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216-074
• • 214_ G—t -( ,�,-- RECEIVED ConocoPhillips SEP 2 6 2017 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 September 24, 2017 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name,top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sin rely, Roger Winter I :'1 ConocoPhillips Well Integrity Field Supervisor ti i • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 9/25/2017 2S pad i Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 2S-05 501032073900 216-039-0 22" 0.05 11" 6/7/2017 1.7 9/10/2017 2S-06 501032074700 216-085-0 4' 0.25 15" 6/10/2017 3.4 9/10/2017 2S-07 501032071300 215-079-0 22" 0.16 11" 6/7/2017 3.4 9/10/2017 2S-08 501032072200 215-174-0 17" 0.10 13" 6/7/2017 3.4 9/10/2017 2S-09A 501032074901 216-128-0 39" 0.30 12" 6/10/2017 4.25 9/20/2017 2S-10 501032071700 215-110-0 10' 1.50 9" 6/10/2017 1.7 9/10/2017 2S-11 501032073200 215-219-0 20" 0.10 10" 6/7/2017 3.4 9/10/2017 2S-12 501032074300 216-074-0 25" 0.10 13" 6/7/2017 4.8 9/10/2017 2S-13A 501032072001 216-104-0 30" 0.40 9" 6/7/2017 3.4 9/10/2017 2S-14 501032073300 215-220-0 27" 0.24 12" 6/7/2017 3.9 9/10/2017 • e 1 . . _ OO O t N • Cn 9 a * . , w .-. 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CO ° (/) T p 2• O 0,‘ N a) r aEw V O 0 d 0 T I J EI so Q N E T ° 0. cal r ch H 0 11‘ G M4111WW d' r Y0 co Q o Y ° r Y f-') 11 Q ° E G z• ° ' E 04 z d • co CON 0 0 . > m o ~ V CD 3 T I N d • co I W D (0 o 1 N t0i o « c U ° m to U E .a c7 co 0 E E 0 a 2 0 10 10 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS. REPORT OF SUNDRY WELL OPERATIONS 2 7 5 4 9 1.Operations Abandon la Plug Perforations ra Fracture Stimulate F Pull Tubing la Operations Shutdown Performed: Suspend E' Perforate fa Other Stimulate l Alter Casing la Change Approved Program E Plug for Redrill la Perforate New Pool l Repair Well la Re-enter Susp Well E n 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratoryla 216-074-0 3.Address: 6.API Number: Stratigraphic 1— Service P. O. Box 100360,Anchorage,Alaska 99510 50-103-20743-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 2677,ADL 2681 KRU 2S-12 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 13638 feet Plugs(measured) None true vertical 6263 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 8013, 8084 true vertical 0 feet (true vertical) 6109,6131 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 107 107 SURFACE 2817 11.8 2845 2557 INTERMEDIATE 8211 10 3/4 8239 6177 LINER 3807 41/2 11891 6276 RECEIVED ED Perforation depth: Measured depth: 8908,9466, 10027, 10667, 11345, 11745, AUG 2 3 2016 True Vertical Depth: 6290,6288,6293,6283, 6261,6268 AOGCC Tubing(size,grade,MD,and ND) 3.5, L-80, 8109 MD, 6139 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER PREMIER PRODUCTION PACKER @ 8013 MD and 6109 TVD PACKER-BAKER HRD-E ZXP FLEX LOCK LINER TOP PACKER @ 8084 MD and 6131 TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): 11745' MD, 11345' MD, 10667' MD, 10027' MD, 9466' MD, 8908' MD Treatment descriptions including volumes used and final pressure: Total Well -6 stages, placed 605,045 lbs 16/20 Proppant and 37,200 lbs 100 mesh ...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 0 500 1900 Subsequent to operation 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: � Daily Report of Well Operations F Exploratory Development 17 '., Service fa Stratigraphic l' Copies of Logs and Surveys Run ra lJ"y,1 16.Well Status after work: Oil F Gas E WDSPL fl Printed and Electronic Fracture Stimulation Data '+ GSTOR E WINJ r WAG la GINJ fa SUSP ra SPLUG 1- 17. 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: 316-358 Contact Mick Davasher(a,265-6870 Email mick.j.davasher(a�conocophillips.com Printed Name Mick Davasher Title Completions Engineer Signature Phone:263-4612pate W1-9._ /2'1- f7 11 V Form 10-404 Revised 5/2015 VTL q/Z// C- RBDMS LU AUG 2 5 2016 Submit Original Only c- J `1/7/2,0t c. ,oef 947, • • 2S-12 DTTMS.JOBTYP SUMMARYOPS 7/16/16 FRACTURING SET BAITED PT ON BALL AND ROD @ 8029' RKB, PULL SOV @ 7937' RKB& REPLACE WITH DV, PERFORM PASSING MIT'S ON TBG & IA, PULL BAITED BALL AND ROD @ 8029' RKB, PULL RHC PLUG BODY @ 8029' RKB, JOB COMPLETE. READY FOR FRAC. 7/20/16 FRACTURING ASSIST WITH FRACAS DIRECTED 7/20/16 FRACTURING Finished rigging up frac equipment. Pressure tested equipment and treating lines to 9500 psi. Sheared open Alpha sleeve (sleeve opened @ 6375 WHTP; able to inject into well at 1.0 BPM @ 1900 psi). Secure well &equipment for upcoming frac in A.M. 7/21/16 FRACTURING ASSIST WITH FRAC AS DIRECTED 7/21/16 FRACTURING Pumped stages 1-6 placing all proppant as designed. Pumped total 605,045 lbs 16/20 carbolate. Job complete. 7/23/16 FRACTURING BRUSH N' FLUSH TBG TO 4400' SLM; DRIFTED W/2.78" DMY PLUG. CORRELATE TO GLM @ 4095' RKB. SET 2.725" PII RBP (PLUG MID ELEMENT @ 4127' RKB) MITT TBG TO 3000 PSI ( PASS) DDT ON TBG ( PASS) DEPLOYED 7/23/16 PUMPING ASSIST SLICKLINE TRACKING ONLY 7/26/16 FRACTURING (MISC) : TESTED BPV TO 1000 PSI PASSED, POT-T PASSED, PPPOT-T PASSED, INTERMEDIATE POT-T PASSED, INTERMEDIATE PPPOT-T PASSED, POT-IC PASSED, PPPOT-IC PASSED, DDT-T/IA PASSED, C/O TREE, SHELL TESTED TREE PASSED. 7/28/16 FRACTURING ASSIST SLICKLINE AS DIRECTED 7/28/16 FRACTURING PULLED CATCHER &3 1/2 RBP @ 4127' RKB; MEASURED BHP @ 8486' RKB; SET 2.75" CSV @ 8029' RKB. JOB SUSPENDED DUE TO CEMENT OPERATIONS ON RIG. 7/30/16 FRACTURING SET GLV @ 4102' RKB; REPLACE DV IN KIND @ 7688' RKB; PULLED DV&SET OV @ 7937' RKB; PULLED CSV @ 8029' RKB. • • Hydraulic Fracturing Fluid Product Component Information Dis sure Job Start Date: 7/20/2016 Job End Date: 7/21/2016 State: Alaska -44110110, County: Harrison Bay API Number: 50-103-20743-00-00 Operator Name: ConocoPhillips Company/Burlington Resources Disciaraxe t`y Well Name and Number: 2S-12 Latitude: 70.21951700 Longitude: -150.15648900 Ci LATER Datum: NAD83 OEstsc Federal Well: NO �M Indian Well: NO True Vertical Depth: 402,241 Total Base Non Water Volume: 0 HYcrn . rn :Laing Ruiti Congoosilionz Chemical Maximum Maximum Ingredient Ingredient Trade Name Supplier Purpose Ingredients Abstract berviceConcentration in Concentration in Comments Number Additive HF Fluid (CAS#) (%by mass)" (%by massy*. Sea Water Operator Base Fluid Seawater NA 100.00000 83.540570ensity=8.45 ppg CarboLite 16/20 Carbo Ceramics Inc 'roppant NA NA SS-200 Halliburton Proppant NA NA 3E-6 MICROBIOCIDE,Halliburton Additive,Biocide, CL-22 UC,CL-31 Breaker,Crosslinker, CROSSLINKER, Selling Agent, _OSURF-300D,MO- Microbiocide,Non- 57,OPTIFLO-Il ionic Surfactant,pH DELAYED RELEASE Control Additive, BREAKER,OPTIFLO- 'roppant II DELAYED RELEASE BREAKER, SAND-COMMON WHITE-100 MESH, SSA-2,100 LB SACK ;100002158),SP BREAKER,WG-36 GELLING AGENT NA NA • • Ingredients shown above are s„blect to 29 CFR 1910 1200(11 and appear on Material Safety Data Sheets(tr1SDS),ingredients shown below are Non-MSDS. azardous and Non- Hazardous Ingredients Ceramic materials and wares, 66402-68-4 100.00000 14.78644 chemicals Crystalline silica,quartz 14808-60-7 100.00000 1.05327 Guar gum 9000-30-0 100.00000 0.32390 Nater 7732-18-5 100.00000 0.11135 Potassium formate 590-29-4 60.00000 0.06238 Borate salts Confidential 60.00000 0.06232 Ethanol 64-17-5 60.00000 0.04425 Potassium metaborate 13709-94-9 60.00000 0.03057 Oxyalkylated phenolic resin Confidential 30.00000 0.02950 Heavy aromatic petroleum 64742-94-5 30.00000 0.02212 naphtha Ammonium persulfate 7727-54-0 100.00000 0.02205 Bentonite,benzyl(hydrogenated 121888-68-4 5.00000 0.01619 allow alkyl)dimethylammonium stearate complex Sodium hydroxide 1310-73-2 30.00000 0.01488 Cured acrylic resin Confidential 30.00000 0.00661 Surfactant mixture Confidential 1.00000 0.00648 Naphthalene 91-20-3 5.00000 0.00369 Poly(oxy-1,2-ethanediyl),alpha- 127087-87-0 5.00000 0.00369 (4-nonyl phenyl)-omega- hydroxy-,branched Silica gel 112926-00-8 1.00000 0.00324 Potassium hydroxide 1310-58-3 5.00000 0.00255 2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00000 0.00162 Sodium chloride 7647-14-5 1.00000 0.00154 Sodium glycollate 2836-32-0 1.00000 0.00104 Acrylate polymer Confidential 1.00000 0.001040enise Tuck,Halliburton, 3000 N.Sam Houston Pkwy E., Houston,TX 77032,281- 871-6226 Sodium carboxymethyl cellulose 9004-32-4 1.00000 0.00104 1,2,4 Trimethylbenzene 95-63-6 1.00000 0.00074 Crystalline Silica,Quartz 14808-60-7 0.10000 0.00032 Sodium persulfate 7775-27-1 100.00000 0.00012 Sodium sulfate 7757-82-6 0.10000 0.0000C *Total Water Volume sources may include fresh water,produced water,and/or recycled water **Information is based on the maximum potential for concentration and thus the total may be over 100% Note:For Field Development Products(products that begin with FDP),MSDS level only information has been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i)and Appendix D are obtained from suppliers Material Safety Data Sheets(MSDS) KUP PRC • 2S-12 ConocoPhillips :,-'a Well Attributes Max Angle&MD TD .lkAlaska.Inc Wellbore API/UWI Field Name Wellbore Status ncl I°I MD(ftKB) Act Btm(ftKB) conoutPhilhps 501032074300 KUPARUK RIVER UNIT PROD 95.76 13,535.43 13,638.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-2S-12,8/23/2316628:27 AM SSSV: NONE Last WO. 27.50 7/9/2016 Vertical schematic(scamp Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:STIM 8 TREATMENT pproven 8/22/2016 HANGER;255 1�P, t Casing Strings "® Casmg Descnption OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I. Grade Top Thread CONDUCTOR 16 15.060 27.5 107.5 107.5 62.58 B cut off Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I_Grade Top Thread SURFACE 10 3/4 9.950 28.6 2,845.5 2,556.7 45.50 L-80 HYD 563 Casing Description INTERMEDIATE OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 7 5/8 6.875 27.7 8,239.0 6,177.2 29.70 L-80 Hyd 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread X0 Reducing;59.2 f LINER 4 1/2 3.958 8,084.4 11,891.1 6,275.6 12.60 L-80 Hyd 563 i. Liner Details Nominal ID -6,. CONDUCTOR;27.5-107.5.eNv- +.t-. Top(ftKB) Top(TVD)(MB) Top Incl yl Item Des Com (in) r 8,084.4 6,131.3 7205 PACKER Baker HRD-E ZXP 5.5"x 7.63"Flex-Lock Liner top 4.810 packer L-80 Hyd 563 pin SURFACE;28.6-2,845.5--411 8,104.2 6,137.4 7219 NIPPLE Baker 5.5""RS"Packoff Seal Nipple 17#Q-125 4.250 Hyd 563 box obox I`I 8,106.5 6,138.1 72.21 HANGER Baker 5.5"x 7.63"Flex-Lock Liner hanger P-110 4.800 GAS LIFT;4,094.6 - Hyd 563 pin x On 8,115.7 6,140.9 72.28 XO Crossover 5.5"Hyd 563 box x 4-1/2"Hyd 563 3.890 8,683.8 6,278.7 81.76 SWELL Baker-"Swell Packer"-#i SN:50794-002-9 3.900 PACKER 1 ,£ 8,908.1 6,289.9 90.72 FRAC PORT Baker 4W 5th Frac Sleeve#9-(2.438"Ball,Drift w/ 2.406 GAS LIFT,7,688.5 2.375")PN:10437085 9,201.7 6,286.9 89.94 SWELL Baker-"Swell Packer"-#6 SN:50794-002-14 3.900 I :PACKER GAS LIFT;7,938.6 9,466.1 6,288.1 89.58 FRAC PORT Baker 4%"4th Frac Sleeve#8-(2.375"Ball,Drift w/ 2.343 2.313") PN:10437084 SLIDING SLEEVE,7,964.2 f 9,722.6 6,290.0 89.58 SWELL Baker-"Swell Packer"-#D SN:50794-002-11 1900 Pump Sensor,8, 3.3 PACKER X0 Threads;8,003 410,027.0 6,292.7 89.49 FRAC PORT Baker 4W 3rd Frac