1,625,052.91 1.70 3,178.65 MWD+IFR-AK-CAZ-SC(4) 2/23/2016 2:58:10PM Page 4 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: 120+39.64 @ 159.64usft(D25) Well: 2S-03 North Reference: True Wellbore: 2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,851.51 54.93 159.69 5,883.55 5,723.91 -1,228.72 3,800.78 5,928,534.99 1,625,080.92 1.20 3,254.39 MWD+IFR-AK-CAZ-SC(4) 7,944.13 57.65 160.82 5,934.95 5,775.31 -1,301.23 3,826.80 5,928,462.42 1,625,106.74 3.11 3,328.10 MWD+IFR-AK-CAZ-SC(4) 8,037.87 61.20 162.16 5,982.62 5,822.98 -1,377.75 3,852.40 5,928,385.84 1,625,132.15 3.98 3,404.78 MWD+IFR-AK-CAZ-SC(4) 8,134.96 65.11 163.68 6,026.46 5,866.82 -1,460.54 3,877.81 5,928,302.99 1,625,157.35 4.26 3,486.38 MWD+IFR-AK-CAZ-SC(4) 8,227.49 67.60 165.32 6,063.57 5,903.93 -1,542.21 3,900.45 5,928,221.27 1,625,179.78 3.14 3,565.42 MWD+IFR-AK-CAZ-SC(4) 8,321.13 69.49 167.84 6,097.82 5,938.18 -1,626.98 3,920.66 5,928,136.46 1,625,199.78 3.22 3,645.49 MWD+IFR-AK-CAZ-SC(4) 8,416.49 71.30 170.93 6,129.83 5,970.19 -1,715.26 3,937.20 5,928,048.15 1,625,216.08 3.59 3,726.19 MWD+IFR-AK-CAZ-SC(4) 8,511.46 72.15 172.50 6,159.61 5,999.97 -1,804.49 3,950.19 5,927,958.89 1,625,228.85 1.81 3,805.54 MWD+IFR-AK-CAZ-SC(4) 8,606.43 72.76 174.79 6,188.24 6,028.60 -1,894.48 3,960.21 5,927,868.89 1,625,238.64 2.39 3,883.72 MWD+IFR-AK-CAZ-SC(4) 8,701.25 73.21 177.13 6,215.99 6,056.35 -1,984.92 3,966.59 5,927,778.44 1,625,244.79 2.41 3,960.09 MWD+IFR-AK-CAZ-SC(4) 8,756.84 74.39 178.49 6,231.50 6,071.86 -2,038.26 3,968.63 5,927,725.10 1,625,246.69 3.17 4,004.11 MWD+IFR-AK-CAZ-SC(4) 8,826.90 74.24 179.92 6,250.44 6,090.80 -2,105.70 3,969.56 5,927,657.66 1,625,247.46 1.98 4,058.78 I NOT an Actual Survey 7-5/8 x 9-7/8 by 11" 8,852.56 74.19 180.45 6,257.42 6,097.78 -2,130.39 3,969.48 5,927,632.97 1,625,247.31 1.98 4,078.54 INC+TREND(5) 8,947.89 75.01 181.42 6,282.74 6,123.10 -2,222.29 3,967.98 5,927,541.09 1,625,245.58 1.30 4,151.37 MWD+IFR-AK-CAZ-SC(6) 9,042.78 75.22 183.94 6,307.12 6,147.48 -2,313.88 3,963.69 5,927,449.52 1,625,241.06 2.58 4,222.31 MWD+IFR-AK-CAZ-SC(6) 9,137.59 76.65 185.80 6,330.16 6,170.52 -2,405.51 3,955.88 5,927,357.92 1,625,233.02 2.43 4,291.16 MWD+IFR-AK-CAZ-SC(6) 9,232.40 80.93 185.26 6,348.59 6,188.95 -2,498.06 3,946.92 5,927,265.40 1,625,223.83 4.55 4,360.07 MWD+IFR-AK-CAZ-SC(6) 9,326.85 84.53 184.89 6,360.54 6,200.90 -2,591.37 3,938.64 5,927,172.13 1,625,215.30 3.83 4,429.99 MWD+IFR-AK-CAZ-SC(6) 9,421.97 88.76 186.02 6,366.10 6,206.46 -2,685.87 3,929.61 5,927,077.65 1,625,206.04 4.60 4,500.43 MWD+IFR-AK-CAZ-SC(6) 9,519.33 92.15 185.87 6,365.33 6,205.69 -2,782.69 3,919.53 5,926,980.87 1,625,195.71 3.49 4,572.09 MWD+IFR-AK-CAZ-SC(6) 9,612.10 91.39 188.72 6,362.46 6,202.82 -2,874.65 3,907.76 5,926,888.94 1,625,183.71 3.18 4,638.85 MWD+IFR-AK-CAZ-SC(6) 9,707.04 92.46 191.75 6,359.27 6,199.63 -2,968.02 3,890.90 5,926,795.63 1,625,166.62 3.38 4,703.70 MWD+IFR-AK-CAZ-SC(6) 9,801.77 92.57 195.88 6,355.11 6,195.47 -3,059.90 3,868.31 5,926,703.82 1,625,143.79 4.36 4,763.94 MWD+IFR-AK-CAZ-SC(6) 9,896.56 92.10 200.03 6,351.25 6,191.61 -3,149.98 3,839.11 5,926,613.82 1,625,114.38 4.40 4,818.79 MWD+IFR-AK-CAZ-SC(6) 9,992.30 89.33 200.03 6,350.06 6,190.42 -3,239.91 3,806.33 5,926,523.98 1,625,081.36 2.89 4,871.38 MWD+IFR-AK-CAZ-SC(6) 10,086.92 88.93 198.88 6,351.49 6,191.85 -3,329.12 3,774.82 5,926,434.87 1,625,049.63 1.29 4,924.14 MWD+IFR-AK-CAZ-SC(6) 10,181.40 88.83 197.79 6,353.34 6,193.70 -3,418.78 3,745.10 5,926,345.29 1,625,019.69 1.16 4,978.35 MWD+IFR-AK-CAZ-SC(6) 10,277.03 88.49 196.66 6,355.58 6,195.94 -3,510.10 3,716.79 5,926,254.05 1,624,991.15 1.23 5,034.72 MWD+IFR-AK-CAZ-SC(6) 10,371.90 88.07 196.20 6,358.42 6,198.78 -3,601.05 3,689.97 5,926,163.17 1,624,964.10 0.66 5,091.68 MWD+IFR-AK-CAZ-SC(6) 10,466.92 87.39 196.30 6,362.19 6,202.55 -3,692.20 3,663.40 5,926,072.10 1,624,937.31 0.72 5,148.96 MWD+IFR-AK-CAZ-SC(6) 10,561.36 87.32 195.65 6,366.54 6,206.90 -3,782.90 3,637.44 5,925,981.48 1,624,911.12 0.69 5,206.23 MWD+IFR-AK-CAZ-SC(6)k 10,656.01 87.63 197.44 6,370.71 6,211.07 -3,873.54 3,610.51 5,925,890.92 1,624,883.96 1.92 5,262.89 MWD+IFR-AK-CAZ-SC(7) 10,676.59 87.95 198.16 6,371.51 6,211.87 -3,893.12 3,604.23 5,925,871.36 1,624,877.63 3.83 5,274.85 MWD+IFR-AK-CAZ-SC(7) Tie-in tb old 10,731.24 87.40 197.04 6,373.73 6,214.09 -3,945.17 3,587.72 5,925,819.35 1,624,860.99 2.28 5,306.75 MWD+IFR-AK-CAZ-SC(7) u 10,770.72 86.42 197.40 6,375.85 6,216.21 -3,982.82 3,576.05 5,925,781.73 1,624,849.22 2.64 5,330.00 MWD+IFR-AK-CAZ-SC(7) hole 10,867.03 86.22 201.11 6,382.04 6,222.40 -4,073.54 3,544.36 5,925,691.10 1,624,817.31 3.85 5,383.87 MWD+IFR-AK-CAZ-SC(7) 10,961.97 87.21 203.25 6,387.48 6,227.84 -4,161.30 3,508.58 5,925,603.44 1,624,781.31 2.48 5,432.93 MWD+IFR-AK-CAZ-SC(7) 11,055.87 90.67 205.48 6,389.22 6,229.58 -4,246.81 3,469.85 5,925,518.04 1,624,742.37 4.38 5,478.42 MWD+IFR-AK-CAZ-SC(7) 11,150.83 92.32 205.35 6,386.74 6,227.10 -4,332.55 3,429.11 5,925,432.42 1,624,701.42 1.74 5,522.90 MWD+IFR-AK-CAZ-SC(7) 2/23/2016 2:58:10PM Page 5 COMPASS 5000.1 Build 74 i i Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: 120+39.64 @ 159.64usft(D25) Well: 2S-03 North Reference: True Wellbore: 2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03 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 11,244.08 92.15 205.27 6,383.10 6,223.46 -4,416.78 3,389.28 5,925,348.29 1,624,661.37 0.20 5,566.71 MWD+IFR-AK-CAZ-SC(7) 11,338.63 89.98 204.52 6,381.34 6,221.70 -4,502.52 3,349.49 5,925,262.66 1,624,621.37 2.43 5,611.75 MWD+1FR-AK-CAZ-SC(7) 11,433.70 88.79 201.15 6,382.36 6,222.72 -4,590.12 3,312.60 5,925,175.16 1,624,584.26 3.76 5,660.02 MWD+IFR-AK-CAZ-SC(7) 11,529.43 89.43 197.69 6,383.85 6,224.21 -4,680.38 3,280.78 5,925,084.99 1,624,552.22 3.68 5,713.45 MWD+IFR-AK-CAZ-SC(7) 11,623.50 89.56 194.59 6,384.68 6,225.04 -4,770.73 3,254.63 5,924,994.72 1,624,525.84 3.30 5,770.33 MW D+I FR-AK-CAZ-SC(7) 11,718.25 89.81 192.67 6,385.20 6,225.56 -4,862.81 3,232.31 5,924,902.71 1,624,503.29 2.04 5,830.88 MWD+IFR-AK-CAZ-SC(7) 11,813.16 88.18 191.81 6,386.87 6,227.23 -4,955.54 3,212.19 5,924,810.04 1,624,482.94 1.94 5,893.28 MWD+IFR-AK-CAZ-SC(7) 11,909.04 88.36 191.70 6,389.76 6,230.12 -5,049.37 3,192.66 5,924,716.27 1,624,463.18 0.22 5,956.91 MW D+I FR-AK-CAZ-SC(7) 12,003.80 88.19 193.00 6,392.61 6,232.97 -5,141.89 3,172.41 5,924,623.81 1,624,442.69 1.38 6,019.05 MWD+I FR-AK-CAZ-SC(7) 12,096.90 87.70 194.18 6,395.95 6,236.31 -5,232.32 3,150.54 5,924,533.44 1,624,420.60 1.37 6,078.56 MWD+IFR-AK-CAZ-SC(7) 12,192.51 89.27 195.64 6,398.48 6,238.84 -5,324.68 3,125.95 5,924,441.16 1,624,395.77 2.24 6,137.99 MWD+IFR-AK-CAZ-SC(7) 12,287.54 88.32 196.32 6,400.48 6,240.84 -5,416.01 3,099.80 5,924,349.90 1,624,369.39 1.23 6,195.66 MWD+IFR-AK-CAZ-SC(7) 12,383.45 88.95 199.63 6,402.76 6,243.12 -5,507.20 3,070.21 5,924,258.79 1,624,339.58 3.51 6,251.16 MWD+IFR-AK-CAZ-SC(7) 12,478.63 89.84 199.82 6,403.77 6,244.13 -5,596.79 3,038.09 5,924,169.29 1,624,307.23 0.96 6,303.87 MWD+IFR-AK-CAZ-SC(7) 12,573.07 89.93 199.96 6,403.96 6,244.32 -5,685.60 3,005.96 5,924,080.58 1,624,274.88 0.18 6,355.95 MWD+1FR-AK-CAZ-SC(7) 12,667.82 91.24 200.21 6,402.99 6,243.35 -5,774.58 2,973.42 5,923,991.69 1,624,242.12 1.41 6,407.92 MW D+I FR-AK-CAZ-SC(7) 12,762.82 91.59 198.98 6,400.65 6,241.01 -5,864.05 2,941.58 5,923,902.31 1,624,210.05 1.35 6,460.70 MWD+IFR-AK-CAZ-SC(7) 12,857.98 91.48 198.00 6,398.10 6,238.46 -5,954.26 2,911.41 5,923,812.18 1,624,179.65 1.04 6,515.08 MWD+IFR-AK-CAZ-SC(7) 12,952.68 92.38 197.28 6,394.91 6,235.27 -6,044.46 2,882.73 5,923,722.07 1,624,150.75 1.22 6,570.32 MWD+IFR-AK-CAZ-SC(7) 13,047.58 91.94 193.03 6,391.33 6,231.69 -6,135.97 2,857.94 5,923,630.63 1,624,125.73 4.50 6,628.96 MWD+IFR-AK-CAZ-SC(7) 13,141.13 89.50 189.18 6,390.15 6,230.51 -6,227.74 2,839.93 5,923,538.91 1,624,107.49 4.87 6,691.83 MWD+IFR-AK-CAZ-SC(7) 13,236.33 87.48 186.50 6,392.66 6,233.02 -6,322.00 2,826.95 5,923,444.69 1,624,094.27 3.52 6,759.72 MWD+IFR-AK-CAZ-SC(7) 13,332.50 88.77 186.41 6,395.81 6,236.17 -6,417.51 2,816.14 5,923,349.22 1,624,083.23 1.34 6,829.90 MWD+1FR-AK-CAZ-SC(7) 13,427.95 88.67 185.98 6,397.94 6,238.30 -6,512.38 2,805.85 5,923,254.39 1,624,072.69 0.46 6,899.87 MWD+IFR-AK-CAZ-SC(7) 13,521.41 88.40 184.44 6,400.33 6,240.69 -6,605.42 2,797.36 5,923,161.38 1,624,063.97 1.67 6,969.46 MWD+IFR-AK-CAZ-SC(7) 13,616.06 88.14 184.70 6,403.19 6,243.55 -6,699.72 2,789.82 5,923,067.10 1,624,056.19 0.39 7,040.62 MWD+IFR-AK-CAZ-SC(7) 13,710.58 89.46 188.26 6,405.17 6,245.53 -6,793.60 2,779.16 5,922,973.26 1,624,045.29 4.02 7,109.58 MWD+1FR-AK-CAZ-SC(7) 13,805.91 90.70 190.81 6,405.03 6,245.39 -6,887.60 2,763.37 5,922,879.31 1,624,029.27 2.97 7,175.58 MWD+1FR-AK-CAZ-SC(7) 13,900.16 91.17 193.44 6,403.50 6,243.86 -6,979.73 2,743.58 5,922,787.24 1,624,009.24 2.83 7,237.68 MWD+IFR-AK-CAZ-SC(7) 13,995.25 89.31 189.76 6,403.10 6,243.46 -7,072.86 2,724.46 5,922,694.17 1,623,989.89 4.34 7,300.99 MWD+IFR-AK-CAZ-SC(7) 14,090.63 89.54 188.91 6,404.05 6,244.41 -7,166.97 2,708.99 5,922,600.11 1,623,974.19 0.92 7,367.27 MWD+IFR-AK-CAZ-SC(7) 14,184.95 87.80 187.34 6,406.24 6,246.60 -7,260.31 2,695.67 5,922,506.81 1,623,960.62 2.48 7,434.21 MWD+IFR-AK-CAZ-SC(7) 14,280.00 87.90 187.25 6,409.81 6,250.17 -7,354.52 2,683.60 5,922,412.64 1,623,948.33 0.14 7,502.60 MWD+IFR-AK-CAZ-SC(7) 14,376.13 85.97 190.37 6,414.95 6,255.31 -7,449.37 2,668.91 5,922,317.84 1,623,933.39 3.81 7,569.93 MWD+IFR-AK-CAZ-SC(7) 14,470.87 87.50 195.44 6,420.35 6,260.71 -7,541.53 2,647.79 5,922,225.74 1,623,912.04 5.58 7,631.27 MW D+I FR-AK-CAZ-SC(7) 14,564.13 89.21 200.48 6,423.03 6,263.39 -7,630.18 2,619.05 5,922,137.18 1,623,883.08 5.70 7,685.24 MW D+I FR-AK-CAZ-SC(7) 14,659.33 88.74 199.03 6,424.73 6,265.09 -7,719.76 2,586.88 5,922,047.69 1,623,850.68 1.60 7,737.91 MWD+IFR-AK-CAZ-SC(7) 14,754.81 89.12 197.48 6,426.52 6,266.88 -7,810.41 2,556.98 5,921,957.12 1,623,820.56 1.67 7,792.80 MWD+IFR-AK-CAZ-SC(7) 14,848.40 89.08 194.78 6,427.99 6,268.35 -7,900.30 2,530.98 5,921,867.31 1,623,794.33 2.88 7,849.41 MWD+IFR-AK-CAZ-SC(7) 14,944.18 89.08 192.03 6,429.52 6,269.88 -7,993.45 2,508.78 5,921,774.22 1,623,771.90 2.87 7,910.90 MWD+IFR-AK-CAZ-SC(7) 2/23/2016 2:58:10PM Page 6 COMPASS 5000.1 Build 74 • • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: 120+39.64 @ 159.64usft(D25) Well: 2S-03 North Reference: True Wellbore: 2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03 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 15,040.54 89.32 190.61 6,430.87 6,271.23 -8,087.92 2,489.87 5,921,679.81 1,623,752.75 1.49 7,975.41 MWD+IFR-AK-CAZ-SC(7) 15,132.00 89.29 190.42 6,431.98 6,272.34 -8,177.84 2,473.18 5,921,589.94 1,623,735.84 0.21 8,037.59 MWD+IFR-AK-CAZ-SC(7) 15,224.25 88.98 192.17 6,433.37 6,273.73 -8,268.29 2,455.11 5,921,499.55 1,623,717.54 1.93 8,099.38 MWD+IFR-AK-CAZ-SC(7) 15,316.87 89.29 194.17 6,434.77 6,275.13 -8,358.46 2,434.02 5,921,409.44 1,623,696.22 2.18 8,159.13 MWD+I FR-AK-CAZ-SC(7) 15,409.64 89.63 196.87 6,435.64 6,276.00 -8,447.84 2,409.20 5,921,320.14 1,623,671.17 2.93 8,216.03 MWD+IFR-AK-CAZ-SC(7) 15,501.00 89.74 195.82 6,436.15 6,276.51 -8,535.50 2,383.49 5,921,232.55 1,623,645.24 1.16 8,271.02 MWD+IFR-AK-CAZ-SC(7) 15,595.47 89.53 196.59 6,436.75 6,277.11 -8,626.21 2,357.12 5,921,141.91 1,623,618.65 0.84 8,328.07 MWD+I FR-AK-CAZ-SC(7) 15,688.46 90.01 196.44 6,437.12 6,277.48 -8,715.37 2,330.69 5,921,052.83 1,623,592.00 0.54 8,383.83 MWD+IFR-AK-CAZ-SC(7) 15,778.27 90.28 196.42 6,436.89 6,277.25 -8,801.51 2,305.29 5,920,966.76 1,623,566.38 0.30 8,437.78 MWD+1FR-AK-CAZ-SC(7) 15,871.03 89.36 195.54 6,437.19 6,277.55 -8,890.68 2,279.75 5,920,877.66 1,623,540.62 1.37 8,494.09 MWD+IFR-AK-CAZ-SC(7) 15,961.10 88.98 194.67 6,438.49 6,278.85 -8,977.63 2,256.28 5,920,790.78 1,623,516.93 1.05 8,549.84 MWD+IFR-AK-CAZ-SC(7) 16,055.33 88.28 195.44 6,440.74 6,281.10 -9,068.60 2,231.81 5,920,699.89 1,623,492.24 1.10 8,608.22 MWD+IFR-AK-CAZ-SC(7) 16,147.87 88.98 195.97 6,442.96 6,283.32 -9,157.66 2,206.77 5,920,610.90 1,623,466.97 0.95 8,664.73 MWD+1FR-AK-CAZ-SC(7) 16,240.83 89.64 195.90 6,444.08 6,284.44 -9,247.04 2,181.25 5,920,521.59 1,623,441.23 0.71 8,721.22 MWD+IFR-AK-CAZ-SC(7) 16,331.08 88.54 194.28 6,445.51 6,285.87 -9,334.16 2,157.76 5,920,434.54 1,623,417.52 2.17 8,777.10 MWD+1FR-AK-CAZ-SC(7) 16,423.08 85.94 192.86 6,449.94 6,290.30 -9,423.48 2,136.20 5,920,345.28 1,623,395.73 3.22 8,835.89 MWD+IFR-AK-CAZ-SC(7) 16,514.67 85.62 193.28 6,456.68 6,297.04 -9,512.45 2,115.54 5,920,256.37 1,623,374.85 0.58 8,894.95 MWD+IFR-AK-CAZ-SC(7) 16,607.53 84.30 192.22 6,464.84 6,305.20 -9,602.67 2,095.13 5,920,166.22 1,623,354.21 1.82 8,955.15 MWD+IFR-AK-CAZ-SC(7) 16,696.12 79.93 188.81 6,476.99 6,317.35 -9,688.91 2,079.11 5,920,080.02 1,623,337.97 6.23 9,014.79 MWD+IFR-AK-CAZ-SC(7) 16,760.00 79.93 188.81 6,488.16 6,328.52 -9,751.07 2,069.48 5,920,017.90 1,623,328.18 0.00 9,058.91 PROJECTED to TD 2/23/2016 2:58:10PM Page 7 COMPASS 5000.1 Build 74 • • Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. Lives L No I have checked to the best of my ability that the following data is correct: U Surface Coordinates p Declination & Convergence El GRS Survey Corrections Survey Tool Codes Vincent Osara - SLB DE Client Representative Mike Callahan 24-Feb-2016 Date RECEIVED 21 52 05 MARt 201'6 • 2 6 932 AOGCC SchlumbergerDrilling & Measurements Transmittal#: 14MAR16-SPO2 DATA LOGGED MWD/LWD Log Product Delivery % /2014, B M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2S-03PB1 Date Dispatched: 14-Mar-16 Job#: 15AKA0039 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Contents on CD N/A Scope Services 2" MD x x Scope Services T TVD x x Scope Services 5'MD x x Scope Services 5'TVD 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(a�conocophillips.com AlaskaPTSPrintCenter0,slb.com Tom Osterkamp o_eii_eatAttn:Stephanie Pacillo 907 263 4795 ,j ✓..// J Received By: • • RECEIVED MAR 14 Z616 AOGCC FINAL NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-03PB1 2S-03 Definitive Survey Report 23 February, 2016 NAD 27 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: Rig: 120+39.64 @ 159.64usft(D25) Well: 2S-03 North Reference: True Wellbore: 2S-03PB1 Survey Calculation Method: Minimum Curvature Design: 2S-03PB1 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-03 Well Position +N/-S 0.00 usft Northing: 5,930,023.62 usfl Latitude: 70°13'11.933 N +E/-W 0.00 usft Easting: 481,250.32 usfl Longitude: 150°9'4.542 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 120.00 usft Wellbore 2S-03PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 2/1/2016 18.37 80.86 57,485 Design 2S-03PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.64 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.64 0.00 0.00 195.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 99.00 1,031.00 2S-03 Srvy#1 -GYD-GC-SS(2S-03PB1 GYD-GC-SS Gyrodata gyro single shots 1/31/2016 10:2 1,058.15 2,718.88 2S-03 Srvy#2-GMAG(2S-03PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/31/2016 10:2 2,740.81 2,740.81 2S-03 Srvy#3-Inc+Trend(2S-03PB1) INC+TREND Inclinometer+known azi trend 2/5/2016 9:34 2,835.17 8,756.84 2S-03 Srvy#4-GMAG(2S-03PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/5/2016 9:38 8,852.56 8,852.56 2S-03 Srvy#5-Inc+Trend(2S-03PB1) INC+TREND Inclinometer+known azi trend 2/16/2016 9:1, 8,947.89 13,667.30 2S-03 Srvy#6-GMAG(2S-03PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/16/2016 9:11 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) (0/100') (ft) Survey Tool Name 39.64 0.00 0.00 39.64 -120.00 0.00 0.00 5,930,023.62 481,250.32 0.00 0.00 UNDEFINED 99.00 0.68 307.59 99.00 -60.64 0.21 -0.28 5,930,023.84 481,250.04 1.15 -0.14 GYD-GC-SS(1) 120.40 0.76 307.84 120.40 -39.24 0.38 -0.49 5,930,024.00 481,249.83 0.35 -0.24 NOT an Actual Survey 16"x 20" 187.00 0.99 308.38 186.99 27.35 1.01 -1.29 5,930,024.63 481,249.04 0.35 -0.64 GYD-GC-SS(1) 279.00 1.43 323.75 278.97 119.33 2.42 -2.59 5,930,026.05 481,247.74 0.59 -1.67 GYD-GC-SS(1) 373.00 2.73 352.26 372.91 213.27 5.59 -3.59 5,930,029.22 481,246.75 1.73 -4.47 GYD-GC-SS(1) 467.00 4.05 3.66 466.74 307.10 11.12 -3.68 5,930,034.75 481,246.68 1.57 -9.79 GYD-GC-SS(1) 560.00 4.75 8.02 559.47 399.83 18.21 -2.93 5,930,041.84 481,247.44 0.83 -16.83 GYD-GC-SS(1) 654.00 5.88 10.82 653.06 493.42 26.79 -1.48 5,930,050.41 481,248.91 1.23 -25.50 GYD-GC-SS(1) 2/23/2016 9:01:28AM Page 2 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: Rig: 120+39.64 @ 159.64usft(D25) Well: 2S-03 North Reference: True Wellbore: 2S-03PB1 Survey Calculation Method: Minimum Curvature Design: 2S-03PB1 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) (°l100') (ft) Survey Tool Name 748.00 7.82 21.67 746.39 586.75 37.47 1.78 5,930,061.08 481,252.20 2.47 -36.65 GYD-GC-SS(1) 843.00 9.53 23.20 840.30 680.66 50.70 7.27 5,930,074.30 481,257.72 1.82 -50.86 GYD-GC-SS(1) 937.00 10.63 22.72 932.85 773.21 65.85 13.68 5,930,089.43 481,264.17 1.17 -67.15 GYD-GC-SS(1) 1,031.00 12.43 22.65 1,024.95 865.31 83.19 20.93 5,930,106.75 481,271.46 1.91 -85.77 GYD-GC-SS(1) 1,058.15 13.24 22.22 1,051.42 891.78 88.76 23.23 5,930,112.32 481,273.77 3.00 -91.75 MWD+IFR-AK-CAZ-SC(2) 1,152.92 15.04 22.94 1,143.31 983.67 110.14 32.13 5,930,133.66 481,282.72 1.91 -114.70 MWD+IFR-AK-CAZ-SC(2) 1,247.26 17.39 24.50 1,233.89 1,074.25 134.24 42.75 5,930,157.74 481,293.40 2.53 -140.73 MWD+IFR-AK-CAZ-SC(2) 1,340.99 21.22 26.16 1,322.34 1,162.70 162.22 56.04 5,930,185.68 481,306.76 4.13 -171.20 MWD+IFR-AK-CAZ-SC(2) 1,435.66 24.72 24.77 1,409.49 1,249.85 195.58 71.89 5,930,219.00 481,322.69 3.74 -207.53 MWD+IFR-AK-CAZ-SC(2) 1,530.79 25.79 26.03 1,495.53 1,335.89 232.24 89.31 5,930,255.61 481,340.20 1.26 -247.44 MWD+IFR-AK-CAZ-SC(2) 1,626.16 26.71 26.08 1,581.06 1,421.42 270.13 107.83 5,930,293.46 481,358.82 0.96 -288.84 MWD+IFR-AK-CAZ-SC(2) 1,721.19 27.14 25.69 1,665.79 1,506.15 308.85 126.62 5,930,332.12 481,377.70 0.49 -331.10 MWD+IFR-AK-CAZ-SC(2) 1,815.71 27.42 33.73 1,749.82 1,590.18 346.39 148.06 5,930,369.61 481,399.22 3.91 -372.91 MWD+IFR-AK-CAZ-SC(2) 1,909.84 27.44 39.74 1,833.39 1,673.75 381.10 173.96 5,930,404.25 481,425.21 2.94 -413.14 MWD+IFR-AK-CAZ-SC(2) 2,004.80 25.17 44.51 1,918.52 1,758.88 412.33 202.11 5,930,435.41 481,453.44 3.26 -450.59 MWD+IFR-AK-CAZ-SC(2) 2,099.72 24.63 50.47 2,004.63 1,844.99 439.32 231.52 5,930,462.32 481,482.91 2.70 -484.27 MWD+IFR-AK-CAZ-SC(2) 2,194.87 25.45 63.12 2,090.90 1,931.26 461.20 265.08 5,930,484.11 481,516.52 5.68 -514.09 MWD+IFR-AK-CAZ-SC(2) 2,289.33 27.45 75.16 2,175.53 2,015.89 475.96 304.26 5,930,498.78 481,555.73 6.05 -538.49 MWD+IFR-AK-CAZ-SC(2) 2,383.45 30.15 81.07 2,258.01 2,098.37 485.19 348.59 5,930,507.90 481,600.09 4.17 -558.88 MWD+IFR-AK-CAZ-SC(2) 2,476.89 32.78 84.16 2,337.71 2,178.07 491.41 396.95 5,930,513.99 481,648.45 3.30 -577.40 MWD+IFR-AK-CAZ-SC(2) 2,572.22 32.39 83.70 2,418.04 2,258.40 496.84 448.00 5,930,519.29 481,699.51 0.48 -595.86 MWD+IFR-AK-CAZ-SC(2) 2,666.25 33.43 89.38 2,497.00 2,337.36 499.88 498.95 5,930,522.21 481,750.46 3.46 -611.99 MWD+IFR-AK-CAZ-SC(2) 2,718.88 33.57 90.10 2,540.88 2,381.24 500.01 528.00 5,930,522.27 481,779.51 0.80 -619.63 MWD+IFR-AK-CAZ-SC(2) 2,740.81 33.44 88.91 2,559.17 2,399.53 500.12 540.10 5,930,522.35 481,791.61 3.05 -622.87 INC+TREND(3) 2,781.70 33.89 89.13 2,593.20 2,433.56 500.51 562.77 5,930,522.68 481,814.28 1.15 -629.11 NOT an Actual Survey (4) 10 3/4"x 13-1/2" 2,835.17 34.49 89.40 2,637.43 2,477.79 500.89 592.81 5,930,522.99 481,844.32 1.15 -637.26 MWD+IFR-AK-CAZ-SC(4) 2,929.75 36.21 90.65 2,714.57 2,554.93 500.86 647.53 5,930,522.82 481,899.03 1.97 -651.38 MWD+IFR-AK-CAZ-SC(4) 3,024.24 37.57 93.01 2,790.14 2,630.50 499.03 704.21 5,930,520.85 481,955.70 2.08 -664.29 MWD+IFR-AK-CAZ-SC(4) 3,123.14 38.70 94.95 2,867.94 2,708.30 494.78 765.13 5,930,516.44 482,016.60 1.67 -675.95 MWD+IFR-AK-CAZ-SC(4) 3,214.24 39.66 97.87 2,938.56 2,778.92 488.34 822.30 5,930,509.86 482,073.76 2.28 -684.53 MWD+IFR-AK-CAZ-SC(4) 3,309.20 39.94 100.70 3,011.52 2,851.88 478.53 882.28 5,930,499.91 482,133.70 1.93 -690.57 MWD+IFR-AK-CAZ-SC(4) 3,404.39 40.64 103.86 3,084.14 2,924.50 465.43 942.41 5,930,486.66 482,193.79 2.27 -693.48 MWD+IFR-AK-CAZ-SC(4) 3,498.42 41.50 108.17 3,155.04 2,995.40 448.37 1,001.75 5,930,469.46 482,253.08 3.15 -692.37 MWD+IFR-AK-CAZ-SC(4) 3,593.22 42.17 111.43 3,225.68 3,066.04 426.95 1,061.22 5,930,447.89 482,312.49 2.40 -687.07 MWD+IFR-AK-CAZ-SC(4) 3,687.80 42.71 112.59 3,295.48 3,135.84 403.03 1,120.39 5,930,423.82 482,371.60 1.01 -679.27 MWD+IFR-AK-CAZ-SC(4) 3,782.58 44.52 112.00 3,364.10 3,204.46 378.23 1,180.88 5,930,398.88 482,432.02 1.96 -670.98 MWD+IFR-AK-CAZ-SC(4) 3,876.02 46.63 112.03 3,429.50 3,269.86 353.22 1,242.74 5,930,373.71 482,493.82 2.26 -662.83 MWD+IFR-AK-CAZ-SC(4) 3,970.37 49.13 112.04 3,492.77 3,333.13 326.96 1,307.61 5,930,347.30 482,558.61 2.65 -654.26 MWD+IFR-AK-CAZ-SC(4) 4,064.96 50.96 111.78 3,553.52 3,393.88 299.91 1,374.88 5,930,320.08 482,625.80 1.95 -645.54 MWD+IFR-AK-CAZ-SC(4) 2/23/2016 9:01:28AM Page 3 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: Rig:120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: Rig: 120+39.64 @ 159.64usft(D25) Well: 2S-03 North Reference: True Wellbore: 2S-03PB1 Survey Calculation Method: Minimum Curvature Design: 2S-03PB1 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 4,159.92 51.08 111.85 3,613.25 3,453.61 272.48 1,443.41 5,930,292.49 482,694.26 0.14 -636.78 MWD+IFR-AK-CAZ-SC(4) 4,254.49 51.03 111.77 3,672.70 3,513.06 245.15 1,511.70 5,930,264.99 482,762.47 0.08 -628.05 MWD+IFR-AK-CAZ-SC(4) 4,349.76 51.11 111.87 3,732.56 3,572.92 217.61 1,580.50 5,930,237.28 482,831.20 0.12 -619.25 MWD+IFR-AK-CAZ-SC(4) 4,444.28 51.03 110.84 3,791.95 3,632.31 190.83 1,648.98 5,930,210.33 482,899.61 0.85 -611.12 MWD+IFR-AK-CAZ-SC(4) 4,537.03 51.10 110.83 3,850.24 3,690.60 165.17 1,716.41 5,930,184.51 482,966.96 0.08 -603.78 MW D+I FR-AK-CAZ-SC(4) 4,632.40 51.17 109.61 3,910.09 3,750.45 139.51 1,786.08 5,930,158.67 483,036.57 1.00 -597.03 MWD+IFR-AK-CAZ-SC(4) 4,726.93 51.25 108.73 3,969.31 3,809.67 115.31 1,855.68 5,930,134.31 483,106.10 0.73 -591.67 MW D+I FR-AK-CAZ-SC(4) 4,820.81 51.07 107.98 4,028.18 3,868.54 92.28 1,925.08 5,930,111.11 483,175.44 0.65 -587.39 MW D+I FR-AK-CAZ-SC(4) 4,916.59 51.13 106.93 4,088.33 3,928.69 69.93 1,996.19 5,930,088.58 483,246.48 0.86 -584.20 MWD+IFR-AK-CAZ-SC(4) 5,010.86 51.21 106.99 4,147.44 3,987.80 48.50 2,066.43 5,930,066.99 483,316.66 0.10 -581.68 MWD+IFR-AK-CAZ-SC(4) 5,104.99 51.11 108.41 4,206.48 4,046.84 26.22 2,136.27 5,930,044.53 483,386.44 1.18 -578.23 MWD+IFR-AK-CAZ-SC(4) 5,199.04 51.12 109.40 4,265.52 4,105.88 2.50 2,205.53 5,930,020.64 483,455.64 0.82 -573.24 MWD+IFR-AK-CAZ-SC(4) 5,294.20 50.66 110.68 4,325.55 4,165.91 -22.80 2,274.90 5,929,995.17 483,524.93 1.15 -566.76 MWD+IFR-AK-CAZ-SC(4) 5,389.44 50.33 110.32 4,386.13 4,226.49 -48.54 2,343.73 5,929,969.26 483,593.69 0.45 -559.72 MWD+IFR-AK-CAZ-SC(4) 5,483.64 50.61 110.40 4,446.09 4,286.45 -73.82 2,411.85 5,929,943.82 483,661.74 0.30 -552.93 MWD+IFR-AK-CAZ-SC(4) 5,578.33 50.43 110.44 4,506.29 4,346.65 -99.32 2,480.34 5,929,918.15 483,730.16 0.19 -546.03 MW D+I FR-AK-CAZ-SC(4) 5,673.16 50.65 110.27 4,566.56 4,406.92 -124.78 2,548.98 5,929,892.52 483,798.73 0.27 -539.19 MWD+IFR-AK-CAZ-SC(4) 5,768.21 50.23 110.52 4,627.10 4,467.46 -150.32 2,617.67 5,929,866.81 483,867.35 0.49 -532.30 MWD+IFR-AK-CAZ-SC(4) 5,862.27 50.51 111.83 4,687.09 4,527.45 -176.49 2,685.22 5,929,840.48 483,934.83 1.11 -524.51 MWD+IFR-AK-CAZ-SC(4) 5,957.06 50.54 112.78 4,747.36 4,587.72 -204.26 2,752.91 5,929,812.54 484,002.44 0.77 -515.21 MWD+IFR-AK-CAZ-SC(4) 6,052.13 50.63 112.23 4,807.72 4,648.08 -232.37 2,820.76 5,929,784.27 484,070.22 0.46 -505.61 MWD+IFR-AK-CAZ-SC(4) 6,146.51 50.47 113.62 4,867.69 4,708.05 -260.76 2,887.88 5,929,755.72 484,137.26 1.15 -495.57 MWD+IFR-AK-CAZ-SC(4) 6,240.39 50.88 115.73 4,927.19 4,767.55 -291.07 2,953.86 5,929,725.24 484,203.16 1.79 -483.36 MWD+IFR-AK-CAZ-SC(4) 6,335.37 51.43 118.56 4,986.77 4,827.13 -324.82 3,019.68 5,929,691.33 484,268.88 2.39 -467.79 MWD+IFR-AK-CAZ-SC(4) 6,430.02 52.39 121.19 5,045.16 4,885.52 -361.93 3,084.25 5,929,654.06 484,333.36 2.41 -448.66 MWD+IFR-AK-CAZ-SC(4) 6,524.27 52.99 124.07 5,102.30 4,942.66 -402.35 3,147.37 5,929,613.49 484,396.37 2.51 -425.96 MWD+IFR-AK-CAZ-SC(4) 6,619.02 53.30 126.46 5,159.13 4,999.49 -446.12 3,209.26 5,929,569.57 484,458.15 2.04 -399.70 MWD+IFR-AK-CAZ-SC(4) 6,714.34 53.81 129.69 5,215.77 5,056.13 -493.40 3,269.61 5,929,522.14 484,518.37 2.78 -369.64 MWD+IFR-AK-CAZ-SC(4) 6,807.69 54.01 131.52 5,270.76 5,111.12 -542.50 3,326.87 5,929,472.91 484,575.51 1.60 -337.04 MWD+IFR-AK-CAZ-SC(4) 6,903.31 54.07 133.10 5,326.91 5,167.27 -594.60 3,384.11 5,929,420.68 484,632.60 1.34 -301.54 MWD+IFR-AK-CAZ-SC(4) 6,998.16 54.04 134.47 5,382.59 5,222.95 -647.73 3,439.54 5,929,367.41 484,687.90 1.17 -264.56 MWD+IFR-AK-CAZ-SC(4) 7,092.00 53.65 137.03 5,437.96 5,278.32 -701.99 3,492.41 5,929,313.03 484,740.63 2.24 -225.83 MWD+IFR-AK-CAZ-SC(4) 7,187.22 53.65 139.87 5,494.41 5,334.77 -759.37 3,543.26 5,929,255.52 484,791.34 2.40 -183.57 MWD+IFR-AK-CAZ-SC(4) 7,281.99 53.38 143.30 5,550.77 5,391.13 -819.06 3,590.60 5,929,195.73 484,838.52 2.92 -138.17 MW D+I FR-AK-CAZ-SC(4) 7,376.46 53.33 146.73 5,607.16 5,447.52 -881.14 3,634.05 5,929,133.54 484,881.81 2.91 -89.44 MWD+IFR-AK-CAZ-SC(4) 7,470.40 54.01 150.28 5,662.83 5,503.19 -945.66 3,673.57 5,929,068.93 484,921.16 3.13 -37.35 MWD+IFR-AK-CAZ-SC(4) 7,565.20 54.64 153.51 5,718.12 5,558.48 -1,013.58 3,709.83 5,929,000.93 484,957.25 2.85 18.87 MWD+IFR-AK-CAZ-SC(4) 7,659.92 54.58 156.32 5,772.99 5,613.35 -1,083.50 3,742.56 5,928,930.93 484,989.81 2.42 77.94 MWD+IFR-AK-CAZ-SC(4) 7,755.31 54.76 158.29 5,828.15 5,668.51 -1,155.29 3,772.58 5,928,859.07 485,019.65 1.70 139.51 MWD+IFR-AK-CAZ-SC(4) 7,851.51 54.93 159.69 5,883.55 5,723.91 -1,228.72 3,800.78 5,928,785.59 485,047.66 1.20 203.13 MWD+IFR-AK-CAZ-SC(4) 2/23/2016 9:01:28AM Page 4 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: Rig: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: Rig: 120+39.64 @ 159.64usft(D25) Well: 2S-03 North Reference: True Wellbore: 2S-03PB1 Survey Calculation Method: Minimum Curvature Design: 2S-03PB1 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 7,944.13 57.65 160.82 5,934.95 5,775.31 -1,301.23 3,826.80 5,928,713.02 485,073.49 3.11 266.44 MWD+IFR-AK-CAZ-SC(4) 8,037.87 61.20 162.16 5,982.62 5,822.98 -1,377.75 3,852.40 5,928,636.44 485,098.90 3.98 333.73 MWD+IFR-AK-CAZ-SC(4) 8,134.96 65.11 163.68 6,026.46 5,866.82 -1,460.54 3,877.81 5,928,553.59 485,124.11 4.26 407.12 MWD+IFR-AK-CAZ-SC(4) 8,227.49 67.60 165.32 6,063.57 5,903.93 -1,542.21 3,900.45 5,928,471.87 485,146.54 3.14 480.15 MWD+IFR-AK-CAZ-SC(4) 8,321.13 69.49 167.84 6,097.82 5,938.18 -1,626.98 3,920.66 5,928,387.07 485,166.54 3.22 556.80 MWD+IFR-AK-CAZ-SC(4) 8,416.49 71.30 170.93 6,129.83 5,970.19 -1,715.26 3,937.20 5,928,298.76 485,182.85 3.59 637.79 MWD+IFR-AK-CAZ-SC(4) 8,511.46 72.15 172.50 6,159.61 5,999.97 -1,804.49 3,950.19 5,928,209.50 485,195.62 1.81 720.62 MWD+IFR-AK-CAZ-SC(4) 8,606.43 72.76 174.79 6,188.24 6,028.60 -1,894.48 3,960.21 5,928,119.50 485,205.42 2.39 804.95 MWD+IFR-AK-CAZ-SC(4) 8,701.25 73.21 177.13 6,215.99 6,056.35 -1,984.92 3,966.59 5,928,029.05 485,211.58 2.41 890.65 MWD+IFR-AK-CAZ-SC(4) 8,756.84 74.39 178.49 6,231.50 6,071.86 -2,038.26 3,968.63 5,927,975.71 485,213.48 3.17 941.65 MWD+IFR-AK-CAZ-SC(4) 8,826.90 74.24 179.92 6,250.44 6,090.80 -2,105.70 3,969.56 5,927,908.27 485,214.25 1.98 1,006.55 NOT an Actual Survey 7-5/8 x 9-7/8 by 11" 8,852.56 74.19 180.45 6,257.42 6,097.78 -2,130.39 3,969.48 5,927,883.58 485,214.11 1.98 1,030.43 INC+TREND(5) 8,947.89 75.01 181.42 6,282.74 6,123.10 -2,222.29 3,967.98 5,927,791.70 485,212.38 1.30 1,119.58 MWD+IFR-AK-CAZ-SC(6) 9,042.78 75.22 183.94 6,307.12 6,147.48 -2,313.88 3,963.69 5,927,700.13 485,207.86 2.58 1,209.16 MWD+IFR-AK-CAZ-SC(6) 9,137.59 76.65 185.80 6,330.16 6,170.52 -2,405.51 3,955.88 5,927,608.53 485,199.82 2.43 1,299.69 MWD+IFR-AK-CAZ-SC(6) 9,232.40 80.93 185.26 6,348.59 6,188.95 -2,498.06 3,946.92 5,927,516.01 485,190.64 4.55 1,391.40 MWD+IFR-AK-CAZ-SC(6) 9,326.85 84.53 184.89 6,360.54 6,200.90 -2,591.37 3,938.64 5,927,422.73 485,182.12 3.83 1,483.67 MWD+IFR-AK-CAZ-SC(6) 9,421.97 88.76 186.02 6,366.10 6,206.46 -2,685.87 3,929.61 5,927,328.26 485,172.86 4.60 1,577.29 MWD+IFR-AK-CAZ-SC(6) 9,519.33 92.15 185.87 6,365.33 6,205.69 -2,782.69 3,919.53 5,927,231.48 485,162.54 3.49 1,673.42 MWD+IFR-AK-CAZ-SC(6) 9,612.10 91.39 188.72 6,362.46 6,202.82 -2,874.65 3,907.76 5,927,139.55 485,150.54 3.18 1,765.30 MWD+IFR-AK-CAZ-SC(6) 9,707.04 92.46 191.75 6,359.27 6,199.63 -2,968.02 3,890.90 5,927,046.24 485,133.45 3.38 1,859.85 MWD+IFR-AK-CAZ-SC(6) 9,801.77 92.57 195.88 6,355.11 6,195.47 -3,059.90 3,868.31 5,926,954.42 485,110.63 4.36 1,954.45 MWD+IFR-AK-CAZ-SC(6) 9,896.56 92.10 200.03 6,351.25 6,191.61 -3,149.98 3,839.11 5,926,864.43 485,081.22 4.40 2,049.01 MWD+IFR-AK-CAZ-SC(6) 9,992.30 89.33 200.03 6,350.06 6,190.42 -3,239.91 3,806.33 5,926,774.58 485,048.21 2.89 2,144.36 MWD+IFR-AK-CAZ-SC(6) 10,086.92 88.93 198.88 6,351.49 6,191.85 -3,329.12 3,774.82 5,926,685.47 485,016.48 1.29 2,238.69 MWD+IFR-AK-CAZ-SC(6) 10,181.40 88.83 197.79 6,353.34 6,193.70 -3,418.78 3,745.10 5,926,595.88 484,986.55 1.16 2,332.99 MWD+IFR-AK-CAZ-SC(6) 10,277.03 88.49 196.66 6,355.58 6,195.94 -3,510.10 3,716.79 5,926,504.65 484,958.02 1.23 2,428.52 MWD+IFR-AK-CAZ-SC(6) 10,371.90 88.07 196.20 6,358.42 6,198.78 -3,601.05 3,689.97 5,926,413.77 484,930.97 0.66 2,523.31 MWD+IFR-AK-CAZ-SC(6) 10,466.92 87.39 196.30 6,362.19 6,202.55 -3,692.20 3,663.40 5,926,322.70 484,904.18 0.72 2,618.24 MWD+IFR-AK-CAZ-SC(6) 10,561.36 87.32 195.65 6,366.54 6,206.90 -3,782.90 3,637.44 5,926,232.07 484,877.99 0.69 2,712.56 MWD+IFR-AK-CAZ-SC(6) 10,656.01 87.61 197.86 6,370.73 6,211.09 -3,873.44 3,610.18 5,926,141.61 484,850.51 2.35 2,807.07 MWD+IFR-AK-CAZ-SC(6) 10,750.57 89.80 195.90 6,372.87 6,213.23 -3,963.89 3,582.74 5,926,051.24 484,822.84 3.11 2,901.54 MWD+IFR-AK-CAZ-SC(6) 10,845.81 90.41 197.42 6,372.69 6,213.05 -4,055.13 3,555.43 5,925,960.08 484,795.32 1.72 2,996.74 MWD+IFR-AK-CAZ-SC(6) 10,941.49 90.34 197.54 6,372.07 6,212.43 -4,146.39 3,526.69 5,925,868.90 484,766.35 0.15 3,092.33 MWD+IFR-AK-CAZ-SC(6) 11,036.30 89.40 197.75 6,372.28 6,212.64 -4,236.74 3,497.95 5,925,778.63 484,737.39 1.02 3,187.04 MWD+IFR-AK-CAZ-SC(6) 11,130.21 89.65 197.86 6,373.06 6,213.42 -4,326.15 3,469.24 5,925,689.30 484,708.46 0.29 3,280.83 MWD+IFR-AK-CAZ-SC(6) 11,224.93 88.62 196.31 6,374.49 6,214.85 -4,416.67 3,441.42 5,925,598.85 484,680.42 1.96 3,375.47 MWD+IFR-AK-CAZ-SC(6) 11,319.09 88.00 196.62 6,377.27 6,217.63 -4,506.93 3,414.74 5,925,508.67 484,653.52 0.74 3,469.56 MWD+IFR-AK-CAZ-SC(6) 11,413.70 87.76 195.11 6,380.77 6,221.13 -4,597.87 3,388.90 5,925,417.80 484,627.45 1.61 3,564.09 MWD+IFR-AK-CAZ-SC(6) 2/23/2016 9:01:28AM Page 5 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-03 Project: Kuparuk River Unit TVD Reference: Rig:120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: Rig:120+39.64 @ 159.64usft(D25) Well: 2S-03 North Reference: True Wellbore: 2S-03PB1 Survey Calculation Method: Minimum Curvature Design: 2S-03PB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,508.90 88.35 192.64 6,384.00 6,224.36 -4,690.23 3,366.08 5,925,325.51 484,604.41 2.67 3,659.21 MWD+IFR-AK-CAZ-SC(6) 11,604.26 88.38 191.80 6,386.72 6,227.08 -4,783.39 3,345.91 5,925,232.41 484,584.00 0.88 3,754.42 MWD+I FR-AK-CAZ-SC(6) 11,698.69 88.59 192.00 6,389.22 6,229.58 -4,875.76 3,326.44 5,925,140.10 484,564.31 0.31 3,848.68 MWD+I FR-AK-CAZ-SC(6) 11,793.62 88.59 191.14 6,391.55 6,231.91 -4,968.73 3,307.41 5,925,047.18 484,545.05 0.91 3,943.41 MW D+I FR-AK-CAZ-SC(6) 11,888.42 89.03 192.55 6,393.52 6,233.88 -5,061.49 3,287.95 5,924,954.48 484,525.36 1.56 4,038.04 MWD+IFR-AK-CAZ-SC(6) 11,984.62 89.00 192.00 6,395.18 6,235.54 -5,155.48 3,267.50 5,924,860.55 484,504.68 0.57 4,134.12 MWD+1FR-AK-CAZ-SC(6) 12,077.92 89.58 190.74 6,396.33 6,236.69 -5,246.94 3,249.11 5,924,769.15 484,486.07 1.49 4,227.22 MWD+1FR-AK-CAZ-SC(6) 12,172.68 88.78 190.34 6,397.69 6,238.05 -5,340.09 3,231.78 5,924,676.05 484,468.51 0.94 4,321.68 MWD+1FR-AK-CAZ-SC(6) 12,268.19 89.21 191.47 6,399.36 6,239.72 -5,433.86 3,213.71 5,924,582.34 484,450.21 1.27 4,416.93 MWD+IFR-AK-CAZ-SC(6) 12,363.22 88.69 192.78 6,401.11 6,241.47 -5,526.75 3,193.76 5,924,489.50 484,430.02 1.48 4,511.83 MW D+I FR-AK-CAZ-SC(6) 12,457.52 88.52 194.38 6,403.40 6,243.76 -5,618.38 3,171.62 5,924,397.93 484,407.66 1.71 4,606.07 MW D+I FR-AK-CAZ-SC(6) 12,552.96 87.20 194.32 6,406.96 6,247.32 -5,710.78 3,147.99 5,924,305.61 484,383.80 1.38 4,701.43 MWD+IFR-AK-CAZ-SC(6) 12,647.84 88.43 196.83 6,410.58 6,250.94 -5,802.10 3,122.53 5,924,214.36 484,358.12 2.94 4,796.23 MWD+IFR-AK-CAZ-SC(6) 12,743.26 86.87 197.05 6,414.50 6,254.86 -5,893.30 3,094.75 5,924,123.24 484,330.12 1.65 4,891.51 MWD+1FR-AK-CAZ-SC(6) 12,838.22 84.17 196.98 6,421.91 6,262.27 -5,983.82 3,067.05 5,924,032.80 484,302.20 2.84 4,986.11 MWD+IFR-AK-CAZ-SC(6) 12,932.91 83.12 196.47 6,432.39 6,272.75 -6,073.94 3,039.97 5,923,942.75 484,274.89 1.23 5,080.18 MWD+IFR-AK-CAZ-SC(6) 13,028.27 83.02 197.75 6,443.90 6,284.26 -6,164.41 3,012.12 5,923,852.36 484,246.82 1.34 5,174.77 MWD+IFR-AK-CAZ-SC(6) 13,121.95 82.94 196.16 6,455.35 6,295.71 -6,253.35 2,985.01 5,923,763.50 484,219.49 1.69 5,267.69 MWD+IFR-AK-CAZ-SC(6) 13,218.25 78.76 197.01 6,470.66 6,311.02 -6,344.45 2,957.88 5,923,672.48 484,192.14 4.43 5,362.71 MW D+I FR-AK-CAZ-SC(6) 13,312.58 77.33 196.63 6,490.20 6,330.56 -6,432.78 2,931.17 5,923,584.22 484,165.22 1.57 5,454.94 MWD+IFR-AK-CAZ-SC(6) 13,407.89 80.90 195.90 6,508.19 6,348.55 -6,522.62 2,904.97 5,923,494.46 484,138.79 3.82 5,548.50 MWD+IFR-AK-CAZ-SC(6) 13,502.54 83.19 195.32 6,521.29 6,361.65 -6,612.89 2,879.75 5,923,404.25 484,113.35 2.49 5,642.23 MW D+I FR-AK-CAZ-SC(6) 13,596.27 86.56 193.49 6,529.67 6,370.03 -6,703.30 2,856.53 5,923,313.92 484,089.91 4.09 5,735.56 MW D+I FR-AK-CAZ-SC(6) 13,667.30 89.00 194.05 6,532.42 6,372.78 -6,772.23 2,839.64 5,923,245.03 484,072.85 3.52 5,806.52 MWD+IFR-AK-CAZ-SC(6) 13,728.00 89.00 194.05 6,533.48 6,373.84 -6,831.10 2,824.90 5,923,186.20 484,057.97 0.00 5,867.20 PROJECTED to TD 2/23/2016 9:01:28AM Page 6 COMPASS 5000.1 Build 74 • Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. Li Yes L No 1 have checked to the best of my ability that the following data is correct: Li Surface Coordinates 11 Declination & Convergence p GRS Survey Corrections n Survey Tool Codes Vincent DOWN signed by Vincent o33t' CM.al,Vincent arra. 0-Schlumbercom OB,:Sthlurrine,Z.E. SLB DE: Osara ° 3a` Mike Callahan Client Representative: Oita 16ID]}t24:S7U➢4n Date: 23-Feb-2016 • • RECEIVED MAR 14 2 h6 AOGCC FINAL ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad 2S-03PB1 2S-03 Definitive Survey Report 22 February, 2016 NAD 83 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Rig:2S-03 Project: Kuparuk River Unit TVD Reference: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: 120+39.64 @ 159.64usft(D25)True Well: 2S-03 North Reference: Minimum Curvature Wellbore: 2S-03PB1 Survey Calculation Method: OAKEDMP2 Design: 2S-03PB1 Database: 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 Rig:2S-03 Well Position +NI-S 0.00 usft Northing: 5,929,773.21 usfl Latitude: 70°13'10.813 N +E/-W 0.00 usft Easting: 1,621,283.64 usfl Longitude: 150°9'15.692W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 120.00 usft Wellbore 2S-03PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2015 2/1/2016 18.37 80.86 57,485 Design 2S-03PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.64 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 39.64 0.00 0.00 195.00 Survey Program Date 2/22/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 99.00 1,031.00 2S-03 Srvy#1 -GYD-GC-SS(2S-03PB1 GYD-GC-SS Gyrodata gyro single shots 1/31/2016 10:2 1,058.15 2,718.88 2S-03 Srvy#2-GMAG(2S-03PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/31/2016 10::.: 2,740.81 2,740.81 2S-03 Srvy#3-Inc+Trend(2S-03PB1) INC+TREND Inclinometer+known azi trend 2/5/2016 9:34 2,835.17 8,756.84 2S-03 Srvy#4-GMAG(2S-03PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/5/2016 9:38 8,852.56 8,852.56 2S-03 Srvy#5-Inc+Trend(2S-03PB1) INC+TREND Inclinometer+known azi trend 2/16/2016 9:1. 8,947.89 13,667.30 2S-03 Srvy#6-GMAG(2S-03PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/16/2016 9:11 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 39.64 0.00 0.00 39.64 -120.00 0.00 0.00 5,929,773.21 1,621,283.64 0.00 0.00 UNDEFINED 99.00 0.68 307.59 99.00 -60.64 0.21 -0.28 5,929,773.43 1,621,283.36 1.15 -0.14 GYD-GC-SS(1) 120.40 0.76 307.84 120.40 -39.24 0.38 -0.49 5,929,773.59 1,621,283.15 0.35 -0.24 NOT an Actual Survey 16"x 20" 187.00 0.99 308.38 186.99 27.35 1.01 -1.29 5,929,774.22 1,621,282.35 0.35 -0.64 GYD-GC-SS(1) 279.00 1.43 323.75 278.97 119.33 2.42 -2.59 5,929,775.64 1,621,281.06 0.59 -1.67 GYD-GC-SS(1) 373.00 2.73 352.26 372.91 213.27 5.59 -3.59 5,929,778.81 1,621,280.07 1.73 -4.47 GYD-GC-SS(1) 467.00 4.05 3.66 466.74 307.10 11.12 -3.68 5,929,784.34 1,621,279.99 1.57 -9.79 GYD-GC-SS(1) 560.00 4.75 8.02 559.47 399.83 18.21 -2.93 5,929,791.43 1,621,280.76 0.83 -16.83 GYD-GC-SS(1) 654.00 5.88 10.82 653.06 493.42 26.79 -1.48 5,929,800.01 1,621,282.23 1.23 -25.50 GYD-GC-SS(1) 2/22/2016 4:46:50PM Page 2 COMPASS 5000.1 Build 74 0 • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Rig:2S-03 Project: Kuparuk River Unit TVD Reference: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: 120+39.64 @ 159.64usft(D25)True Well: 2S-03 North Reference: Minimum Curvature Wellbore: 2S-03PB1 Survey Calculation Method: OAKEDMP2 Design: 2S-03PB1 Database: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 748.00 7.82 21.67 746.39 586.75 37.47 1.78 5,929,810.67 1,621,285.52 2.47 -36.65 GYD-GC-SS(1) 843.00 9.53 23.20 840.30 680.66 50.70 7.27 5,929,823.89 1,621,291.04 1.82 -50.86 GYD-GC-SS(1) 937.00 10.63 22.72 932.85 773.21 65.85 13.68 5,929,839.02 1,621,297.49 1.17 -67.15 GYD-GC-SS(1) 1,031.00 12.43 22.65 1,024.95 865.31 83.19 20.93 5,929,856.34 1,621,304.78 1.91 -85.77 GYD-GC-SS(1) 1,058.15 13.24 22.22 1,051.42 891.78 88.76 23.23 5,929,861.91 1,621,307.09 3.00 -91.75 MWD+IFR-AK-CAZ-SC(2) 1,152.92 15.04 22.94 1,143.31 983.67 110.14 32.13 5,929,883.25 1,621,316.04 1.91 -114.70 MWD+IFR-AK-CAZ-SC(2) 1,247.26 17.39 24.50 1,233.89 1,074.25 134.24 42.75 5,929,907.33 1,621,326.72 2.53 -140.73 MWD+IFR-AK-CAZ-SC(2) 1,340.99 21.22 26.16 1,322.34 1,162.70 162.22 56.04 5,929,935.27 1,621,340.08 4.13 -171.20 MWD+IFR-AK-CAZ-SC(2) 1,435.66 24.72 24.77 1,409.49 1,249.85 195.58 71.89 5,929,968.59 1,621,356.02 3.74 -207.53 MWD+IFR-AK-CAZ-SC(2) 1,530.79 25.79 26.03 1,495.53 1,335.89 232.24 89.31 5,930,005.20 1,621,373.53 1.26 -247.44 MWD+IFR-AK-CAZ-SC(2) 1,626.16 26.71 26.08 1,581.06 1,421.42 270.13 107.83 5,930,043.04 1,621,392.15 0.96 -288.84 MWD+IFR-AK-CAZ-SC(2) 1,721.19 27.14 25.69 1,665.79 1,506.15 308.85 126.62 5,930,081.71 1,621,411.03 0.49 -331.10 MWD+IFR-AK-CAZ-SC(2) 1,815.71 27.42 33.73 1,749.82 1,590.18 346.39 148.06 5,930,119.19 1,621,432.56 3.91 -372.91 MWD+IFR-AK-CAZ-SC(2) 1,909.84 27.44 39.74 1,833.39 1,673.75 381.10 173.96 5,930,153.83 1,621,458.55 2.94 -413.14 MWD+IFR-AK-CAZ-SC(2) 2,004.80 25.17 44.51 1,918.52 1,758.88 412.33 202.11 5,930,184.99 1,621,486.78 3.26 -450.59 MWD+IFR-AK-CAZ-SC(2) 2,099.72 24.63 50.47 2,004.63 1,844.99 439.32 231.52 5,930,211.90 1,621,516.25 2.70 -484.27 MWD+IFR-AK-CAZ-SC(2) 2,194.87 25.45 63.12 2,090.90 1,931.26 461.20 265.08 5,930,233.69 1,621,549.86 5.68 -514.09 MWD+IFR-AK-CAZ-SC(2) 2,289.33 27.45 75.16 2,175.53 2,015.89 475.96 304.26 5,930,248.35 1,621,589.07 6.05 -538.49 MWD+IFR-AK-CAZ-SC(2) 2,383.45 30.15 81.07 2,258.01 2,098.37 485.19 348.59 5,930,257.47 1,621,633.43 4.17 -558.88 MWD+IFR-AK-CAZ-SC(2) 2,476.89 32.78 84.16 2,337.71 2,178.07 491.41 396.95 5,930,263.56 1,621,681.80 3.30 -577.40 MWD+IFR-AK-CAZ-SC(2) 2,572.22 32.39 83.70 2,418.04 2,258.40 496.84 448.00 5,930,268.86 1,621,732.86 0.48 -595.86 MWD+IFR-AK-CAZ-SC(2) 2,666.25 33.43 89.38 2,497.00 2,337.36 499.88 498.95 5,930,271.78 1,621,783.81 3.46 -611.99 MWD+IFR-AK-CAZ-SC(2) 2,718.88 33.57 90.10 2,540.88 2,381.24 500.01 528.00 5,930,271.83 1,621,812.85 0.80 -619.63 MWD+IFR-AK-CAZ-SC(2) 2,740.81 33.44 88.91 2,559.17 2,399.53 500.12 540.10 5,930,271.91 1,621,824.95 3.05 -622.87 INC+TREND(3) 2,781.70 33.89 89.13 2,593.20 2,433.56 500.51 562.77 5,930,272.24 1,621,847.62 1.15 -629.11 r NOT an Actual Survey 4) 10 3/4"x 13-1/2" 2,835.17 34.49 89.40 2,637.43 2,477.79 500.89 592.81 5,930,272.55 1,621,877.66 1.15 -637.26 MWD+IFR-AK-CAZ-SC(4) 2,929.75 36.21 90.65 2,714.57 2,554.93 500.86 647.53 5,930,272.37 1,621,932.37 1.97 -651.38 MWD+IFR-AK-CAZ-SC(4) 3,024.24 37.57 93.01 2,790.14 2,630.50 499.03 704.21 5,930,270.40 1,621,989.04 2.08 -664.29 MWD+IFR-AK-CAZ-SC(4) 3,123.14 38.70 94.95 2,867.94 2,708.30 494.78 765.13 5,930,266.00 1,622,049.94 1.67 -675.95 MWD+IFR-AK-CAZ-SC(4) 3,214.24 39.66 97.87 2,938.56 2,778.92 488.34 822.30 5,930,259.41 1,622,107.10 2.28 -684.53 MWD+IFR-AK-CAZ-SC(4) 3,309.20 39.94 100.70 3,011.52 2,851.88 478.53 882.28 5,930,249.45 1,622,167.04 1.93 -690.57 MWD+IFR-AK-CAZ-SC(4) 3,404.39 40.64 103.86 3,084.14 2,924.50 465.43 942.41 5,930,236.20 1,622,227.13 2.27 -693.48 MWD+IFR-AK-CAZ-SC(4) 3,498.42 41.50 108.17 3,155.04 2,995.40 448.37 1,001.75 5,930,219.00 1,622,286.42 3.15 -692.37 MWD+IFR-AK-CAZ-SC(4) 3,593.22 42.17 111.43 3,225.68 3,066.04 426.95 1,061.22 5,930,197.43 1,622,345.83 2.40 -687.07 MWD+IFR-AK-CAZ-SC(4) 3,687.80 42.71 112.59 3,295.48 3,135.84 403.03 1,120.39 5,930,173.36 1,622,404.93 