Sleeve#7-(2.313"Ball,Drift w/ 2.281 PACKER,8,012.8 I ■ 2.250") PN:10437083 xoThreads,8519.5 10,322.9 6,292.9' 90.99 SWELL Baker-"Swell Packer"-#C SN:50794-002-8 3.900 NIPPLE;8,029.0 PACKER 10,667.3 6,283.2 92.42 FRAC PORT Baker 4W 2nd Frac Sleeve#6-(2.25"Ball,Drift w/ 2.218 2.188") PN:10437082 t 10,925.2 6,273.1 91.01 SWELL Baker-"Swell Packer"-#B SN:50794-0027 3.900 LOCATOR;8,078.2 ( PACKER LOCATOR;8,079.2 11,345.3 6,261.2 92.46 FRAC PORT Baker 4-1/2" 1st Frac Sleeve#5-(2.188"Ball,Drift 2.135 w/2.125")PN:10437089 11,602.3 6,260.6 87.93 SWELL Baker-"Swell Packer"-#A SN:50794-002-15 3.900 fil a PACKER SHOE.e,108.7 11,736.0' 6,267.3 85.52 XO 4-1/2"12.6 ppf L-80 x-o Pup Jt,Hyd 563 box x BTC 3.958 pin 11,745.4 6,268.1 85.44 FRAC PORT 4-1/2"Baker Alpha Pressure Sleeve 3.010 i I] 11,749.1 6,268.4 85.51 XO 4-1/2"12.6 ppf L-80 x-o Pup Jt,BTC box x BTC pin 3.958 11,758.8 6,269.1 85.68 SLEEVE 4-1/2"Baker Wellbore Isolation Valve(H036784300) 2.938 ' INTERMEDIATE;27.7-8,239.0-4 11,761.8 6,269.3 85.74 XO 4-1/2"12.6 ppf L-80 x-o Pup Jt,BTC box x BTC pin 3.958 11,848.6 6,274.6 87.62 COLLAR 4-1/2"12.6 ppf L-80 Weatherford Float Collar 3.885 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..r Set Depth(TVD)(...Wt(Ib/rt) Grade Top Connection TUBING 31/2 2.992 25.5 8,109.7 6,139.0 9.30 L-80 EUE-m Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Inci(°) Item Des Com (in) 25.5 25.5 0.07 HANGER Cameron 11"x 4-1/2"IBT-m Tubing Hanger 3.900 582 58.2 0.17 XO Reducing XO,4-1/2"12.68 L-80 IBTM box x 3-1/2"9.3#L-80 EUE 3.063 pin 7,964.2 6,093.5 71.30 SLIDING Baker 3W CMU in closed position w/2.813"DS Profile 2.813 SLEEVE 7,988.3 6,101.2 71.43 Pump Sensor Schlumberger Gauge Carrier 3W EUE P X P 2.913 C13GM0181 1 8,012.8 6,108.9 71.57 PACKER Baker Premier Production Packer 659-287 2.880 i 8,029.1 6,114.0 71.66 NIPPLE Camco 2.75 D nipple 4,5"OD w/RHC plug body(73°) 2.750 8,078.2 6,129.4 72.01 LOCATOR Baker 7.625"x 3.5"Shear pinned Fluted No-Go Sub- 3.000 Hyd Frac-Gell0250/0r:8,908.1 Large OD 11 8,079.2 6,129.7 72.01 LOCATOR Baker 7.625"x 3.5"Shear pinned Fluted No-Go Sub- 3.000 small OD 8,108.7 6,138.7 72.23 SHOE Mule shoe WLEG,3-1/2"IBT box 3.000 Stimulations&Treatments Min Top Max Ben Depth Depth Top(TVD) Btm(TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 8,908.1 11,758.8 6,289.9 6,269.1 Hyd Frac- 7/21/2016 Pumped minifrac and stages 1-6 placing 605,0451bs Gelledwater 16/20 proppant 37,200lbs 100 Mesh. Mandrel Inserts St ati N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com i HI 1 4,094.6 3,497.8 Camco KBMG 2 7,688.5 5,996.2 Camco 1 GAS LIFT GLV BK 0.188 1,903.0 7/30/2016 - KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 7/30/2016 3 7,936.6 6,084.6 Camco KBMG 1 GAS LIFT OV 'BKO-3 ' 0.313 0.0 7/30/2016 LINER;8,084.4-11,891.1 I HALLIEPURTONSfirrry Drilling RECEIVED 2 1 60 74 AUG 11 2016 2 7 4 7 1 AOGCC WELL LOG/DATA TRANSMITTAL To: Makana Bender August 8, 2016 AOGCC 333 W. 7th Ave., Suite 100 DATA LOGGED Anchorage, Alaska 99501-3539 e6/Ix/201(9 M.K.BENDER LWD Cement Evaluation Logs—2S-12 AK-MW-0903356037 LWD Cement Evaluation Logs-2S-12(50-103-20743-00-001 1"MD&5" MD LWD Cement Evaluation Logs 1 Color Print Digital Data: CD ROM disc 1 Disc Digital data LAS v2.0 Digital graphic logs in EMF, CGM, PDF, and TIFF formats PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Ben Schulze 6900 Arctic Blvd. Anchorage,Alaska 99518 Office:907-273-3536 Benjamin.Schulze@)halliburton.com Date: Signed: 644,tedt 21 6074 rlilli TRANSMITTAL DATA LOGGED %/2./201‘ M.K.BENDER FROM: Sandra D. Lemke, AT0704 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 2S-12 & 2S-12PB1 DATE: 08/01/2016 Transmitted: Kuparuk River Unit, Alaska 2S-12 27 448 2S-12PB1 2 7 4 4 9 1 CD (.pdf) &1 color prints each log: 2" MD Formation Evaluation log 2" MD Drilling Engineering log 2" MD Gas ration log Please promptly sign, scan and return electronically to Sandra.D.LemkePConocoph/ilips.com CC: 2S-12 transmittal folder, production well files, eSearch Receipt: /'22.4L11_ftdL#' .' u GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska Ph: 907265.6947 p • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil El • Gas❑ SPLUG❑ Other E Abandoned ❑ Suspended ❑ lb.Well Class: 20aac 25.105 20AAC 25.110 Development E . Exploratory ❑ GINJ ❑ WINJ❑ WAG❑ WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6.Date Comp.,Susp.,or 14.Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 7/9/2016 216-074/ f 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 6/8/2016 50-103-20743-00 • 4a. Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 3080'FNL, 1584'FEL,Sec 17,T1ON,R8E, UM 6/30/2016 KRU 2S-12/2S-12PB1 . Top of Productive Interval: 9. Ref Elevations: KB:147.e. 17. Field/Pool(s): 3466'FNL,534'FEL,Sec 18,T1ON, R8E, UM GL: 120 BF: Kupurak River Field/Kuparuk Oil Pool v Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 2991'FNL, 1798'FEL,Sec 19,T1ON, R8E, UM 12303/6244 . ADL 25603,ADL 25608 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 480986 y- 5929968 Zone- 4 13638/6263 - 2677,2681 TPI: x- 476757 y- 5929594 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 475495 y- 5924794 Zone- 4 N/A 1425/1405 5. Directional or Inclination Survey: Yes Q (attached) No ❑ 13.Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) I 11900/6276 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,ED . elry,and perforation record. Acronyms may be used.Attach a separate page if necessary REC E I V GR/Res/Neut/Dens/Sonic Casing/Mud Log JUL 2 9 72016 AOGCC 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 16 62.5 B 27 107 27 107 24 61 sx AS1 10 3/4 45.5 L-80 28 2845 28 2557 13.5 1214 SX 11.0ppg LiteCrete 7 5/8 29.7 L-80 28 8239 28 6177 9.875 Stagel:663 sx 15.8ppg ClassG Stage2:302 sx 15.8ppg ClassG 4 1/2 12.6 L-80 8084 11891 6131 6276 6.75 n/a 24.Open to production or injection? Yes 2 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 1/2 _ 8110 8013/6110 FRAC PORT-8908 MD,6290 ND 8084/6131 FRAC PORT-9466 MD,6288 ND COMPLETION 26.ACID, FRACTURE,CEMENT SQUEEZE,ETC. FRAC PORT-10027 MD,6293 ND f.)AT Was hydraulic fracturing used during completion? Yes❑ No 2 FRAC PORT-10667 MD,6283 ND VliggiLe FRAC PORT-11345 MD,6261 NDPer 20 AAC 25.283(i)(2)attach electronic and printed information FRAC PORT-11745 MD,6268 ND w�RIF1E0 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): Waiting for Hook-Up Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period - Flow Tubing Casino Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate Form 10-407TReevviised 11//220152 V72 c3/26`/G d f� IT TI ON PAGE 2 RBDMS �V JUL 2 9 206 ubmit ORIGINIAL only • • 28.CORE DATA Conventional Core(s): Yes ❑ No 2 Sidewall Cores: Yes ❑ No r] If Yes,list formations and intervals cored(MD/TVD,From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 0 Permafrost-Top Surface Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1428 1406 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 8661 6275 information, including reports,per 20 AAC 25.071. Top W Sak 1895 1822 Base W Sak 2768 2498 C-80 3267 2874 C-37 5683 4696 HRZ 7595 5958 Top Upper Kalubik 7923 6080 Top Lower Kalubik 8215 6170 Kuparuk A 8612 6266 Kuparuk A 13556 6272 Kuparuk C 13589 6268 Formation at total depth: Kalubik 31. List of Attachments: Daily Operations Summary,Definitive Survey,Cement Report,Schematics Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, oaleontoloaical 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: Scott Brunswick(a7 263-4249 Email: scott.a.brunswick(cilcop.com Printed Name: G.L.Alvord Title: Alaska Drilling Manager Signature: LVbi 1) Phone: 265-6120 Date: INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 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 lb: 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 • • 2S-12 ConocoPhillips Grassroots Horizontal A-Sand Producer Wellbore Schematic (wp10.1 -D141 RKB) ! J t CAMERON Last Edited: ) 4-W tree,top joint iso-''/,"12.6#IBTM Davasher 7/8/16 16"Conductor to-107.5' g ;TT 1 13.5" Surface Hole v ' 1 Base West Sak:2,797'MD 12,519'ND 3'h"x1'/="CamcoMMGGLM Surface Casing 10-3/4"45.5#L-80 Hydril 563 2,845'MD/2,569'TVD(41.6' INC) . 9-7/8"x 11" Intermediate Hole 4 Tubing: 3-1/2" 9.3#L-80 EUE 8RD-MOD J GLM w/ :7 SOV :h 2'Stage TOC= 500'MD above C-37 Formation at 5,272'MD :, ? ....................... .......'. '.— -:':':::::::::::::'::::'-:::-::".:/'???ii:O»»::iJ:•»>???i?i?iiiii:.:iii:•:.,i: :., v.•::::::r.;'ilp::::: .4:::::.::.... , .. i • •Iii •••••:•:-..' : 1Noathe oid:St ecolia?:,6:r72'MD >:':.:..,:,:,:.:>G 37- fl'22 NO1414r tVtlt>: >:i a l Stage Tac:,_,..A.1) >/—BerinLdalCalrn formation) Kawier C ,,, ,-.,• • ryt� a ''' i7/. v \\\ \ ,v\v\� `+ Baker2.812"CMU.Sliding Cairn 6+ItffIS-4N''"'�VD'. 4y' g Sleeve SLB DHC j' �3-'4".k 7•5l8",Premier Packer Bermuda:5 95' ll 5,571 '' 3/"2.75"D Nipple —. , ,1 N .--.- /.a yl.., . M°15'967. , 93' ND Kalubik:8,048'MD 16,107'TVD . � , •,. .....,,,,/,::„„4,<*,. 5.75"x,4-'s":Swell Packer `1 Kuparuk C:8,744'MD/6.272'ND r .� , i\ , - -_ Kuparuk A4:8,833'MD/6,282'ND-11.2 ppg-_M_ 3-*/731ver"'--- 7-5/8"x 5-'/:"Baker ZXP -S / 1.; 17 - --�--- ),< — ~� ~;ilHet Shoe T • .' Packer/Flex Lock Liner i • Hanger(8,073'MD/6133' ND) ``,____C61_ �'< ®---- Alpha and TO:13,638'MD 16,263'NO la Intermediate Casing Production Liner: 6-3/4" Production Hole 7-5/8"29.7#L-80 Hyd563 Casing 4-1/2"12.6#L-80 HYD563 8,239"MD/6,177'ND(78°INC) 11,878'MD/6,275'TVD lir' PROD • 2S-12 Conoc©Phillips Well Attributes Max Angle&MD TD Alaska(11 Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) crnarnPPtralprOw 501032074300 KUPARUK RIVER UNIT PROD 95.76 13,535.43 13,638.0 --. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-2S-12,7/28/20162;06;32 PM SSSV:NONE Last WO: 27.50 7/9/2016 verncalschematc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason: NEW WELL;GLV C/O lehallf 7/29/2016 HANGER 255-. r.:. _ Casing Strings " "` "`mom Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread CONDUCTOR 16 15.060 27.5 107.5 107.5 62.58 B cutoff ................-._.........._......_.__._.._ - "-Casin Oestri t W n ID(in) TopftKB Set Depth ftKB Set Depth(TVD)...WULen(I...Grade TopThread 9 Pion (i) ( ) (ftKB) SURFACE 10 3/4 9.950 28.6 2,845.5 2,556.7 45.50 LAM HYD 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread INTERMEDIATE 7 5/8 6.875 27.7 8,239.0 6,177.2 29.70 L-80 Hyd 563 Casing Description OD(in) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread XO Reducing;58.2 pw: LINER 41/2 3.958 8,084.4 11,891.1 6,275.6 12.60 L-80 Hyd 563 Liner Details Nominal ID ,..A-A-/CONDUCTOR 27.5-107.5 A sr.' Top(ftKB) Top(TVD)(MB) Top Incl(°) Item Des Com (in) 8,084.4 6,131.3 72.05 PACKER Baker HRD-E ZXP 5.5"x 7.63"Flex-Lock Liner top 4.810 packer L-80 Hyd 563 pin SURFACE;28.6-2,845.5 + 8,104.2 6,137.4 72.19 NIPPLE Baker5.5""RS"Packoff Seal Nipple 17#0-125 4.250 Hyd 563 box x box 8,106.5 6,138.1 72.21 HANGER Baker 5.5"x 7.63"Flex-Lock Liner hanger P-110 4.800 GAS LIFT;4,094.6 -:. Hyd 563 pin x pin IR 8,115.7 6,140.9 72.28 XO Crossover 5.5"Hyd 563 box x 4-1/2"Hyd 563 3.890 { 8,683.8 6,278.7 81.76 SWELL Baker-"Swell Packet"-#i SN:50794-002-9 3.900 PACKER 8,908.1 6,289.9 90.72 FRAC PORT Baker 4W 5th Frac Sleeve#9-(2.438"Ball,Drift w/ 2.406 GAS LIFT;7,659.5 : 2.375")PN:10437085 i9,201.7 6,286.9 89.94 SWELL Baker-"Swell Packer-#E SN:50794-002-14 3.900 t PACKER GAS LIFT;7,936.6 ..r.. ' 9,466.1 6,288.1 89.58 FRAC PORT Baker 41/2"4th Frac Sleeve#8-(2.375"Ball,Drift w/ 2.343 SLIDING SLEEVE;7,9642 2.313")PN:10437084 tall � + 9,722.6 6,290.0 89.58 SWELL Baker-"Swell Packet'-#D SN:50794-002-11 3.900 Pump Sensor 7,988.3 PACKER xo Threads 8,003. 