1.01 -679.27 MWD+IFR-AK-CAZ-SC(4) 3,782.58 44.52 112.00 3,364.10 3,204.46 378.23 1,180.88 5,930,148.41 1,622,465.36 1.96 -670.98 MWD+IFR-AK-CAZ-SC(4) 3,876.02 46.63 112.03 3,429.50 3,269.86 353.22 1,242.74 5,930,123.24 1,622,527.15 2.26 -662.83 MWD+IFR-AK-CAZ-SC(4) 3,970.37 49.13 112.04 3,492.77 3,333.13 326.96 1,307.61 5,930,096.83 1,622,591.94 2.65 -654.26 MWD+IFR-AK-CAZ-SC(4) 4,064.96 50.96 111.78 3,553.52 3,393.88 299.91 1,374.88 5,930,069.60 1,622,659.14 1.95 -645.54 MWD+IFR-AK-CAZ-SC(4) 2/22/2016 4:46:50PM Page 3 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Rig:2S-03 Project: Kuparuk River Unit TVD Reference: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: 120+39.64 @ 159.64usft(D25)True Well: 2S-03 North Reference: Minimum Curvature Wellbore: 2S-03PB1 Survey Calculation Method: OAKEDMP2 Design: 2S-03PB1 Database: 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) (°/100') (ft) Survey Tool Name 4,159.92 51.08 111.85 3,613.25 3,453.61 272.48 1,443.41 5,930,042.00 1,622,727.59 0.14 -636.78 MWD+IFR-AK-CAZ-SC(4) 4,254.49 51.03 111.77 3,672.70 3,513.06 245.15 1,511.70 5,930,014.51 1,622,795.80 0.08 -628.05 MWD+IFR-AK-CAZ-SC(4) 4,349.76 51.11 111.87 3,732.56 3,572.92 217.61 1,580.50 5,929,986.79 1,622,864.53 0.12 -619.25 MWD+IFR-AK-CAZ-SC(4) 4,444.28 51.03 110.84 3,791.95 3,632.31 190.83 1,648.98 5,929,959.84 1,622,932.93 0.85 -611.12 MWD+IFR-AK-CAZSC(4) 4,537.03 51.10 110.83 3,850.24 3,690.60 165.17 1,716.41 5,929,934.01 1,623,000.29 0.08 -603.78 MWD+IFR-AK-CAZ-SC(4) 4,632.40 51.17 109.61 3,910.09 3,750.45 139.51 1,786.08 5,929,908.17 1,623,069.89 1.00 -597.03 MWD+IFR-AK-CAZ-SC(4) 4,726.93 51.25 108.73 3,969.31 3,809.67 115.31 1,855.68 5,929,883.81 1,623,139.42 0.73 -591.67 MWD+IFR-AK-CAZ-SC(4) 4,820.81 51.07 107.98 4,028.18 3,868.54 92.28 1,925.08 5,929,860.61 1,623,208.76 0.65 -587.39 MWD+IFR-AK-CAZ-SC(4) 4,916.59 51.13 106.93 4,088.33 3,928.69 69.93 1,996.19 5,929,838.07 1,623,279.80 0.86 -584.20 MWD+IFR-AK-CAZ-SC(4) 5,010.86 51.21 106.99 4,147.44 3,987.80 48.50 2,066.43 5,929,816.47 1,623,349.98 0.10 -581.68 MWD+IFR-AK-CAZ-SC(4) 5,104.99 51.11 108.41 4,206.48 4,046.84 26.22 2,136.27 5,929,794.01 1,623,419.76 1.18 -578.23 MWD+IFR-AK-CAZ-SC(4) 5,199.04 51.12 109.40 4,265.52 4,105.88 2.50 2,205.53 5,929,770.11 1,623,488.95 0.82 -573.24 MWD+IFR-AK-CAZ-SC(4) 5,294.20 50.66 110.68 4,325.55 4,165.91 -22.80 2,274.90 5,929,744.64 1,623,558.25 1.15 -566.76 MWD+IFR-AK-CAZ-SC(4) 5,389.44 50.33 110.32 4,386.13 4,226.49 -48.54 2,343.73 5,929,718.74 1,623,627.00 0.45 -559.72 MWD+IFR-AK-CAZ-SC(4) 5,483.64 50.61 110.40 4,446.09 4,286.45 -73.82 2,411.85 5,929,693.29 1,623,695.05 0.30 -552.93 MWD+IFR-AK-CAZ-SC(4) 5,578.33 50.43 110.44 4,506.29 4,346.65 -99.32 2,480.34 5,929,667.62 1,623,763.47 0.19 -546.03 MWD+IFR-AK-CAZ-SC(4) 5,673.16 50.65 110.27 4,566.56 4,406.92 -124.78 2,548.98 5,929,641.98 1,623,832.04 0.27 -539.19 MWD+IFR-AK-CAZ-SC(4) 5,768.21 50.23 110.52 4,627.10 4,467.46 -150.32 2,617.67 5,929,616.27 1,623,900.66 0.49 -532.30 MWD+IFR-AK-CAZ-SC(4) 5,862.27 50.51 111.83 4,687.09 4,527.45 -176.49 2,685.22 5,929,589.93 1,623,968.13 1.11 -524.51 MWD+IFR-AK-CAZ-SC(4) 5,957.06 50.54 112.78 4,747.36 4,587.72 -204.26 2,752.91 5,929,562.00 1,624,035.75 0.77 -515.21 MWD+IFR-AK-CAZ-SC(4) 6,052.13 50.63 112.23 4,807.72 4,648.08 -232.37 2,820.76 5,929,533.71 1,624,103.52 0.46 -505.61 MWD+IFR-AK-CAZ-SC(4) 6,146.51 50.47 113.62 4,867.69 4,708.05 -260.76 2,887.88 5,929,505.16 1,624,170.56 1.15 -495.57 MWD+IFR-AK-CAZ-SC(4) 6,240.39 50.88 115.73 4,927.19 4,767.55 -291.07 2,953.86 5,929,474.68 1,624,236.46 1.79 -483.36 MWD+IFR-AK-CAZ-SC(4) 6,335.37 51.43 118.56 4,986.77 4,827.13 -324.82 3,019.68 5,929,440.76 1,624,302.18 2.39 -467.79 MWD+IFR-AK-CAZ-SC(4) 6,430.02 52.39 121.19 5,045.16 4,885.52 -361.93 3,084.25 5,929,403.49 1,624,366.66 2.41 -448.66 MWD+IFR-AK-CAZ-SC(4) 6,524.27 52.99 124.07 5,102.30 4,942.66 -402.35 3,147.37 5,929,362.92 1,624,429.67 2.51 -425.96 MWD+IFR-AK-CAZ-SC(4) 6,619.02 53.30 126.46 5,159.13 4,999.49 -446.12 3,209.26 5,929,319.00 1,624,491.44 2.04 -399.70 MWD+IFR-AK-CAZ-SC(4) 6,714.34 53.81 129.69 5,215.77 5,056.13 -493.40 3,269.61 5,929,271.57 1,624,551.66 2.78 -369.64 MWD+IFR-AK-CAZ-SC(4) 6,807.69 54.01 131.52 5,270.76 5,111.12 -542.50 3,326.87 5,929,222.33 1,624,608.80 1.60 -337.04 MWD+IFR-AK-CAZ-SC(4) 6,903.31 54.07 133.10 5,326.91 5,167.27 -594.60 3,384.11 5,929,170.10 1,624,665.89 1.34 -301.54 MWD+IFR-AK-CAZ-SC(4) 6,998.16 54.04 134.47 5,382.59 5,222.95 -647.73 3,439.54 5,929,116.83 1,624,721.18 1.17 -264.56 MWD+IFR-AK-CAZ-SC(4) 7,092.00 53.65 137.03 5,437.96 5,278.32 -701.99 3,492.41 5,929,062.44 1,624,773.91 2.24 -225.83 MWD+IFR-AK-CAZ-SC(4) 7,187.22 53.65 139.87 5,494.41 5,334.77 -759.37 3,543.26 5,929,004.93 1,624,824.62 2.40 -183.57 MWD+IFR-AK-CAZ-SC(4) 7,281.99 53.38 143.30 5,550.77 5,391.13 -819.06 3,590.60 5,928,945.13 1,624,871.80 2.92 -138.17 MWD+IFR-AK-CAZ-SC(4) 7,376.46 53.33 146.73 5,607.16 5,447.52 -881.14 3,634.05 5,928,882.94 1,624,915.08 2.91 -89.44 MWD+IFR-AK-CAZ-SC(4) 7,470.40 54.01 150.28 5,662.83 5,503.19 -945.66 3,673.57 5,928,818.33 1,624,954.43 3.13 -37.35 MWD+IFR-AK-CAZ-SC(4) 7,565.20 54.64 153.51 5,718.12 5,558.48 -1,013.58 3,709.83 5,928,750.33 1,624,990.52 2.85 18.87 MWD+IFR-AK-CAZ-SC(4) 7,659.92 54.58 156.32 5,772.99 5,613.35 -1,083.50 3,742.56 5,928,680.33 1,625,023.07 2.42 77.94 MWD+IFR-AK-CAZ-SC(4) 7,755.31 54.76 158.29 5,828.15 5,668.51 -1,155.29 3,772.58 5,928,608.47 1,625,052.91 1.70 139.51 MWD+IFR-AK-CAZ-SC(4) 7,851.51 54.93 159.69 5,883.55 5,723.91 -1,228.72 3,800.78 5,928,534.99 1,625,080.92 1.20 203.13 MWD+IFR-AK-CAZ-SC(4) 2/22/2016 4:46:50PM Page 4 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Rig:2S-03 Project: Kuparuk River Unit TVD Reference: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: 120+39.64 @ 159.64usft(D25)True Well: 2S-03 North Reference: Minimum Curvature Wellbore: 2S-03PB1 Survey Calculation Method: OAKEDMP2 Design: 2S-03PB1 Database: Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,944.13 57.65 160.82 5,934.95 5,775.31 -1,301.23 3,826.80 5,928,462.42 1,625,106.74 3.11 266.44 MWD+IFR-AK-CAZ-SC(4) 8,037.87 61.20 162.16 5,982.62 5,822.98 -1,377.75 3,852.40 5,928,385.84 1,625,132.15 3.98 333.73 MWD+IFR-AK-CAZ-SC(4) 8,134.96 65.11 163.68 6,026.46 5,866.82 -1,460.54 3,877.81 5,928,302.99 1,625,157.35 4.26 407.12 MWD+IFR-AK-CAZ-SC(4) 8,227.49 67.60 165.32 6,063.57 5,903.93 -1,542.21 3,900.45 5,928,221.27 1,625,179.78 3.14 480.15 MWD+IFR-AK-CAZ-SC(4) 8,321.13 69.49 167.84 6,097.82 5,938.18 -1,626.98 3,920.66 5,928,136.46 1,625,199.78 3.22 556.80 MWD+IFR-AK-CAZ-SC(4) 8,416.49 71.30 170.93 6,129.83 5,970.19 -1,715.26 3,937.20 5,928,048.15 1,625,216.08 3.59 637.79 MWD+IFR-AK-CAZ-SC(4) 8,511.46 72.15 172.50 6,159.61 5,999.97 -1,804.49 3,950.19 5,927,958.89 1,625,228.85 1.81 720.62 MWD+IFR-AK-CAZ-SC(4) 8,606.43 72.76 174.79 6,188.24 6,028.60 -1,894.48 3,960.21 5,927,868.89 1,625,238.64 2.39 804.95 MWD+IFR-AK-CAZ-SC(4) 8,701.25 73.21 177.13 6,215.99 6,056.35 -1,984.92 3,966.59 5,927,778.44 1,625,244.79 2.41 890.65 MWD+IFR-AK-CAZ-SC(4) 8,756.84 74.39 178.49 6,231.50 6,071.86 -2,038.26 3,968.63 5,927,725.10 1,625,246.69 3.17 941.65 MWD+IFR-AK-CAZ-SC(4) 8,826.90 74.24 179.92 6,250.44 6,090.80 -2,105.70 3,969.56 5,927,657.66 1,625,247.46 1.98 1,006.55 NOT an Actual Survey 7-5/8 x 9-7/8 by 11" 8,852.56 74.19 180.45 6,257.42 6,097.78 -2,130.39 3,969.48 5,927,632.97 1,625,247.31 1.98 1,030.43 INC+TREND(5) 8,947.89 75.01 181.42 6,282.74 6,123.10 -2,222.29 3,967.98 5,927,541.09 1,625,245.58 1.30 1,119.58 MWD+IFR-AK-CAZ-SC(6) 9,042.78 75.22 183.94 6,307.12 6,147.48 -2,313.88 3,963.69 5,927,449.52 1,625,241.06 2.58 1,209.16 MWD+IFR-AK-CAZ-SC(6) 9,137.59 76.65 185.80 6,330.16 6,170.52 -2,405.51 3,955.88 5,927,357.92 1,625,233.02 2.43 1,299.69 MWD+IFR-AK-CAZ-SC(6) 9,232.40 80.93 185.26 6,348.59 6,188.95 -2,498.06 3,946.92 5,927,265.40 1,625,223.83 4.55 1,391.40 MWD+IFR-AK-CAZ-SC(6) 9,326.85 84.53 184.89 6,360.54 6,200.90 -2,591.37 3,938.64 5,927,172.13 1,625,215.30 3.83 1,483.67 MWD+IFR-AK-CAZ-SC(6) 9,421.97 88.76 186.02 6,366.10 6,206.46 -2,685.87 3,929.61 5,927,077.65 1,625,206.04 4.60 1,577.29 MWD+IFR-AK-CAZ-SC(6) 9,519.33 92.15 185.87 6,365.33 6,205.69 -2,782.69 3,919.53 5,926,980.87 1,625,195.71 3.49 1,673.42 MWD+IFR-AK-CAZ-SC(6) 9,612.10 91.39 188.72 6,362.46 6,202.82 -2,874.65 3,907.76 5,926,888.94 1,625,183.71 3.18 1,765.30 MWD+IFR-AK-CAZ-SC(6) 9,707.04 92.46 191.75 6,359.27 6,199.63 -2,968.02 3,890.90 5,926,795.63 1,625,166.62 3.38 1,859.85 MWD+IFR-AK-CAZ-SC(6) 9,801.77 92.57 195.88 6,355.11 6,195.47 -3,059.90 3,868.31 5,926,703.82 1,625,143.79 4.36 1,954.45 MWD+IFR-AK-CAZ-SC(6) 9,896.56 92.10 200.03 6,351.25 6,191.61 -3,149.98 3,839.11 5,926,613.82 1,625,114.38 4.40 2,049.01 MWD+IFR-AK-CAZ-SC(6) 9,992.30 89.33 200.03 6,350.06 6,190.42 -3,239.91 3,806.33 5,926,523.98 1,625,081.36 2.89 2,144.36 MWD+IFR-AK-CAZ-SC(6) 10,086.92 88.93 198.88 6,351.49 6,191.85 -3,329.12 3,774.82 5,926,434.87 1,625,049.63 1.29 2,238.69 MWD+IFR-AK-CAZ-SC(6) 10,181.40 88.83 197.79 6,353.34 6,193.70 -3,418.78 3,745.10 5,926,345.29 1,625,019.69 1.16 2,332.99 MWD+IFR-AK-CAZ-SC(6) 10,277.03 88.49 196.66 6,355.58 6,195.94 -3,510.10 3,716.79 5,926,254.05 1,624,991.15 1.23 2,428.52 MWD+IFR-AK-CAZ-SC(6) 10,371.90 88.07 196.20 6,358.42 6,198.78 -3,601.05 3,689.97 5,926,163.17 1,624,964.10 0.66 2,523.31 MWD+IFR-AK-CAZ-SC(6) 10,466.92 87.39 196.30 6,362.19 6,202.55 -3,692.20 3,663.40 5,926,072.10 1,624,937.31 0.72 2,618.24 MWD+IFR-AK-CAZ-SC(6) 10,561.36 87.32 195.65 6,366.54 6,206.90 -3,782.90 3,637.44 5,925,981.48 1,624,911.12 0.69 2,712.56 MWD+IFR-AK-CAZ-SC(6) 10,656.01 87.61 197.86 6,370.73 6,211.09 -3,873.44 3,610.18 5,925,891.02 1,624,883.63 2.35 2,807.07 MWD+IFR-AK-CAZ-SC(6) 10,750.57 89.80 195.90 6,372.87 6,213.23 -3,963.89 3,582.74 5,925,800.65 1,624,855.96 3.11 2,901.54 MWD+IFR-AK-CAZ-SC(6) 10,845.81 90.41 197.42 6,372.69 6,213.05 -4,055.13 3,555.43 5,925,709.49 1,624,828.43 1.72 2,996.74 MWD+IFR-AK-CAZ-SC(6) 10,941.49 90.34 197.54 6,372.07 6,212.43 -4,146.39 3,526.69 5,925,618.31 1,624,799.46 0.15 3,092.33 MWD+IFR-AK-CAZ-SC(6) 11,036.30 89.40 197.75 6,372.28 6,212.64 -4,236.74 3,497.95 5,925,528.04 1,624,770.50 1.02 3,187.04 MWD+IFR-AK-CAZ-SC(6) 11,130.21 89.65 197.86 6,373.06 6,213.42 -4,326.15 3,469.24 5,925,438.72 1,624,741.56 0.29 3,280.83 MWD+IFR-AK-CAZ-SC(6) 11,224.93 88.62 196.31 6,374.49 6,214.85 -4,416.67 3,441.42 5,925,348.27 1,624,713.51 1.96 3,375.47 MWD+IFR-AK-CAZ-SC(6) 11,319.09 88.00 196.62 6,377.27 6,217.63 -4,506.93 3,414.74 5,925,258.09 1,624,686.61 0.74 3,469.56 MWD+IFR-AK-CAZ-SC(6) 11,413.70 87.76 195.11 6,380.77 6,221.13 -4,597.87 3,388.90 5,925,167.22 1,624,660.53 1.61 3,564.09 MWD+IFR-AK-CAZ-SC(6) 2/22/2016 4:46:50PM Page 5 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Rig:2S-03 Project: Kuparuk River Unit TVD Reference: 120+39.64 @ 159.64usft(D25) Site: Kuparuk 2S Pad MD Reference: 120+39.64 @ 159.64usft(D25)True Well: 2S-03 North Reference: Minimum Curvature Wellbore: 2S-03PB1 Survey Calculation Method: OAKEDMP2 Design: 2S-03PB1 Database: 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 11,508.90 88.35 192.64 6,384.00 6,224.36 -4,690.23 3,366.08 5,925,074.93 1,624,637.49 2.67 3,659.21 MWD+IFR-AK-CAZ-SC(6) 11,604.26 88.38 191.80 6,386.72 6,227.08 -4,783.39 3,345.91 5,924,981.83 1,624,617.08 0.88 3,754.42 MWD+IFR-AK-CAZ-SC(6) 11,698.69 88.59 192.00 6,389.22 6,229.58 -4,875.76 3,326.44 5,924,889.52 1,624,597.38 0.31 3,848.68 MWD+IFR-AK-CAZ-SC(6) 11,793.62 88.59 191.14 6,391.55 6,231.91 -4,968.73 3,307.41 5,924,796.60 1,624,578.11 0.91 3,943.41 MW D+I FR-AK-CAZ-SC(6) 11,888.42 89.03 192.55 6,393.52 6,233.88 -5,061.49 3,287.95 5,924,703.90 1,624,558.42 1.56 4,038.04 MWD+I FR-AK-CAZ-SC(6) 11,984.62 89.00 192.00 6,395.18 6,235.54 -5,155.48 3,267.50 5,924,609.98 1,624,537.74 0.57 4,134.12 MWD+1FR-AK-CAZ-SC(6) 12,077.92 89.58 190.74 6,396.33 6,236.69 -5,246.94 3,249.11 5,924,518.58 1,624,519.12 1.49 4,227.22 MWD+IFR-AK-CAZ-SC(6) 12,172.68 88.78 190.34 6,397.69 6,238.05 -5,340.09 3,231.78 5,924,425.48 1,624,501.55 0.94 4,321.68 MWD+IFR-AK-CAZ-SC(6) 12,268.19 89.21 191.47 6,399.36 6,239.72 -5,433.86 3,213.71 5,924,331.76 1,624,483.25 1.27 4,416.93 MWD+I F R-AK-CAZ-SC(6) 12,363.22 88.69 192.78 6,401.11 6,241.47 -5,526.75 3,193.76 5,924,238.93 1,624,463.06 1.48 4,511.83 MWD+IFR-AK-CAZ-SC(6) 12,457.52 88.52 194.38 6,403.40 6,243.76 -5,618.38 3,171.62 5,924,147.36 1,624,440.69 1.71 4,606.07 MWD+IFR-AK-CAZ-SC(6) 12,552.96 87.20 194.32 6,406.96 6,247.32 -5,710.78 3,147.99 5,924,055.04 1,624,416.83 1.38 4,701.43 MWD+IFR-AK-CAZ-SC(6) 12,647.84 88.43 196.83 6,410.58 6,250.94 -5,802.10 3,122.53 5,923,963.79 1,624,391.14 2.94 4,796.23 MWD+IFR-AK-CAZ-SC(6) 12,743.26 86.87 197.05 6,414.50 6,254.86 -5,893.30 3,094.75 5,923,872.67 1,624,363.14 1.65 4,891.51 MWD+1FR-AK-CAZ-SC(6) 12,838.22 84.17 196.98 6,421.91 6,262.27 -5,983.82 3,067.05 5,923,782.23 1,624,335.21 2.84 4,986.11 MWD+1FR-AK-CAZ-SC(6) 12,932.91 83.12 196.47 6,432.39 6,272.75 -6,073.94 3,039.97 5,923,692.19 1,624,307.90 1.23 5,080.18 MWD+IFR-AK-CAZ-SC(6) 13,028.27 83.02 197.75 6,443.90 6,284.26 -6,164.41 3,012.12 5,923,601.79 1,624,279.82 1.34 5,174.77 MWD+1FR-AK-CAZ-SC(6) 13,121.95 82.94 196.16 6,455.35 6,295.71 -6,253.35 2,985.01 5,923,512.94 1,624,252.49 1.69 5,267.69 MWD+IFR-AK-CAZ-SC(6) 13,218.25 78.76 197.01 6,470.66 6,311.02 -6,344.45 2,957.88 5,923,421.92 1,624,225.13 4.43 5,362.71 MW D+I FR-AK-CAZ-SC(6) 13,312.58 77.33 196.63 6,490.20 6,330.56 -6,432.78 2,931.17 5,923,333.66 1,624,198.21 1.57 5,454.94 MWD+IFR-AK-CAZ-SC(6) 13,407.89 80.90 195.90 6,508.19 6,348.55 -6,522.62 2,904.97 5,923,243.90 1,624,171.78 3.82 5,548.50 MWD+IFR-AK-CAZ-SC(6) 13,502.54 83.19 195.32 6,521.29 6,361.65 -6,612.89 2,879.75 5,923,153.70 1,624,146.33 2.49 5,642.23 MWD+IFR-AK-CAZ-SC(6) 13,596.27 86.56 193.49 6,529.67 6,370.03 -6,703.30 2,856.53 5,923,063.36 1,624,122.89 4.09 5,735.56 MW D+I FR-AK-CAZ-SC(6) 13,667.30 89.00 194.05 6,532.42 6,372.78 -6,772.23 2,839.64 5,922,994.48 1,624,105.82 3.52 5,806.52 MWD+IFR-AK-CAZ-SC(6) 13,728.00 89.00 194.05 6,533.48 6,373.84 -6,831.10 2,824.90 5,922,935.65 1,624,090.94 0.00 5,867.20 PROJECTED to TD 2/22/2016 4:46:50PM Page 6 COMPASS 5000.1 Build 74 • ! Final Definitive Survey Verified and Sianed-off All targets and/or well position objectives have been achieved. LJ Yes L No 1 have checked to the best of my ability that the following data is correct: U Surface Coordinates p Declination & Convergence Li GRS Survey Corrections El Survey Tool Codes Vincent Digitally signed by Vincent Dsara Ymccnt Clara. o-Schlumberger.ne Sdrn Juberger. SLB DE 4 s a ra Date 20602.230957.214N 00' r)grar.4T1Ctwai Alai Mike Callahan ',�,;. `zi �` '"'m` u:�Megl Noh Client Representative _,____ry__, 99 DAP i 161011'N2:9 4990 Date: 23-Feb-:016 V OF Tit • V"- ► //7„'s THE STATE Alaska Oil and Gas fit ;s����, OfA T e TA Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g ^ Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Adan Klem Completions Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field,Kuparuk River Oil Pool, KRU 2S-03 Permit to Drill Number: 215-205 Sundry Number: 316-134 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, i Cathy . Foerster /61.1"d Chair DATED this/©'1day of March, 2016. RBDMS t-'- MAR 1 1 2016 STATE OF ALASKA • RECEIVEDFEB 1 $ ��� ALASKA OIL AND GAS CONSERVATION COMMISSION • APPLICATION FOR SUNDRY APPROVALS 0 3 !s i/ 20 AAC 25.280 ° W®1 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate 2- Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. - Exploratory ❑ Development 0, 215-205 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-103-20729-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2S-03 • Will planned perforations require a spacing exception? Yes ❑ No ❑., 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25604, 25607, 25603 • Kuparuk River Field/Kuparuk River Oil Pool , 11. PRESENT WELL CONDITION SUMMARY Total Dept MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TV i MPSP(psi): Plugs(MD): Junk(MD): 16,016st. r 6,4$ j(o1 N (S$ti f''+• 4,400 Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 120' 120' Surface 2,553' 10-3/4" 2,782' 2,593' Intermediate 5,209' 7-5/8" 8,826' 6,249' Production Liner 7,717'est. 4-1/2" 16,543'est. 6,440'est. Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See attached schematic See attached schematic 3.5" L-80 8,768'est. Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): LEM Installation,no SSSV 8,678'est.x256'est,TVD SU A•TWA4t6 12.Attachments: Proposal Summary Q Wellbore schematic U 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development E• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: March 1st,2016 Commencing Operations: _,-------+-,„... OIL ❑✓ , WIND ❑ 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 Ada lem Title: Completions Engineer d/ig/f'6 Signature Phone 907-263-4529 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .Plug .3\t .'- \ i.- Plug Integrity ❑ BOPCI OTest ❑ Mechanical Integrity Test ❑ Location Clearance Other: �e S-� /4 3 Q,-O 10 s 1 . Post Initial Injection MIT Req'd? Yes ❑ No Er RBDMS (.V MAR 1 1 2016 Spacing Exception Required? Yes ❑ No [4 Subsequent Form Required: /0 ..- 4 04 APPROVED BY Approved by: ` COMMISSIONER THE COMMISSION Date: 3�(6-/,6' TL 3�f / Submit Form and Form 10-403 evised 11/2015 OFdbINA [ vilapC�islid for12 mont�s�'om the date of approval. // Attac mein�plicate 37' GDI,I 2/ 6 b • ConocoPhillips Alaska, Inc. Paul K.Wharton Staff Landman P.O.Box 100360—Suite ATO 1482 Anchorage,Alaska 99510-0360 Phone(907)263-4076 Fax (907)263-4966 Paul.K.W harton@conocophillips.corn To: Operator and Owners (shown on Exhibit 2) Re: Notice pursuant to 20 AAC 25.283 (1) 2S-03 Well Kuparuk River Unit, Alaska ADL 25603, KRU Tract 90; ADL 25604, KRU Tract 89; and ADL 25607, KRU Tract 96 Dear Sirs: ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Kuparuk River Unit ("KRU") working interest owners, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the 2S-03 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about February 2, 2016. This Notice is being provided pursuant to 20 AAC 25.283. The Well has been drilled as a directional well on leases ADL 25603, KRU Tract 90; ADL 25604, KRU Tract 89; and ADL 25607, KRU Tract 96 as depicted on Exhibit 1 as follows: Surface Location: 3024' FNL, 1320' FEL, Section 17, T1ON, RO8E, UM Target Location: 5160' FNL, 2621' FEL, Section 16, T1ON, RO8E, UM Bottomhole Location: 1994' FNL, 4514' FEL, Section 28, T1ON, RO8E, UM 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 to you. If you require any additional information, please contact the undersigned. Very truly yours, 14 • u Paul Wharton Staff Landman cc: Hanna Sylte Rebecca Swensen • • Ric-'101 3/7/I ;II- KUP PROD 2S-03 ConocoPhillips ) Well Attributes Max Angle&MD TD Wallbore APSUWI PIM NOM WyeabOre Statue n:,...'12 5711110 4nR819 801 n Ad Btmitt1160 c 501032072930 KUPARUK RIVER UNIT .7"..2i: ••. Callanaart 112liPPTI Date ..:11s1aton End DM. KII-GRI{RI Pig Pewee Data 35.64 1'22*3 Algol:den Darin,TP(6, !Id DM Annotiaton ,..es!M:,1 Ei End Dina -E,2 .-: .... .•,... - Casing%.,..,...:,.:. . '..1...,::. Strings `,, --- ..,,,'::::Casing DeecnptIon ODiall ID OM Top4111(111 SR Depth IRKS) Si Dept.jTVIII .1.1:Lon IL..Grads Uri-bread so simpapie mai*. a a".,-....: ..., ....,•:..............:r Ca!,.np Deetription -fi '5 255 4514 '2:4 '3,7 4 82 53 H•40 Welrer 00.pni 01;Pi 1op5tlX91 Se Depth ittK01 Set Cacti,17vD1 ii4111..s11...Grille lop Timed '0 94 5 5,53 43.4 2 73-7 2 553'a 45 53 i.-33 TSH 553 -A-0......A.,ep,,,,,,,,,,6,,,p,..=, ro:, :...,,:•.•Casing prisons-Don .00111148 s 10 ilni s.15 Top ittKsBii 2.Pit Car&:,rtK„,,Es;,Set Dicta s.,,T1,7,:i.5 t•rtien251,;:.Grids 14,7:.5,.... .. ..,._.Dimino Description .01:14119 0551 Top irtKiii set Depth irtKei Set Dicta MIDI_Sittiien 0...Graaf Top Tamed ' Is- 4 .2 3 555 E.0'52' '0.725 7 5432.5 "2,90 L-63 Hy:J.553 Liner Details 1,...CV 214.4 t 4T-, los,,115131 Too 595;Mfrs, lc;Inc IleT Des .41e 111- 3E76.5 523973.09 Nipple iP,S: 3ara-5 2 82 =err:"Ese ,::a -7ri...a: 424: H. 543 r::,rrir ••••-acs•-OS-S OIC= ••. 5.575.2 5 235 7 73.-- Har;ar Bars':5 rz 7 13 ilir.--rrr- 0'-h-ps• . : . .1 :...0 11; -,..!53:-.4.• ,..aToor o o•o••: ES L-: 5 2-2.5 73.-5 / 5ec.:In; 52 -- 552 .25.7.:-.5.15 5.725.2. 8.2'5 5 732' SealBore Ea a 5r-a a r-2.5,-FC r Hyr 5.3":--Sri 4,, 3.35: 9o,os ....,c Pe-so-C•••4O I. Vim- Exters or -...,.5:- 5 23-: 5 343 4 75.51 Spelt Parker 3a rs---2w-s i a:ra-• .3N 5:454-03,s4 3 it"3 .2L{r.......,•PIPS,: x0•,oroco IS'S' E•453' 5 355 0 9579 FRAC Eartara-1.27,sc 3.,,s.':•3.2 is .7-..-•ir ;445 ;I :•:- Sleest.Port 2.43C R1.1.10437C:1 = 1: , :. 13.2:0; 5 354: 8575 sFRAC,..v.70,, 21119tramir4-.,41.7",c7,..z-aqicia,a rri•:.:432 Ea 3".-.o., 2.350 " aancri : :,L........., . 79534E. 5053- 07.42 Swell Packer lilaitarr-"Earrial.racca'• ,-1" 3\ 5:854•52.--43 3 950 I, ::. 10,70.52 5,535.7 06.53 FRAC SIMIC,4-1:7=RP SanIVOT,'••;.:27 Ea 3.-,,ii 2 322 Sle.isPon 2 3'2'1.-"N-.7.431m4 :: risni s .s 553.7 2,3.25 ;. ...pr, RA21,. 5s2".•••... .7 ...12-rt.Lete.7.;2.3-2 Ea 3-.-.w 2.252 0 555 0 55 30 5,el,Pinker Ears"- .3.... =arra.• 3 2, 5:4174•3:-.32 3555 • '234.7 5 55-5 4 ET 52, 5=.A.:7 2 E.-..74-4•'2 4-a:3•Es',..5"-2.7! Fi 7,-'-.-, 5.vali`ort ;-11. i'.'1. 27:::: -2A:'3,4 545..5 55 ,,PO Pinker ?E.,- 2.is isr•ca-• 048.-3:-.37 3.955 :•11 I. 2,824.2" 6 385.7" 5-8.7 't 5:A',7. Ears-c--3 r•-ar 3 aa-,PE• 2'73 Es 2-.7, 2135 r cevePo, '5 62.7 5.357.5 Li:2 S.,01.arke- ta-re..- 2'..a 5 a:•,-- 0 3, 2:4i4•::-.2.- 3.958 'liar -3 342 8 5,43-" 3.3 34 i RAC Eara-4,"; re:iee•EP-• :':f. Es :"':--, 2.073 LJ al 54' a..- : •:... 56 4.3D3.4 542O 5742 3ais4; 4a:ts1,-:.:• Z55 7-'v 2 010 1- 3 '4 5E3.5 5 425 1 32 32 L.,s =2=r e- i.E.,'•• E... =E:•,..-• ::, i`.• 2:i E4-::1.4 3.958 -5:54.3 5 41-1 32,2.1 i.,..::•.:.; ...,,_ E.s.s:"3,.-..:sr.,3 es,a n;•; is 3,".-., '5E3 1.942, 1111 5 435 5 8 552 4 -5 585 i Tubing Strings 8 455 7 Li 5' 2-, E---P:, " E .2_..- • 5 47,7: Li El :::,;•,":„„,::", E i_;.......:; -..,,,,5:.e_tare'• -i-.2.1 Es 25',II-.!- 54435 33-32. L, t•,......,.. :.,-:- .. 5 5'.' 53-": 5 452 5.. 5455 i-sr.ilea, Ea.e. 5 453 5 54.47 2.58.5 _ cars . s r,-.-: :r: 'SE! 3 33: 5911w5 Cai.•ir Or r String 14a. Dir; /cc MKS; SO Depth irt. id DaptIr1TVCi 1. oil ttt.111 Grade Tap Cbrialet102'1195E Complelion Details - , 2553 :, , TSP f111(1!” lop 1TVD)1550, 111,-5. .• loT riear7 3 a 75 5 5.22:' .5 2,7 5-57 EJE8n1-1.4 21•,. NOrnInal ID (a) 6 6 37,3 37.5 :233 -ic.-ra- 23scra-r- 4.-;7,-.-i-la-gs- 3.900 3.5435 5.-95 5 72.09 2:,,s.:;!.....-1: 5".q;.-,;;sTi.,--_::--;,,-,3_11;;e2'...a::a-3- 2 5.3 i".--i- 2.913 11°I. 0,55.5- 5-3E 3 12.06 N‘ra-3,13 2rinyer.275 n-sr. 5 2:-, ..-:r.r...,r, --.s; 2.812 61 6i E.640' 5 33:7 72.88 LOOSTO, ?airs,T SIT::x 2 5 2-aa•:--sr i-rar 2.5-35595-- 3.01: ..i's W 5,540-' 5.2:-: 73,-c .. 11?• .:3,2 2 2 sa :--a:i--..Nr-Sc 3.r.-- 3.073 0 0E.7-4 3 Mandrel Inserts 3.0:3 1.0.1.1 I si cn 159525; vat. eaten Port Size 7PO Ti it)•' 4 . 1055555(5; 1)5(5; 1,1515 M.. 7.7:'.n, Sr, Typo Typo (Mt (pan Run Date Con. ' 3,984.8 3.532.3 Discs 314.344i5 - aAS SIFT Di.enrn 0.1(2 21291201G W 2 7.43'e 5 555 7 :,'s-- ..:2_-.,:• _,77 yDumm BK2 2129120'6 4 Ca-:r '3,"Er•.‘ '2.-ii_=7 SOV ii-.2 3:5 229.2016 .11 li • . i.li. l't . n , 2*ETM S-03 ConocoPhillipser Grassroots Horizontal A-Sand Produc ,j iil.il It cProposed Wellbore Schematc(wp09) ii Ai c.r. .. 1. . Last Edited: 4- c TCc'rt 4.'''' Callahan 12-11-15 18-Cdor -118 .. 131 115" Surface Hole ... i... - • . mat Mt MEM 3-1.c x V.v."Cameo WAG GLM - " Surface Casing i 50TVD below W Saki 10-3,14"45.5#L-80 Flydril 563 2,837'MD I 2,727'1VD(32'INC) 9-718-x 11"Intermediate Hole Tubing- 3-1112- 9.3 O L-80 EUE ORD-MOD IMI CCM ati SCV .2."`ZI.age-CC.. sair wo above c-r, Formation at.S.,QO 14114,531"rob .„ ..... .„ :';',- 11111111 : 16M4MarMal It".Cc1M"4"124'MD C-37:attl.0 MO t kgser T.,:d _ . orewur cosbelvl:e,4-ir MO t 6 1,4tY NO TC C: Too of Eartowta,`Ct afro lomat ton) .W.A. bow lair C'V-I ltdrno Sews Cairn:7,271'MO;4,600'NO t .3-,i,I 7-6,,tr.Rnsvaar P-aaker El arnada.7414'MO t'6,04O'NO _...1046 . 1..",2.f'D Moo* HRZ:time ldo Ja.afir TVD Kalteta.446 1).alD'8.120''ND tr-*0- 4 Sri Pram . . r Kuwait A4:6,648'MD;0,3711'NO-11.6 ogig 7.rx 4-..te Bailor DP -.. PadttartRea Loot Lama I lt It It iirlt____m_iti.1 [3: Hir,... ... N • -.. tt 1D:111.64.1"MIDI BMW'ND intermediate Casino Production Liner 6-3/4" Production Holt- 7-5'8"'2,E.I.7#L-60 14yd563 Casing 4-112"11.6#L-80 1BTM with Torque Rings 13,1388'MD!0.250'TVD(7'50 INC) 16,543'MD16,440'TVD 2S-03 Hydraulic Fracturing Notice Lett./ 41110 February 2, 2016 Page 2 Exhibit 1 s--- AGL02cce0 '76 ConocoPhillips IiI''pJ T� ACLD2, 8e 23-03 Alaska, Inc,. lop Platt OlFetta ZSQ3 18 DS2 -- sa t/2 mile radius .gDLOI2E +4 from Well ADL02Em3 i T N R8E / , I i i ACL02Eeas ADLD25607 1 1 —^ Kuparuk PA Boundary _ :a • Frac Point References: 126090 ---Well Trajectory Well Data:CaneccPhillips Al9s.:9 Technical D9tsta3e;ATCIEI • - Open Section N gi 1..+2 Mi Radius Unit Tract Number 0 0.2 0.4 0.6 0.8 0CPAI Lease 11 Iles 2S-03 Hydraulic Fracturing Notice Lett* • February 2, 2016 Page 3 Exhibit 2 Mineral Owners: Operator: 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 Non-Operators: 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 Surface Owners: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 Attention: Director a 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 TH•ASKA OIL AND GAS CONSERVATION COSSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Paul K.Wharton Request of ConocoPhillips Alaska, Inc.for ) Hydraulic fracturing for the 2S-03 Well ) under the Provisions of 20AAC 25.280 ) STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) Paul K.Wharton, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Paul K.Wharton, and I have personal knowledge of the matters set forth herein. 2. 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 or about February 2, 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 2nd day of February, 2016. Paul K.Wharton STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 2nd day of February, 2016, by Paul K.Wharton. Notary Public, State of Alaska My Commission Expires: STATE OF ALASKA Via" m, NOTARY PUBLIC • REBECCA SWENSEN My Commission Expires Aug.V,2010 • S Section 2 — Plat 20 AAC 25.283 (a)(2) Plat 1: 2S-03 Landowners " 1FEfl1€ ConocoPhillips Alar•ca Inc. 25-03 ADLfl25510 _._—,_ __ -ease P!.a: N 7 7� /i1 V ors fI F I ,..•F1 f iN ,---- is rr le g-.- t?525 40 .?8-0,3 iii I 1\ Id1025:04 42_2-ft,_., `j KR 8S 22G8 f 21-10-8 l_-10 1 E 72 20 21 T10 R8E ,r / 1 ,i. f F 27 95 \\*%."-•..... 2E, 96 :.......--.................----- ADLO25t 08 * Frac Point r - Well Trajectory —Open Section Well Within 1t2Mi.Radius Kuparuk PA Boundary (s : 0112 Mi.Radius �,., ...� Unit Tract Number Q CPAI Lease • • Table 1: Wells within .5 miles Well Name API Drill Site Status Well Type KRU 21-10-8 501032010300 N/A PA N/A 2S-02 501032071000 2S ACTIVE INJ 2S-07 501032071300 2S ACTIVE INJ 2S-10 501032071700 2S ACTIVE INJ 2S-13 501032072000 2S ACTIVE INJ 2S-13PB1 501032072070 2S PA N/A 25-04 501032072100 2S ACTIVE INJ 2S-04PB1 501032072170 2S PA N/A 2S-08 501032072200 2S ACTIVE INJ 2S-01 501032072700 2S ACTIVE PROD • SECTION 3 — FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) • There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. See conclusion of the Aquifer Exception Order No. 2 — Milne nt Unit. Which states "Those portions of freshwater aquifers lying directly below Milne Por6t Unit qualify as exempt freshwater agyifers under 10 AAC 25.440" kv.t-itr (rxkorka .77.H4 4/0 c.FR /40: /0Z(11)(3) 10o bits grAis ovU /UoAv7f- Sio 011scr,hec/ ih, /L A -hyo ovvi 1 / � / klo� E (/ n,,/C �2,v'r alt.* 011 cel �,1J • • 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 2/3/2016 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 12 ppg tail cement. Full returns were seen throughout the job. The plug bumped at 257 psi and the floats were checked and they held. The 7-5/8" casing cement report on 2/11/2016 shows that the job was pumped as designed, 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 1,103 psi and the floats were checked and 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 2/5/2016 the 10 & 3/4" casing was pressure tested to 3500 psi. On 2/15/2016 the 7 & 5/8" casing was pressure tested to 3500 psi. The 7 & 5/8" casing will be pressure tested to 3, 0 psi prior to frac'ing. es) 14 The 3.5" tubing will be pressure tested to 4,000 psi prior to frac'ing. Min IS-COPS\ . C-- b1") 3/3/2016 • • 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/" 45.5 L-80 2,090 psi 3,580 psi 7 & 5/8" 29.7 L-80 6,890 psi 4,790 psi 3.5" 9.3 L-80 10,160 psi 10,540 psi Table 2: Pressure Ratings • • Stimulation Surface Rig-Up Bleed/Tattle ►i/ Tate Far* 0 d IP .> 3 ,1. • Minimum pressure rating on all surface treating lines 10,000 psi 04:11Der ovz4D8c1 • Main treating line PRV is set to 95%of max treating pressure • IA parallel PRV set to 3 0 psi 3 o 1101111* • Frac pump trip pressure setting are staggered �� and set below main treating line PRV (,)r„/ • Tree saver used on all fracs rated for 15,000 3/, �` dg b psi. (JJII// dun Pop-Off Tank 2 NI Pump Truck Pop-Oft Tank Oi N c y_ a Z Sar- 'i .5 Frac Pump N, 1J —DSC f'. 1-!3_I-LII"IC Frac Pump --{J---- Frac Pump 2 Frac Pnp 4 _-f -- -- - - Frac Pump • S 10K Frac Tree 'I e DInertsaannal informa+.son retorted On this drawing are Pct mated nionirernents only. 6.5 0-'5 TN crid 4"1002 ., .. 4"1002 4-1/16` 10000# 4-1/16' 10,000 rn 4!!! !!„1, _ 4' 1502-- 4-1/16- 502-4-1+16. 10,000# 1ytriraaiik MI II. 4-1/16 11,06, # 4-1/16` 10,000# ConocoPhillips CAMERON Drib Site 2S-10K Frac[Yee STEPHEN 12-30-15 N 1162040-t-2 • 0 Wellhead with 10K Frac Tree a'll 6 5 OTt5 , ' , **me tylthrtotoonssotrorawalauliftimarrrotaccoontimmerittflocld e -°,.......-7. rnoisoromentson14. 4. rt:_pil IN JO .... z .4 4 10,02 , ' 4'1002 401111.TA 4-111610,0008 WAL.4-V,M1 wyvir Nuipmirr 4.1/I 6- 10.000 .,.,, 1 401. Ilk .• • .4011 lk ' A t'lli -118111At ‘411'4V11111;11184 ti,t ' - ' .:%.,,t;'; '‘.41,:sa 1 Ii*r ',,,,T/b i I 1111111 124.08' or . ' r Illi me 1 '1'- .,./ 4-Ino.10,0008 x2' 1507 4-1/16* 16118108 I lytirattitx 56,94" -41 ,trt. 184.45" 4-1/161000O „,... ., thleiTOF i 4-1/16* 1080008 * I 4* 11131' to 1 11"SOUOS . I -—ii ii--- 1111 , to 2-1/16'5,0001t 10.19' 1S894. - int t - I - - - I 1111 '--) 1.91.1111 ,i Mel p..., .:1 Aill I II• 11 5.4144 , 1 IL PTO 1 %OR Ho 2-1/16'5,0001 —19.11- iillimil I _ .e. .1,-4 lc ' ....ir 7.29' II IP Top of f.onfikutof Top of 7.12- (.01f/odor to111m I)!hanger NI, .' f (CP1Got I 16. 6.0-ct8AL) 10-3/4 ConocoPhillips 7-5,8" -------4-1/2" (CAMERON .... STEPHEN ...„12-30-15 # 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 76' TVT thick at the heel, with the top of the Kuparuk A at 6,173' TVDSS (9150' MD) and 77' TVT at the toe of the well, with the top Kuparuk A at 6,257' (16,543' MD). 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 (977' MD) and consists of HRZ and Kalubik mudstones. Top HRZ was encountered at 5,854' TVDSS (8,093' 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 6,270' TVDSS at the heel (no MD as the Miluveach interval was not penetrated in the 2S-03 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-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-07: The 7 & 5/8 casing cement pump report on 8/6/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.3 ppg cement, displaced with 10.6 ppg mud. The plug bumped at 1,251 psi and the floats were checked and they held. 2S-02: The 7 & 5/8 casing cement pump report on 7/1/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg cement, displaced with 10.4 ppg LSND. The plug bumped at 1,505psi and the floats were checked and they held. 2S-10: The 7 & 5/8 casing cement pump report on 9/2/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg cement, displaced with 10.5 ppg mud. The plug bumped at 1,450 psi and the floats were checked and they held. 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. KRU 21-10-8: KRU 21-10-8 was plugged and abandoned as per state regulations on 4/28/1989. 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. • S 2S-13 PB1: 2S-13PB1 was plugged and abandoned per state regulations on 12/17/2015 2S-01: The 7-5/8" casing cement report on 1/3/2016 shows that the job was pumped as designed, 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 1,100 psi 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)(11) CPAI has formed the opinion based on seismic, well, and other subsurface information currently available that there are 9 mapped faults that transect the Kuparuk A interval and enter the confining zone within one half mile radius of the wellbore trajectory for 2S-03. One fault intersects the 2S-03 wellbore and terminates within the confining layer. No losses were observed at any of the fault crossings during drilling of the 2S-03 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-03 Fault MD SSTVD Throw Fault#1(A4/A4) 12600 6202 20(DTN) Two mapped faults intersect the offset 2S-10 wellbore in the Kuparuk A sands. Fault#1 terminates in the C35 and Fault#2 terminates within the HRZ. The C35 in this area consists of shales and siltstone lithologies with an estimated fracture pressure of -16ppg. No losses were observed at any faults during drilling of the 2S-10 lateral section. The 2S-10 lateral is greater than 1500' west of the 2S-03 wellbore. 2S-10 Faults MD SSTVD Throw Fault#1 (A4/A5) 9052 6196 15(DTS) Fault#2 (A4/A4) 11635 6227 20(DTN) The effective fracture length is estimated to be 327'. All of the fractures will be longitudinal, running parallel to the 2S-03 wellbore. Distance of the projected fracture wings to the nearest fault that does not intersect the 2S-03 wellbore is approximately 1160' to the west. 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 1:Feb1E ConocoPhillips ADS_, Al _ 1���:aa5, Inc.Inca ' '' N Faust Analysis 0 CAE 03 CAE . Ai Jed i L. '11111111111FIPP- , / 1fi 3 f Y 1 15 i 1 2:r 13 -""fry ; u 2t-14$x. . :S-1Q + 22tot i ,- / f'klib64.- ADLMeal O8 I . ADLo2OO —'Kupartsk PA Boundary • Frac Point _ :' —Fault Within Confining Zone 1 —Active Weil Within Confining Zone I Abandoned Weil Within Confining Zone IWell Within 112 Mi.Radius Well Trajectory 1,2 Mi.Frac Point Radius Q 1/2 Mi.Trajectory Radius ['CPA!Lease • t • _▪ ti Nti . 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The well will be completed with 3.5" tubing and a 4.5" liner with ball actuated sliding sleeves. After the 1st stage we will shift a sleeve to close off that section of the lateral. We will then pump the 2nd stage and drop a ball (progressively getting larger) after each remaining stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. Proposed Procedure: Halliburton Pumping Services: (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 and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 16 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. 20,000 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU HES Frac Equipment. 7. PT Surface lines to 9,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 310 bbl breakdown stage (27# linear gel) according to the attached excel HES pump schedule. Bring pumps up to maximum rate of 25 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule with a maximum expected treating pressure of 4,400 psi. 6 e 4e,df-e,d. 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O aU E C N E O_ � Ca `"� • i :� co = co 0 .= u) 2 > , Ln Lf1 Ln Ln co - -08scoO CDF- ....... LO LD Lip tD O 0 c L_ c � O � C� " � U -0 cn N C 1° . . CCZ �; t- pa) ® u12 0 ,.... .4 Ln Ln Ln W O O .4) C r4 › ,t. mmmrn 4_, 4,... :1=, .... ..z... 0 1._ .,..,• tD kr) tD Li) 0 ca � Cll 0_._ ._ .� � . 43) Z > opc }, o N O O O O i O cn � � -EI -0 0 0 0 0 w � � Lco � coCD O � 'p O p N E — > _c _ — u) -0 O = '- -0 -0 7) Eocpsna) oo U- 0) tits N 0 CO d' N vi 4-a1 m in r-i to 00 r-1 0 • S SECTION 13 — POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through a third party flowback vendor until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to appropriate disposal well until they are clean enough for production.) • • Bettis, Patricia K (DOA) From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Monday, March 07, 2016 10:18 AM To: Bettis, Patricia K (DOA) Subject: FW: KRU 2S-03 (PTD 215-205) Fracture Stimulation Sundry Application Patricia, Let me know if this and the email from Jen Hoyt are sufficient. Thanks, Adam Klem From:Sylte, Hanna Sent: Monday, March 07, 2016 7:24 AM To: Klem, Adam <Adam.Klem@conocophillips.com> Subject: RE: KRU 2S-03 (PTD 215-205) Fracture Stimulation Sundry Application Hi Adam, Below is the information for the AOGCC. 1)Total Depth: 16,760' MD, 6,586'TVD Effective Depth: 16,728' MD, 6,585'TVD Intermediate casing cement top-7,308' MD, surface casing cement top-39.6' MD 2) Final Schematic: 1 a • • �d Ir.,' PROD 2S-03 i e . Conoc Ph hips Well Attributes Max Angle 8 MD TD ,r Alaska,lac. Wellborn APMUWi Plaid dams Wsiltore Status Mot( MD(ttKB) act (ttKB)tonocofha . -peefS3`.C'32't5T28C'. +•.L6Fi•.R,UY{RIVER.UNIT FF..t:7 92 57 6,,,a,::,*77 €£",,60a ... Comment H2SOpen} Date Annotation Eno Date K5:-Gro(Tt) Rig Release Date ?-0 2 ::::....705'<-+S, 39.64 :12:13 Cnnflfatfcn Depth{TtKB} End Date Annotation Last hi-o4 8-g End'Date art Casing Strings ' asrrg Description 81(ut D tin( } Top(TtKeI Sat Depth(ttKEi set Dep4n(T'D} ,WVLeh41...81132 Tc3Tnreaa -tor <.: �k�+4 a4' 2 4 525'' H-�r=a wore:ev'' x•o�ececsfi?mx+ry : asutgDaatxipt34 00(ip K3(ln{ TrrpIftKBJ SatOapdt(itKB) -Set to T TYJ..Wt1Lan$1 Came T p,Thte.38 22.x4 5.953 414 1,t3?.7 3 45.5_ _S� ?.,H Sr"ti -",^-a,,`�` ,e,aoa .a •iw' ;. CasIrg Description { ) 1D{art} Ttp{itKBp tD to{'ikKB( Set Depot IT 1114 . .vinscz(a., Gra311 TO Ttire3'J' i ; :term afi;?t_ .755'8 a.$7.^, 25.1 E�_.S 25 v i s•: Hoa 563 CasingDaa ription OO(in} ID On) Top(ttKS} eat Depth(TtKB} Sat Dept/(P12I ',Alen( T T re e,wtaec-is ua73.1.r`- L.,s7 41,2 3.5.2 5,6552': 3.728.7 3,45x. ..3: --- 533 Liner Details tae:e^ea;34244 MM.: Nc21:22 IG Tap ittKeI T9p TOIHtIKBl Top In {'t tternDes cam. ON8.572 6 6,136; 71.06 N p k(P.5) ?a4 ,. ,_'iso d,; _. t 7#L-204.240 4y'2563 r x Mil,Ift, ..<57ro 202 7 73.11 Ha ry'rer itr r x a,. __ L _ F'.'_ 4.300 Hy:, aaa,,,vw s.ata.a 3,3E:3.2 6,212.6 73.15 XC R acrrg - H .=rx x 5 50 452'o:-.): 4.420 0.44: =:--Sn:ee-acs:a,iea.s 2.•,33.5 6.215.'3 73.2' E Dore _ 32-40 5 Hyo 52' ,,:x 4:6' 3.990 Extension -ty:__ __ _=':r xoTnrcecs 1.1151s 8,2.'8 6.3.4.3.4 79.51 Swell Packer .a _.a. SN: 5:494-33'-44 3.859 =ecw:;rwc€s.,a Sie0 if za 7,114,asrs7 ' 6,432 1 6.3x+3.6 52.19 ;RAC =_ _ _ (2.5'Sea,0tit w1 2.443 SiseverPoTt 2. :411'.':E.' 12205.2: 5.254.0 38.75 FRAC - ao-5-(24.,E 2a;.Dot'orf 2.335 Sleeve:Port 2.2.75-i RN 437:35 :.OKoa-+' 241 t--__. 4 . Lov :erzb1,---ri. '.. 13462 8 6.'x+2' 87.42 S'atetPasker Ea:✓_ _",a:'Ra: _"-,•H., SN 5%'434C2'.-48 3.953 10.735.2 3375.7 2•:'•.53 FRAC Ea..st 4 _ _d=R3 it.37e ?_ti.Dtet^0101 2.323 Sieave Ort 2.._. 1- i 11,532.6 s_33,7 89,25 r=RAC Ea4 - __=.'1 ',..:.313'Sail,Draf3'sr. 2.260 caaver'Port 22 r RN'_4_. „3 . al ___3 __4.3 8x.39 SNajPaola: Baker "Save-IR__,_ ,3' SN 52:~45#-L5°-20 3.958 •y q t '2'247 53:3.4 87.22 -RAC Baks,4-1.t'P.,-ac.9 save#5 .25"Batt Drift.w. 2.158 Saxe EMI'3,7'a-4 .1M1 6-aava<Port 2.1E31 RN 13437022 ..s�;ac ..•+.:`.3 6403.2 972 ..r_:Packer Bak.,: ..rrat!Pa_._ ..?J 5e:433-0:1-37 8.8.2E _ti r'. '2.224.2 22,395. 21 52 PRA.; Baker 4-1 F.Te: �aave#5-'2`33'Bag,Off,.vwF x.135 yii, eeverPoot 2,1251 PN'5437021 13 162.7 6.253 5 ._._1• _2223!Packet Bake -- udve,Pa_ 2 S'J.53424-201-42 3.955 13542.6. 6,4:1,1 s3,33 =.R;A:C 6aka-4-'1'Fra=Sleeve#4 i1�2.,`Eat.Dr fl w,' 2.073 _eeveraPon 2.,:s2.1 RN,12437070 rill't '3,919.3 5,403.3 60'_: Swat:Pa:k=_r Baker-"SweaRacke''-''D" SN.50464-00°-22 3.953 iffil '4:3:3.4 3413.9 37.4 EaKat'4li'Frac -r3 ,2__3 Ea fl.D^°f:dv, 2.0110 a e,F oc 2071P1445V1-9 _ 14.433.3 6.,425.3 2.S.32 EweliPac a r Cakan .,v-.. __,_r ,. SN: 50494-001.4 3.958 IIIII', 152,'64.3 22;431.3 85.3' FRAC ,-4 . a ' :E� e2_.e f2 Sayom ,D .v/11,6331 1.946 Sok. S!e ae"Port PN.41104:x•:+417 5,433,1, 6,436:3 39.67 Swat Pecker Cake'-"SesgPa.6:ee .?,. EN:5C454 3271-:35 3.953 I 10 ,32.3.3 2,437:: 36,33 ;RAC Ea a;1'Fr,. _.•a#t 1,2336a=1,Drt'aa 1.865 Save/Port `7.'375•PN 43' -3473. 16.'653 3,443,2 2.:.25 Ewe,Packet. Sake, Ewe.i=,:3_{_,•A" SN:: 5:454-0:1-'- 3.558 11 141 'S 522,4 6,4626 24:36 7 r___'save Esker 4 1,Z A,''a Sraeoe2N 194E7899 300,0 16,595 9 6.463.3 54.47 ___L.:_. Eake,4-1,'Z'NettootelsoltOr:VaNet,W1Vt-N 1'@43546 Tubing Strings ak IN Tut mg Des^.dtp3Cn string ma...ID 01.1 Top(111K1) Sat Depth.(TI Yat Depth(7121 i.,.µ'1t iit1Tt( Grape Top Connection ,, r _._.:_ 777_ 2.592 2.7= 3.75._ 227071 "'✓L-33 :UE S- 1 Completion Details 1 Nansat3 10 IliI. Top11tK8} Tcp(T'/DI{itKBJ Tapst8(9 lternDes ..a ,_ Cot- vin) `9 7 27.3 Bb Harr o Ha 3. 1 8543.5 6,169.5 72.36;Gaau+ge,Ptrolp . _ _J E IR X P 2.913 ...,�. Samos £,596.1 6.185.3 72.69 Nipple-DB. 0 :: 323 ::o- 5 -- ,. =-i2.PL1 to4y{;?=deli. 2.212 XN,DS,D 3,648.1 6,2337 72'996Locator Sager 7.625'x 3,5 _ _ e ...8:NC-SS Sat-- 3.010 Large CD -. 