1; 10,027.0 6,292.7 89.49 FRAC PORT Baker 4h"3rd Frac Sleeve#7-(2.313"Ball,Drift w/ 2.281 PACKER;8,012.8 2.250")PN:10437083 XO Threads;8,019.5 Bat&Rod;8,020.0 t 1- 10,322.9 6,292.9 90.99 SWELL Baker-"Swell Packer"-#C SN:50794-002-8 3.900 NIPPLE;8,029.e ,' U,„ PACKER °t RHC Plug Body;8,025.0, 1. 10,667.3 6,283.2 92.42 FRAC PORT Baker 4%"2nd Frac Sleeve#6-(2.25"Ball,Dug w/ 2.218 171 2.188")PN:10437082 , 10,925.2 6,273.1 91.01 SWELL Baker-"Swell Packet'-#B SN:50794-002-7 3.900 i,.. „ PACKER LOCATOR;8,078.211,345.3 6,261.2 92.46 FRAC PORT Baker4-1/2"1st Frac Sleeve#5-(2.188"Ball,Drift 2135 LOCATOR;8,079.2 w/2.125")PN:10437089 11,602.3 6,260.6 87.93 SWELL Baker-"Swell Packer"-#A SN:50794-002;15 3.900 PACKER 11,736.0 6,267.3 85.52 XO 4-1/2"12.6 ppf L-80 xo Pup Jt,Hyd 563 box x BTC 3.958 0406:0,100.7 tI: pin 11,745.4 6,268.1 85.44 FRAC PORT 4-1/2"Baker Alpha Pressure Sleeve 3.010 11,749.1 6,268.4 85.51 XO 4-1/2"12.6 ppf L-80 x-o Pup Jt,BTC box x BTC pin 3.958 I:: 11,758.8 6,269.1 85.68 SLEEVE 4-1/2"Baker Wellbore Isolation Valve(H036784300) 2.938 INTERMEDIATE,27.7-8,239.0 ` 11,761.8 6,269.3 85.74 XO 4-1/2"12.6 ppf L-80 xo Pup Jt,BTC box x BTC pin 3.958 11,848.6 6,274.6' 87.62 COLLAR 4-1/2"12.6 ppf L-80 Weatherford Float Collar 3.885 Tubing Strings Tubing Description String Ma...ID(in) Tap(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection • TUBING 31/2 2.992 25.5 8,109.7 6,139.0 9.30 L-80 EUE-m I! li Completion Details Nominal ID Top(ftKB) Top(ND)(MB) Top Incl(°) Item Des Com (in) 25.5 25.5 0.07 HANGER Cameron 11"x 4-1/2"IBT-m Tubing Hanger 3.900 58.2 58.2 0.17 XO Reducing XO,4-1/2"12.6#L-80 IBTM box x 3-1/2"9.3#L-80 EUE 3.063 pin IN I 7,964.2 6,093.5 71.30 SLIDING Baker 3'/a"CMU in closed position w/2.813"DS Profile 2.813 SLEEVE 7,988.3 6,101.2 71.43 Pump Sensor Schlumberger Gauge Carrier 3W EUE P X P 2.913 C13GM0181 8,012.8 6,108.9 71.57 PACKER Baker Premier Production Packer 659-287 2.880 ti I# 8,029.1 6,114.0 71.66 NIPPLE Camco 2.75 D nipple 4W OD w/RHC plug body(73°) 2.750 8,078.2 6,129.4 72.01 LOCATOR Baker 7.625"x 3.5"Shear pinned Fluted No-Go Sub- 3.000 Large OD 8,079.2 6,129.7 72.01 LOCATOR Baker 7.625"x 3.5"Shear pinned Fluted No-Go Sub- 3.000 small OD 8,108.7 6,138.7 72.23 SHOE Mule shoe WLEG,3-1/2"IBT box 3.000 It It Mandrel Inserts St ati InnTop(ND) Valva Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sera Type Type (in) (psi) Run Date Com 4,094.6 3,497.8 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,903.0 7/29/2016 2 7,688.5 5,996.2 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 7/282016 3 7,936.6 6,084.6 Cameo KBMG 1 GAS LIFT OV BKO-3 0.313 0.0 7/28/2016 /8 3 • LINER;8,084 4-11891.1 Perations Summary (with Timelog ths) i 109 Dep F° 2S-12 Co itXX: �hiIHps Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Cede Activity Code Tune P-T-X Operation (ftKB) End Depth(ftKB) 6/7/2016 6/7/2016 1.50 MIRU MOVE RURD P Prep rig for move.Sim-ops/U-tube 0.0 0.0 00:00 01:30 freeze protect diesel.Set BPV. 6/7/2016 6/7/2016 1.00 MIRU MOVE RURD P PJSM-Blow down and rig down freeze 0.0 0.0 01:30 02:30 protect lines.Secure well and cellar. 6/7/2016 6/7/2016 2.00 MIRU MOVE MOB P Move rock washer,pipe sheds and 0.0 0.0 02:30 04:30 support complexes.Stage on location. 6/7/2016 6/7/2016 0.50 MIRU MOVE MOB P Move substructure off of 2S-05. 0.0 0.0 04:30 05:00 6/7/2016 6/7/2016 2.50 MIRU MOVE MOB P Move,spot and shim substructure on 0.0 0.0 05:00 07:30 2S-12. 6/7/2016 6/7/2016 1.50 MIRU MOVE MOB P Lay mats for support complexes.Spot 0.0 0.0 07:30 09:00 pit,pump,motor and boiler complexes. 6/7/2016 6/7/2016 1.00 MIRU MOVE MOB P Set herculite and spot rockwasher. 0.0 0.0 09:00 10:00 6/7/2016 6/7/2016 1.00 MIRU MOVE MOB P Set mats and spot pipe sheds. 0.0 0.0 10:00 11:00 6/7/2016 6/7/2016 3.00 MIRU MOVE RURD P Hook up electrical,air,steam and 0.0 0.0 11:00 14:00 water lines.Berm boiler complex and rock washer.Work on rig acceptance check list. Rig on shore power @ 11:45 hrs. Accept rig @ 14:00 hrs 6/7/16 6/7/2016 6/7/2016 1.00 MIRU MOVE RURD P PJSM-Load pipe shed with 75 jts 5" 0.0 0.0 I 14:00 15:00 DP.Sim-ops/Mix spud mud. 6/7/2016 6/7/2016 1.00 MIRU MOVE NUND P Install riser/tighten annular bolts. 0.0 0.0 15:00 16:00 6/7/2016 6/7/2016 1.50 MIRU MOVE RURD P Change out saver sub to 4 1/2 IF.Sim 0.0 0.0 16:00 17:30 -ops/Energize diverter adapter seals. Test seals to 500 psi/10 min. 6/7/2016 6/7/2016 1.50 MIRU MOVE RURD P Change out handling equipment to 5" 0.0 0.0 17:30 19:00 and rig up to pick up 5"DP. 6/7/2016 6/7/2016 0.50 MIRU MOVE SVRG P Service rig. 0.0 0.0 19:00 19:30 6/7/2016 6/7/2016 2.50 MIRU MOVE PULD P Pick up and rack back 25 stands 5" 0.0 0.0 19:30 22:00 DP and 6 stands 5"HWDP. 6/7/2016 6/7/2016 0.50 MIRU MOVE BOPE P Perform diverter test,knife valve open 0.0 0.0 22:00 22:30 in 8 sec,annular closed in 24 sec. Accumulator test;system pressure 3000 psi,pressure after closure 1825 psi,200 psi recharge time 42 sec,full recharge time 190 sec.5 nitrogen bottles averaged 2000 psi.Tested gas &pit level(gain/loss)alarms,good. Witness waived by AOGCC Rep Lou Grimaldi.. 6/7/2016 6/7/2016 1.25 MIRU MOVE BHAH P PJSM-Pick up BHA#1 as per SLB 0.0 0.0 22:30 23:45 DD. 6/7/2016 6/8/2016 0.25 MIRU MOVE SEQP P Test mud lines to 3500 psi/10 min. 0.0 0.0 23:45 00:00 6/8/2016 6/8/2016 0.50 MIRU MOVE SFTY P Hold 2S-12 pre-spud meeting with 0.0 0.0 00:00 00:30 crew. 6/8/2016 6/8/2016 1.75 MIRU MOVE BHAH P Make up BHA#1 as per SLB DD • 0.0 0.0 00:30 02:15 6/8/2016 6/8/2016 0.25 MIRU MOVE DRLG P Fill conductor and check for leaks. 0.0 0.0 02:15 02:30 Clean out f/92'MD to 107'MD. PageReportPrinted: 7/12/2016 1/35 Operations Summary (with Timelog Depths) � ►wa 2S-12 ConacaPhillips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time" End Time Our(hr) Phase Op Code Activity Code Time P-T-x Operation (ftK8) End Depth MKS) 6/8/2016 6/8/2016 1.00 SURFAC DRILL DDRL P Drill from 107'to180'MD. 108'TVD. 107.0 180.0 02:30 03:30 ADT=1.04 hrs,Bit hrs=1.04 hrs, P/U=50 K,S/O=50 K,Rot=50 K, RPM=40.Torque on/off= 1 1</1 K, Flow out=51%,WOB=8,550 gpm, 700 psi. 6/8/2016 6/8/2016 0.25 SURFAC DRILL TRIP P Stand back one stand HWDP. 180.0 91.0 03:30 03:45 6/8/2016 6/8/2016 0.75 SURFAC DRILL RURD P PSJM-Hang sheave for gyro. 91.0 91.0 03:45 04:30 6/8/2016 6/8/2016 0.75 SURFAC DRILL BHAH P PJSM-Make up 2 NMDC's,stab,and 91.0 180.0 04:30 05:15 saver sub. 6/8/2016 6/8/2016 6.75 SURFAC DRILL DDRL P Drill from 180'to 624'MD.623'TVD. 180.0 624.0 05:15 12:00 AST=1.19 ADT=4.38 hrs,Bit hrs= 5.42 hrs,Jar hrs=.87 P/U=70 K, S/O=70 K,Rot=70 K,RPM=40. Torque on/off=2-3 K/1 K, Flow out= 71%,WOB=15, 550 gpm, 1010 psi. 6/8/2016 6/8/2016 6.00 SURFAC DRILL DDRL P Drill from 624'to 1012'MD. 1008' 624.0 1,012.0 12:00 18:00 TVD.AST=2.91 ADT=4.52 hrs,Bit hrs=9.94 hrs,Jar hrs=5.39 P/U=78 K,S/O=77 K, Rot=79 K,RPM=50. Torque on/off=4-7 K/1-2 K, Flow out =99%,WOB=25-30 K, 650 gpm, 1600 psi. Max gas=51 units 6/8/2016 6/9/2016 6.00 SURFAC DRILL DDRL P Drill from 1012'to 1643'MD. 1605' 1,012.0 1,643.0 18:00 00:00 TVD.AST=2.11 ADT=4.40 hrs,Bit hrs=14.34 hrs,Jar hrs=9.79 P/U= 95 K,S/O=82 K, Rot=85 K,RPM= 60.Torque on/off=3-9 K/1-3 K, Flow out=85%,WOB=25-30 K, 700 gpm, 2025 psi. Max gas=28 units 6/9/2016 6/9/2016 6.00 SURFAC DRILL DDRL P Drill from 1643'to 2294'MD.2139' 1,643.0 2,294.0 00:00 06:00 TVD.AST=1.95 ADT=4.20 hrs,Bit hrs=18.54 hrs,Jar hrs=13.99 P/U= 94 K,S/O=84 K,Rot=88 K,RPM= 60.Torque on/off=5-7 K/1-3 K, Flow out=73%,WOB=20-30 K, 719 gpm, 2250 psi. Max gas=76 units 6/9/2016 6/9/2016 6.00 SURFAC DRILL DDRL P Drill from 2294'to 2667'MD.2421' 2,294.0 2,667.0 06:00 12:00 TVD.AST=0.60 ADT=3.52 hrs,Bit hrs=22.06 hrs,Jar hrs=17.51 P/U= 102 K,S/O=85 K,Rot=92 K,RPM= 60.Torque on/off=5-7 K/3-5 K, Flow out=67%,WOB=20-30 K, 701 gpm, 2150 psi. Max gas=108 units 6/9/2016 6/9/2016 1.75 SURFAC DRILL DDRL P Drill from 2667'to TD of 2857'MD.' 2,667.0 2,857.0 12:00 13:45 2565'TVD.AST=0.16 ADT=1.69 hrs,Bit hrs=23.75 hrs,Jar hrs=19.20 P/U=112 K,3/0=93 K,Rot= 100 K, RPM=60.Torque on/off=5-7 K/3-5 K, Flow out=67%,WOB=20-30 K, 713 gpm,2200 psi. Max gas=27 units Page 2/35 Report Printed: 7/12/2016 • xOperations Summary (with Timelog Depths) 0 2S-12 '�. ifu Rig: DOYON 141 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(ftKS) 6/9/2016 6/9/2016 1.25 SURFAC CASING CIRC P CBU x 2 at full drilling rate w/700 2,857.0 2,857.0 13:45 15:00 gpm,2100 psi decreasing to 2000 psi, 60rpm,5k Torque.Observe hole unload when reaching first bottoms up. 6/9/2016 6/9/2016 0.50 SURFAC CASING OWFF P OWFF 2,857.0 2,857.0 15:00 15:30 6/9/2016 6/9/2016 5.00 SURFAC CASING BKRM P PJSM-BROOH f/2857'MD t/1469' 2,857.0 1,469.0 15:30 20:30 MD.700 gpm,2100 psi,60 rpm,3-7 K tq. Calc disp=11.4 bbls Act disp=16.5 bbls. 6/9/2016 6/9/2016 1.50 SURFAC CASING SRVY T Rig up slickline.Reciprocate pipe 1,469.0 1,469.0 20:30 22:00 while rigging up.P/U=90K S/O=85K. Monitor well w/trip tank. 6/9/2016 6/9/2016 1.00 SURFAC CASING SRVY T RIH w/MS Gyro on slickline.Tag up 1,469.0 1,469.0 22:00 23:00 on jars @ 975'MD depth. Perform multi-shot gyro surveys at 100' stations from 975'MD to 100'MD. • 6/9/2016 6/9/2016 0.25 SURFAC CASING SRVY T Rig down slickline 1,469.0 1,469.0 23:00 23:15 6/9/2016 6/10/2016 0.75 SURFAC CASING TRIP P POOH on elevators from 1469'MD to 1,469.0 1,179.0 23:15 00:00 1179'MD. 6/10/2016 6/10/2016 0.75 SURFAC CASING TRIP P POOH on elevators from 1179'MD to 1,179.0 716.0 00:00 00:45 716'MD. 6/10/2016 6/10/2016 0.25 SURFAC CASING OWFF P Observe well for flow-well static. 716.0 716.0 00:45 01:00 6/10/2016 6/10/2016 3.00 SURFAC CASING BHAH P Rack back 6 x stands HWDP,jar,and 716.0 0.0 01:00 04:00 NMDCs.L/D BHA#1 as per SLB rep. Observed balling around stabilizers. Bit graded 3-4-WT-A-E-1-NO-TD. Calculated displacement for trip:21.47 bbls Actual displacement for trip:25.02 bbls 6/10/2016 6/10/2016 1.25 SURFAC CASING BHAH P Clean/clear rig floor. 0.0 0.0 04:00 05:15 6/10/2016 6/10/2016 0.50 SURFAC CASING WWWH P M/U stack washer and jet landing ring 0.0 0.0 05:15 05:45 profile. 6/10/2016 6/10/2016 1.75 SURFAC CASING RURD P R/U to run 10-3/4"casing.Pick up and 0.0 0.0 05:45 07:30 R/U GBR Volant tool,bail extensions, elevators,slips and floor valve. 6/10/2016 6/10/2016 0.25 SURFAC CASING SFTY P Hold PJSM on running 10-3/4" 1,425.0 07:30 07:45 Dopeless Hydril 563 casing. 6/10/2016 6/10/2016 0.75 SURFAC CASING PUTB P Make up shoe track from surface to 0.0 117.0 07:45 08:30 115'and check floats. 6/10/2016 6/10/2016 3.50 SURFAC CASING PUTB P RIH w/10-3/4"45.5#L-80 Dopeless 117.0 1,425.0 08:30 12:00 Hydril 563 casing as per tally from 117-1425'MD,filling on the fly and topping off every 10 with Volant tool. Torque 6/10/2016 6/10/2016 1.00 SURFAC CASING CIRC P Circulate 1 x casing volume at base of 1,425.0 1,425.0 12:00 13:00 permafrost.Stage pump up to 4 bpm, 180 psi.PU 82K SO 70K. 6/10/2016 6/10/2016 4.00 SURFAC CASING PUTB P RIH w/10-3/4"45.5#L-80 Dopeless 1,425.0 2,813.0 13:00 17:00 Hydril 563 casing as per tally from 1425'-2813'MD,filling on the fly and topping off every 10 with Volant tool. Page 3/35 Report Printed: 7/12/2016 • 4 Operations Summary (with Timelog Depths) lat 2S-12 ConacoE'tsiflf�ss Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start.Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (EKS) End Depth(ftKE)i 6/10/2016 6/10/2016 0.50 SURFAC CASING HOSO P Make up hanger and landing joint. 2,813.0 2,845.0 17:00 17:30 Break circ @ 1.5 bpm,200 psi.Land casing. P/U=135K S/0=100K. Ran total of 69 jts casing.Ran 35 bowspring centralizers,one each on FS joint and FC joint on stop rings 10' up and then every other joint.0 remakes,0 rejects 6/10/2016 6/10/2016 1.00 SURFAC CEMENT CIRC P CBU.Stage pumps up from 1.5 2,845.0 2,845.0 17:30 18:30 bpm/200 psi to 7 bpm/600 psi. Reciprocate pipe 10'strokes. 6/10/2016 6/10/2016 3.00 SURFAC CEMENT CIRC P Rig up cement line.Circulate and 2,845.0 2,845.0 18:30 21:30 condition mud for cement job.Stage pump up to 8 bpm/600 psi 6/10/2016 6/10/2016 0.50 SURFAC CEMENT SFTY P PJSM on cementing surface casing. 2,845.0 2,845.0 21:30 22:00 6/10/2016 6/10/2016 0.25 SURFAC CEMENT RGRP T Pump 5 bbls CW100.Attempt to test 2,845.0 2,845.0 22:00 22:15 cement line.Leaking at weld on 45 above manifold on rig floor.Rig up hose to bypass leak. 6/10/2016 6/11/2016 1.75 SURFAC CEMENT CMNT P Test lines to 4000 psi.Pump 15 bbls 2,845.0 2,845.0 22:15 00:00 8.35 ppg CW-100. Pump 75 bbls 10.5 ppg MPII w/red dye at 4.5 bpm.Drop bottom plug.Pump 150 bbls 11 ppg lead cement at 6 bpm/150 psi. Reciprocate pipe 10'with full returns. 6/11/2016 6/11/2016 1.25 SURFAC CEMENT CMNT P Cont Surface cement job:Pumped 2,845.0 2,845.0 00:00 01:15 total of 400 bbls 11 ppg LiteCRETE lead cement at 6 bpm/150 psi increasing to 490 psi.Reciprocate pipe 10'with full returns.Observe 30k drop in SOW with 350 bbls of lead pumped away-land hanger for remaining portion of job.Pumped 60 bbls 15.8 ppg Class G tail cement at 5 bpm/550 psi.Shut down,drop top plug,and line up to divert all returns to the cellar.Kicked top plug out with 3 bbls of tail cement followed by 10 bbls of H20. 6/11/2016 6/11/2016 1.50 SURFAC CEMENT CMNT P Swapped to rig pumps and displaced 2,845.0 0.0 01:15 02:45 cement @ 3 bpm w/270 psi increasing to 550 psi pump pressure. 3 bpm was max rate that trucks could manage sucking out of the cellar. Observed cement at surface 35 bbls into displacement.Bumped plug @ 2510 strokes,FCP=550 psi. Pressured up to 1100 psi and held for 5 min then bled off and checked floats -floats held.CIP @ 02:45 am.218 bbls of cement returned to surface. 6/11/2016 6/11/2016 0.50 SURFAC CEMENT OWFF P Observe well for flow-well static. 0.0 0.0 02:45 03:15 Simops-clean cement out of cellar box. 6/11/2016 6/11/2016 1.25 SURFAC CEMENT RURD P Flush stack with black water.Blow 0.0 0.0 03:15 04:30 down and R/D cement lines. 6/11/2016 6/11/2016 1.00 SURFAC CEMENT RURD P L/D landing joint,R/D volant tool,and 0.0 0.0 04:30 05:30 clear casing tools from rig floor. 6/11/2016 6/11/2016 3.75 SURFAC CEMENT NUND P N/D surface riser and diverter. 0.0 0.0 05:30 09:15 Page 4/35 Report Printed: 7/12/2016 Operations Summary (with Timelog Depths) .F 2S-12 Ccx:vac hiEiips Rig: DOYON 141 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) 6/11/2016 6/11/2016 2.00 SURFAC WHDBOP NUND P N/U Cameron MBS wellhead and 0.0 0.0 09:15 11:15 verify orientation.Test seals to 5000 psi f/15 min witnessed by CPAI- good test. 6/11/2016 6/11/2016 2.75 SURFAC WHDBOP NUND P N/U BOPE's 0.0 0.0 11:15 14:00 6/11/2016 6/11/2016 3.00 SURFAC WHDBOP SVRG P Perform between well maintenance on 0.0 0.0 14:00 17:00 BOPE.Observe top rams and blind rams worn-change out top rams for 2 -7/8"x 5"VBRs and replace top seals on blind rams.Sim-ops/Take on 9.6 ppg LSND mud. 6/11/2016 6/11/2016 1.50 SURFAC WHDBOP MPDA P PJSM-Rig up scaffold in cellar.Sim- 0.0 0.0 17:00 18:30 ops/build containment around MPD choke skid. 6/11/2016 6/11/2016 2.50 SURFAC WHDBOP MPDA P PJSM-Rig up MPD lines and install 0.0 0.0 18:30 21:00 KatchKan. 6/11/2016 6/11/2016 1.50 SURFAC WHDBOP RURD P PJSM-Rig up to test BOPE.Purge air 0.0 0.0 21:00 22:30 and perform shell test. 6/11/2016 6/12/2016 1.50 SURFAC WHDBOP BOPE P Test BOPE w/5"test joint to 250/3500 0.0 0.0 22:30 00:00 psi for 5 min each.#1:Top pipe rams, CV 1,12,13, 14&manual kill valve. #2:Upper IBOP, HCR kill,CV 9,&11. #3:Lower IBOP,CV 5,8&10. #4: FOSV,CV 4,6&7. 6/12/2016 6/12/2016 3.50 SURFAC WHDBOP BOPE P Continue testing BOPE w/5"test joint 0.0 0.0 00:00 03:30 to 250/3500 psi for 5 min each. #5: FOSV and CV 2. #6:HCR choke&4" kill line Demco valve, #7:Manual choke valve&HCR kill. #8:Annular preventer tested to 250/2500 psi.#9: Lower pipe rams.#10:Blind rams and CV 3. Accumulator test:System pressure= 3000 psi,Pressure after closing=1800 psi,200 psi attained after 42 seconds, full pressure attained after 193 seconds.Five bottle nitrogen avg= 1975 psi.Chuck Scheve of the AOGCC waived witness. 6/12/2016 6/12/2016 0.50 SURFAC WHDBOP RURD P R/D BOPE test equipment. 0.0 0.0 03:30 04:00 6/12/2016 6/12/2016 1.00 SURFAC WHDBOP MPDA P Perform MPD training with rig crew. 0.0 0.0 04:00 05:00 6/12/2016 6/12/2016 0.50 SURFAC WHDBOP MPDA P Pull trip nipple,install MPD test cap, 0.0 0.0 05:00 05:30 and fill lines. 6/12/2016 6/12/2016 0.75 SURFAC WHDBOP MPDA P Pressure test MPD system to 0.0 0.0 05:30 06:15 250/1300psi for 5 min each.#1:BV-3, BV-5,BV-7,LT-1, LT-2.#2:LT-6 and Air Valve. 6/12/2016 6/12/2016 0.25 SURFAC WHDBOP MPDA P Pull test cap and install trip nipple. 0.0 0.0 06:15 06:30 6/12/2016 6/12/2016 0.25 SURFAC WHDBOP RURD P Pull test plug,install 10"ID wear 0.0 0.0 06:30 06:45 bushing,and blow down choke/kill line. 6/12/2016 6/12/2016 0.50 SURFAC CEMENT RURD P R/U to P/U 5"DP in mousehole 0.0 0.0 06:45 07:15 Page 5/35 Report Printed: 7/12/2016 Operations Summary (with Timelog Depths) 2S-12 Co acoPhiiiips Rig: DOYON 141 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(ftKD), 6/12/2016 6/12/2016 1.25 SURFAC CEMENT PULD P P/U 5"DP singles from the shed and 0.0 0.0 07:15 08:30 R/B 10 x stands using mousehole. 6/12/2016 6/12/2016 1.50 SURFAC CEMENT RGRP T Repair iron roughneck 0.0 0.0 08:30 10:00 6/12/2016 6/12/2016 0.50 SURFAC CEMENT PULD P P/U 5"DP singles from the shed and 0.0 0.0 10:00 10:30 R/B 2 x stands using mousehole. Noticed cement residue in 5"DP. Decision made to run 5"DP in hole w/ mule shoe and circulate pipe clean. 6/12/2016 6/12/2016 2.25 SURFAC CEMENT PULD P P/U and RIH w/45 x singles 5"DP 0.0 2,511.0 10:30 12:45 from shed and 12 x stands 5"DP from derrick to 2,511'MD. 6/12/2016 6/12/2016 0.75 SURFAC CEMENT CIRC P Stage up pumps to 720 gpm w/610 2,511.0 2,511.0 12:45 13:30 psi and circulate pipe clean. 6/12/2016 6/12/2016 1.00 SURFAC CEMENT TRIP P POOH and R/B 27 x stands 5"DP in 2,511.0 0.0 13:30 14:30 derrick. 6/12/2016 6/12/2016 2.00 SURFAC CEMENT PULD P P/U and RIH w/81 x singles 5"DP 0.0 2,500.0 14:30 16:30 from shed from derrick to 2500'MD. 6/12/2016 6/12/2016 0.25 SURFAC CEMENT CIRC P Stage up pumps to 720 gpm w/650 2,500.0 2,500.0 16:30 16:45 psi and circulate pipe clean. 6/12/2016 6/12/2016 1.00 SURFAC CEMENT TRIP P POOH and R/B 27 x stands 5"DP in 2,500.0 0.0 16:45 17:45 derrick. 6/12/2016 6/12/2016 0.75 SURFAC CEMENT PULD P P/U and RIH w/18 x singles 5"DP 0.0 550.0 17:45 18:30 from shed from derrick to 550'MD. 6/12/2016 6/12/2016 0.25 SURFAC CEMENT CIRC P Stage up pumps to 700 gpm w/200 550.0 550.0 18:30 18:45 psi and circulate pipe clean. 6/12/2016 6/12/2016 0.25 SURFAC CEMENT TRIP P POOH and R/B 6 x stands 5"DP in 550.0 0.0 18:45 19:00 derrick. 6/12/2016 6/12/2016 0.50 SURFAC CEMENT RURD P Clean and clear rig floor. 0.0 0.0 19:00 19:30 6/12/2016 6/12/2016 1.50 SURFAC CEMENT BHAH P PJSM-Make up BHA#2 as per SLB 0.0 123.0 19:30 21:00 DD to 123'MD. 6/12/2016 6/12/2016 0.25 SURFAC CEMENT BHAH P PJSM-Install nuclear source in LWD 123.0 123.0 21:00 21:15 as per SLB. 6/12/2016 6/12/2016 1.00 SURFAC CEMENT BHAH P Continue to pick up BHA as per SLB 123.0 751.0 21:15 22:15 DD to 751'MD. 6/12/2016 6/12/2016 0.75 SURFAC CEMENT TRIP P RIH to 2521'MD. 751.0 2,521.0 22:15 23:00 6/12/2016 6/12/2016 0.75 SURFAC CEMENT CIRC P Brk circ. Fill pipe.Circ.surface to 2,521.0 2,521.0 23:00 23:45 surface.535 gpm, 1525 psi,50 rpm, 6K tq.Rot wt=90K.Check MWD. 6/12/2016 6/13/2016 0.25 SURFAC CEMENT SLPC P Hang blocks to cut drilling line. 2,521.0 2,521.0 23:45 00:00 6/13/2016 6/13/2016 1.50 SURFAC CEMENT SLPC P Slip and cut 65'of drilling line. 2,521.0 2,521.0 00:00 01:30 Calibrate totco and service top drive. 6/13/2016 6/13/2016 1.25 SURFAC CEMENT PRTS P R/U and pressure test 10 3/4"casing 2,521.0 2,521.0 01:30 02:45 to 3500 psi/30 min on chart-good test.Rig down test equipment.Blow down kill line. 6/13/2016 6/13/2016 1.00 SURFAC CEMENT COCF P Wash and ream down f/2521'MD to 2,521.0 2,717.0 02:45 03:45 2717'MD @ 300 gpm=550 psi,26% FO,P/U=110K,S/O=83K,ROT= 95K,20 rpm,Tq=5K.Tag firm cement @2717'MD w/10k WOB. SPR's @ 2521'MD 2311'TVD w/ 10.05 ppg @ 0245 hrs. #1 30/40 SPM @ 120/180 psi #2 30/40 SPM @ 120/180 psi Page 6/35 Report Printed: 7/12/2016 • !erations Summary (with Timelog Depths) ��,�►,��,, � 2S-12 ConocoPhiiitips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (MKS) End Depth(ftKS), 6/13/2016 6/13/2016 1.00 SURFAC CEMENT COCF P Cleanout cement to top of plugs f/ 2,717.0 2,766.0 03:45 04:45 2717'MD to 2766'MD @ 300 gpm= 550 psi,26%FO,P/U= 110K,S/O= 83K,ROT=95K,20 rpm,Tq=5-7K. Tag top of plugs @ 2766'MD. 6/13/2016 6/13/2016 10.00 SURFAC CEMENT DRLG P Drill out float collar,shoe track,float 2,766.0 2,857.0 04:45 14:45 shoe and rat hole to 2857'MD @ 90- 500gpm,80-1300 psi,5-60 rpm,Tq 5- 11k,WOB 2-40K,5-45%FO,P/U= 115K,S/O=85K,ROT=97K. 6/13/2016 6/13/2016 0.25 SURFAC CEMENT DDRL P Drill 20'of new hole f/2857'MD to 2,857.0 2,877.0 14:45 15:00 2877'MD.P/U=115K,S/0=85K, ROT=97K.Pump @ 512 gpm= 1300 psi,rotate @ 50 rpms w/Tq 7-8K on, WOB=5-7K,FO=45%, ECD= 10.25 ppg,Max gas=0 6/13/2016 6/13/2016 1.00 SURFAC CEMENT CIRC P Circulate and condition mud for FIT, 2,877.0 2,799.0 15:00 16:00 pump @ 512 gpm=1300 psi,45%FO. MW 9.65 ppg in/out.While CBU dressed up casing shoe,observed pipe torque up/stall out and overpull while pulling back into casing. 6/13/2016 6/13/2016 0.25 SURFAC CEMENT RURD P Rig up to perform FIT/LOT. 2,799.0 2,799.0 16:00 16:15 6/13/2016 6/13/2016 0.50 SURFAC CEMENT FIT P Perform FIT to 16.0ppg EMW,test, 2,799.0 2,799.0 16:15 16:45 charted. 6/13/2016 6/13/2016 1.00 INTRM1 DRILL RURD P Rig down testing equipment,blow 2,799.0 2,799.0 16:45 17:45 down kill and cement lines,and change out shaker screens. 