8,349,1 6,201..0 72.84 Locator Baker 7.225'x 3.o'S._8" «r CCS 163-305110-- 3.010 11013OD 8,714.0 6.219.8 73.48 #.tie Shoe 144T3shoe a"2283 3.063 i 4 Mandrel Inserts st att Cl TOS IPA)} jag Laton Port Size TRO 111111 N 703(088! (nKB} Make Model OD Intl Seiv Type Type MI) (pet) Ra11034 Coon t 3,:•34.9 3.5£2.3 Cam co SN224A 1 t14SLiFT D.nm Eo2 229,3016 2 From: Klem, Adam • • Sent: Friday, March 04, 2016 11:29 AM To:Sylte, Hanna <Hanna.Sylte@conocophillips.com>; Hoyt,Jennifer N <Jennifer.N.Hoyt@conocophillips.com>; Bottrell, Phil M <Phil.M.Bottrell@conocophillips.com> Subject: FW: KRU 2S-03 (PTD 215-205) Fracture Stimulation Sundry Application Hanna, can you answer#1 &2? Jen/Phil, can you answer#3 &4? From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday, March 04, 2016 11:19 AM To: Klem, Adam <Adam.Klem@conocophillips.com> Subject: [EXTERNAL]KRU 2S-03 (PTD 215-205) Fracture Stimulation Sundry Application Good morning Adam: Please provide the following information for the KRU 2S-03 fracture stimulation sundry application: 1. Form 10-403, Box 11,total depth, both measured depth and true vertical depth; and effective depth, both measured depth and true vertical depth. 2. Final wellbore schematic with actual packer depths, casing info, and tops of cement. 3. Discussion of any losses observed while drilling KRU 2S-03. 4. Actual tops for HRZ, Kalubik, and Kuparuk A. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 3 • • Bettis, Patricia K (DOA) From: Hoyt,Jennifer N <Jennifer.N.Hoyt@conocophillips.com> Sent: Monday, March 07, 2016 10:06 AM To: Klem, Adam; Sylte, Hanna; Bottrell, Phil M; Bettis, Patricia K (DOA) Subject: RE: KRU 2S-03 (PTD 215-205) Fracture Stimulation Sundry Application #3—There were no significant losses in the production section. #4—HRZ—8093' MD, 5854' TVDss; Kalubik—8430' MD, 5973'TVDss; Kuparuk A—9151' MD, 6174'TVDss Jennifer Hoyt 907-265-6156 From: Klem, Adam Sent: Friday, March 04, 2016 11:29 AM To: Sylte, Hanna <Hanna.Sylte@conocophillips.com>; Hoyt,Jennifer N<Jennifer.N.Hoyt@conocophillips.com>; Bottrell, Phil M <Phil.M.Bottrell@conocophillips.com> Subject: FW: KRU 2S-03 (PTD 215-205) Fracture Stimulation Sundry Application Hanna, can you answer#1 &2? Jen/Phil, can you answer#3 &4? From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday, March 04, 2016 11:19 AM To: Klem, Adam <Adam.Klem@conocophillips.com> Subject: [EXTERNAL]KRU 2S-03 (PTD 215-205) Fracture Stimulation Sundry Application Good morning Adam: Please provide the following information for the KRU 2S-03 fracture stimulation sundry application: 1. Form 10-403, Box 11, total depth, both measured depth and true vertical depth; and effective depth, both measured depth and true vertical depth. 2. Final wellbore schematic with actual packer depths, casing info, and tops of cement. 3. Discussion of any losses observed while drilling KRU 2S-03. 4. Actual tops for HRZ, Kalubik, and Kuparuk A. 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If this open hole sidetrack is unsuccessful, please notify the AOGCC of the plan forward. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a)alaska.cQov 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.Loepp@alaska.gov From: Callahan, Mike S [mailto:Mike.Callahan@conocophillips.com] Sent: Friday, February 19, 2016 10:46 AM To: Loepp, Victoria T(DOA) Subject: PTD #215-205 2S-03 Open Hole Sidetrack Plan Victoria,as discussed on the phone,we drilled out of zone unintentionally in our production lateral on 2S-03. We crossed an unexpected fault at 12,590'with an estimated throw of 15-20 feet. At the time we believed it had put us above the A4 target zone in the lower A5, but after drilling down for—30'TVD, we now believe we were actually below the pay in the lower A4. We drilled to a total depth of 13,728' MD, attempting to find the target sand and then turn up to get back into it once we realized we were below instead of above. We made the decision that the out of zone time was going to be too long,so we need to pull back above where we went out of zone for an open hole sidetrack. The best kickoff point we have is back at 10,670' MD, which is where we would like to try to sidetrack with the current BHA in the hole. If we are successful,we will continue drilling to TD without tripping out of hole, paralleling the original wellbore"'100'to the east to the original planned TD of 16,543' MD. If we are unable to sidetrack with the current BHA,we will have to trip out to either set a cement kickoff plug, or pick up a BHA with a motor to give a better chance of sidetracking. Please let me know if you would like any more information, and if an amended PTD or any other form of documentation is required. 1 • i Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907)263-4180 Cell: (907)231-2176 2 P�OF 771, fps • • �7,; THE STATE Alaska Oil and Gas � ofALAS KJ\ Conservation Commission 1 441V-1:==-_--f---f 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 of ALAE' 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-03 ConocoPhillips Alaska, Inc. Permit No: 215-205 Surface Location: 3024' FNL, 1320' FEL, Sec. 17,T1ON,RO8E,UM Bottomhole Location: 1994' FNL,4514' FEL, Sec. 28, T1ON, RO8E,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, Cathy '. Foerster / Chair [ DATED this day of December,2015. RECEIVED • STATE OF ALASKA • NOV 2 4 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL AO CC 20 AAC 25.005 la.Type of Work: 1 b.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp 0 1c.Specify if well is proposed for: Drill a Lateral ❑ Stratigraphic Test ❑ Development-Oil ❑' -Service- Winj ❑ Single Zone Q- Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket O • Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska,Inc. + Bond No. 59-52-180 • KRU 2S-03 - 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 16,543 * TVD: ‘ 6,440 Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 3024'FNL, 1320'FEL, Sec 17, T 10N,R008E,UM ADL 25604,25607,25603 Kuparuk River Oil Pool. Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 535'FNL,2723'FEL,Sec 21,T1ON,R008E,UM 2677,2678 1/4/2016 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1994'FNL, 4514'FEL, Sec 28,T1ON,R008E,UM . 2560;2560;2512 766'to ADL025608 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- 481250 y- 5930023 Zone- 4 - GL Elevation above MSL(ft): 120 + to Same Pool: 1,725'to 2S-02 16.Deviated wells: Kickoff depth: . 350 feet 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: - 90 degrees Downhole: 3826 + Surface: 3189 ' 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 78' 39.5' 39.5' 118' 118' pre-driven 13.5" 10.75" 45.5# L-80 Hydril 563 2819' 39.5' 39.5' 2859' 2662' 1211 sx DeepCRETE,194sx DeepCRETE 9.875" 7.625" 29.7# L-80 Hydril 563 8995' 39.5' 39.5' 9035' 6290' 737 sx GasBLOK,205 sx GasBLOK 6.75" 4.5" 12.6# L-80 IBTM 7658 8885' 6255' 16543' 6440' N/A 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 R/ Time v.Depth Plot ❑ Shallow Hazard Analysis[ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 20 AAC 25.050 requirements[ 21. Verbal Approval: Commission Representative: Date 22.I hereby certify that the foregoing is true and the procedure approved herein will not be Mike Callahan @ 263-4180 deviated from without prior written approval. Contact mike.callahan ci.cop.com Email Printed Name G.L.Alvord L Title Alaska Drilling Manager Signature ` (\��/. �1 cat 6.1. 4LU 265-6120 Date I, , 4 I Zb! 5 V Commission Use Only Permit to Drill ..-- API Number: Permit Approval See cover letter for other Number: 0/I S-t� o5 50- i 03- 020-?,23 -Dv-0:3 Date: 1 aI Nil, 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 shat[ Other: B&A f CS f to 35 D O p5.7qq Samples req'd: Yes, No WI Mud log req'd:2 ix II rt r5 c/1 R r pre VCr7 IT,- '7-e"5f to ZSUOpS K-/ H25 measures: Yes No❑ Directional svy req'd: 0 Spacing✓ exception req'd: Yes❑ NoL ' Inclination-only svy req'd:D 210. Post initial injection MIT req'd:LI APPROVED BY / _/ / Approved by: ("- �l COMMISSIONER THE COMMISSION Date: `� -/ 4-/,.S vTL Z/6/' ? 1113°1/S- , e� Submit Form and Form 10-401(Revised 11/2015) Q1R?rIflGvfliI( Am4ns from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate • i Application for Permit to Drill,Well 2S-03 Saved:24-Nov-15 Post Office Box 100360 Anchorage,Alaska9510-0360 Phone 907263-4180novo l l i ps Email: mike.callahan(Wconocophillips.com November 24,2015 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill Well 2S-03,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 4,2015.It is planned to use rig Doyon 25. 2S-03 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+/-2,858'MD/2,662'TVD. The intermediate section will be drilled with 9-7/8"x 11"bit/Under Reamer and run 7-5/8"casing to 9,035'MD/6,290'TVD.The production hole will be drilled with 6-3/4"bit and run 4- 1/2"slotted liner to+/- 16,543'MD/6,440'TVD.The upper completion will be run with 3-1/2"tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005(a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold 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 Mike Callahan at 263-4180 (mike.callahanAconocophillips.com)or Chip Alvord at 265-6120. Sincere � � tAcc>ttkA ,,R :�;t' cart &: Chip Alvord Drilling Manager • • Application for Permit to Drill Document Drilling .&Wells Kuparuk Well 2S-03 ConocoPhi°i.. Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 2S-03 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 identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 3024'FNL, 1320'FEL, Sec 17, T 10N,R008E,UM NGS Coordinates RKB Elevation 159.5'AMSL Northings: 5,930,023.62' Eastings: 481,250.32' Pad Elevation 120'AMSL Location at Top of 535'FNL,2723'FEL,Sec 21,T1ON,R008E,UM Productive Interval (Kuparuk A4 Sand) NGS Coordinates Measured Depth,RKB: 9,548' Northings: 5,927,224.77' Eastings: 485,128.04 Total Vertical Depth,RKB: 6,370' Total Vertical Depth, SS: 6,210' Location at Total Depth 1994'FNL, 4514'FEL, Sec 28,T1ON,R008E,UM NGS Coordinates Measured Depth,RKB: 16,543' Northings: 5,920,489.59' Eastings: 483,340.60' Total Vertical Depth, RKB: 6,440' Total Vertical Depth, SS: 6,280' 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. • S 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 (MPSP)while drilling 2S-03 is calculated using an estimated maximum reservoir pressure of 3,826 psi (11.6 ppg, based on 2S-02 development well), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A4 sand at 6,370' TVD (WP09): A Sand Estimated. BHP = 3,826 psi A Sand estimated depth (WP09) = 6,370' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 637 psi (6,370' TVD * 0.10 psi/ft) MPSP =BHP—gas column =3,189 psi (3,826 psi—637psi) (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-03 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 25.0300; A procedure is on file with the commission for performing LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill 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 MC 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) ��) (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program 16 24 62.5 H-40 Welded 78 Surf 118/118 Existing • HydraCement to Surface with 10-3/4 13-1/2 45.5 L-80 563 2819 Surf 2,859/2,662 1,211 sx DeepCRETE Lead 11.0 ppg, 194 sx DeepCRETE Tail Slurry 12.0 ppg Stage 1: 737 sx Class G+GASBLOK at 9-7/8 Hydril 15.8 ppg w/TOC at 7,280 MD 7-5/8 X 29.7 L-80 8,995 Surf 9,035/6,290 Stage 2: 205 sx Class G+GASBLOK at 11 563 15.8 ppg w/TOC at 5,622'MD 4 1/2 6-3/4 11.6 L-80 IBTM 7,658 8,885/6,255 16,543/6,440 Uncemented Liner with Frac Sleeves 2S-03_wp09 Cementing Schematic 411J 16" Conductor to 118' 10-314"45.5# L-80 HYD563 hi, 2.859MD/2,667 TVD c 32'inc. 9-718"x lr Hole Top of 2rd Stage Cement 5,622' MD/4,532'TVD C-37 6,127 MD 14.850 TVD Top of 1 Stage Cement{top Cairn) 7,280'MD15,560'TVD Kalubik 7-5/8" 29.7#1-80 HYD563 Casing 8,450' MD 16,120'TVD .11 9.035 MDI 6,290'TVD 78' Kuparuk A4 9,548' PAD 6370'TVD 6-3/4" Hole 4-112" Liner 11.6# 180 181 16,543' MD! 6.440'TVD c 88' • 10-3/4"Surface casing run to 2,859'MD/2,662'TVD Cement from 2859' MD to 2359'(500'of tail)with DeepCrete.@ 12 ppg,and from 2359'to surface with 11 ppg DeepCrete.Assume 250%excess annular volume in permafrost and 50%excess below the permafrost(1400'MD),zero excess in 16"conductor. Lead slurry from 2,359' MD to surface with Arctic Lite Crete @ 11 ppg Conductor (115'—0')X 1.339 ft3/ft X 1.0(0%excess) = 154 ft3 Permafrost to Conductor (1,400'—115') X 0.3637 ft3/ft X 3.5(250%excess)= 1,636 ft3 Top of Tail to Permafrost (2,359—1,400')X 0.3637 ft3/ft X 1.5(50%excess) =523 ft3 Total Volume= 154+ 1,636+523=2,313 ft3=> 1,211 sx of 11 ppg DeepCrete @ 1.91 ft3lsk Tail slurry from 2,859' MD to 2,359' MD with 12 ppg DeepCrete Shoe to Top of Tail (2,859—2,359')X 0.3637 ft3/ft X 1.50(50%excess) =273 ft3 Shoe Joint (80')X 0.5400 ft3/ft X 1.0(0%excess) =43 ft3 Total Volume=273+43=316 ft3=> 194 sx of 12 ppg DeepCrete @ 1.63 ft3/sk 7-5/8"Intermediate casing run to 9,035'MD/6,290'TVD 1st stage slurry designed to be at the top of Bermuda/Cairn Formation at 7,280'MD.Top of 2nd stage slurry is designed to be at 5,622' MD,which is 500' above the C-37.Assume 40%excess annular volume. 1st Stage slurry from 9,035'MD to 7,280'MD with 15.8ppg Class G+additives Shoe to Top of Cement (9,035'—7,280')X 0.3428 ft3/ft X 1.40(40%excess) =842 ft3 Shoe Joint (80')X 0.2578 ft3/ft X 1.0(0%excess) =21 ft3 Total Volume=842+21 =863 ft3=>737 sx of 15.8 ppg Class G+GasBLOK @ 1.17 ft3/sk 2"d Stage slurry from 6,122' MD to 5,622' MD with 15.8ppg Class G+additives Stage Collar to Top of Cement (6,122'—5,622')X 0.3428 ft3/ft X 1.40(40%excess) =240 ft3 Total Volume=240 ft3=>205sx 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 AAC 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 MC 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 9.6-10.5 10.5-11.5 J 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 • S 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+/-2,859 MD/2,662'TVD as per directional plan (wp09). 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 of cement from annulus for sealant job(post rig.) 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 psi) high and 250 psi low. Notify AOGCC 24 hrs before test. / 6. PU 9-7/8"PDC bit and directional drilling assembly,with MWD/LWD(Gamma,resistivity). RIH and clean out to 100'above shoe. Test surface casing to 3500 psi for 30 minutes. 7. Drill out shoe track and 20'of new hole. Perform leak off test to a minimum of 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 C-37 at 6,122'MD/4,850 TVD. Install RCD bearing at this time for use of MPD if necessary. 9. Directionally drill to intermediate TD of 9,035'MD/6,290'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. Lay down intermediate BHA and rack back 5"DP 12. Run 7-5/8",29.7#L80,Hydril 563 casing from surface to TD at 9,035'MD. 13. Pump two stage cement job as per Schlumberger proposal. Top of first stage to be 7,280'MD(top of Cairn formation),top of second stage to be 5,622'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) 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 through the Kuparuk A4 sand to TD 16,543'MD as per directional plan(wp09). 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 8,885'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 • i 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 DS 1B). All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well,or stored,tested for hazardous substances,and(if free of hazardous substances)used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Well Schematic Attachment 2 Diverter Layout Diagram Attachment 3 Directional Plan Attachment 4 Drilling Hazards Summary • 0 2S-03 ConocoPhillips Grassroots Horizontal A-Sand Producer Proposed Wellbore Schematic(wp09) `CAMERON Last Edited: ,w' 4-'/="tree,top joint is4-/ 12.642IBTM Callahan 11-18-15 .m atS• . 16"Conductor to-118' a :,; ' 1 GL 13.5" Surface Hole • • -t } West Sak Sand ,W k GL 3-1/2"x 1-1/2"Camco MMG GLM Surface Casing(-50'TVD below W Sak) 10-3/4"45.5#L-80 Hydril 563 2,859'MD/2,661'TVD(32° INC) 9-7/8" x 11" Intermediate Hole Tubing: 3-1/2" 9.3#L-80 EUE 8RD-MOD GL GLM w/SOV 2ntl Stage TOC= 500'MD above C-37 Formation at 5,622'MD/4,532'TVD f'..*,' ted a dei 11111 1 11 ___------ Weatherford Stage Collar:6,122'MD C-37:6,122 MD 14,850'TVD ler l ebe 5418'MD/5,040'TVD 1'Stage TOC: Top of Bermuda/Cairn formation) , Grow „•- �, +,. Baker 2.812^cntu Sliding Sleeve Cairn:7,270'MD/5,560'TVD 3-''/:"x 7-5/8",Premier Packer Bermuda:7,415'MD/5,640'TVD --.• 31/2"2.813"XN Nipple '>k HRZ:8,260'MD/6,040'TVD et 9L8 DHG 4. 6.376"x 4-%"Swell Packer 4,y� ���t , '? / I. iff Kuparuk C:9,304'MO/6,340'TVD `' Kuparuk A4:9,574'MDI 6,372'ND-11.5 ppg Z '•1. ■ a���_�aw Sino Bunel� 0 7-5/8"x 4-%"Baker ZXP ,° "O Packer/Flex Lock Liner ° III III III I. 1111 ■ ■ w;v°�a urn, I' Hanger iea:e jr; i2 TD:16,543'MD/6,440'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 9,035'MD/6,290'TVD(78° INC) 16,543'MD/6,440'TVD 0 S i go c z V o Cm N N N r A D N m w m N U -1 IN m II' o n -0 < No r' I— _ O O • o I- I— Z < < o m r^ g g O I I- :A o pF < I x Pr ..A N ` 9 m :- O 1 = v o ❑ .' O m. 0— — 10111 ism o0 o ❑ y oo CD -- © o , — O El " I I3 Ist, ---< ir 0 y `� o 8 � m 0 , `. r L-- k _ Q D �( ' q \ ',' vi �" I g Do 0 3 \ l) ❑e r N \iiiiih, 11 I n LI m DI1 1 0 FI 1 ac ►. cn w � ii4 o O �— D C tl D Z N G7 O_ to --< T T T T T T � m 2S-03wp09[Bamboo] 6.876 Plan Summary �O v� OOU 5 �� 0001 >.5- A4 ..,'11;401W.--' 7-5/8"X 9-7/8'I ..‘' - a) ..,.__.. -,, ,.., i'z ,.....04911 1 000 rn 0 I ( I I I 1 I ( I I I I . , l 0 0 4000 8000 12000 16000 Measured Depth 4-1/2'x 6-3/4'I o Geodetic Datum: North American Datum 19831003/4"x 13-1/2I' `' Depth Reference: Plan:120+39.5 @ 159.50usft(Doyon25) \ U�,.r NVO Rig: Doyon25 \ Q s, 0 2�° o r` u) '00 csi - - 'it, oO 75/8X 97/8 14-1/2"x 6-3/4'1 __--3/4'I - o 00 .1. pp00° m o 0 0 ° 0 0 0 01 La _ u1 tali oow o CM 2 m a ,10d `,2 \-\\ I ( I I 1 i I I I I I I I I I I I I 1 I I I l I 40 350 0 1500 3000 4500 6000 7500 9000 10500 12000 13500 0 350 "" 540 Horizontal Departure sao - 7ao 33030- , . 740 - 930 ® ........ __.®® ® �r 920 - 1320 ,//.•' p //i• }; 1120 1320 m 60 300 I/: - 60 1320 - 1510 o. .1-\` \ ._. I /� :, ,. 510 - 1700 (0 \ `, 2S-02. . __.I �+ i - noo - 2310 E.' ` `\ ‘ 2$-0' 2310 2930 `\ 2930 - 3540 U30 r , O I 2S 04'B1 270 90 3540 - 4150 • 4150 '- 4760 N > ] `r 25-U't' -- -- IT\ +'• 4780 - 5370 2S- MakO - g o 5wp08.1 urse] .+ 5370 -" 5990 0 �? 5990 6600 !♦ mit. 6600 - 7840 ,,�: -c.'' 7840 - 9090 0 2000 4000 6000 8000 10000 12000 zoo `.,' 120I. SURVEY PROGRAM ��de i1 rI ,;y.,,. 9090 - 10330 Surface Location : �'���� 10330 - 11570 Depth From Depth To Survey/Plan Tool bri'oe t #'' 39.50 650.00 2S-03wp09[Bamboo](Plan 2S-03) GYD-GC-SS Pad Elevation: 120.00 210 ra.;,. 't';: 11570 12820 650.00 1650.00 2S-03wp09[Bamboo](Plan 2S-03) MWD iii,,,z,„,„ 12820 14060 650.00 2858.71 2S-03wp09[Bamboo](Plan 2S-03yVD+IFR-AK-CAZ-SC 180 14060 15300 2858.71 4358.71 2S-03wp09[Bamboo](Plan 2S-03) MWD CASING DETAILS 15300 - 16543 2858.71 9035.22 2S-03wp09[Bamboo](Plan 2S-03yVD+IFR-AK-CAZ-SC 9035.22 10535.22 25-03wp09[Bamboo](Plan 2S-03) MWD TVD MD Name M 9035.22 16543.33 25-03wp09[Bamboo](Plan 2S-03WD+IFR-AK-CAZ-SC 2661.50 2858.71 10-3/4"x 13-1/2" Magnetic Model: BGGM2015 T 6289.50 6543.33 7-5/8"X 9-7/8" MagneticModel Date: 01-Feb-16 - 6439.50 16543.33 4-1 1/2/2"x 6-3/4" Magnetic18 Declination: 18.37°' To convert a Magnetic Direction to a True Direction,Add 18.37°East SECTION DETAILS 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 2 350.00 0.00 0.00 350.00 0.00 0.00 0.00 0.00 0.00 KOP:Start 1.5°/100'DLS,20°TF,for 250.18' 3 600.18 3.75 20.00 600.00 7.70 2.80 1.50 20.00 -8.16 Start 2.5°/100'DLS,0°TF,for 905.86' 4 1506.04 26.40 20.00 1469.00 227.66 82.86 2.50 0.00 -241.35 Hold for 111.64' 5 1617.68 26.40 20.00 1569.00 274.31 99.84 0.00 0.00 -280.80 Start 3.5°/100'DLS,110.09°TF,for 874.02' 6 2491.70 31.92 84.68 2350.00 483.32 403.62 3.50 110.09 -571.32 Hold for 353.45' 7 2845.15 31.92 84.68 2650.00 500.66 589.69 0.00 0.00 -636.23 Start 2.5°/100'DLS,53.45°TF,for 1001.84' 8 3846.99 50.53 110.81 3405.65 386.01 1225.03 2.50 53.45 -689.92 Hold for 2394.9' 9 6241.89 50.53 110.81 4927.97 -270.90 2953.20 0.00 0.00 -502.68 Start 2.5°/100'DLS,89.71°TF,for 2793.33' 10 9035.22 77.56 184.81 6289.50 -2266.44 3976.62 2.50 89.71 1159.99 Hold for 20' 11 9055.22 77.56 184.81 6293.81 -2285.90 3974.98 0.00 0.00 1179.21 Start 2.5°/100'DLS,55.2°TF,for 344.44' 12 9399.66 82.56 191.93 6353.33 -2621.20 3925.48 2.50 55.20 1515.89 Hold for 4.59' 13 9404.24 82.56 191.93 6353.92 -2625.64 3924.54 0.00 0.00 1520.43 Start 2.577100'DLS,48.72°TF,for 143.73' 14 9547.98 85.00 194.72 6369.50 -2764.66 3891.61 2.57 48.72 1663.23 2S-Bamboo 1.Heel Start 4°/100'DLS,0'TF,for 116.58' 15 9664.56 89.66 194.72 6374.93 -287727 3862.03 4.00 0.00 1779.66 Hold for 5884.24' 16 15548.80 89.68 194.72 6409.50 -8568.39 2367.32 0.00 0.00 7663.72 2S-Bamboo 2.Toe Start 1°/1 00'DLS,179.82°TF,for 150.6' A4 17 15699.40 88.16 194.72 6412.36 -8714.02 2329.07 1.00 179.82 7814.29 Hold for 843.94' 18 16543.33 88.16 194.72 6439.50 -9529.83 2114.73 0.00 0.00 8657.77 2S-Bamboo 3.TD TD:16543.33'MD,6439.5'TVD Permit Pack 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. Prepared by: Checked by: Accepted by: Approved by: Vinent Osara Nate Beck Ifeanyi Ifesie • • co o cr. cn Nlorthin (4500 usftlin) 0 0 ,� N M N 7 \NN 'V - C7 9 co _ CO CA N0 — N N CO r Cfl V _ M _ O O O N- ` N _ 00 C7 C.9 Y - CN N N - 4, — Lo n d o `o O O o 0 . N o n Y N N N O 3 N J N N - N N - ca n-5,,3 / O 6:: v O N _ 4. = Y N T N NE _ . (NJ N F- 1 N O J 4. ....YO N V .