6/13/2016 6/13/2016 2.00 INTRM1 DRILL DDRL P Wash down to 2877'MD. Drill from 2,799.0 2,981.0 17:45 19:45 2877'to 2981'MD.2658'TVD.ADT= 1.50 hrs,Bit hrs=1.07 hrs,Jar hrs= 84.36 P/U=115 K,S/O=85 K,Rot= 96 K, RPM=60-100.Torque on/off=4 -8 K/4-7 K, Flow out=45%,WOB=6 -10 K, 650 gpm, 1610 psi. Max gas=104 units.ECD=10.33 6/13/2016 6/13/2016 0.50 INTRM1 DRILL CIRC P Break connection&pump down RFID 2,981.0 2,981.0 19:45 20:15 chips per WFT Rep to open reamer. @ 650 gpm, 1600 psi. Drop pump rate to 200 gpm while RFID chips pass tool,then stage back up to 650 gpm,initial pressure 1600 psi dropping to 1400 psi,MWD turbine speed dropped from 2422 rpm to 1953 rpm indicating knives opened.Pull up to shoe&observe 5K over pull to verify reamer open. 6/13/2016 6/14/2016 3.75 INTRM1 DRILL DDRL P Drill 9 7/8"x 11"surface hole from 2,981.0 3,262.0 20:15 00:00 2981'to 3249'MD.2658'TVD.ADT= 2.66 hrs, Bit hrs=4.16 hrs,Jar hrs= 87.02 P/U=115 K,S/O=87 K,Rot= 100 K, RPM=100.Torque on/off=5- 10 K/2-8 K, Flow out=46%,WOB=8 -14 K, 710 gpm, 1600 psi. Max gas=104 units.ECD=10.43 SPR's @ 2981'MD 2658'TVD w/ 9.5+ppg @ 2030 hrs. #1 30/40 SPM @ 110/150 psi #2 30/40 SPM @ 100/160 psi Page 7/35 Report Printed: 7/12/2016 • fterations Summary (with TimelogDepths) g 2S-12 Coniacciehillips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phsse Op Code Activity Code Time P-T-X Operation (ftKFB) End Depth(ftKE) 6/14/2016 6/14/2016 6.00 INTRM1 DRILL DDRL P Drill 9 7/8"x 11"surface hole from 3,262.0 3,823.0 00:00 06:00 3249'to 3823'MD.3302'TVD.ADT= 4.57 hrs,Bit hrs=8.73 hrs,Jar hrs= 91.59 P/U=125 K,S/O=94 K,Rot= 106 K,RPM= 140.Torque on/off=7-8 K/0-10 K, Flow out=48%,WOB=10 K, 750 gpm, 1750 psi. Max gas=68 units.ECD=10.44 SPR's @ 3544'MD 3080'TVD w/9.6 ppg @ 0300 hrs. #1 30/40 SPM @ 110/160 psi #2 30/40 SPM @ 110/180 psi 6/14/2016 6/14/2016 6.00 INTRM1 DRILL DDRL P Drill 9 7/8"x 11"surface hole from 3,823.0 4,328.0 06:00 12:00 3823'to 4328'MD.3669'TVD.ADT= 3.79 hrs,Bit hrs= 12.52 hrs,Jar hrs= 95.38 P/U=145 K,S/O=100 K,Rot =114 K,RPM=160.Torque on/off=8 -10 K/6-8 K, Flow out=50%,WOB= 12-15 K, 775 gpm,2210 psi. Max gas=178 units.ECD=10.63 • SPR's @ 4286'MD 3641'TVD w/ 9.65 ppg @ 1030 hrs. #1 30/40 SPM @ 130/200 psi #2 30/40 SPM @ 150/200 psi 6/14/2016 6/14/2016 0.50 INTRM1 DRILL DDRL P Drill 9 7/8"x 11"surface hole from 4,328.0 4,382.0 12:00 12:30 4328'to 4382'MD.3714'TVD.ADT= 0.39 hrs,Bit hrs= 12.91 hrs,Jar hrs= 95.77 P/U=145 K,S/O=100 K,Rot =114 K,RPM=160.Torque on/off=8 -10 K/6-8 K, Flow out=50%,WOB= 12-15 K, 775 gpm,2210 psi. Max gas=185 units.ECD=10.60 6/14/2016 6/14/2016 1.25 INTRM1 DRILL CIRC T Decision made to POOH due to MWD 4,382.0 4,196.0 12:30 13:45 tool failure.CBU x 1.5 per stand, racking back 2 x stands w/700 gpm, 1825 psi, 100 rpm,7k Tq, ECD= 10.36. 6/14/2016 6/14/2016 1.50 INTRM1 DRILL CIRC T Continue circulating hole clean whilst 4,196.0 4,196.0 13:45 15:15 CPAI and DDI safety investigate dropped object incident with broken hobble for elevators.700 gpm, 1810 psi, 100 rpm,7k TQ,ECD=10.23 6/14/2016 6/14/2016 0.50 INTRM1 DRILL CIRC T Pump RFID chips to shut under 4,196.0 4,196.0 15:15 15:45 reamer @ 658 gpm, 1650 psi,FO 46%,2109 turbine rpm,slow to 200 gpm,275 psi,FO 12%for 400 strokes whilst chips pass through the reamer. Pump total of 900 strokes&shut down.Work pipe for 10 min.Pump at 658 gpm,2000 psi,FO 46%,2617 turbine rpm.Observe 350 psi increase &increase in turbine speed indicating reamer blocks closed. 6/14/2016 6/14/2016 0.50 INTRM1 DRILL OWFF T Observe well for flow-well static. 4,196.0 4,196.0 15:45 16:15 6/14/2016 6/14/2016 3.75 INTRM1 DRILL TRIP T POOH on elevators from 4196'to 751' 4,196.0 752.0 16:15 20:00 MD,monitoring well on trip tank. Page 8/35 Report Printed: 7/12/2016 ;IV wfi Operations Summary (with Timelog Depths) 2S-12 asp o hi€lips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log '.: Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKD) 6/14/2016 6/14/2016 0.25 INTRM1 DRILL OWFF T Observe well for flow-well static. 751.0 751.0 20:00 20:15 6/14/2016 6/14/2016 0.75 INTRM1 DRILL TRIP T POOH on elevators from 751'to 199' 751.0 199.0 20:15 21:00 MD racking back HWDP and jars. 6/14/2016 6/14/2016 1.50 INTRM1 DRILL BHAH T PJSM-Lay down BHA.Remove 199.0 0.0 21:00 22:30 nuclear source.POOH and inspect under reamer and bit. Calc disp=46.14 bbls Act disp=48.28 bbls for trip. 6/14/2016 6/14/2016 1.00 INTRM1 DRILL BHAH T RIH and change out MWD.Load 0.0 199.0 22:30 23:30 nuclear source. 6/14/2016 6/15/2016 0.50 INTRMI DRILL TRIP T RIH f/199'MD to 937'MD. 199.0 937.0 23:30 00:00 6/15/2016 6/15/2016 0.75 INTRM1 DRILL TRIP T RIH on 5"DP from 937'-1681'MD, 937.0 1,681.0 00:00 00:45 monitoring displacement on the trip tank. 6/15/2016 6/15/2016 0.25 INTRM1 DRILL DHEQ T Shallow hole test MWD tools-good 1,681.0 1,681.0 00:45 01:00 test. 6/15/2016 6/15/2016 0.50 INTRM1 DRILL TRIP T RIH on 5"DP from 1681'to 2981'MD, 1,681.0 2,981.0 01:00 01:30 monitoring displacement on the trip tank. 6/15/2016 6/15/2016 0.50 INTRM1 DRILL CIRC T Break connection&pump down RFID 2,981.0 2,981.0 01:30 02:00 chips per WFT Rep to open reamer. @ 650 gpm, 1750 psi. Drop pump rate to 200 gpm,250 psi whilst RFID chips pass tool,then stage back up to 650 gpm,initial pressure 1750 psi dropping to 1480 psi and initial MWD turbine speed of 2656 rpm dropping to 2148 rpm.Pull up to shoe&observe 5K over pull to verify reamer open. SPR's @ 2981'MD 2658'TVD w/ 9.6+ppg @ 0200 hrs. #1 30/40 SPM @ 110/140 psi #2 30/40 SPM @ 110/150 psi 6/15/2016 6/15/2016 0.75 INTRMI DRILL TRIP T RIH on 5"DP from 2981'to 4106'MD, 2,981.0 4,106.0 02:00 02:45 monitoring displacement on the trip tank. 6/15/2016 6/15/2016 1.00 INTRMI DRILL WASH T Wash down last 3 x stands from 4106' 4,106.0 4,382.0 02:45 03:45 to 4382'MD @ 600 gpm, 1530 psi. PUW=130k,SOW=100k,ROT= 115k. 6/15/2016 6/15/2016 2.25 INTRM1 DRILL DDRL P Drill 9 7/8"x 11"surface hole from 4,382.0 4,567.0 03:45 06:00 4382'to 4567'MD.3853'TVD.ADT= 0.21 hrs,Bit hrs= 13.12 hrs,Jar hrs= 95.98 P/U=145 K,S/O=95 K,Rot= 117 K,RPM=160.Torque on/off=9- 11 K/7-9 K, Flow out=50%,WOB= 15-17 K, 775 gpm,2275 psi. Max gas=188 units.ECD=10.52 SPR's @ 4567'MD 3853'TVD w/9.6 ppg @ 0530 hrs. #1 30/40 SPM @ 125/180 psi #2 30/40 SPM @ 130/185 psi Page 9/35 Report Printed: 7/12/2016 • !erations Summary (with Timelog Depths) � . 2S-12 ConocoPhillips fi Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log_, Start Depth Start Time s End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKS), 6/15/2016 6/15/2016 6.00 INTRM1 DRILL DDRL P Drill 9 7/8"x 11"surface hole from 4,567.0 5,105.0 06:00 12:00 4567'to 5105'MD.4259'TVD.ADT= 5.82 hrs,Bit hrs=18.94 hrs,Jar hrs= 101.80 P/U=160 K,S/O=100 K, Rot=125 K,RPM=160.Torque on/off = 10-15 K/2-15 K, Flow out=50%, WOB= 18 K, 775 gpm,2410 psi. Max gas=193 units.ECD=10.54 6/15/2016 6/15/2016 4.00 INTRM1 DRILL DDRL P Drill 9 7/8"x 11"surface hole from 5,105.0 5,502.0 12:00 16:00 5105'to 5502'MD.4550'TVD.ADT= 3.22 hrs,Bit hrs=22.16 hrs,Jar hrs= 105.02 P/U= 163 K,S/O=105 K, Rot=125 K, RPM=160.Torque on/off =11-15 K/10-14 K, Flow out=52%, WOB=10-20 K, 775 gpm,2560 psi. Max gas=293 units.ECD=10.54 6/15/2016 6/15/2016 0.50 INTRM1 DRILL CIRC P Circulate hi-vis sweep surface to 5,502.0 5,502.0 16:00 16:30 surface.775 gpm,2550 psi, 100 rpm,6 -10K tq. 6/15/2016 6/15/2016 0.25 INTRM1 DRILL OWFF P Monitor well.Static. 5,502.0 5,502.0 16:30 16:45 6/15/2016 6/15/2016 1.25 INTRM1 DRILL MPDA P PJSM-Pull trip nipple. Install RCD 5,502.0 5,502.0 16:45 18:00 bearing assy.Connect coolant lines. 6/15/2016 6/15/2016 0.50 INTRM1 DRILL MPDA P Calibrate MPD system. 5,502.0 5,502.0 18:00 18:30 6/15/2016 6/16/2016 5.50 INTRM1 DRILL DDRL P Drill 9 7/8"x 11"surface hole from 5,502.0 5,968.0 18:30 00:00 5502'to 5968'MD.4907'TVD.ADT= 4.31 hrs,Bit hrs=26.47 hrs,Jar hrs= 109.33 P/U=175 K,S/O=105 K, Rot=132 K,RPM=100-140.Torque on/off=10-15 K/10-15 K, Flow out= 92%,WOB=10-15 K, 775 gpm,2600 psi. Max gas=449 units.ECD=10.79 SPR's @ 5594'MD 4628'TVD w/ . 9.6+ppg @ 19:15 hrs. #1 30/40 SPM @ 200/270 psi #2 30/40 SPM @ 210/280 psi 40 bbls lost downhole for tour. 6/16/2016 6/16/2016 6.00 INTRM1 DRILL DDRL P Drill 9 7/8"x 11"surface hole from 5,968.0 6,433.0 00:00 06:00 5968'to 6433'MD.5237'TVD.ADT= 4.37 hrs,Bit hrs=30.84 hrs,Jar hrs= 113.70 P/U=176 K,S/O=116 K, Rot=135 K,RPM=160.Torque on/off =12-14 K/8-15 K, Flow out=93%, WOB= 13-16 K, 775 gpm,2800 psi. Max gas=303 units.ECD=10.73 SPR's @ 6264'MD 5103'TVD w/ 9.7+ppg @ 0340 hrs. #1 30/40 SPM @ 175/230 psi #2 30/40 SPM @ 170/250 psi Page 10/35 Report Printed: 7/12/2016 !erations Summary (with Timelog epths) 2S-12 cxmocoPhillips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Lag Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth MKS) 6/16/2016 6/16/2016 6.00 INTRM1 DRILL DDRL P Drill 9 7/8"x 11"surface hole from 6,433.0 6,899.0 06:00 12:00 6433'to 6899'MD.5566'TVD.ADT= 3.83 hrs,Bit hrs=34.67 hrs,Jar hrs= 117.53 P/U=183 K,S/O=110 K,' Rot=140 K,RPM=160.Torque on/off =13-16 K/5-18 K, Flow out=92%, WOB= 14-20 K, 775 gpm,2900 psi. Max gas=1254 units.ECD=10.87 SPR's @ 6803'MD 5501'TVD w/ 9.7+ppg @ 1010 hrs. #1 30/40 SPM @ 175/221 psi #2 30/40 SPM @ 185/225 psi Losses for tour=2.65 bbls 6/16/2016 6/16/2016 3.50 INTRM1 DRILL DDRL P Drill 9 7/8"x 11"surface hole from 6,899.0 7,179.0 12:00 15:30 6899'to 7179'MD.5760'TVD.ADT= 2.78 hrs,Bit hrs=37.45 hrs,Jar hrs= 120.31 P/U=192 K,S/0=115 K, Rot=143 K, RPM=160.Torque on/off =15-18 K/10-15 K, Flow out=94%, WOB=15-20 K, 785 gpm,3050 psi. Max gas=1451 units. ECD=10.81 6/16/2016 6/16/2016 0.50 INTRM1 DRILL CIRC T RCD failure.CBU.Pick up to 7120' 7,179.0 7,120.0 15:30 16:00 MD.700 gpm, 100 rpm,2400 psi,9K tq. 6/16/2016 6/16/2016 1.50 INTRM1 DRILL MPDA T PJSM-Change out RCD bearing ashy. 7,120.0 7,120.0 16:00 17:30 Install new 5"assy. 6/16/2016 6/16/2016 0.50 INTRM1 DRILL WASH T Wash down from 7120'MD to 7179' 7,120.0 7,179.0 17:30 18:00 MD.775 gpm,2800 psi, 100 rpm, 10K tq.No fill. 6/16/2016 6/16/2016 2.00 INTRM1 DRILL DDRL P Drill 9 7/8"x 11"surface hole from 7,179.0 7,364.0 18:00 20:00 7179'to 7364'MD.5848'TVD.ADT= 1.73 hrs,Bit hrs=39.18 hrs,Jar hrs= 122.04 P/U=172 K,S/O= 130 K, Rot=146 K,RPM=160.Torque on/off = 14 K/10 K, Flow out=94%,WOB= 12-15 K, 780 gpm,3000 psi. Max gas=539 units.ECD=11.0 SPR's @ 7272'MD 5801'TVD w/ 9.7+ppg @ 1850 hrs. #1 30/40 SPM @ 205/285 psi #2 30/40 SPM @ 194/260 psi Observe loss rate of—32bb1/hr from 1900-2000 hrs,7271'-7355'MD,MW 9.9+ppg. 6/16/2016 6/16/2016 1.75 INTRM1 DRILL CIRC T Pump 36 bbl LCM pill#1 and circulate 7,364.0 7,364.0 20:00 21:45 to surface w/775gpm,3000 psi,ECD 11.0 ppg decreasing to 10.88ppg. Pump 27bb1 LCM pill#2 and spot across C-37 formation w/650 gpm, 2250 psi, 10.8oppg ECD.Ramp down pumps and shut in on MPD chokes.w/ 125 psi back pressure. Page 11/35 Report Printed: 7/12/2016 Iterations Summary (with Timelog Depths) 2S-12 ConocoPhitlips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time- End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKBI', 6/16/2016 6/16/2016 0.75 INTRM1 DRILL CIRC T Close air valve and squeeze LCM pill 7,364.0 7,364.0 21:45 22:30 #2,staging up to 11.1 ppg EMW @ C- 37.Observed initial pressure drop of 5 psi/min decrease to 2 psi/min. 6/16/2016 6/17/2016 1.50 INTRM1 DRILL DDRL P Drill 9 7/8"x 11"surface hole from 7,364.0 7,456.0 22:30 00:00 7364'to 7456'MD.5900'TVD.ADT =.88 hrs, Bit hrs=40.06 hrs,Jar