� "' N Q Q N 01 It �C N II N M Q M D ' . -(iL Y - 7 O ' MIli N N — J N N co V = - 1 Q r N N N N = MM O N — 1 N N Y N 727 N O O (n CO l= :. N 1- O J �, 1 O (6 m N N CANCSJ '�. ,'` O 00 Cti o 1 o N 3 3 - _ c N o 3 N q o C Z .� to C7 N Y N U) - -e CU i O m _O Lo o 01 _ ' Oi • •co NO co Cin n ii _ r.. r, 0 d d O 1�.. O N W = N tt7 J N F N ry i w Z W •c N C� V N '� `111 Y O(n {tel N N M • i \ N /(g (r N N = 1i, 1 Lt_ Uti L\\ a .- I \ M \ C co _-;`\ a L®d 42 Q (C;\)1 ��. � � car coo. J �N D . O 3N CO ea it 3 00 0 co co -47 w? co0 . N N O.. ON J i M to J N pq J . S G7 0_ N ,• J 1 a �� N N q OCO �7 4. M C- J M 0 CO- N Q. 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N ti ina V d a) 0 tn _OOOti6 - ,;___,_ O , O .,_ (,)O 000EL 0 0 L. 006 o �- o ° —LU 0 OOOZL o LU rn Co Q 0°°00:0°0°°0:c1.661.'' 001 O 0 _o t, O U co Q) �� Cl) O 0000 L `z U p L Q / QEQQ6 Lo ' r, , as 00r- Ca 0 0 o 0 00 ° 9, X o O -o �� o ° ° o 0 0 c:, c'el cs) o ri O N MMM d r N O O M =>< OM 1 0 N o O o 0 0 0 0 Lo o o o 7 co 0 ti (ui/T}sn 0090 gTdaa lea!TJeA en-11 • • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-03 Plan: 2S-03 Plan: 2S-03wp09[Bamboo] Report Permit Pack 11 November, 2015 410 • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-03 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-03 North Reference: True Wellbore: Plan:2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03wp09[Bamboo] 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-03 Well Position +N/-S usft Northing: usft Latitude: +EI-W usft Easting: usfi Longitude: Position Uncertainty usft Wellhead Elevation: usfi Ground Level: 120.00 usft Wellbore Plan:2S-03 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2015 2/1/2016 18.37 80.86 57,485 Design 2S-03wp09[Bamboo] 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 0.00 195.00 Survey Tool Program Date 11/11/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 39.50 650.00 2S-03wp09[Bamboo (Plan:2S-03) GYD-GC-SS Gyrodata gyro single shots 650.00 1,650.00 2S-03wp09[Bamboo (Plan:2S-03) MWD MWD-Standard 650.00 2,858.71 2S-03wp09[Bamboo (Plan:2S-03) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,858.71 4,358.71 2S-03wp09[Bamboo (Plan:2S-03) MWD MWD-Standard 2,858.71 9,035.22 25-03wp09[Bamboo (Plan:2S-03) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9,035.22 10,535.22 2S-03wp09[Bamboo (Plan:2S-03) MWD MWD-Standard 9,035.22 16,543.33 2S-03wp09[Bamboo (Plan:2S-03) 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 0.04 200.00 0.00 0.00 200.00 40.50 0.00 0.00 0.19 300.00 0.00 0.00 300.00 140.50 0.00 0.00 0.33 350.00 0.00 0.00 350.00 190.50 0.00 0.00 0.41 KOP:Start 1.5°/100'DLS,20°TF,for 250.18' 400.00 0.75 20.00 400.00 240.50 1.50 20.00 0.48 11/11/2015 10:35:08AM Page 2 COMPASS 5000.1 Build 74 • Schlumberger • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-03 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-03 North Reference: True Wellbore: Plan:2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03wp09[Bambool Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (°) (usft) 500.00 2.25 20.00 499.96 340.46 1.50 0.00 0.62 600.00 3.75 20.00 599.82 440.32 1.50 0.00 0.76 600.18 3.75 20.00 600.00 440.50 1.50 0.00 0.76 Start 2.5°/100'DLS,0°TF,for 905.86' 700.00 6.25 20.00 699.43 539.93 2.50 0.00 0.84 800.00 8.75 20.00 798.57 639.07 2.50 0.00 0.89 900.00 11.25 20.00 897.04 737.54 2.50 0.00 1.02 1,000.00 13.75 20.00 994.67 835.17 2.50 0.00 1.23 1,100.00 16.25 20.00 1,091.25 931.75 2.50 0.00 1.54 1,200.00 18.75 20.00 1,186.62 1,027.12 2.50 0.00 1.93 1,300.00 21.25 20.00 1,280.58 1,121.08 2.50 0.00 2.39 1,400.00 23.75 20.00 1,372.96 1,213.46 2.50 0.00 2.92 1,500.00 26.25 20.00 1,463.59 1,304.09 2.50 0.00 3.52 1,506.04 26.40 20.00 1,469.00 1,309.50 2.50 0.00 3.56 Hold for 111.64' 1,600.00 26.40 20.00 1,553.16 1,393.66 0.00 0.00 4.16 1,617.68 26.40 20.00 1,569.00 1,409.50 0.00 0.00 4.27 Start 3.5°/100'DLS,110.09°TF,for 874.02' 1,700.00 25.54 26.29 1,643.02 1,483.52 3.50 110.09 2.10 1,800.00 24.89 34.36 1,733.52 1,574.02 3.50 104.44 2.19 1,900.00 24.68 42.70 1,824.33 1,664.83 3.50 97.13 2.28 2,000.00 24.94 51.03 1,915.13 1,755.63 3.50 89.55 2.37 2,100.00 25.65 59.06 2,005.57 1,846.07 3.50 82.00 2.47 2,200.00 26.77 66.57 2,095.31 1,935.81 3.50 74.73 2.59 2,300.00 28.25 73.44 2,184.03 2,024.53 3.50 67.99 2.73 2,400.00 30.05 79.61 2,271.38 2,111.88 3.50 61.90 2.89 2,491.70 31.92 84.68 2,350.00 2,190.50 3.50 56.50 3.07 Hold for 353.45' 2,500.00 31.92 84.68 2,357.05 2,197.55 0.00 0.00 3.09 2,600.00 31.92 84.68 2,441.93 2,282.43 0.00 0.00 3.39 2,700.00 31.92 84.68 2,526.80 2,367.30 0.00 0.00 3.69 2,800.00 31.92 84.68 2,611.68 2,452.18 0.00 0.00 4.01 2,845.15 31.92 84.68 2,650.00 2,490.50 0.00 0.00 4.15 Start 2.5°/100'DLS,53.45°TF,for 1001.84' 2,858.71 32.12 85.19 2,661.50 2,502.00 2.50 53.45 4.30 10-3/4"x 13-1/2" 2,900.00 32.75 86.71 2,696.35 2,536.85 2.50 53.01 4.30 3,000.00 34.35 90.19 2,779.69 2,620.19 2.50 51.72 4.66 3,100.00 36.04 93.39 2,861.41 2,701.91 2.50 48.82 5.16 3,200.00 37.81 96.33 2,941.36 2,781.86 2.50 46.21 5.79 3,300.00 39.64 99.05 3,019.37 2,859.87 2.50 43.86 6.53 3,400.00 41.54 101.56 3,095.31 2,935.81 2.50 41.74 7.37 3,500.00 43.48 103.89 3,169.03 3,009.53 2.50 39.83 8.30 3,600.00 45.47 106.05 3,240.39 3,080.89 2.50 38.12 9.29 3,700.00 47.49 108.07 3,309.25 3,149.75 2.50 36.57 10.36 11/11/2015 10:35:08AM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-03 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-03 North Reference: True Wellbore: Plan:2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03wp09[Bamboo] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Lat.Error (usft) (°) (0) (usft) (usft) (°/100usft) (°) (usft) 3,800.00 49.55 109.96 3,375.48 3,215.98 2.50 35.18 11.48 3,846.99 50.53 110.81 3,405.65 3,246.15 2.50 33.93 12.02 Hold for 2394.9' 3,900.00 50.53 110.81 3,439.35 3,279.85 0.00 0.00 12.70 4,000.00 50.53 110.81 3,502.92 3,343.42 0.00 0.00 14.00 4,100.00 50.53 110.81 3,566.48 3,406.98 0.00 0.00 15.30 4,200.00 50.53 110.81 3,630.04 3,470.54 0.00 0.00 16.62 4,300.00 50.53 110.81 3,693.61 3,534.11 0.00 0.00 17.95 4,400.00 50.53 110.81 3,757.17 3,597.67 0.00 0.00 8.69 4,500.00 50.53 110.81 3,820.74 3,661.24 0.00 0.00 9.18 4,600.00 50.53 110.81 3,884.30 3,724.80 0.00 0.00 9.69 4,700.00 50.53 110.81 3,947.87 3,788.37 0.00 0.00 10.20 4,800.00 50.53 110.81 4,011.43 3,851.93 0.00 0.00 10.71 4,900.00 50.53 110.81 4,075.00 3,915.50 0.00 0.00 11.22 5,000.00 50.53 110.81 4,138.56 3,979.06 0.00 0.00 11.74 5,100.00 50.53 110.81 4,202.13 4,042.63 0.00 0.00 12.26 5,200.00 50.53 110.81 4,265.69 4,106.19 0.00 0.00 12.79 5,300.00 50.53 110.81 4,329.26 4,169.76 0.00 0.00 13.31 5,400.00 50.53 110.81 4,392.82 4,233.32 0.00 0.00 13.84 5,500.00 50.53 110.81 4,456.39 4,296.89 0.00 0.00 14.37 5,600.00 50.53 110.81 4,519.95 4,360.45 0.00 0.00 14.90 5,700.00 50.53 110.81 4,583.52 4,424.02 0.00 0.00 15.44 5,800.00 50.53 110.81 4,647.08 4,487.58 0.00 0.00 15.97 5,900.00 50.53 110.81 4,710.65 4,551.15 0.00 0.00 16.51 6,000.00 50.53 110.81 4,774.21 4,614.71 0.00 0.00 17.04 6,100.00 50.53 110.81 4,837.78 4,678.28 0.00 0.00 17.58 6,200.00 50.53 110.81 4,901.34 4,741.84 0.00 0.00 18.12 6,241.89 50.53 110.81 4,927.97 4,768.47 0.00 0.00 18.34 Start 2.5°/100'DLS,89.71°TF,for 2793.33' 6,300.00 50.55 112.69 4,964.90 4,805.40 2.50 89.71 18.55 6,400.00 50.66 115.93 5,028.37 4,868.87 2.50 88.51 18.79 6,500.00 50.86 119.14 5,091.63 4,932.13 2.50 86.46 18.98 6,600.00 51.15 122.34 5,154.57 4,995.07 2.50 84.42 19.11 6,700.00 51.52 125.51 5,217.05 5,057.55 2.50 82.41 19.19 6,800.00 51.98 128.64 5,278.97 5,119.47 2.50 80.43 19.23 6,900.00 52.52 131.72 5,340.20 5,180.70 2.50 78.50 19.22 7,000.00 53.14 134.76 5,400.63 5,241.13 2.50 76.60 19.16 7,100.00 53.83 137.75 5,460.14 5,300.64 2.50 74.77 19.07 7,200.00 54.60 140.68 5,518.62 5,359.12 2.50 72.99 18.94 7,300.00 55.44 143.56 5,575.96 5,416.46 2.50 71.27 18.79 7,400.00 56.34 146.38 5,632.05 5,472.55 2.50 69.62 18.60 7,500.00 57.30 149.13 5,686.79 5,527.29 2.50 68.05 18.40 7,600.00 58.33 151.83 5,740.06 5,580.56 2.50 66.54 18.17 7,700.00 59.41 154.46 5,791.76 5,632.26 2.50 65.10 17.93 7,800.00 60.54 157.04 5,841.81 5,682.31 2.50 63.74 17.69 11/11/2015 10:35:08AM Page 4 COMPASS 5000.1 Build 74 Schlumberger • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-03 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-03 North Reference: True Wellbore: Plan:2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03wp09[Bambool Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (0) (usft) (usft) (°/100usft) (°) (usft) 7,900.00 61.72 159.55 5,890.10 5,730.60 2.50 62.45 17.43 8,000.00 62.94 162.01 5,936.54 5,777.04 2.50 61.24 17.18 8,100.00 64.21 164.42 5,981.04 5,821.54 2.50 60.09 16.93 8,200.00 65.52 166.78 6,023.52 5,864.02 2.50 59.02 16.68 8,300.00 66.86 169.08 6,063.90 5,904.40 2.50 58.02 16.44 8,400.00 68.23 171.34 6,102.10 5,942.60 2.50 57.09 16.22 8,500.00 69.64 173.56 6,138.04 5,978.54 2.50 56.23 16.01 8,600.00 71.07 175.73 6,171.67 6,012.17 2.50 55.43 15.82 8,700.00 72.53 177.87 6,202.91 6,043.41 2.50 54.70 15.65 8,800.00 74.00 179.98 6,231.71 6,072.21 2.50 54.03 15.51 8,900.00 75.50 182.05 6,258.00 6,098.50 2.50 53.42 15.40 9,000.00 77.02 184.10 6,281.75 6,122.25 2.50 52.88 15.32 9,035.22 77.56 184.81 6,289.50 6,130.00 2.50 52.39 15.30 Hold for 20'-7-5/8"X 9-7/8" 9,055.22 77.56 184.81 6,293.81 6,134.31 0.00 0.00 15.40 Start 2.5°/100'DLS,55.2°TF,for 344.44' 9,100.00 78.20 185.75 6,303.21 6,143.71 2.50 55.20 15.36 9,200.00 79.64 187.83 6,322.43 6,162.93 2.50 55.00 15.35 9,300.00 81.10 189.89 6,339.16 6,179.66 2.50 54.60 15.48 9,399.66 82.56 191.93 6,353.33 6,193.83 2.50 54.25 15.73 Hold for 4.59' 9,400.00 82.56 191.93 6,353.37 6,193.87 0.00 0.00 15.73 9,404.24 82.56 191.93 6,353.92 6,194.42 0.00 0.00 15.77 Start 2.57°/100'DLS,48.72°TF,for 143.73' 9,500.00 84.18 193.79 6,364.98 6,205.48 2.57 48.72 16.07 9,547.98 85.00 194.72 6,369.50 6,210.00 2.57 48.51 16.29 Start 4°/100'DLS,0°TF,for 116.58'-2S-Bamboo 1.Heel-2S-Bamboo 1.Heel_Circle 9,573.53 86.02 194.72 6,371.50 6,212.00 4.00 0.00 16.80 A4 9,600.00 87.08 194.72 6,373.09 6,213.59 4.00 0.00 16.80 9,664.56 89.66 194.72 6,374.93 6,215.43 4.00 0.00 17.41 Hold for 5884.24' 9,700.00 89.66 194.72 6,375.13 6,215.63 0.00 -70.71 17.76 9,800.00 89.66 194.72 6,375.72 6,216.22 0.00 0.00 18.77 9,900.00 89.66 194.72 6,376.31 6,216.81 0.00 0.00 19.85 10,000.00 89.66 194.72 6,376.90 6,217.40 0.00 0.00 20.97 10,100.00 89.66 194.72 6,377.48 6,217.98 0.00 0.00 22.14 10,200.00 89.66 194.72 6,378.07 6,218.57 0.00 0.00 23.34 10,300.00 89.66 194.72 6,378.66 6,219.16 0.00 0.00 24.57 10,400.00 89.66 194.72 6,379.25 6,219.75 0.00 0.00 25.82 10,500.00 89.66 194.72 6,379.83 6,220.33 0.00 0.00 27.10 10,600.00 89.66 194.72 6,380.42 6,220.92 0.00 0.00 16.66 10,700.00 89.66 194.72 6,381.01 6,221.51 0.00 0.00 17.04 10,800.00 89.66 194.72 6,381.60 6,222.10 0.00 0.00 17.43 10,900.00 89.66 194.72 6,382.19 6,222.69 0.00 0.00 17.83 11/11/2015 10:35:08AM Page 5 COMPASS 5000.1 Build 74 Schlumberger • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-03 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-03 North Reference: True Wellbore: Plan:2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03wp09[Bamboo] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (0) (usft) 11,000.00 89.66 194.72 6,382.77 6,223.27 0.00 0.00 18.24 11,100.00 89.66 194.72 6,383.36 6,223.86 0.00 0.00 18.65 11,200.00 89.66 194.72 6,383.95 6,224.45 0.00 0.00 19.08 11,300.00 89.66 194.72 6,384.54 6,225.04 0.00 0.00 19.51 11,400.00 89.66 194.72 6,385.12 6,225.62 0.00 0.00 19.96 11,500.00 89.66 194.72 6,385.71 6,226.21 0.00 0.00 20.40 11,600.00 89.66 194.72 6,386.30 6,226.80 0.00 0.00 20.86 11,700.00 89.66 194.72 6,386.89 6,227.39 0.00 0.00 21.32 11,800.00 89.66 194.72 6,387.47 6,227.97 0.00 0.00 21.79 11,900.00 89.66 194.72 6,388.06 6,228.56 0.00 0.00 22.26 12,000.00 89.66 194.72 6,388.65 6,229.15 0.00 0.00 22.74 12,100.00 89.66 194.72 6,389.24 6,229.74 0.00 0.00 23.22 12,200.00 89.66 194.72 6,389.82 6,230.32 0.00 0.00 23.70 12,300.00 89.66 194.72 6,390.41 6,230.91 0.00 0.00 24.19 12,400.00 89.66 194.72 6,391.00 6,231.50 0.00 0.00 24.69 12,500.00 89.66 194.72 6,391.59 6,232.09 0.00 0.00 25.18 12,600.00 89.66 194.72 6,392.17 6,232.67 0.00 0.00 25.68 12,700.00 89.66 194.72 6,392.76 6,233.26 0.00 0.00 26.19 12,800.00 89.66 194.72 6,393.35 6,233.85 0.00 0.00 26.70 12,900.00 89.66 194.72 6,393.94 6,234.44 0.00 0.00 27.21 13,000.00 89.66 194.72 6,394.52 6,235.02 0.00 0.00 27.72 13,100.00 89.66 194.72 6,395.11 6,235.61 0.00 0.00 28.23 13,200.00 89.66 194.72 6,395.70 6,236.20 0.00 0.00 28.75 13,300.00 89.66 194.72 6,396.29 6,236.79 0.00 0.00 29.27 13,400.00 89.66 194.72 6,396.87 6,237.37 0.00 0.00 29.79 13,500.00 89.66 194.72 6,397.46 6,237.96 0.00 0.00 30.32 13,600.00 89.66 194.72 6,398.05 6,238.55 0.00 0.00 30.84 13,700.00 89.66 194.72 6,398.64 6,239.14 0.00 0.00 31.37 13,800.00 89.66 194.72 6,399.22 6,239.72 0.00 0.00 31.90 13,900.00 89.66 194.72 6,399.81 6,240.31 0.00 0.00 32.43 14,000.00 89.66 194.72 6,400.40 6,240.90 0.00 0.00 32.97 14,100.00 89.66 194.72 6,400.99 6,241.49 0.00 0.00 33.50 14,200.00 89.66 194.72 6,401.57 6,242.07 0.00 0.00 34.04 14,300.00 89.66 194.72 6,402.16 6,242.66 0.00 0.00 34.57 14,400.00 89.66 194.72 6,402.75 6,243.25 0.00 0.00 35.11 14,500.00 89.66 194.72 6,403.34 6,243.84 0.00 0.00 35.65 14,600.00 89.66 194.72 6,403.93 6,244.43 0.00 0.00 36.19 14,700.00 89.66 194.72 6,404.51 6,245.01 0.00 0.00 36.74 14,800.00 89.66 194.72 6,405.10 6,245.60 0.00 0.00 37.28 14,900.00 89.66 194.72 6,405.69 6,246.19 0.00 0.00 37.82 15,000.00 89.66 194.72 6,406.28 6,246.78 0.00 0.00 38.37 15,100.00 89.66 194.72 6,406.86 6,247.36 0.00 0.00 38.92 15,200.00 89.66 194.72 6,407.45 6,247.95 0.00 0.00 39.46 15,300.00 89.66 194.72 6,408.04 6,248.54 0.00 0.00 40.01 11/11/2015 10:35:08AM Page 6 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-03 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-03 North Reference: True Wellbore: Plan:2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03wp09[Bamboo] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 15,400.00 89.66 194.72 6,408.63 6,249.13 0.00 0.00 40.56 15,500.00 89.66 194.72 6,409.21 6,249.71 0.00 0.00 41.11 15,548.80 89.66 194.72 6,409.50 6,250.00 0.00 0.00 41.38 Start 1°/100'DLS,179.82°TF,for 150.6'-2S-Bamboo 2.Toe 15,600.00 89.15 194.72 6,410.03 6,250.53 1.00 179.82 41.50 15,699.40 88.16 194.72 6,412.36 6,252.86 1.00 179.82 41.41 Hold for 843.94' 15,700.00 88.16 194.72 6,412.38 6,252.88 0.00 -178.36 41.41 15,800.00 88.16 194.72 6,415.60 6,256.10 0.00 0.00 41.64 15,900.00 88.16 194.72 6,418.81 6,259.31 0.00 0.00 42.19 16,000.00 88.16 194.72 6,422.03 6,262.53 0.00 0.00 42.75 16,100.00 88.16 194.72 6,425.24 6,265.74 0.00 0.00 43.30 16,200.00 88.16 194.72 6,428.46 6,268.96 0.00 0.00 43.85 16,300.00 88.16 194.72 6,431.68 6,272.18 0.00 0.00 44.40 16,400.00 88.16 194.72 6,434.89 6,275.39 0.00 0.00 44.96 16,500.00 88.16 194.72 6,438.11 6,278.61 0.00 0.00 45.51 16,543.33 88.16 194.72 6,439.50 6,280.00 0.00 0.00 45.75 TD:16543.33'MD,6439.5'TVD-4-1/2"x 6-3/4"-2S-Bamboo 3.TD-2S-Bamboo 3.TD_Circle 11/11/2015 10:35:08AM Page 7 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-03 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-03 North Reference: True Wellbore: Plan:2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03wp09[Bamboo] Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C') C') 9,035.22 6,289.50 7-5/8"X 9-7/8" 7-5/8 9-7/8 2,858.71 2,661.50 10-3/4"x 13-1/2" 10-3/4 13-1/2 16,543.33 6,439.50 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 (°) (°) 9,573.53 6,371.50 A4 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 350.00 350.00 0.00 0.00 KOP:Start 1.5°/100'DLS,20°TF,for 250.18' 600.18 600.00 7.70 2.80 Start 2.5°/100'DLS,0°TF,for 905.86' 1,506.04 1,469.00 227.66 82.86 Hold for 111.64' 1,617.68 1,569.00 274.31 99.84 Start 3.5°/100'DLS, 110.09°TF,for 874.02' 2,491.70 2,350.00 483.32 403.62 Hold for 353.45' 2,845.15 2,650.00 500.66 589.69 Start 2.5°/100'DLS,53.45°TF,for 1001.84' 3,846.99 3,405.65 386.01 1,225.03 Hold for 2394.9' 6,241.89 4,927.97 -270.90 2,953.20 Start 2.5°/100'DLS,89.71°TF,for 2793.33' 9,035.22 6,289.50 -2,266.44 3,976.62 Hold for 20' 9,055.22 6,293.81 -2,285.90 3,974.98 Start 2.57100'DLS,55.2°TF,for 344.44' 9,399.66 6,353.33 -2,621.20 3,925.48 Hold for 4.59' 9,404.24 6,353.92 -2,625.64 3,924.54 Start 2.57°/100'DLS,48.72°TF,for 143.73' 9,547.98 6,369.50 -2,764.66 3,891.61 Start 4°/100'DLS,0°TF,for 116.58' 9,664.56 6,374.93 -2,877.27 3,862.03 Hold for 5884.24' 15,548.80 6,409.50 -8,568.39 2,367.32 Start 1°/100'DLS, 179.82°TF,for 150.6' 15,699.40 6,412.36 -8,714.02 2,329.07 Hold for 843.94' 16,543.33 6,439.50 -9,529.83 2,114.73 TD: 16543.33'MD,6439.5'TVD Checked By: Approved By: Date: 11/11/2015 10:35:08AM Page 8 COMPASS 5000.1 Build 74 • • N -0 a E C C 1O .R ■ l6 N Cir) Oo y0C v♦ 9 Co O CC CD m a N C _ E O o � �� ' 3 x m o CD re c o - t GI o t: N O . . 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O O O N N y 4) 4) O Ln O O f� N- N N (0 4) 4) a1 C a `I'. O O O O 06 40 ui O` U 3 •(O 4) 4) L >, E.��'' co in LU L0 L0 co co N O o y c0mo� 4000 co • N a m IL _ N N CT O 'O N 4) O O U V NG) 0 4) m m ) re 13 LO N . U 4) _ O O Q a a W U In N OV C C w 4) p Q .� Ca "- U U O N • 713 � y �' 4) 4) 4) II 0 oz C 4) E Q Y O O -0 •0 w �' m 0 5 O N -a) LL U e O 4) O co O O C au (6 Q U d m a3u) Q — (O 4) N 4) W 0 cn E 5 Q 10:34, November 11 2015 u09 BamLadder View 2S-03w 1_ [ boo] The Reference Well is along the X-axis. rror Ellipses are the Sum of the Reference and Offset Well Errors I, I t E E ` Pg E o 16 m y E IB t E f 2 gao ,e I w 3 3 3 -o N 441C NSW N N 300 I Til , III 'II�� III III II1 II� III' r,;I�- II IIIIII III�I 1 —woo. ,i V 1 IIIA m 'I I' /„ 7 L I ,lli co a mnnmp111/I�i I ISI I I I -- I ��Illlll�I iI 1 I,ll N 150 0 �i) EI 2 upIIIIIVIIIl� Ili If (,! C quill 11111 II .. NY1111111' U ,n-1II �,tl'ili „oA . 0 Equivelant Magnetic Distance I I I I I I I I I I I I I I I I I I I I 0 2000 4000 6000 8000 10000 12000 Displayed interval could be less than entire well:Measured Depth 39.50 To 16543.33 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.50 650.00 25-03wp09[Bamboo] (Plan: 25-03)GYD-GC-SS 2661. B58.71 10-3/4” x 13-1/2" 650.00 1650.00 2S-03wp09[Bamboo] (Plan: 2S-03)MWD 6289.: 35.22 7-5/8"X 9-7/8" 650.00 2858.71 25-03wp09[Bamboo] (Plan: 2S-03)MWD+IFR-AK-CAZ-SC 64391543.33 4-1/2"x 6-3/4" 2858.71 4358.71 2S-03wp09[Bamboo] (Plan: 2S-03)MWD 2858.71 9035.22 25-03wp09[Bambool (Plan: 2S-03)MWD+IFR-AK-CAZ-SC 9035.2210535.22 25-03wp09[Bamboo] (Plan: 2S-03)MWD 9035.2216543.33 25-03wp09[Bamboo] (Plan: 2S-03)MWD+IFR-AK-CAZ-SC 8 e i n m n a ; a 9 4 4 Njj N 60 , mllllllllll11 '.I i 41 GIs ridip , 30 •1400® Ga.. ill1I r�f�� . iii , -E i a0i — U 0i 1 , 1 I 1 I I I I I I I I I I i i I I I I I I i I i I i i i I I I 0 \\ 500 1000 1500 2000 2500 3000 3500 Equivelant Magnetic Distance Partial Measured Depth 4U JOU 2S-03wp09[Bamboo] �MD Inc Azi •TVD Dleg TFace Target 350 540 39.50 0.00 0.00 39.50 0.00 0.00 39.50 To 16543.33 350.00 0.00 0.00 350.00 0.00 0.00 540 740 600.18 3.75 20.00 600.00 1.50 20.00 740 930 1506.04 26.40 20.00 1469.00 2.50 0.00 10:36, November112015 1617.68 26.40 20.00 1569.00 0.00 0.00 930 "-""" 1120 2491.70 31.92 84.68 2350.00 3.50 110.09 CASING DETAILS 2845.15 31.92 84.68 2650.00 0.00 0.00 1120 1320 3846.99 50.53 110.81 3405.65 2.50 53.45 TVD MD Name 6241.89 50.53 110.81 4927.97 0.00 0.00 1320 1510 2661.50 2858.71 10-3/4" x 13-1/2" 9035.22 77.56 184.81 6289.50 2.50 89.71 6289.50 9035.22 7-5/8" X 9-7/8" 1510 1700 6439.50 16543.33 9-1/2" x 6-3/4" 9055.22 77.56 184.81 6293.81 0.00 0.00 9399.66 82.56 191.93 6353.33 2.50 55.20 1700 2310 9404.24 82.56 191.93 6353.92 0.00 0.00 SURVEY PROGRAM 9547.98 85.00 194.72 6369.50 2.57 48.72 2S-Bamboo 1.Heel 2310 2930 � m,0 S aviei :oa 9664.56 89.66 194.72 6374.93 4.00 0.003950 2930 3540 650 00 65000 i5-03.09[5 i (Plan 00 P5-on¢spo'`-SS 15548.80 89.66 199.72 6909.50 0.00 0.00 25-Bamboo 2.Toe 58 i 25-03.R09c5 m ] (.3 : 25-0.0.055-xc-cu-S< 500i :5 S_o ,,,,po9,5 � ,23.5: 25.0.w 15699.40 88.16 194.72 6412.36 1.00 179.82 3540 4150 55:u 30555:PP 0-03,09[10.0] 03',R00�5 i ieim z5- .:�-'�`-�-5C 16543.33 88.16 194.72 6439.50 0.00 0.00 2S-Bamboo 3. TD 9035.22 36543.33 2S-03"p09(5 ) (410: 2S-0604:0.-,,s-2-SC 4150 4760 4760 5370 5370 - -"""""" 5990 5990 6600 6600 7840 0/360 7840 9090 9090 10330 ��y�•1�/�67, 30 10330 11570 -30/330 �Z����ri'10 11570 12820 2S-05wp06 [Nurse ,�=i►��� ,-=�.',0156;' 195 12820 14060 -_���Orapif 180 4111M7-416.