hrs= 122.92 P/U= 172 K,S/O=130 K, Rot= 146 K,RPM=160.Torque on/off = 13-15 K/10 K, Flow out=93%, WOB=15-18 K, 750 gpm,2900 psi. Max gas=291 units.ECD=11.03 SPR's @ 7272'MD 5801'TVD w/ 9.7+ppg @ 1850 hrs. #1 30/40 SPM @ 205/285 psi #2 30/40 SPM @ 194/260 psi Losses for tour=90 bbls 6/17/2016 6/17/2016 6.00 INTRM1 DRILL DDRL P Drill 9 7/8"x 11"surface hole from 7,456.0 7,923.0 00:00 06:00 7456'to 7923'MD.6080'TVD.ADT= 4.95 hrs,Bit hrs=45.01 hrs,Jar hrs= 127.87 P/U=185 K,S/O=115 K,• Rot=142 K,RPM=160.Torque on/off =13-15 K/10-15 K, Flow out=95%, WOB= 15-18 K, 775 gpm,3290 psi. Max gas=1852 units.ECD=11.15 SPR's @ 7733'MD 6018'TVD w/ 10.0+ppg @ 0300 hrs. #1 30/40 SPM @ 200/300 psi #2 30/40 SPM @ 215/300 psi 6/17/2016 6/17/2016 6.00 INTRM1 DRILL DDRL P Drill 9 7/8"x 11"surface hole from 7,923.0 8,184.0 06:00 12:00 7923'to 8184'MD.6162'TVD.ADT= 5.00 hrs,Bit hrs=50.01 hrs,Jar hrs= 132.87 P/U=185 K,S/O= 117 K, Rot=147 K,RPM=160.Torque on/off = 10-181K/10-13 K, Flow out=95%, WOB=5-10 K, 775 gpm,3050 psi. Max gas=1946 units.ECD=11.15 Note:Start control drilling at 40ft/hr from 8045' 6/17/2016 6/17/2016 2.25 INTRM1 DRILL DDRL P Drill 9 7/8"x 11"surface hole from 8,184.0 8,250.0 12:00 14:15 8184'to 8250'MD.6179'TVD.ADT= 1.75 hrs,Bit hrs=51.76 hrs,Jar hrs= 134.62 P/U=185 K,S/O= 117 K, Rot=147 K,RPM=160.Torque on/off =10-12 K/10-13 K, Flow out=94%, WOB=5-10 K, 775 gpm,2910 psi. Max gas=1131 units.ECD=11.08 6/17/2016 6/17/2016 1.00 INTRM1 CASING CIRC P Circulate 35 bbls(35 ppb)LCM pill 8,250.0 8,250.0 14:15 15:15 surface to surface.775 gpm,2910 psi, 140 rpm,8-10K tq. Page 12/35 Report Printed: 7/12/2016 Iterations Summary (with Timelog Depths) • 2S-12 ConocoPhillips ,iSx':ka Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) ; Phase Op Code Activity Code Time P-T-X Operation (5KB); End Depth(5KB) 6/17/2016 6/17/2016 0.75 INTRM1 CASING CIRC P Stand back one stand DP to 8205' 8,250.0 8,205.0 15:15 16:00 MD.Drop RFID chip to close under reamer. Pump down at 650 gpm,2440 psi.,MWD turbine speed 2400 rpm. Reduce rate to 200 gpm as chip passes reamer. 6/17/2016 6/17/2016 1.25 INTRM1 CASING MPDA T PJSM-Change out leaking RCD 8,205.0 8,205.0 16:00 17:15 bearing assy. 6/17/2016 6/17/2016 0.50 INTRM1 CASING CIRC P Stage pump up to 650 gpm,2610 psi. 8,205.0 8,205.0 17:15 17:45 MWD turbine speed 2600 rpm.Gain of 170 psi and loss of 200 rpm. 6/17/2016 6/17/2016 1.50 INTRM1 CASING OWFF P Perform exhale test.5 cycles of 2 min 8,205.0 8,205.0 17:45 19:15 bleed back and 3 min shut in. Initial shut in pressure=132 psi.Initial bleed back=2.5 bbls.Final shut in pressure =108 psi.Final bleed back=1.4 bbls. Perform 2 cycles of 3 min bleed back and 3 min shut in. Final shut in=99 psi and final bleed back=1.5 bbl. • 6/17/2016 6/17/2016 1.00 INTRM1 CASING CIRC P CBU.640 gpm,2500 psi.30 rpm,7- 8,205.0 8,205.0 19:15 20:15 9K tq.ECD=10.78 ppg.No losses. 6/17/2016 6/17/2016 1.50 INTRM1 CASING PMPO P Pump OOH f/8205'MD t/7553'MD.3 8,205.0 7,553.0 20:15 21:45 bpm,400 psi.P/U wt=190K.Hold 120 psi back pressure.From 7800'MD to 7710'MD hole lost 13 bbls.From 7710'MD to 7550'MD gained 13 bbls back. 6/17/2016 6/17/2016 1.75 INTRM1 CASING CIRC T CBU x 2.650 gpm,2490 psi,Rot 7,553.0 7,553.0 21:45 23:30 wt=155K, 15 rpm, 10K tq,F/0=90%. Max gas 7531 units. No losses/no gains. 6/17/2016 6/18/2016 0.50 INTRM1 CASING OWFF T Perform exhale test.6 cycles of 2 min 7,553.0 7,553.0 23:30 00:00 bleed back and 3 min shut in.Initial shut in pressure=80 psi. Initial bleed back=.7 bbls.Final shut in pressure= 38 psi.Final bleed back=.5 bbls. Lost 290 bbls for tour 6/18/2016 6/18/2016 0.50 INTRM1 CASING OWFF T Continue performing exhale test, 7,553.0 7,553.0 00:00 00:30 rotating @ 10rpm, 10k TQ. 6/18/2016 6/18/2016 10.00 INTRM1 CASING OWFF T Monitor well on trip tank.Confirm that 7,553.0 7,553.0 00:30 10:30 well was breathing back @ 3.57 bbl/hr decreasing down to static-total of 16 bbl bled back. 6/18/2016 6/18/2016 1.00 INTRM1 CASING CIRC T Circulate 1 x BU w/475 gpm, 1500 7,553.0 7,553.0 10:30 11:30 psi,F/O 45%,40 rpm,7-8k Tq.Max gas observed=774 units at bottoms up. 6/18/2016 6/18/2016 0.25 INTRM1 CASING OWFF T Monitor well and establish well is 7,553.0 7,553.0 11:30 11:45 breathing. 6/18/2016 6/18/2016 5.25 INTRM1 CASING SMPD P PJSM-Strip OOH f/7553'MD t/2799' 7,553.0 2,799.0 11:45 17:00 MD.Hold back pressure as per stripping schedule. 6/18/2016 6/18/2016 0.50 INTRM1 CASING CIRC P CBU.475 gpm, 1190 psi,30 rpm,2- 2,799.0 2,799.0 17:00 17:30 5K tq. F0=71%Rot=95K.Max gas=138 units. 6/18/2016 6/18/2016 0.75 INTRM1 CASING OWFF P Perform exhale test.Slight breathing. 2,799.0 2,799.0 17:30 18:15 Open choke and check for flow.Well flowing at 1.4 bph decreasing to.2 bph in 20 min. Page 13/35 Report Printed: 7/12/2016 S : a , r Aerations Summary (with Timelog Depths) 2S-12 Corso iiiiips Rig: DOYON 141 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) 6/18/2016 6/18/2016 0.50 INTRM1 CASING MPDA P Flush and blow down MPD choke skid 2,799.0 2,799.0 18:15 18:45 and lines. 6/18/2016 6/18/2016 1.00 INTRM1 CASING MPDA P Pull RCD bearing assy.Install trip 2,799.0 2,799.0 18:45 19:45 nipple.Monitor well via cellar. 6/18/2016 6/18/2016 0.25 INTRM1 CASING OWFF P Monitor well.Static. 2,799.0 2,799.0 19:45 20:00 6/18/2016 6/18/2016 1.75 INTRM1 CASING TRIP P POOH(/2799'MD t/751'MD. 2,799.0 751.0 20:00 21:45 6/18/2016 6/18/2016 0.25 INTRM1 CASING OWFF P Monitor well.Static.Sim-ops/Hold 751.0 751.0 21:45 22:00 PJSM on laying down BHA. 6/18/2016 6/18/2016 1.50 INTRM1 CASING BHAH P Lay down HWDP,jars,saver sub, 751.0 126.0 22:00 23:30 NMDC's and stab. Calc disp=68.26 bbls Act disp=68.41 bbls for trip. 6/18/2016 6/19/2016 0.50 INTRM1 CASING BHAH P PJSM-Remove nuclear source. 126.0 126.0 23:30 00:00 6/19/2016 6/19/2016 1.00 INTRM1 CASING BHAH P Continue laying down BHA as per 126.0 0.0 00:00 01:00 Schlumberger. 6/19/2016 6/19/2016 0.50 INTRM1 CASING BHAH P Clean and clear rig floor.Change out 0.0 0.0 01:00 01:30 rotary bushings. 6/19/2016 6/19/2016 0.50 INTRM1 CASING WWWH P Rig up and flush BOPE. 0.0 0.0 01:30 02:00 6/19/2016 6/19/2016 0.50 INTRM1 CASING RURD P PJSM-Drain stack and pull wear 0.0 0.0 02:00 02:30 bushing. 6/19/2016 6/19/2016 0.75 INTRM1 CASING BOPE P PJSM-Change upper VBR's to 7 5/8" 0.0 0.0 02:30 03:15 solid body rams.Sim-ops/Rig up casing equipment. 6/19/2016 6/19/2016 0.50 INTRM1 CASING BOPE P Rig up test equipment. 0.0 0.0 03:15 03:45 6/19/2016 6/19/2016 0.75 INTRM1 CASING BOPE P Test top rams w/7-5/8"test joint to 0.0 0.0 03:45 04:30 250/3500 psi,annular to 250/2500 psi on chart for 5 min each. 6/19/2016 6/19/2016 0.25 INTRM1 CASING BOPE P R/D testing equipment and pull test 0.0 0.0 04:30 04:45 plug. 6/19/2016 6/19/2016 0.25 INTRM1 CASING RURD P Con't to rig up casing equipment. 0.0 0.0 04:45 05:00 6/19/2016 6/19/2016 1.75 INTRM1 CASING PUTB P PJSM-M/U 7-5/8"casing shoe track 0.0 246.0 05:00 06:45 with TopCo float shoe and Weatherford float collar and landing collar,one joint casing and 3 pup jts with BakerLok on shoe track. Fill casing and test floats,good. 6/19/2016 6/19/2016 4.50 INTRM1 CASING PUTB P RIH w/7-5/8",29.7#,L-80,Hyd 563 246.0 2,828.0 06:45 11:15 Dopeless casing f/246'MD to 2828' MD. Calc disp=30.25 bbls Act disp=27.25 bbls. 6/19/2016 6/19/2016 0.75 INTRM1 CASING CIRC P Circulate casing volume.Stage pump 2,828.0 2,828.0 11:15 12:00 up from 1.5 bpm/160 psi to 5.5 bpm/180 psi. 13%FO/P/U=93K S/O=87K 6/19/2016 6/19/2016 2.50 INTRM1 CASING PUTB P RIH w/7-5/8",29.7#,L-80,Hyd 563 2,828.0 4,141.0 12:00 14:30 Dopeless casing f/2828'MD to 4141' MD. 6/19/2016 6/19/2016 1.25 INTRM1 CASING CIRC P CBU.Stage pump up to 5.5 bpm,250 4,141.0 4,141.0 14:30 15:45 psi.P/U=120K 5/0=100K. 15%FO. Page 14/35 Report Printed: 7/12/2016 Iterations Summary (with Timelog Depths) 2S-12 .: CO Ocolil 0.` (� Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Cede Activity Code Time P T X Operation (ftKB) End Depth(ftKS) 6/19/2016 6/19/2016 1.50 INTRM1 CASING PUTB P RIH w/7-5/8",29.7#,L-80,Hyd 563 4,141.0 5,124.0 15:45 17:15 Dopeless casing f/4141'MD to 5124' MD.30K loss of down weight. Decision make to CBU. 6/19/2016 6/19/2016 1.25 INTRM1 CASING CIRC T CBU.Stage pump up to 5.5 bpm,415 5,124.0 5,124.0 17:15 18:30 psi.Began taking losses at 5.5 bpm. Reduce rate to 1.5 bpm.Loss rate at 55 bph.Pumped 1900 stks.P/U=140K 5/0=110K.Max gas=247 units. 6/19/2016 6/20/2016 5.50 INTRM1 CASING PUTB P RIH w/7-5/8",29.7#,L-80,Hyd 563 5,124.0 7,303.0 18:30 00:00 Dopeless casing f/5124'MD to 7303' MD. No returns until 6500'MD then slight returns at flowline. Total losses for tour=183 bbls 6/20/2016 6/20/2016 0.50 INTRM1 CASING PUTB P RIH w/7-5/8",29.7#,L-80, Hyd 563 7,303.0 7,550.0 00:00 00:30 Dopeless casing f/7303'MD to 7550' MD. 6/20/2016 6/20/2016 1.25 INTRM1 CASING CIRC P Break circulation at the top of the HRZ 7,550.0 7,550.0 00:30 01:45 formation w/1 bpm,500 psi staging up to 1 bpm,475psi.Observed —25% returns. PUW= 195k,SOW=132k 6/20/2016 6/20/2016 1.50 INTRM1 CASING PUTB P RIH w/7-5/8",29.7#, L-80,Hyd 563 7,550.0 8,208.0 01:45 03:15 Dopeless casing f/7550'MD to 8208' MD. 6/20/2016 6/20/2016 0.50 INTRM1 CASING HOSO P Make up hanger&landing joint.Wash 8,208.0 8,239.0 03:15 03:45 down hanger to load shoulder @ 8239'MD w/1 bpm,425 psi. 6/20/2016 6/20/2016 3.00 INTRM1 CEMENT CIRC P Circulate&condition mud system for 8,239.0 8,239.0 03:45 06:45 cement job.Stage up 1-5 bpm,ICP 400 psi,FCP 480 psi,0-25%returns, reciprocating 15'. 6/20/2016 6/20/2016 0.25 INTRM1 CEMENT RURD P Rig up cement equipment and line up 8,239.0 8,239.0 06:45 07:00 Schlumberger. 6/20/2016 6/20/2016 0.25 INTRM1 CEMENT SFTY P Hold PJSM for pumping intermediate 8,239.0 8,239.0 07:00 07:15 cement job. 6/20/2016 6/20/2016 2.75 INTRM1 CEMENT CMNT P Pump 5 bbls of H2O&PT lines to 8,239.0 8,239.0 07:15 10:00 900/4000 psi.Pump 40 bbls of 12.5 ppg MPII at 5 bpm,455 psi.Drop bypass plug. Pump 136.9 bbls of 15.8 ppg Class G+cement at 4.5 bpm,400 psi dropping to 225 psi.Drop top plug. Pump 10 bbls of H2O at 5 bpm,301 psi.Displace with 10.0 ppg LSND mud at 5-7 bpm,200 psi increasing to 1050 psi.Slow to 3 bpm,925 psi prior to bumping plug, PU 206K,SO 106K. Bump plug with 3590 strokes,FCP= 980 psi. Pressure up to 1480 psi(500 psi over FCP)for 5 min.Check floats- good.CIP 0930 hrs.Pressure up to open stage collar,observe shift @ 3020 psi. Note-No returns to surface throughout the job Page 15/35 . Report Printed: 7/12/2016 Operations Summary (with Timelog Depths) 2S-12 ConoccipPhillips Rig: DOYON 141 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(ftKS) 6/20/2016 6/20/2016 4.00 INTRM1 CEMENT CIRC P Establish circulation through stage 8,239.0 8,239.0 10:00 14:00 collar w/1 bpm,410 psi,50%losses. Stage up to 5 bpm,420 psi and observe full returns.Shut down pumps and observe well breathing back. Resume circulation and stage up to 6.5 bpm,520 psi.SIMOPS PJSM for 2nd stage held. Note:Small amount of MPII returns were observed @-2800 strokes. 6/20/2016 6/20/2016 2.25 INTRM1 CEMENT CMNT P Pump 44.9 bbls of 12.5 ppg MPII at 5 8,239.0 8,239.0 14:00 16:15 bpm, 151 psi.Pump 62.8 bbls of 15.8 ppg Class G+cement w/1 lb/bbl CemNet LCM added©3.5 bpm, 120 psi.Drop closing plug.Pump 10.4 bbls of H2O at 5 bpm, 100 psi.Displace with 10.0 ppg LSND mud at 5 bpm, 125 psi increasing to 660 psi. Decrease rate to 3 bpm,FCP=550 psi prior to bumping plug.Bump plug with 2535 strokes&pressure up to 1800 psi,holding for 5 min.Observed stage collar shift closed @ 1500 psi. CIP 16:00 hrs.Bleed off pressure in 500 psi increments and confirm that stage collar is closed.No losses observed. 6/20/2016 6/20/2016 6.00 INTRM1 CEMENT OWFF T Shut in well on annular and wait on 8,239.0 8,239.0 16:15 22:15 cement. SIMOPS:Remove casing from shed, load 4"DP,clean pits,and service MP #2. 6/20/2016 6/20/2016 0.25 INTRM1 CEMENT OWFF P PJSM-110 psi on casing,0 psi on OA. 8,239.0 8,239.0 22:15 22:30 Bleed pressure from casing and check for flow on OA. 6/20/2016 6/20/2016 0.50 INTRM1 CEMENT WWSP P Back out landing jt.Install 7 5/8"x 10 8,239.0 0.0 22:30 23:00 3/4"packoff as per CIW Rep. 6/20/2016 6/21/2016 1.00 INTRM1 CEMENT WWSP P RILDS.Test packoff 250 psi/5 min low 0.0 0.0 23:00 00:00 and 5000psi/10 min high.Witnessed by CPAI Rep. 6/21/2016 6/21/2016 0.25 INTRM1 CEMENT WWSP P PJSM-lay down pack off running tool. 0.0 0.0 00:00 00:15 6/21/2016 6/21/2016 0.75 INTRM1 CEMENT RURD P PJSM-rig/lay down casing equipment, 0.0 0.0 00:15 01:00 CIW equipment,&blow down TD. 6/21/2016 6/21/2016 1.00 INTRM1 CEMENT FRZP P PJSM-rig up to freeze protect OA w/ 0.0 0.0 01:00 02:00 LRS.SIMOPS rig up to lay down 5" DP. 6/21/2016 6/21/2016 3.00 INTRM1 CEMENT FRZP P PJSM-flush&freeze protect OA. 0.0 0.0 02:00 05:00 Pump 130 bbls of H2O at 2 bpm. Observe leak off pressure at 900 psi with 3.8 bbls away.Final pump rate 2.5 bpm&500 psi.Switch to Isotherm &pump 86.7 bbls at 2.25 bpm, IPP 600 psi,FPP 900 psi.Shut in post job 450 psi. 6/21/2016 6/21/2016 2.25 INTRM1 CEMENT PULD P Continue laying down 105 joints of 5" 0.0 0.0 05:00 07:15 DP.Clear rig floor. • Page 16/35 Report Printed: 7/12/2016 • • Aerations Summary (with Timelog Depths) 014 - 2S-12 CococoPhiiiip Rig: DOYON 141 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(ftKE 6/21/2016 6/21/2016 1.50 INTRM1 CEMENT BOPE P PJSM-Change out upper rams to 2- 0.0 0.0 07:15 08:45 7/8"X 5"VBR's.SIMOPS load pipe shed w/291 joint of 4"DP&C/O saver sub to XT39. 6/21/2016 6/21/2016 1.00 INTRM1 CEMENT RURD P Continue changing out saver sub on 0.0 0.0 08:45 09:45 the TD&handling equipment to 4". Spill Drill CRT 90 sec @ 09:45 hrs. 6/21/2016 6/21/2016 1.50 INTRMI CEMENT PULD P PJSM-pick up 36 joints of 4"XT39 DP 0.0 0.0 09:45 11:15 &rack back in the derrick. 6/21/2016 6/21/2016 0.75 INTRM1 CEMENT SVRG P PJSM-service rig. 0.0 0.0 11:15 12:00 OA pressure 350 psi @ 12:00 hrs. 6/21/2016 6/21/2016 0.25 INTRM1 CEMENT SVRG P PJSM-continue servicing drawworks. 0.0 0.0 12:00 12:15 6/21/2016 6/21/2016 0.50 INTRM1 CEMENT RURD P PJSM-clear rig floor of 5"handling 0.0 0.0 12:15 12:45 equipment. 6/21/2016 6/21/2016 6.50'INTRM1 CEMENT PULD P PJSM-pick up 255 joints of 4"DP& 0.0 0.0 12:45 19:15 rack back in the derrick. 6/21/2016 6/21/2016 0.75 INTRM1 CEMENT RURD P PJSM-clear&clean rig floor,lay 0.0 0.0 19:15 20:00 down mouse hole. 6/21/2016 6/21/2016 1.50 INTRM1 WHDBOP RURD P PJSM-rig up test equipment,change 0.0 0.0 20:00 21:30 out test plug seal,flood stack,& perform shell test. 6/21/2016 6/22/2016 2.50 INTRM1 WHDBOP BOPE P Test BOPE w/4.5"test joint to 0.0 0.0 21:30 00:00 250/3500 psi for 5 min each.#1:Top pipe rams,CV 1,12,13, 14&manual kill valve.#2:Upper IBOP, HCR kill, CV 9,&11.#3:Lower IBOP,CV 5,8& 10. #4: Dart Valve,CV 4,6&7. #5: FOSV and CV 2. #6: HCR choke&4" kill line Demco valve, #7:Manual choke valve&HCR kill. #8:Annular preventer tested to 250/2500 psi.#9: Lower pipe rams.Test witness waived by AOGCC Rep Brian Bixby. OA pressure 240 psi @ 24:00 hrs. 6/22/2016 6/22/2016 2.50 INTRM1 WHDBOP BOPE P PJSM-Continue to testing BOPE w/ 0.0 0.0 00:00 02:30 3.5"test joint to 250/3500 psi for 5 min each.#10:Blind rams&CV 3.#11: Annular.#12:Upper VBR's.#13: Lower VBR's.Accumulator test: System pressure=3000 psi,Pressure after closing=1800 psi,200 psi attained after 37 seconds,full pressure attained after 166 seconds. Five bottle nitrogen avg= 1950 psi. Test flow out&pit level alarms.Test gas alarms.Test manual&super choke.Brian Bixby of the AOGCC waived witness. 6/22/2016 6/22/2016 1.00 INTRM1 WHDBOP RURD P PJSM-rig down test equipment,blow 0.0 0.0 02:30 03:30 down all lines&top drive.SIMOPS set wear bushing 10.0"ID, 10.75"OD, 1.08'L. 6/22/2016 6/22/2016 1.00 INTRMI CEMENT PULD P PJSM-pick up 5 joints of 4"HWDP& 0.0 0.0 03:30 04:30 JARS,racking back in the derrick. Pick up&rack back 21 joints of 4"DP. 6/22/2016 6/22/2016 0.50 INTRM1 CEMENT RURD P PJSM-remove&lay down mouse 0.0 0.0 04:30 05:00 hole.Clear&clean rig floor. 6/22/2016 6/22/2016 0.50 INTRM1 CEMENT BHAH P PJSM-mobilize BHA 4 tools to the rig 0.0 0.0 05:00 05:30 floor. Page 17/35 Report Printed: 7/12/2016 • 4' Operations Summary (with Timelog Depths) • 2S-12 • ConocoPhillips Rig: DOYON 141 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) 6/22/2016 6/22/2016 2.75 INTRM1 CEMENT BHAH P PJSM-make up BHA 4 per SLB DD, 0.0 410.0 05:30 08:15 Sperry MWD,&WFD tech f/0-410' MD. 6/22/2016 6/22/2016 2.50 INTRM1 CEMENT PULD P PJSM-single in the hole w/4"DP f/ 410.0 2,967.0 08:15 10:45 410'-2967'MD,filling every 20 stands. Kick w/Tripping Drill CRT 85 sec @ 09:15 hrs. 6/22/2016 6/22/2016 0.25 INTRM1 CEMENT QEVL P Continue to single in f/2967'-3062' 2,967.0 3,062.0 10:45 11:00 MD,obtain free ring w/BAT Sonic. 6/22/2016 6/22/2016 3.00 INTRM1 CEMENT PULD P Continue to single in f/3062'-5712' 3,062.0 5,712.0 11:00 14:00 MD,PU 110K,SO 95K,fill pipe every 20 stands. OA pressure 350 psi at 12:00 hrs. 6/22/2016 6/22/2016 0.50 INTRM1 CEMENT REAM P PJSM-wash&ream to tag cement f/ 5,712.0 5,797.0 14:00 14:30 5712'-5797'MD,208 gpm,900 psi, FO 20%,40 rpm,Tq 6K. 6/22/2016 6/22/2016 0.75 INTRM1 CEMENT COCF P Clean out cement to stage collar f/ 5,797.0 5,820.0 14:30 15:15 5797'-5820'MD,208 gpm,900 psi, FO 20%,80 rpm,Tq 7-8K,WOB 5- 10K. 6/22/2016 6/22/2016 0.75 INTRM1 CEMENT DRLG P Drill out stage collar,f/5820'-5825' 5,820.0 5,825.0 15:15 16:00 MD, 170 gpm,900 psi,FO 25%,80 rpm,Tq 5-10K, PU 110K,SO 95K, WOB 5-10K.Work through collar 3 times. 6/22/2016 6/22/2016 1.00 INTRM1 CEMENT CIRC P CBU f/5825'-5709'MD,210 gpm, 5,825.0 5,709.0 16:00 17:00 1200 psi,FO 25%,80 rpm,Tq 7K. 6/22/2016 6/22/2016 0.75 INTRM1 CEMENT PULD P Continue to single in f/5709'-6058' 5,709.0 6,058.0 17:00 17:45 MD,fill pipe every 20 stands. 6/22/2016 6/22/2016 5.25 INTRM1 CEMENT QEVL P Continue to single in the hole& 6,058.0 7,975.0 17:45 23:00 perform MAD pass f/6058'-7975' MD,at 500 fph,PU 155K,SO 85K. 6/22/2016 6/23/2016 1.00 INTRM1 CEMENT CIRC P Circulate&condition mud at 210 gpm, 7,975.0 7,975.0 23:00 00:00 1400 psi,FO 22%,60 rpm,Tq 9K. 6/23/2016 6/23/2016 0.25 INTRM1 CEMENT CIRC P Condition mud at 210 gpm, 1400 psi, 7,975.0 7,975.0 00:00 00:15 FO 22%,60 rpm,Tq 9K. 6/23/2016 6/23/2016 0.50 INTRM1 CEMENT RURD P PJSM-rig up test equipment. 7,975.0 7,975.0 00:15 00:45 6/23/2016 6/23/2016 0.50 INTRM1 CEMENT PRTS P PJSM-pressure test 7-5/8",29.7#, 7,975.0 7,975.0 00:45 01:15 intermediate casing to 3500 psi, charted. Pressured up with 4.6 bbls to 3600 psi.Shut in&observe pressure level out at 3575 psi over 30 minutes. 6/23/2016 6/23/2016 1.50 INTRM1 CEMENT SLPC P PJSM-cut&slip 59'of drill line. 7,975.0 7,975.0 01:15 02:45 6/23/2016 6/23/2016 0.50 INTRM1 CEMENT SVRG P PJSM-service rig. 7,975.0 7,975.0 02:45 03:15 6/23/2016 6/23/2016 0.75 INTRM1 CEMENT COCF P PJSM-wash&ream f/7975'-8088' 7,975.0 8,088.0 03:15 04:00 MD,210 gpm, 1450 psi,FO 23%,60 rpm,Tq 9-10K. Page 18/35 Report Printed: 7/12/2016 • Aerations Summary (with Timelog Depths) ko: ,= 2S-12 ConocoPhillips , ,n Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKE) End Depth(ftKB) 6/23/2016 6/23/2016 6.00 INTRM1 CEMENT DRLG P Drill out shoe track&rat hole f/8088'- 8,088.0 8,250.0 04:00 10:00 8250'MD,210 gpm, 1520 psi,FO 23%,60-80 rpm,Tq 9-10K,WOB 10- 15K,PU 155K,SO 86K,ROT 115K. Drilled out shoe w/195 gpm,75 rpm, WOB 3-5K. Fire Drill CRT 70 sec @ 10:00 hrs. SPR's at 8231'MD,6157'TVD,MW 10.0 ppg,09:00 hrs. #1 @ 20=420,@ 30=600 psi #2 @ 20=420,@ 30=620 psi 6/23/2016 6/23/2016 0.75 INTRM1 CEMENT DDRL P DDrill 6-3/4"production section f/ 8,250.0 8,270.0 10:00 10:45 8250'-8270'MD,6157'TVD, ADT.22,Bit.22,Jars 51.48,PU 158K, SO 85K,ROT 115K,Tq on 8-10K,off 8-10K,ECD 10.76,FO 22%,WOB 5- 7K,80 rpm, 1580 psi,gas 0,footage 20'MD. 6/23/2016 6/23/2016 0.75 INTRM1 CEMENT CIRC P C&C mud for FIT racking back one 8,270.0 8,166.0 10:45 11:30 stand f/8270'-8166'MD,at 220 gpm, 1580 psi,60 rpm,Tq 9K.SIMOPS rig up for FIT. 6/23/2016 6/23/2016 0.25 INTRM1 CEMENT OWFF P Monitor well,static. 8,166.0 8,166.0 11:30 11:45 6/23/2016 6/23/2016 0.25 INTRM1 CEMENT FIT P PJSM-perform FIT to an EMW of 13.0 8,166.0 8,166.0 11:45 12:00 ppg at 8238'MD,6167'TVD,with a MW 10.0 ppg.Pressured up to 950 psi w/1.2 bbls.shut in&observe pressure decrease f/940 psi to 910 psi over 10 minutes.Bled back 1.1 bbls. OA pressure 435 psi at 12:00 hrs. 6/23/2016 6/23/2016 0.50 PROD1 DRILL RURD P PJSM-rig/blow down test equipment. 8,166.0 8,166.0 12:00 12:30 6/23/2016 6/23/2016 0.50 PROD1 DRILL SVRG P PJSM-service rig&change out Willis 8,166.0 8,166.0 12:30 13:00 choke valve. 6/23/2016 6/23/2016 1.75 PROD1 DRILL DISP P Displace well to 10.3 ppg FloPro mud 8,166.0 8,230.0 13:00 14:45 system f/8166'-8230'MD.Pump 29 bbls Hi-Vis pill followed by 365 bbls of 10.3 ppg FloPro @ 210 gpm, 1500 psi,FO 24%,60 rpm,Tq 9.5K • SPR's at 8255'MD,6182'TVD,MW 10.3 ppg, 14:30 hrs. #1 @ 20=600,@ 30=760 psi #2 @ 20=580,@ 30=790 psi 6/23/2016 6/23/2016 0.25 PROD1 DRILL OWFF P Monitor well,static. 8,230.0 8,230.0 14:45 15:00 6/23/2016 6/23/2016 0.75 PROD1 DRILL MPDA P PJSM-remove trip nipple&install 8,230.0 8,230.0 15:00 15:45 RCD bearing.Hook up all associated lines. 6/23/2016 6/23/2016 1.00 PROD1 DRILL MPDA P Calibrate MPD chokes at 250 gpm, 8,230.0 8,230.0 15:45 16:45 2080 psi,FO 30%. 6/23/2016 6/23/2016 2.50 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 8,230.0 8,404.0 16:45 19:15 8270'-8404'MD,6225'TVD, ADT.96,Bit 1.18,Jars 52.44,PU 145K,SO 85K, ROT 105K,Tq on 9- 10K,off 7-8K,ECD 10.59,FO 27%, WOB 10-15K,80 rpm,250 gpm,2250 psi,gas 356,footage 134'MD. Page 19/35 Report Printed: 7/12/2016 • Operations Summary (with Timelog Depths) 2S-12 ConocoPhillips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code; Time P-T-X Operation (ftKS) End Depth(ftK�); 6/23/2016 6/23/2016 0.75 PROD1 DRILL CIRC P Pull up to 8385'MD drop RFID chips 8,404.0 8,385.0 19:15 20:00 pumping @ 250 gpm,2250 psi,FO 27%, 10 rpm,Tq 8K.No indication of tool opening after 1200 strokes. 