-.....App.... pr 14060 15300 a r�.�®�`�/� 165 15300 16543 *�.�=-®��0.1f°01" 151 -60/30i eeiv����1/14 .®A. ��0rid-00.1/1' 12-0----- : 60 amrAtirm4ITAtakarvaTevailritAiseitollocji,,fr - 10 041 �• gIf �i j4 \ 2S-06wp06 [Sai ifiior Rig: 2S _. -08 1►�►�'jellaiala101000ii ....mi....J.0,-h, -90/Vd,.; v-irps 4 ,•...w•9 f.d ., . ...;:;.. , •,., , -..,F,. .•%' 1 ', '''..,il';-ttnIttl I•�•? �•ev� "0:7; •r Vo .r.;`. 'i1/,, 144' 1 k10 +t♦®`►.tree ��/ki -120/240 .wV r► � •,4111K1i44 •11104�/���E,714.,PA 120 .®! Yea®1,1 / 120 'i or 4 itiofr A �►lalj ►S' ®1%"47,1'0 2S-08wp12.1 [Hamme, . ► &A;.4,14.4� rri.� -4 �.+.;- 4• f s®, / ',W. 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N ..0 0 rn Ln N. 01 x- MLn N. rn 0\ Ln N. r' a. co O rn in 00 0 M - N N r-N d' r if is\ �0 I. al 0 1- N d- Ln r- r- e- 7- 0 CrN U V `` , /.,� N V V as CO333OC x`333 222222 i`'•� / Lfl / / T L7' EE ssoosa° /EEEEE / A' i\ mmmmmmm x333 ,\ ^,\ 122 n n n n n n �' '\ o�oa��ao 0 0 0 0 o O 00 E Cl � _ r J/// 11 �~' \ % m i N x,, /\ r.oss rn rn 1 r- O M o do- •.fl M 0 rn rn N Lr, Oo O N Ory to ' \ r L CO Vow O 1 .a 0 0 Q o 0 0 0 0 .0 00 00 00 0o rn 0. cu //�� 0 0 0 0 0 0 o . i e- d- d d d- dt o iai p N N N 00 00 ms- r- 00 00 01 01 a. a. G. O, 01 Z pr- e- N- r- e- e- e-- e- Q O 0 COd- 00 0 in 0. 01 N N d- CO .0 0 0 rn M • if.. O 7 O n 7 01 00 N N N .� in 00 d- cr.) O p 0 o •o ''` Ln Ln a; d- oo r d- d- m Ln 0 d- �O d- 01 .' _I M M ,Lfl q)-, x- d- °() m 0(TN OM'\ � 0 al Lf\ N 0 0 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-03 Plan: 2S-03 Plan: 2S-03wp09[Bamboo] Report - Errors 11 November, 2015 Schlumberger Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-03 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-03 North Reference: True Wellbore: Plan:2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03wp09[Bamboo] 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-03 Well Position +N/-S usft Northing: usft Latitude: +EI-W usft Easting: usft Longitude: Position Uncertainty usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore Plan:2S-03 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2015 2/1/2016 18.37 80.86 57,485 Design 2S-03wp09[Bamboo] 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 0.00 195.00 Survey Tool Program Date 11/11/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 39.50 650.00 2S-03wp09[Bamboo](Plan:2S-03) GYD-GC-SS Gyrodata gyro single shots 650.00 1,650.00 2S-03wp09[Bamboo](Plan:2S-03) MWD MWD-Standard 650.00 2,858.71 2S-03wp09[Bamboo](Plan:2S-03) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,858.71 4,358.71 2S-03wp09[Bamboo](Plan:2S-03) MWD MWD-Standard 2,858.71 9,035.22 2S-03wp09[Bamboo](Plan:2S-03) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9,035.22 10,535.22 2S-03wp09[Bamboo](Plan:2S-03) MWD MWD-Standard 9,035.22 16,543.33 2S-03wp09[Bamboo](Plan:2S-03) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 39.50 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 0.04 0.04 200.00 1.15 0.00 0.00 40.50 1.15 0.19 0.19 300.00 1.15 0.00 0.00 140.50 1.15 0.33 0.33 350.00 1.15 0.00 0.00 190.50 1.15 0.41 0.41 KOP:Start 1.5°/100'DLS,20°TF,for 250.18' 400.00 1.15 0.75 135.00 240.50 1.15 0.48 0.48 11/11/2015 10:35:24AM Page 2 COMPASS 5000.1 Build 74 Schlumberger Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-03 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-03 North Reference: True Wellbore: Plan:2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03wp09[Bamboo] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 500.00 1.15 2.25 135.00 340.46 1.15 0.62 0.62 600.00 1.15 3.75 110.40 440.32 1.15 0.76 0.76 600.18 1.15 3.75 110.40 440.50 1.15 0.76 0.76 Start 2.5°/100'DLS,0°TF,for 905.86' 700.00 1.16 6.25 110.37 539.93 1.15 0.84 0.84 800.00 1.16 8.75 20.08 639.07 1.15 0.89 0.85 900.00 1.17 11.25 20.07 737.54 1.15 1.02 0.88 1,000.00 1.18 13.75 20.06 835.17 1.14 1.23 0.93 1,100.00 1.19 16.25 20.05 931.75 1.14 1.54 1.00 1,200.00 1.20 18.75 20.05 1,027.12 1.13 1.93 1.09 1,300.00 1.22 21.25 20.04 1,121.08 1.13 2.39 1.19 1,400.00 1.24 23.75 20.04 1,213.46 1.14 2.92 1.31 1,500.00 1.26 26.25 20.04 1,304.09 1.15 3.52 1.45 1,506.04 1.26 26.40 20.04 1,309.50 1.15 3.56 1.46 Hold for 111.64' 1,600.00 1.27 26.40 20.04 1,393.66 1.17 4.16 1.61 1,617.68 1.27 26.40 20.03 1,409.50 1.18 4.27 1.64 Start 3.5°/100'DLS,110.09°TF,for 874.02' 1,700.00 1.26 25.54 20.19 1,483.52 1.16 2.10 1.47 1,800.00 1.28 24.89 20.56 1,574.02 1.19 2.19 1.60 1,900.00 1.31 24.68 21.84 1,664.83 1.22 2.28 1.75 2,000.00 1.35 24.94 24.11 1,755.63 1.25 2.37 1.91 2,100.00 1.41 25.65 27.27 1,846.07 1.27 2.47 2.07 2,200.00 1.48 26.77 31.26 1,935.81 1.30 2.59 2.22 2,300.00 1.57 28.25 36.00 2,024.53 1.32 2.73 2.37 2,400.00 1.68 30.05 41.37 2,111.88 1.35 2.89 2.49 2,491.70 1.79 31.92 46.70 2,190.50 1.37 3.07 2.60 Hold for 353.45' 2,500.00 1.79 31.92 47.06 2,197.55 1.37 3.09 2.61 2,600.00 1.80 31.92 52.38 2,282.43 1.42 3.39 2.70 2,700.00 1.81 31.92 56.72 2,367.30 1.46 3.69 2.80 2,800.00 1.81 31.92 60.24 2,452.18 1.51 4.01 2.90 2,845.15 1.82 31.92 61.60 2,490.50 1.54 4.15 2.94 Start 2.5°/100'DLS,53.45°TF,for 1001.84' 2,858.71 1.90 32.12 62.53 2,502.00 1.53 4.30 2.98 10-3/4"x 13-1/2" 2,900.00 1.90 32.75 62.53 2,536.85 1.53 4.30 2.98 3,000.00 2.04 34.35 65.52 2,620.19 1.54 4.66 3.02 3,100.00 2.19 36.04 69.40 2,701.91 1.55 5.16 3.08 3,200.00 2.36 37.81 73.46 2,781.86 1.58 5.79 3.17 3,300.00 2.55 39.64 77.34 2,859.87 1.63 6.53 3.27 3,400.00 2.75 41.54 80.89 2,935.81 1.69 7.37 3.39 3,500.00 2.98 43.48 84.09 3,009.53 1.77 8.30 3.53 3,600.00 3.24 45.47 86.95 3,080.89 1.87 9.29 3.68 3,700.00 3.51 47.49 89.52 3,149.75 1.99 10.36 3.85 11/11/2015 10:35:24AM Page 3 COMPASS 5000.1 Build 74 Schlumberger • Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-03 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-03 North Reference: True Wellbore: Plan:2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03wp09[Bambooj Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (0) (°) (usft) (usft) (usft) (usft) 3,800.00 3.81 49.55 91.84 3,215.98 2.13 11.48 4.02 3,846.99 3.96 50.53 92.85 3,246.15 2.21 12.02 4.11 Hold for 2394.9' 3,900.00 3.96 50.53 93.92 3,279.85 2.30 12.70 4.20 4,000.00 3.97 50.53 95.65 3,343.42 2.48 14.00 4.38 4,100.00 3.97 50.53 97.09 3,406.98 2.67 15.30 4.58 4,200.00 3.98 50.53 98.30 3,470.54 2.86 16.62 4.78 4,300.00 3.99 50.53 99.32 3,534.11 3.06 17.95 5.00 4,400.00 3.41 50.53 94.52 3,597.67 2.21 8.69 3.63 4,500.00 3.42 50.53 95.83 3,661.24 2.31 9.18 3.73 4,600.00 3.42 50.53 96.99 3,724.80 2.41 9.69 3.83 4,700.00 3.43 50.53 98.02 3,788.37 2.51 10.20 3.94 4,800.00 3.44 50.53 98.94 3,851.93 2.61 10.71 4.05 4,900.00 3.45 50.53 99.75 3,915.50 2.71 11.22 4.16 5,000.00 3.45 50.53 100.49 3,979.06 2.82 11.74 4.28 5,100.00 3.46 50.53 101.15 4,042.63 2.93 12.26 4.39 5,200.00 3.47 50.53 101.74 4,106.19 3.04 12.79 4.52 5,300.00 3.48 50.53 102.28 4,169.76 3.15 13.31 4.64 5,400.00 3.49 50.53 102.77 4,233.32 3.26 13.84 4.76 5,500.00 3.49 50.53 103.22 4,296.89 3.37 14.37 4.89 5,600.00 3.50 50.53 103.63 4,360.45 3.48 14.90 5.02 5,700.00 3.51 50.53 104.01 4,424.02 3.60 15.44 5.15 5,800.00 3.52 50.53 104.36 4,487.58 3.71 15.97 5.28 5,900.00 3.53 50.53 104.68 4,551.15 3.82 16.51 5.42 6,000.00 3.54 50.53 104.98 4,614.71 3.94 17.04 5.55 6,100.00 3.55 50.53 105.26 4,678.28 4.06 17.58 5.69 6,200.00 3.56 50.53 105.52 4,741.84 4.17 18.12 5.83 6,241.89 3.56 50.53 105.62 4,768.47 4.22 18.34 5.89 Start 2.5°1100'DLS,89.71°TF,for 2793.33' 6,300.00 3.80 50.55 105.74 4,805.40 4.29 18.55 6.00 6,400.00 4.31 50.66 105.92 4,868.87 4.40 18.79 6.24 6,500.00 4.91 50.86 106.17 4,932.13 4.51 18.98 6.53 6,600.00 5.58 51.15 106.48 4,995.07 4.63 19.11 6.85 6,700.00 6.29 51.52 106.84 5,057.55 4.74 19.19 7.20 6,800.00 7.03 51.98 107.25 5,119.47 4.86 19.23 7.57 6,900.00 7.80 52.52 107.71 5,180.70 4.98 19.22 7.93 7,000.00 8.58 53.14 108.21 5,241.13 5.10 19.16 8.29 7,100.00 9.37 53.83 108.75 5,300.64 5.22 19.07 8.64 7,200.00 10.18 54.60 109.32 5,359.12 5.34 18.94 8.96 7,300.00 10.98 55.44 109.92 5,416.46 5.46 18.79 9.25 7,400.00 11.79 56.34 110.55 5,472.55 5.59 18.60 9.51 7,500.00 12.59 57.30 111.21 5,527.29 5.71 18.40 9.73 7,600.00 13.39 58.33 111.89 5,580.56 5.84 18.17 9.92 7,700.00 14.18 59.41 112.59 5,632.26 5.97 17.93 10.06 7,800.00 14.96 60.54 113.31 5,682.31 6.11 17.69 10.17 /1/11/2015 10:35:24AM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-03 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-03 North Reference: True Wellbore: Plan:2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03wp09[Bambool Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 7,900.00 15.72 61.72 114.05 5,730.60 6.24 17.43 10.24 8,000.00 16.48 62.94 114.81 5,777.04 6.38 17.18 10.26 8,100.00 17.21 64.21 115.58 5,821.54 6.52 16.93 10.25 8,200.00 17.93 65.52 116.38 5,864.02 6.66 16.68 10.21 8,300.00 18.63 66.86 117.18 5,904.40 6.81 16.44 10.13 8,400.00 19.31 68.23 118.00 5,942.60 6.95 16.22 10.03 8,500.00 19.96 69.64 118.84 5,978.54 7.10 16.01 9.91 8,600.00 20.59 71.07 119.69 6,012.17 7.25 15.82 9.76 8,700.00 21.19 72.53 120.57 6,043.41 7.40 15.65 9.61 8,800.00 21.77 74.00 121.45 6,072.21 7.56 15.51 9.45 8,900.00 22.31 75.50 122.36 6,098.50 7.71 15.40 9.29 9,000.00 22.83 77.02 123.29 6,122.25 7.87 15.32 9.14 9,035.22 23.01 77.56 123.62 6,130.00 7.93 15.30 9.09 Hold for 20'-7-5/8"X 9-7/8" 9,055.22 23.13 77.56 123.72 6,134.31 7.89 15.40 9.11 Start 2.5°/100'DLS,55.2°TF,for 344.44' 9,100.00 23.35 78.20 124.36 6,143.71 7.89 15.36 8.99 9,200.00 23.85 79.64 125.89 6,162.93 7.90 15.35 8.75 9,300.00 24.32 81.10 127.57 6,179.66 7.94 15.48 8.55 9,399.66 24.78 82.56 129.40 6,193.83 7.98 15.73 8.39 Hold for 4.59' 9,400.00 24.78 82.56 129.40 6,193.87 7.98 15.73 8.39 9,404.24 24.78 82.56 129.48 6,194.42 7.99 15.77 8.39 Start 2.57°/100'DLS,48.72°TF,for 143.73' 9,500.00 25.19 84.18 131.28 6,205.48 8.05 16.07 8.26 9,547.98 25.39 85.00 132.26 6,210.00 8.09 16.29 8.22 Start 4°/100'DLS,0°TF,for 116.58'-2S-Bamboo 1.Heel-2S-Bamboo 1.Heel_Circle 9,573.53 25.43 86.02 133.31 6,212.00 8.13 16.80 8.15 A4 9,600.00 25.43 87.08 133.31 6,213.59 8.13 16.80 8.15 9,664.56 25.44 89.66 134.56 6,215.43 8.19 17.41 8.18 Hold for 5884.24' 9,700.00 25.44 89.66 135.26 6,215.63 8.23 17.76 8.22 9,800.00 25.44 89.66 137.29 6,216.22 8.34 18.77 8.33 9,900.00 25.45 89.66 139.39 6,216.81 8.47 19.85 8.46 10,000.00 25.45 89.66 141.54 6,217.40 8.61 20.97 8.60 10,100.00 25.45 89.66 143.74 6,217.98 8.76 22.14 8.75 10,200.00 25.45 89.66 145.95 6,218.57 8.93 23.34 8.92 10,300.00 25.46 89.66 148.16 6,219.16 9.10 24.57 9.10 10,400.00 25.46 89.66 150.35 6,219.75 9.29 25.82 9.29 10,500.00 25.46 89.66 152.49 6,220.33 9.49 27.10 9.49 10,600.00 25.25 89.66 132.48 6,220.92 8.35 16.66 8.35 10,700.00 25.25 89.66 133.21 6,221.51 8.42 17.04 8.41 10,800.00 25.26 89.66 133.96 6,222.10 8.48 17.43 8.47 10,900.00 25.26 89.66 134.73 6,222.69 8.55 17.83 8.54 11/11/2015 10:35:24AM Page 5 COMPASS 5000.1 Build 74 1 Schlumberger • Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-03 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-03 North Reference: True Wellbore: Plan:2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03wp09[Bamboo] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 11,000.00 25.26 89.66 135.52 6,223.27 8.62 18.24 8.61 11,100.00 25.26 89.66 136.33 6,223.86 8.69 18.65 8.68 11,200.00 25.27 89.66 137.17 6,224.45 8.77 19.08 8.76 11,300.00 25.27 89.66 138.02 6,225.04 8.85 19.51 8.84 11,400.00 25.27 89.66 138.90 6,225.62 8.93 19.96 8.92 11,500.00 25.27 89.66 139.79 6,226.21 9.02 20.40 9.01 11,600.00 25.28 89.66 140.71 6,226.80 9.11 20.86 9.10 11,700.00 25.28 89.66 141.64 6,227.39 9.20 21.32 9.19 11,800.00 25.28 89.66 142.58 6,227.97 9.29 21.79 9.28 11,900.00 25.28 89.66 143.54 6,228.56 9.39 22.26 9.38 12,000.00 25.29 89.66 144.52 6,229.15 9.48 22.74 9.48 12,100.00 25.29 89.66 145.50 6,229.74 9.59 23.22 9.58 12,200.00 25.29 89.66 146.49 6,230.32 9.69 23.70 9.68 12,300.00 25.29 89.66 147.49 6,230.91 9.79 24.19 9.79 12,400.00 25.30 89.66 148.49 6,231.50 9.90 24.69 9.90 12,500.00 25.30 89.66 149.49 6,232.09 10.01 25.18 10.00 12,600.00 25.30 89.66 150.49 6,232.67 10.12 25.68 10.12 12,700.00 25.31 89.66 151.48 6,233.26 10.24 26.19 10.23 12,800.00 25.31 89.66 152.48 6,233.85 10.35 26.70 10.34 12,900.00 25.31 89.66 153.46 6,234.44 10.47 27.21 10.46 13,000.00 25.31 89.66 154.43 6,235.02 10.59 27.72 10.58 13,100.00 25.32 89.66 155.39 6,235.61 10.71 28.23 10.70 13,200.00 25.32 89.66 156.34 6,236.20 10.83 28.75 10.82 13,300.00 25.32 89.66 157.27 6,236.79 10.95 29.27 10.95 13,400.00 25.33 89.66 158.18 6,237.37 11.08 29.79 11.07 13,500.00 25.33 89.66 159.08 6,237.96 11.20 30.32 11.20 13,600.00 25.33 89.66 159.95 6,238.55 11.33 30.84 11.33 13,700.00 25.33 89.66 160.81 6,239.14 11.46 31.37 11.46 13,800.00 25.34 89.66 161.64 6,239.72 11.59 31.90 11.59 13,900.00 25.34 89.66 162.45 6,240.31 11.72 32.43 11.72 14,000.00 25.34 89.66 163.25 6,240.90 11.86 32.97 11.85 14,100.00 25.35 89.66 164.01 6,241.49 11.99 33.50 11.99 14,200.00 25.35 89.66 164.76 6,242.07 12.13 34.04 12.12 14,300.00 25.35 89.66 165.48 6,242.66 12.27 34.57 12.26 14,400.00 25.36 89.66 166.18 6,243.25 12.40 35.11 12.40 14,500.00 25.36 89.66 166.86 6,243.84 12.54 35.65 12.54 14,600.00 25.36 89.66 167.52 6,244.43 12.68 36.19 12.68 14,700.00 25.37 89.66 168.15 6,245.01 12.82 36.74 12.82 14,800.00 25.37 89.66 168.77 6,245.60 12.96 37.28 12.96 14,900.00 25.37 89.66 169.36 6,246.19 13.11 37.82 13.10 15,000.00 25.37 89.66 169.93 6,246.78 13.25 38.37 13.25 15,100.00 25.38 89.66 170.49 6,247.36 13.40 38.92 13.39 15,200.00 25.38 89.66 171.03 6,247.95 13.54 39.46 13.54 15,300.00 25.38 89.66 171.54 6,248.54 13.69 40.01 13.68 11/11/2015 10:35:24AM Page 6 COMPASS 5000.1 Build 74 • Schlumberger • Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-03 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-03 North Reference: True Wellbore: Plan:2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03wp09[Bamboo] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 15,400.00 25.39 89.66 172.04 6,249.13 13.83 40.56 13.83 15,500.00 25.39 89.66 172.53 6,249.71 13.98 41.11 13.98 15,548.80 25.39 89.66 172.76 6,250.00 14.05 41.38 14.05 Start 1°/100'DLS,179.82°TF,for 150.6'-2S-Bamboo 2.Toe 15,600.00 25.40 89.15 172.81 6,250.53 14.13 41.50 14.12 15,699.40 25.40 88.16 172.58 6,252.86 14.28 41.41 14.27 Hold for 843.94' 15,700.00 25.40 88.16 172.58 6,252.88 14.28 41.41 14.27 15,800.00 25.41 88.16 172.70 6,256.10 14.43 41.64 14.42 15,900.00 25.41 88.16 173.15 6,259.31 14.58 42.19 14.57 16,000.00 25.41 88.16 173.59 6,262.53 14.73 42.75 14.72 16,100.00 25.42 88.16 174.01 6,265.74 14.88 43.30 14.87 16,200.00 25.42 88.16 174.42 6,268.96 15.03 43.85 15.02 16,300.00 25.42 88.16 174.82 6,272.18 15.19 44.40 15.18 16,400.00 25.43 88.16 175.21 6,275.39 15.34 44.96 15.33 16,500.00 25.43 88.16 175.58 6,278.61 15.49 45.51 15.49 16,543.33 25.43 88.16 175.74 6,280.00 15.56 45.75 15.55 TD:16543.33'MD,6439.5'TVD-4-1/2"x 6-3/4"-2S-Bamboo 3.TD-2S-Bamboo 3.TD_Circle 11/11/2015 10:35:24AM Page 7 COMPASS 5000.1 Build 74 • Schlumberger • Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-03 Project: Kuparuk River Unit TVD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39.5 @ 159.50usft(Doyon25) Well: Plan:2S-03 North Reference: True Wellbore: Plan:2S-03 Survey Calculation Method: Minimum Curvature Design: 2S-03wp09[Bamboo] Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") ('•) 9,035.22 6,289.50 7-5/8"X 9-7/8" 7-5/8 9-7/8 2,858.71 2,661.50 10-3/4"x 13-1/2" 10-3/4 13-1/2 16,543.33 6,439.50 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 (°) (°) 9,573.53 6,371.50 A4 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 350.00 350.00 0.00 0.00 KOP:Start 1.5°/100'DLS,20°TF,for 250.18' 600.18 600.00 7.70 2.80 Start 2.5°/100'DLS,0°TF,for 905.86' 1,506.04 1,469.00 227.66 82.86 Hold for 111.64' 1,617.68 1,569.00 274.31 99.84 Start 3.5°/100'DLS, 110.09°TF,for 874.02' 2,491.70 2,350.00 483.32 403.62 Hold for 353.45' 2,845.15 2,650.00 500.66 589.69 Start 2.5°/100'DLS,53.45°TF,for 1001.84' 3,846.99 3,405.65 386.01 1,225.03 Hold for 2394.9' 6,241.89 4,927.97 -270.90 2,953.20 Start 2.5°/100'DLS,89.71°TF,for 2793.33' 9,035.22 6,289.50 -2,266.44 3,976.62 Hold for 20' 9,055.22 6,293.81 -2,285.90 3,974.98 Start 2.5°/100'DLS,55.2°TF,for 344.44' 9,399.66 6,353.33 -2,621.20 3,925.48 Hold for 4.59' 9,404.24 6,353.92 -2,625.64 3,924.54 Start 2.57°/100'DLS,48.72°TF,for 143.73' 9,547.98 6,369.50 -2,764.66 3,891.61 Start 4°/100'DLS,0°TF,for 116.58' 9,664.56 6,374.93 -2,877.27 3,862.03 Hold for 5884.24' 15,548.80 6,409.50 -8,568.39 2,367.32 Start 1°/100'DLS, 179.82°TF,for 150.6' 15,699.40 6,412.36 -8,714.02 2,329.07 Hold for 843.94' 16,543.33 6,439.50 -9,529.83 2,114.73 TD: 16543.33'MD,6439.5'TVD Checked By: Approved By: Date: 11/11/2015 10:35:24AM Page 8 COMPASS 5000.1 Build 74 Pool Report O LO O aSooasN z moo8 r o N U U J U V O F O WK PAM A I H o 4 m 0 U'H N 8-a1-1z nam o O DRIPo C B G G Np L pi p§epi 'W^ $ E m E m m 1111111 O Tmmmm .4 U) 2NtmV NNN 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A,„ \\,/,/: . . .. : \:, ./. , ' • M ; • •O (0 \ , • • I2S-03wp09 Surface Location M CPAI Coordr - ,. , ..'t l, From Ta: Datum: NAD83 _1 Region: [alaska ..;J Datum: NAD27 Region: [alaska .1 C Latitude/Longitude [Decimal Degrees �.f (' Latitude/Longitude [Decimal Degrees ..'_I C UTM Zone: I E South f UTM Zone: True E South State Plane Zone: 4 _T] Units: it;;4 r: State Plane Zone: 1-4--..-1Units: us-ft C Legal Description(NAD27 only) r Legal Description(NAD27 only) i r- Starting Coordinates: Ending Coordinates: X: 1621283.64 X: [481250.323306991 4 Y: 1 5929773.21 Y: 1 5930023.61955052 4 l..w_.__. Transform 1 Quit l Help I 2S-03wp09 Intermediate Casing M. CPAI Coordinate Converter< X From: _.. F To: Datum: 1NA083 •j Region: [ataska ' Datum: [NAD27 • Region: [alaska .[ C Latitude/Longitude [Decimal Degrees f Latitude/Longitude Decimal Degrees —+ ( South t" UTM Zone: True E South UTM Zone: ..__._____ [ ';;.- State Plane Zone: 4 " . Units: us ft—.1 i ( ' State Plane Zone: 4 Units: [us•it . r (- Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: Ending Coordinates: ,. X: 11625254.11 X: 1 485220.854002372 Y: [5927496.92 1 [ Y: 1 5927747.32271591 I. r Transform 11 Quit I Help • • r2S-03wp09 Production Horizon ft CPAI Coordinate Converter ., ,, , •••. L 1.,...14,.. - From: To: Datum: 1NAD83 -ir Region: lalaska , Datum. 1NAD 27 .1 Region: lalaska 2:1 , ...._. Latitude/Longitude Decimal Degrees „ C Latitude/Longitude Decimal Degrees ...:1 r• UTM Zone: 1.--- 1— South r UTM f Zone: rITrue- - E South State Plane Zone: Unts. lus.ft 2:----:] .1 . _l 6- State Plane Zone: 14---_,], Units: Win,. Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: Ending Coordinates: -1 i X: 11625161.31 X: 1 485128.044495359 1 Y: 15926974.35 Y: 1 5927224.76575483 Transform Quit I Help I 2S-03wp09 TD -., ;.... -0 (t) CPAI Coordinate Conve X ,- From- To: Datum: INAD83 ••• Region: lalaska ...77.1 Datum: INAD27 ...I Region: lalaska ,..L1 Latitude/Longitude 'Decimal Degrees 2....,1 r Latitude/Longitude )Decimal Degrees _7.1 UTM Zone: .1 I— South r UTM Zone: r-riirue I— South I .:: State Plane Zone: 17----.,, Units: L,1s.7111 (4'. State Plane Zone: 14---;.1 Units: jus-It Legal Description(NAD27 only) i r Legal Description(NAD27 only) Starting Coordinates Ending Coordinates: ...._, X: 11623374 X: 1 483340.596476826 Y: 15920239 Y: 1 5920489,58890219 t , Transform 1 Quit I Help . • l 2S-03wp09 Surface Location ______I M. CPAI Coordinate Converter "� From: To: Datum: f NAD83 Region: lalaska J Datum: [NAD27 Region: alaska C Latitude/Longitude [Decimal Degrees .3 C Latitude/Longitude [Decimal Degrees .,'.I • UTM Zone: r----- (- South !` UTM Zone: True I- South State Plane Zone: Units: us ft State Plane Zone: True Units: us-ft ✓ Legal Description INt .D27 ort{) (i. Legal Description(NAD27 only) r Starting Coordinates: --- ---..w- ~ _ ---- Legal Description X: 11621283.64 Township: 1 of 0 N . Range: 008 E I Y: 15929773.21 Meridian: lu __..f Section:117 ITN-E. -7..j 13024.1862 FEL 11319.9384 Transform Quit I Help 2S-03wp09 Intermediate Casing M CPAI Coordinate Converter a �u 1 From: To: Datum: INAD83 j Region: lalaska _ml Datum: NAD27 Region: alaska l Latitude/Longitude Decimal Degrees C Latitude/Longitude Decimal Degrees C UTM Zone: I r South r UTM Zone: irrue E South 1`:• State Plane Zone: 4 „ Units: u7..1 „. s C State Plane Zone: True Units: us ft r. Legal Description(NAD27 only) C: Legal Description(NAD27 only) Starting Coordinates: ___ Legal Description X: 1625254.11 Township: 010N .• Range: 008 E ---E: Y: 15927496.92 Meridian: 1U —' Section:121 1. - ,„„ „... „ .. .. FNl • 111.891011 FEl • 12630.1107 Transform Quit l Help I 0 • 2S-03wp09 Production Horizon CPAI Coordinate Converter � a .., � � ^- �� ,la1 ' From: , To: Datum: INAD83 +I Region: 111-5.11;;Z; A f Datum: 1NAD27 71 Region: 'ataska +1 ,_. Latitude/Longitude C Latitude/Longitude 'Decimal Degrees + Decimal Degrees . 9 g C UTM Zone: 1 "' South C" UTM Zone: 'True I- South ( State Plane Zone: IT-1E, Units: usft C`.' State Plane Zone: 11.1,1,1-1;;J, Units: Ius-ftTi C Legal l Deacriptton ftNAD27 only! C+ Legal Description(NAD27 only) 1 Starting Coordinates: ___ Legal Description X: 11625161.31 Township: )070 4 17:111E Range: 008 E + Y: 15926974.35 Meridian: Iu J Section:121 FNL 1534.69216 FEL 12723.1845 Transform Quit I Help I . . _ rP,.r...rr___ rr 2S-03wp09 TD eZ CPA'Coordinate Cott 1 From To: _. _ . . . j Datum: INAD83 . Region: 'alaska _.:_I 1 Datum: INAD27 ..+._! Region: jalaska C Latitude/Longitude 'Decimal Degrees _.:.1 ' C^ Latitude/Longitude 'Decimal Degrees 1 C UTM Zone: E South C UTM Zone: True r South C41` State Plane Zone:R---.,3 Units: us-R C State Plane Zone: 'True :77,�' Units: us-ft C Leggwt Description(NAD27 oniyl f Legal Description(NAD27 only) �.1 Starting Coordinates: i Legal Description -- - - a X: 11623374 Township: 1010 IN Range: 1008 E + ' Y: 15920239 Meridian: IU j Section:128 i_. FML + 11994.2671 FEL • 14514.1009 Transform 1 Quit 1 Help As - built REV DATE BY CK APP 41 ' oc�cxrnon REV DATE BY 0 APP DESCRIPTION 1 5/28/15 SZ JAH Created Drawing Per K14O173ACS i3 12 I m NOTES: - ^ ~ ' ~ u~ _fe CC 1. BASIS OF LOCATION AND ELEVATION IS 0S23 ^ -� � 1 'MONUMENTATION PER LOUNSBURY ASSOC.xSSOC� / ^ 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, °� � - \ ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES -- - __�ARE NAD 27. ^' /p » -- ''..._.__(_,/-----1(/'o ` ~^ yv nn,vww 3. ELEVATIONS ARE B.P.W.5.L " �. "^ ^ ^ 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 17, TOWNSHIP 10 NORTH, RANGE 8 EAST, ^ y���, � 9 � 50 } " "- 7 � •" ‘,=.0 - UN|AT MERIDIAN. ....../ '' % 1---'.0. � ' �/ / =� ,� ` / IS •�- p� / �� " �� � 5. DATES OF SURVEY: 5-2 THRU 5-27-15 FIELD BOOKS - ' , // � e u L15-28, U5-29, L15-32. L15-35 - °/ ° ~`�n ' � / A6:. ` � O. ALL DISTANCES SHOWN ARE TRUE. — ' LOCATION 4- � /����� � �`/ `' � '`�" N }7 `=,„4.:,,,,^ \ 1 27 0. .,�� '� \ ---- ~—, . ` ` �i /- . � |' ' / \ " �� ' 32 31 ~ / ' " , /" � `� � � VICINITY MAP NTS T sd Vv. DS2S -� � ` 4 6 � � O m ® 12 10 � � � � � 21 14 � � * ® 9 7 b ® g 11 13 '',' LEGEND ® AS-BUILT CONDUCTOR LOCATION � 17 16±\ ____ __ ` 20 1 21 GRAPHIC SCALE 0 'mu LOUNSBURY SEE PAGE 2 OF 2 FOR LOCATIONS ` ������~ '.--1, ASSOCIATES, INC. 1 inch = 200 ft. SURVEYORS ENGINEERS PLANNERS 'w INVAREA:2S MODULE: XXXX UNIT: D2 ��~� ����°NN° D�2� �_� 0����o�-������NNNN ��~~� ��=��~�'~ ° ���"� WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6219d24 5/28/15 CE/\—D2SX-6219D24 1 OF 2 1 1REV DATE BY CI< APP DESCRIPTION REV DATE BY l APP DESCRIPTION 1 5/28/15 SZ JAH 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. 0.0. 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 5,929,979.72 481,044.13 70' 13' 11.496" 150' 09' 10.528" 2211' 1526' 111.1' 120.0' 11 5,929,973.68 481,015.40 70' 13' 11.436" 150' 09' 11.362" 2205' 1555' 111.1' 120.0' 12 5,929,968.02 480,986.10 70' 13' 11.380" 150° 09' 12.212" 2199' 1584' 110.9' 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' ®®®®®w®®r, '9F ��•f(S SURVEYOR'S CERTIFICATE ' 49th �� ♦� I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND • LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF 1 - $ ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY ':JEREMIAH F. CORNELL DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT v ': LS-1266 /\§" AS OF MAY 27, 2015. S.F LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: 2S MODULE: XXXX UNIT: D2 ConocoPhilli s DS2S 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-03 Drilling Hazards Summary 13-1/2"Hole/10-3/4"Casing Interval Event I Risk Level I 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 I Risk Level I 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 I Risk Level I 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. • 0 TRANSMITTAL LETTER CHECKLIST WELL NAME: (k, g — o3 PTD: a2/S- gOS ✓Development _Service Exploratory Stratigraphic Test _Non-Conventional FIELD: trj„, /RA/Ed— POOL: k Rs VL,f` K Zitir vrl 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, V 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 • • D co m p , ° a N ° D vi' `Q ma). , rn Q v' , a c r U rn co 0 Z > O' °' a w. w ° �' o m O a c o E 0 N' 0, c6 a - coo ow = v' rn 3. co ° a 0. O as Tc' ° a N' a' cQ c >, o E H -, y Qi caa C. ° N 0 co '43 3 a coEE ' D, CD o. 2' N a a) CD co 0 4 Y, o, N' ' a)' C' D o aM tp ' a ar L y, 3,co 3 0 @ CO N, 3, a. Q' Y' C °, c, o' ay L m' N' _' -7.,' '3 1- `) Jo' ac), I E >� c6 C, ° •�, OJ a), C. ,@,� C y Va a), a) O Q M, cp. CIS a, o, c. w. CO 0 ,CSI p, �, a t, 6 N CO0' MOS Y' J' L, '3, V, 'c� g CO .0 °' - N •-.(5" Cr)� = N m, u), ; -V a) N, �, �, N• N, : �, V, a) a, C, N' y V) co E, _� co i 0 E,. 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O _ N M A N O r b N C9) M NM M M tM O Mr W MO in a) O C '.' "'.' "' o p ce o C 0 Coca a 0 m 0 � p 0)CO W % C 0'E CI - N N ° CS) O 0 e' J #t •c a m c o °7. o_ m 0 tZi ILI, o a s c a > ° a s a. Q Q w Q (.9 Q • • Well History File APPENDIX Infoiniation of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Technical Report Title Date Client: ConocoPhillips Alaska, Inc Field: Kuparuk River Unit Rig: Doyon 25 Date: February 10, 2016 Surface Data Logging End of Well Report 2S-03 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Mud Record 6. Bit Record 7. Morning Reports 8. Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: ConocoPhillips Alaska, Inc. Rig: Doyon 25 Well: 2S-03 Field: Kuparuk River Unit Borough: North Slope Borough State: Alaska Country: United States API Number: 50-103-20729-00-00 Halliburton Job Number: AK-XX-0903107368 Job Start Date: 05 February 2016 Spud Date: 31 January 2016 Total Depth: 8830’ MD, 6251’ TVD North Reference: True Declination: 18.3673° Dip Angle: 80.86° Total Field Strength: 57484.59 nT Date Of Magnetic Data: 04 February 2016 Wellhead Coordinates N: North 70° 13’ 10.813” Wellhead Coordinates W: West 150° 9’ 15.692“ Drill Floor Elevation 159.64’ Ground Elevation: 120.00’ Permanent Datum: Mean Sea Level SDL Engineers: Kyle Wiseman, Ryan Lenberg Company Geologist: Brett Harvey, Ryan Massey Company Representatives: Rob Reinhardt, Kurt Alexa SSDS Unit Number: 105 DAILY SUMMARY 02/05/2016 SDL arrives on location mid-intermediate section as requested. Began rigging up CVE equipment, sensors wiring, ran CVE lines in pits, and umbilical cord from pits to the unit. Warm up and place gas gear in unit. Installed new hose in the CVE delivery pump. 02/06/2016 Setup Halliburton network, work on HalNet and internet connection. Configured WITS connection to and from RigSense. Calibrate and test gas gear. Install suction tube assembly and degasser exhaust on the flow line. 02/07/2016 Calibrate the delivery pump output and test CVE system. Began running CVE and logging the well at approximately 1:30am. Continue drilling ahead in 11" x 9-7/8" intermediate section from 5839' MD to 7516' MD. Gas: Max gas of 245 units formation gas from the upper Cairn and an average of 53 units. Fluids: No significant fluids were lost or gained from hole. 02/08/2016 Drilled ahead from 7516’ MD to intermediate TD at 8830’ MD. Begin pumping out of the hole. Gas: Max gas of 660 units formation gas from 8366’ MD and an average of 236 units. Fluids: No significant fluids were lost or gained from hole. 02/09/2016 SDL personnel released to begin rigging down. Rigged down CVE and pulled lines back to the unit. 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 0 5 Me a s u r e d D e p t h Rig Days Prognosed Actual WELL NAME: 2S-03 OPERATOR: ConocoPhillips Alaska, Inc. MUD CO: MI Swaco RIG: Doyon 25 SPERRY JOB: AK-XX-0903107368 Days vs. Depth 05 February 2016 Sperry SDL Arrived on Location LOCATION: Kuparuk River Unit AREA: North Slope Borough STATE: Alaska SPUD: 31-Jan-2016 TD: 8-Feb-2016 Commenced Logging9.875" Intermediate Hole Section 6000' MD, 4774' TVD On Bot: 01:43 07 Feb 2016 TD Intermediate Hole Section 8830' MD, 6251' TVD Off Bot: 18:43 08 Feb 2016 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: MADI crashed three times with in the last six hundred feet. IRIS continued to record Gas data while MADI was down. Time based data was later used to fill in depth based data. Recommendations: Running too many Insite programs on MADI was not efficient. Limit MADI to WITS and DEX only. Innovations and/or cost savings: A large gauge line was used to vent exhaust from the unit. It was insulated where leaving the unit and checked for freezing periodically. Doyon 25 Intermediate Kyle Wiseman 9-Feb-2016 What went as, or better than, planned: Rigged up CVE without problems. Began recording Gas Data 360' MD above Growler Formation. No issues experence with the CVE. The team also blew back the gas lines and vibrated every connecton. No moisture problems occurred. 2S-03 Kuparuk River Unit CPAI North Slope Borough AK-AM-0903107368 Alaska Surface Data Logging After Action Review Surface Data Logging 2S-03 ConocoPhillips Alaska, Inc. MI Swaco Doyon 25 AK-XX-0903107368 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 5-Feb 3677 9.60 62 14 35 16/17/18 5.0 63/49/42/34/16/15 1/-9.0 1/90 tr 0.38 9.8 7.5 .24/1.20 800 4 Drill Ahead 6-Feb 5551 9.60 53 14 26 12/14/16 3.5 54/40/35/29/12/11 1/-12.5 3/85 0.25 0.40 9.2 23.8 .20/1.10 660 4 Drill Ahead 7-Feb 6610 9.60 51 14 29 12/14/16 3.9 57/43/37/30/14/12 1/-10.0 4/86 tr 0.40 9.5 25.0 .25/1.05 550 4 Drill Ahead 8-Feb 8830 9.60 44 10 23 10/12/16 3.2 43/33/27/23/10/9 1/-11.0 3/86 0.25 0.60 9.4 17.5 1.10/2.00 2150 40 TD Inter. Section. & Pump OOH Casing Record WELL NAME:LOCATION:Kuparuk River Unit OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG:SPUD:31-Jan-2016 SPERRY JOB:TD:8-Feb-2016 Remarks 10.75" Casing @ 2782' MD, 2600'TVD W a t e r a n d O i l B a s e d M u d R e c o r d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 2 100 2 MS1516 PDC 9.875 2790 8830 6040 -0.777 ------Intermediate TD - SDL released Alaska RIG:Doyon 25 SPUD:31-Jan-2016 WELL NAME:2S-03 LOCATION:Kuparuk River Unit OPERATOR:ConocoPhillips Alaska, Inc.AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-0903107368 TD:8-Feb-2016 MI Swaco STATE: B i t R e c o r d . . * 24 hr Recap: Bit #Bit Type 9.875 0.777 2790' 1 PDC TFA Depth in / out 5975' Ss 10.75'' 36 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) 821 127 (max)(current) 1123 0 Cly 907-659-7599Unit Phone: 106 Ryan Lenberg Maximum Report By:Logging Engineers:Kyle Wiseman/Ryan Lenberg 6264 23 0 775 183 Units* Casing Summary Lithology (%) Set AtSize 44.3 L-80 110 0 Siltst 649 - Depth 25.051 in MBT 7516' (ppb Eq) LSND 9.60 GR/RES/Neut/Dens C-5n 7407' 135.0 C-2 118.0 ShClyst 0 - 245 Time: 6620' SPP (psi) Gallons/stroke pH Continue drilling ahead in 11" x 9-7/8" intermediate section f/ 5839' MD t/ 7516' MD. Max gas of 245 u formation gas from the upper 62 5839' 7516' 1677' Max @ ft Current Date: Avg to2790 Gas Summary Yesterday's Depth: Current Depth: 24 Hour Progress: 175.9 Flow In (gpm) Flow In (spm) Rob Reinhardt/Kurt Alexa 24 hr Max Job No.: Daily Charges: Depth Bottoms Up Strokes Bottoms Up Time (mins) 6511 85 (current) 17426 Grade C-5i AK-AM-0903107368 - - Drill 11" x 9-7/8" Inter. PV cP 14 Coal Weight Annular Volume (bbls) Lag Correction (bbls) C-3 9.50 C-4i C-4n Footage Type 0 0 TuffGvl 0 357 Hours Lst 3711531 357 C-1 Size Mud Type 6610' Average 9.60 53Background Surface Casing 764 ECD (ppg) ml/30min 3.929 Cht Silt Min Comments RPM Tools rig -Connection (max) Trip API FL Chromatograph (ppm) 10.0550.00 YP (lb/100ft2) Cement 100% Gas In Air=-10,000 Units Minimum Cairn. 2782' Condition Total Charges: MWD Summary 96% Rig Activity: 12.81 Doyon 25 Report For: ROP ROP (ft/hr) Morning Report Report # 1 Customer: Well: Area: Location: Rig: 2S-03 CPAI Kuparuk 2S Pad 4.23 @ Mud Data Depth Chlorides 10.7010.91 Avg 7-Feb-2016 11:59 PM Current Pump & Flow Data: 2713 Max mg/l WOB 244 43 Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Drilled ahead f/ 7516' MD t/ intermediate TD at 8830' MD. Pumping OOH at report time. 1066 93 8-Feb-2016 11:59 PM Current Pump & Flow Data: 2125 Max mg/l WOB 4.23 @ Mud Data Depth Chlorides 10.5910.89 Avg Morning Report Report # 2 Customer: Well: Area: Location: Rig: 2S-03 CPAI Kuparuk 2S Pad Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: ROP ROP (ft/hr) 2782' Condition 100% Gas In Air=668 10,000 Units Minimum API FL Chromatograph (ppm) 11.02150.00 YP (lb/100ft2) Cement rig -Connection (max) Trip Cht Silt Min Comments RPM Tools ECD (ppg) ml/30min 3.223 0Background Surface Casing 2529 Size Mud Type 8830' Average 9.60 1454 Hours Lst 153613135 1346 C-1 Type 0 0 TuffGvl 0 9.40 C-4i C-4n Footage Weight Annular Volume (bbls) Lag Correction (bbls) C-3 AK-AM-0903107368 - - Pumping OOH PV cP 10 Coal 261 (current) 49864 Grade C-5iDepth Bottoms Up Strokes Bottoms Up Time (mins) 7542 Yesterday's Depth: Current Depth: 24 Hour Progress: 172.0 Flow In (gpm) Flow In (spm) Rob Reinhardt/Kurt Alexa 24 hr Max Job No.: Daily Charges: Date: Avg to2790 Gas Summary 236 7516' 8830' 1314' Max @ ft Current Time: 7838' SPP (psi) Gallons/stroke pH 125.0 ShClyst 0 - 660 C-5n 8366' - C-2 Depth 17.544 in MBT 8830' (ppb Eq) LSND 9.60 GR/RES/Neut/Dens 237 0 Siltst 751.7 0 649 154 Units* Casing Summary Lithology (%) Set AtSize 44.3 L-80 16955 0 0 907-659-7599Unit Phone: 296 Ryan Lenberg Maximum Report By:Logging Engineers:Kyle Wiseman/Ryan Lenberg (max)(current) 3810 0 Cly 49 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) 975.39 145.96 Ss 6040' 10.75'' 8830' Bit #Bit Type 9.875 0.777 2790' 1 PDC TFA Depth in / out WELL INFORMATION Created On : Feb 16 2016 Customer :ConocoPhillips Alaska, Inc. Well Name :2S-03 Job Number :AK-XX-0903107368 Rig Name :Doyon 25 Field Name :Kuparuk River Unit Country :USA Survey Report SURVEY HEADER Survey data provided by Schlumberger. DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 39.64 0.00 0.00 39.64 0.00 N 0.00 E 0.00 0.00 99.00 0.68 307.59 99.00 0.21 N 0.28 W 0.21 1.15 187.00 0.99 308.38 186.99 1.01 N 1.29 W 1.01 0.35 279.00 1.43 323.75 278.97 2.42 N 2.59 W 2.42 0.59 373.00 2.73 352.26 372.91 5.59 N 3.59 W 5.59 1.73 467.00 4.05 3.66 466.74 11.12 N 3.68 W 11.12 1.57 560.00 4.75 8.02 559.47 18.21 N 2.93 W 18.21 0.83 654.00 5.88 10.82 653.06 26.79 N 1.48 W 26.79 1.23 748.00 7.82 21.67 746.39 37.47 N 1.78 E 37.47 2.47 843.00 9.53 23.20 840.30 50.70 N 7.27 E 50.70 1.82 937.00 10.63 22.72 932.85 65.85 N 13.68 E 65.85 1.17 1031.00 12.43 22.65 1,024.95 83.19 N 20.93 E 83.19 1.91 1058.15 13.24 22.22 1,051.42 88.76 N 23.23 E 88.76 3.00 1152.92 15.04 22.94 1,143.31 110.14 N 32.13 E 110.14 1.91 1247.26 17.39 24.50 1,233.89 134.24 N 42.75 E 134.24 2.53 1340.99 21.22 26.16 1,322.34 162.22 N 56.04 E 162.22 4.13 1435.66 24.72 24.77 1,409.49 195.58 N 71.89 E 195.58 3.74 1530.79 25.79 26.03 1,495.53 232.24 N 89.31 E 232.24 1.26 1626.16 26.71 26.08 1,581.06 270.13 N 107.83 E 270.13 0.96 1721.19 27.14 25.69 1,665.79 308.85 N 126.62 E 308.85 0.49 1815.71 27.42 33.73 1,749.82 346.39 N 148.06 E 346.39 3.91 1909.84 27.44 39.74 1,833.39 381.10 N 173.96 E 381.10 2.94 2004.80 25.17 44.51 1,918.52 412.33 N 202.11 E 412.33 3.26 2099.72 24.63 50.47 2,004.63 439.32 N 231.52 E 439.32 2.70 2194.87 25.45 63.12 2,090.90 461.20 N 265.08 E 461.20 5.68 2289.33 27.45 75.16 2,175.53 475.96 N 304.26 E 475.96 6.05 2383.45 30.15 81.07 2,258.01 485.19 N 348.59 E 485.19 4.17 2476.89 32.78 84.16 2,337.71 491.41 N 396.95 E 491.41 3.30 2572.22 32.39 83.70 2,418.04 496.84 N 448.00 E 496.84 0.48 INSITE V8.3.0 Page 1Job No:AK-XX-0903107368 Well Name:2S-03 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2666.25 33.43 89.38 2,497.00 499.88 N 498.95 E 499.88 3.46 2718.88 33.57 90.10 2,540.88 500.01 N 528.00 E 500.01 0.80 2740.81 33.44 88.91 2,559.17 500.12 N 540.10 E 500.12 3.05 2835.17 34.59 89.24 2,637.38 500.97 N 592.88 E 500.97 1.23 2929.75 36.26 90.51 2,714.45 501.08 N 647.70 E 501.08 1.93 3024.24 37.55 92.85 2,790.01 499.40 N 704.40 E 499.40 2.02 3123.14 38.74 94.80 2,867.79 495.31 N 765.34 E 495.31 1.71 3214.24 39.63 97.74 2,938.41 489.01 N 822.54 E 489.01 2.26 3309.20 40.00 100.53 3,011.36 479.35 N 882.56 E 479.35 1.92 3404.39 40.67 103.70 3,083.93 466.41 N 942.78 E 466.41 2.27 3498.42 41.47 107.98 3,154.83 449.54 N 1,002.18 E 449.54 3.11 3593.22 42.19 111.23 3,225.47 428.32 N 1,061.72 E 428.32 2.41 3687.80 42.73 112.40 3,295.25 404.59 N 1,120.99 E 404.59 1.01 3782.58 44.51 111.83 3,363.86 379.98 N 1,181.56 E 379.98 1.92 3876.02 46.65 111.84 3,429.26 355.16 N 1,243.51 E 355.16 2.29 3970.37 49.11 111.83 3,492.53 329.14 N 1,308.47 E 329.14 2.61 4064.96 50.96 111.53 3,553.29 302.36 N 1,375.83 E 302.36 1.97 4159.92 51.11 111.61 3,613.00 275.21 N 1,444.50 E 275.21 0.17 4254.49 51.04 111.55 3,672.42 248.15 N 1,512.91 E 248.15 0.09 4349.76 51.14 111.62 3,732.26 220.88 N 1,581.85 E 220.88 0.12 4444.28 51.04 110.58 3,791.63 194.40 N 1,650.46 E 194.40 0.86 4537.03 51.10 110.61 3,849.91 169.02 N 1,718.00 E 169.02 0.07 4632.40 51.17 109.36 3,909.76 143.65 N 1,787.79 E 143.65 1.02 4726.93 51.25 108.48 3,968.98 119.76 N 1,857.49 E 119.76 0.73 4820.81 51.12 107.74 4,027.82 97.02 N 1,927.01 E 97.02 0.63 4916.59 51.16 106.68 4,087.92 74.95 N 1,998.25 E 74.95 0.86 5010.86 51.21 106.75 4,147.01 53.83 N 2,068.60 E 53.83 0.08 5104.99 51.16 108.16 4,206.01 31.83 N 2,138.56 E 31.83 1.17 5199.04 51.11 109.17 4,265.03 8.39 N 2,207.94 E 8.39 0.84 5294.20 50.68 110.42 4,325.05 16.61 S 2,277.42 E -16.61 1.11 5389.44 50.35 110.08 4,385.61 42.05 S 2,346.38 E -42.05 0.44 5483.64 50.63 110.15 4,445.54 67.05 S 2,414.62 E -67.05 0.30 5578.33 50.50 110.19 4,505.69 92.27 S 2,483.27 E -92.27 0.14 5673.16 50.69 110.02 4,565.89 117.45 S 2,552.08 E -117.45 0.24 5768.21 50.26 110.30 4,626.38 142.72 S 2,620.90 E -142.72 0.51 5862.27 50.50 111.60 4,686.36 168.63 S 2,688.56 E -168.63 1.09 5957.06 50.58 112.53 4,746.60 196.12 S 2,756.39 E -196.12 0.76 6052.13 50.66 112.00 4,806.92 223.96 S 2,824.39 E -223.96 0.44 6146.51 50.54 113.37 4,866.83 252.08 S 2,891.68 E -252.08 1.13 6240.39 50.91 115.50 4,926.26 282.15 S 2,957.84 E -282.15 1.80 6335.37 51.48 118.31 4,985.79 315.64 S 3,023.82 E -315.64 2.38 6430.02 52.39 120.94 5,044.15 352.48 S 3,088.59 E -352.48 2.39 6524.27 53.03 123.81 5,101.26 392.63 S 3,151.90 E -392.63 2.52 6619.02 53.35 126.21 5,158.04 436.15 S 3,214.02 E -436.15 2.06 6714.34 53.80 129.47 5,214.65 483.19 S 3,274.57 E -483.19 2.79 INSITE V8.3.0 Page 2Job No:AK-XX-0903107368 Well Name:2S-03 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6807.69 54.04 131.29 5,269.63 532.07 S 3,332.04 E -532.07 1.60 6903.31 54.07 132.88 5,325.76 583.95 S 3,389.49 E -583.95 1.35 6998.16 54.06 134.25 5,381.42 636.88 S 3,445.13 E -636.88 1.17 7092.00 53.69 136.83 5,436.75 690.97 S 3,498.22 E -690.97 2.26 7187.22 53.68 139.66 5,493.15 748.19 S 3,549.30 E -748.19 2.39 7281.99 53.43 143.08 5,549.46 807.73 S 3,596.89 E -807.73 2.91 7376.46 53.37 146.53 5,605.80 869.69 S 3,640.59 E -869.69 2.93 7470.40 54.03 150.02 5,661.42 934.08 S 3,680.38 E -934.08 3.08 7565.20 54.64 153.46 5,716.71 1,001.90 S 3,716.83 E -1001.90 3.02 7659.92 54.58 156.32 5,771.57 1,071.81 S 3,749.60 E -1071.81 2.46 7755.31 54.76 158.29 5,826.74 1,143.60 S 3,779.62 E -1143.60 1.70 7851.51 54.93 159.69 5,882.13 1,217.02 S 3,807.81 E -1217.02 1.20 7944.13 57.65 160.82 5,933.53 1,289.53 S 3,833.83 E -1289.53 3.11 8037.87 61.20 162.16 5,981.20 1,366.06 S 3,859.43 E -1366.06 3.98 8134.96 65.11 163.68 6,025.04 1,448.85 S 3,884.85 E -1448.85 4.26 8227.49 67.60 165.32 6,062.15 1,530.52 S 3,907.49 E -1530.52 3.14 8321.13 69.49 167.84 6,096.41 1,615.28 S 3,927.70 E -1615.28 3.22 8416.49 71.30 170.93 6,128.41 1,703.56 S 3,944.23 E -1703.56 3.59 8511.46 72.15 172.50 6,158.19 1,792.80 S 3,957.22 E -1792.80 1.81 8606.43 72.76 174.79 6,186.82 1,882.79 S 3,967.24 E -1882.79 2.39 8701.25 73.21 177.13 6,214.57 1,973.22 S 3,973.62 E -1973.22 2.41 8756.84 74.39 178.49 6,230.08 2,026.57 S 3,975.66 E -2026.57 3.17 8830.00 75.50 181.00 6,249.09 2,097.21 S 3,975.97 E -2097.21 3.64 DIRECTIONAL SURVEY DATA NOTES - Calculation based on minimum curvature method. - Survey coordinates relative to well system reference point. - TVD values given relative to drilling measurement point. - Vertical section relative to well head. - Vertical section is computed along a direction of 0.00 degrees (Magnetic) - A total correction of 0.00 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 8,830.00 feet is 4,495.18 feet along 117.81 degrees (Magnetic) INSITE V8.3.0 Page 3Job No:AK-XX-0903107368 Well Name:2S-03 Survey Report WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V8.3.0 Page 4Job No:AK-XX-0903107368 Well Name:2S-03 Survey Report