6/23/2016 6/23/2016 1.00 PROD1 DRILL CIRC T Continue to try to open reamer.Drop 6 8,385.0 8,385.0 20:00 21:00 more RFID chips&pump at 250 gpm, 2250 psi, 10 rpm,Tq 8K. Increase pump rate to 280 gpm,2600 psi after 1000 strokes,shutting down after 1300 strokes. Pull test to verify still' closed.Drop 6 more chips w/higher sequence count&observe pressure drop 2650 to 2040 psi&turbine speed 3960 to 2040. Pull test into shoe observing 5K over pull&pressure increase to 2500 psi. Reamer open. 6/23/2016 6/24/2016 3.00 PROD1 DRILL DDRL P DDrill 6-3/4"X 7-1/2"production 8,385.0 8,585.0 21:00 00:00 section f/8404'-8585'MD,6262' TVD,ADT 2.73,Bit 3.81,Jars 55.17, PU 150K,SO 85K,ROT 108K,Tq on 11-12K,off 9-10K, ECD 11.79,FO 79%,WOB 15-20K,100 rpm,340 gpm,2845 psi,gas 5896,footage 181' MD. OA 470 psi @ 24:00 hrs. 6/24/2016 6/24/2016 3.25 PROD1 DRILL DDRL P DDrill 6-3/4"X 7-1/2"production 8,585.0 8,771.0 00:00 03:15 section f/8585 to 8777'MD,6288' TVD,ADT 1.67,Bit 5.62,Jars 56.88, PU 155K,SO 78K, ROT 110K,Tq on 10-13K,off 10-11K,ECD 11.63,FO 13%,WOB 10-15K, 110 rpm,365 gpm,3050 psi,Max gas 5000,footage 192'MD. Under reamed 7-1/2"hole f/8252'- 8631'MD. Kick w/Drilling CRT 95 sec @ 01:15 hrs. 6/24/2016 6/24/2016 0.75 PROD1 DRILL CIRC P Attempt to close reamer as per WFT 8,771.0 8,771.0 03:15 04:00 (50'of 7-1/2"hole into Kup C)@ 8770'MD.Drop RFDI tags and pump down @ 280 gpm,2190 psi, 16%FO, ROT @ 10 rpm's,slow pumps down to 100 gpm,740 psi.Shut down for 10 min then bring pumps up to 280 gpm. No change in pump pressure or turbine rpm's,decision made to drop more RFDI tags, 6/24/2016 6/24/2016 1.50 PROD1 DRILL CIRC T Drop more RFDI tags as per WFT rep. 8,771.0 8,771.0 04:00 05:30 Pump tag down @ 280 gpm,2190 slowing pumps down to 100 gpm. Shut down f/10 min and allow blocks time to close.Establish circulation @ 280 gpm,no change in pump pressure or turbine rpm's. Drop a 3rd set of RFDI tags as per WFT and pump down as above. Observed pump pressure @ 280 gpm increase f/2190 psi to 2800 psi and turbine rpm's increase indicating reamer as closed. Page 20/35 Report Printed: 7/12/2016 41151.1, • k Operations Summary (with Timelog Depths) f." 2S-12 Conac hitilpS ... g i.er,Rz Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKE) End Depth(ftKE) 6/24/2016 6/24/2016 1.00 PROD1 DRILL OWFF P Perform draw down on well,w/MPD. 8,771.0 8,771.0 05:30 06:30 Max trapped pressure was 361 psi. Opened Choke 1 %50,pressure bled down to 0,quickly.Closed up choke 1. Saw increase of 9psi.Continued till well was static.Well is statically over balanced ,with a 11.6ppg EMW. 6/24/2016 6/24/2016 5.50 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 8,771.0 9,226.0 06:30 12:00 8777'to 9226'MD,6287'TVD,ADT 3.89,Bit 9.51,Jars 60.77,PU 148K, SO 78K,ROT 108K,Tq on 11K,off 9K,ECD 11.71,FO 13%,WOB 5-10K, 120 rpm,265 gpm,2600 psi, Max gas 11340,footage 449'MD. OA 425 psi @ 12:00 hrs. SPR's at 8924'MD,6297'TVD,MW 10.3 ppg,08:20 hrs. #1 @20=490,@30=740 psi #2 @20=470,@30=750 psi 6/24/2016 6/24/2016 2.25 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 9,226.0 9,441.0 12:00 14:15 9226'to 9441'MD,6288'TVD,ADT 1.81,Bit 11.32,Jars 62.58,PU 150K, SO 75K,ROT 110K,Tq on 11-12K,off 10K,ECD 11.63,FO 13%,WOB 5- 10K, 140 rpm,265 gpm,2520 psi, Max gas 11454,footage 215'MD. 6/24/2016 6/24/2016 1.25 PROD1 DRILL DHEQ T Trouble shoot PeriScope,for failed 9,441.0 9,441.0 14:15 15:30 resistivity.Decision made to drill ahead without. 6/24/2016 6/24/2016 2.50 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 9,441.0 9,680.0 15:30 18:00 9441'to 9680'MD,6289'TVD,ADT 2.09,Bit 13.41,Jars 64.67, PU 155K, S0 75K, ROT 107K,Tq on 11-12K,off 9K,ECD 12.65,FO 14-18%,WOB 4- 8K, 140 rpm,265 gpm,2550 psi,Max gas 11384,footage 239'MD. SPR's at 9675'MD,6289'TVD,MW 10.3 ppg, 18:00 hrs. #1 @20=520,@30=770 psi #2 @20=480,@30=740 psi 6/24/2016 6/25/2016 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 9,680.0 10,058.0 18:00 00:00 9680'to 10058'MD,6293'TVD,ADT 3.45,Bit 16.86,Jars 68.12,PU 160K, SO 70K, ROT 105K,Tq on 11-12K,off 9-11K,ECD 11.59,FO 35% (recalibrated),WOB 10-15K, 140 rpm, 265 gpm,2550 psi,Max gas 10838, footage 378'MD. 6/25/2016 6/25/2016 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 10,058.0 10,625.0 00:00 06:00 10058'-10625'MD,6284'TVD,ADT 4.79,Bit 21.65,Jars 72.91,PU 160K, SO 65K,ROT 110K,Tq on 12K,off 11K, ECD 11.76,FO 35%,WOB 5-8K, 140 rpm,263 gpm,2560 psi, Max gas 10639,footage 567'MD. Page 21/35 Report Printed: 7/12/2016 • °° g i Operations Summary (with Timelog Depths) 2S-12 ConocaPhiiiips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 6/25/2016 6/25/2016 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 10,625.0 11,099.0 06:00 12:00 10625-11099'MD,6271'TVD,ADT 4.05,Bit 25.7,Jars 76.96,PU 169K, SO 63K,ROT 108K,Tq on 13K,off 10K,ECD 11.71,FO 34%,WOB 6- 10K, 140 rpm,265 gpm,2600 psi, Max gas 10660,footage 474'MD. SPR's at 11095'MD,6271'TVD,MW 10.3 ppg, 11:43 hrs. #1 @20=560,@30=820 psi #2 @20=610,@30=860 psi 6/25/2016 6/25/2016 2.00 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 11,099.0 11,287.0 12:00 14:00 11099'-11287'MD,6271'TVD,ADT 1.65,Bit 27.35,Jars 7861,PU 170K, SO 60K,ROT 110K,Tq on 13-14K,off 10K,ECD 11.79,FO 35%,WOB 6- 10K, 140 rpm,265 gpm,2450 psi, Max gas 10690,footage 188'MD. 6/25/2016 6/25/2016 0.50 PROD1 DRILL SEQP T PJSM-observe 150 psi pressure loss. 11,287.0 11,287.0 14:00 14:30 Check both pumps&surface lines. Bled off pump psi&observe no back pressure loss.Wash out suspected below the drill string floats. SPR's at 11287'MD,6264'TVD,MW 10.3 ppg, 14:15 hrs. #1 @20=610,@30=860 psi #2 @20=630,@30=870 psi 6/25/2016 6/25/2016 7.75 PROD1 DRILL PMPO T PJSM-pump out of hole down the DP 11,287.0 8,832.0 14:30 22:15 &across the top f/11287'-8832'MD, 174 gpm,880 psi,800 fph,230 bpsi. 6/25/2016 6/25/2016 1.00 PROD1 DRILL BKRM T PJSM-BROOH f/8832'-8456'MD,2 8,832.0 8,456.0 22:15 23:15 bpm,800 psi,20 rpm,Tq 9K,pump across the top holding 230 bpsi. 6/25/2016 6/26/2016 0.75 PROD1 DRILL BKRM T Work tight hole&pack off w/varying 8,456.0 8,542.0 23:15 00:00 parameters f/8456'-8542'MD.Regain rotation&circulation 1 bpm,550 psi, 20 rpm,Tq 9-10K. OA 50 psi @ 24:00 hrs. 6/26/2016 6/26/2016 0.50 PROD1 DRILL CIRC T PJSM,Circulate @ 2 bpm=775 psi, 8,542.0 8,524.0 00:00 00:30 ROT @ 20 rpm's,7K Tq to attempt to clear cutting from BHA 6/26/2016 6/26/2016 3.25 PROD1 DRILL BKRM T Cont to work thought Kalubik f/8542' 8,524.0 8,239.0 00:30 03:45 MD to 8239'MD w/varying parameters,Rot @ 10-20 rpm's,pump 1-2 bpm w/9-15K TQ.Observed pipe stalling out with some 300 psi pack offs to casing shoe.Pulled tight all the way to shoe.Held 230-330 psi w/ MPD.Lost 7 bbls while working though tight hole. 6/26/2016 6/26/2016 0.25 PROD1 DRILL SMPD T Strip OOH f/8239'MD to 8170'MD, 8,239.0 8,170.0 03:45 04:00 P/U=155K,S/0=85K,ROT= 115K. 6/26/2016 6/26/2016 0.75 PROD1 DRILL COND T Prep mud pits for displacement,load 8,170.0 8,170.0 04:00 04:45 11.8 ppg brine into pits and move mud for displacement. 6/26/2016 6/26/2016 1.50 PROD1 DRILL DISP T Pump 34 bbls of high vis 11.8 ppg KW 8,170.0 7,696.0 04:45 06:15 brine to bit,POOH w/pump laying pill in f/8170'MD to 7696'MD.Pump @ 2 bpm=915 psi, 14%FO,pulling @ 2400 fph Page 22/35 Report Printed: 7/12/2016 • ,5•4 - Operations Summary (with Timelog Depths) • 2S-12 ConocoPhillips it Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time ' End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (MKS) End Depth(5Ke); 6/26/2016 6/26/2016 1.00 PROD1 DRILL DISP T Displace well to 11/8 ppg KWF pump 7,696.0 7,696.0 06:15 07:15 @ 240 gpm=2000 psi,30%FO,40 rpm's.Staging pumps down to 200 gpm to maintain CBHP, 1450 psi,25 %FO. 6/26/2016 6/26/2016 0.75 PROD1 DRILL OWFF T Monitor well through MPD flow line, 7,696.0 7,696.0 07:15 08:00 slight flow to static. Spill Drill CRT 87 sec @ 07:30 hrs. 6/26/2016 6/26/2016 1.50 PROD1 DRILL MPDA T PJSM-blow down MPD lines,pull 7,696.0 7,696.0 08:00 09:30 RCD&install trip nipple.Obtain parameters PU143K,SO 95K, ROT 115K,25 rpm,Tq 5K. SPR's at 7696'MD,5999'TVD,MW 11.8 ppg,09:15 hrs. #1 @20=350,@30=580 psi #2 @20=360,@30=600 psi 6/26/2016 6/26/2016 3.75 PROD1 DRILL TRIP T PJSM-TOH f/7696'-410'MD. 7,696.0 410.0 09:30 13:15 6/26/2016 6/26/2016 0.25 PROD1 DRILL OWFF T Monitor well at the HWDP,static. 410.0 410.0 13:15 13:30 6/26/2016 6/26/2016 3.25 PROD1 DRILL BHAH T PJSM-stand back&lay down BHA 4 410.0 0.0 13:30 16:45 per service reps.Surface test of the reamer showed washout at jets. Calculated fill 46,actual 52 bbls for trip. 6/26/2016 6/26/2016 0.25 PROD1 DRILL BHAH T Clear&clean rig floor.Mobilize BHA 5 0.0 0.0 16:45 17:00 6/26/2016 6/26/2016 2.25 PROD1 DRILL BHAH T PJSM-make up BHA 5 f/0-360'MD 0.0 360.0 17:00 19:15 per SLB DD. 6/26/2016 6/26/2016 0.50 PROD1 DRILL TRIP T PJSM-TIH f/360'-1482'MD. 360.0 1,482.0 19:15 19:45 Kick w/Tripping CRT 97 sec @ 19:30 hrs. 6/26/2016 6/26/2016 0.25 PROD1 DRILL DHEQ T Shallow hole test MWD @ 150 gpm= 1,482.0 1,482.0 19:45 20:00 500 psi&230 gpm=1140 psi.Tested good. 6/26/2016 6/26/2016 3.00 PROD1 DRILL TRIP T PJSM-TIH f/1482'-8214'MD.Fill pipe 1,482.0 8,214.0 20:00 23:00 every 20 stands. 6/26/2016 6/27/2016 1.00 PROD1 DRILL SLPC T PJSM-cut&slip 39'of drill line. 8,214.0 8,214.0 23:00 00:00 6/27/2016 6/27/2016 0.50 PROD1 DRILL SLPC T PJSM-continue cut&slip of drill line. 8,214.0 8,214.0 00:00 00:30 6/27/2016 6/27/2016 0.50 PROD1 DRILL SVRG T Service rig,blocks,TD,&drawworks. 8,214.0 8,214.0 00:30 01:00 6/27/2016 6/27/2016 1.00 PROD1 DRILL MPDA T PJSM-remove trip nipple&install ' 8,214.0 8,214.0 01:00 02:00 RCD bearing. Line up on MPD. 6/27/2016 6/27/2016 0.50 PROD1 DRILL COND T PJSM-transfer mud&brine for 8,214.0 8,214.0 02:00 02:30 displacement. 6/27/2016 6/27/2016 1.75 PROD1 DRILL DISP T PJSM-pump 34 bbls Hi-Vis spacer& 8,214.0 8,214.0 02:30 04:15 displace well w/330 bbls of 10.3 ppg Flo-Pro mud system at 190 gpm, 1725 psi,FO 34%,FCP 1450 psi,40 rpm, Tq 7K. 6/27/2016 6/27/2016 0.50 PROD1 DRILL CIRC T CBU @ 190-258 gpm, 1450-2100 psi, 8,214.0 8,214.0 04:15 04:45 FO 34%,40 rpm,Tq 7K,PU 145K,SO 80K,ROT 108K. 6/27/2016 6/27/2016 0.50 PROD1 DRILL OWFF T Monitor well shut in on MPD chokes 8,214.0 8,214.0 04:45 05:15 observed pressure steady at 395 psi for an EMW of 11.5 ppg. Page 23/35 Report Printed: 7/12/2016 • Operations Summary (with Timelog Depths) 2S-12 ConocoPhiitttps Rig: DOYON 141 Job: DRILLING ORIGINAL TimeLog Start Depth Start Time End Time Our(hr) Phase Op Code Aetrvity Code Time P-T-X Operation (ftKE)', End Depth(ftKE) 6/27/2016 6/27/2016 3.00 PROD1 DRILL SMPD T PJSM-line up MPD&TIH f/8214'- 8,214.0 10,957.0 05:15 08:15 10957'MD,as per trip schedule. It to 10-28K to push through Kalubik. Calculated displacement 16.2,actual 16.6 bbls. 6/27/2016 6/27/2016 2.00 PROD1 DRILL REAM T PJSM-wash&ream f/10957'-11286' 10,957.0 11,286.0 08:15 10:15 MD,245 gpm,2190 psi, FO 33%, 100 rpm,Tq 11K,450 fph. 6/27/2016 6/27/2016 1.00 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 11,286.0 11,379.0 10:15 11:15 11287'-11379'MD,6260'TVD, ADT.81,Bit 28.16,Jars 79.42,PU 170K,SO 65K, ROT 108K,Tq on 12- 13K,off 10K,ECD 11.65,FO 34%, WOB 5-8K, 140 rpm,263 gpm,2350 psi,Max gas 9590,footage 92'MD. 6/27/2016 6/27/2016 0.25 PROD1 DRILL OWFF T Pits gas alarm activated from gas cut 11,379.0 11,379.0 11:15 11:30 mud.Monitor well bore pressure with no pressure build up. 6/27/2016 6/27/2016 1.00 PROD1 DRILL CIRC T CBU at 245 gpm,2200 psi,FO 33%, 11,379.0 11,379.0 11:30 12:30 100 rpm,Tq 11K. SPR's at 11367'MD,6260'TVD,MW 10.3 ppg, 12:00 hrs. #1 @20=570,@30=820 psi #2 @20=620,@30=800 psi OA 490 psi @ 12:00 hrs. 6/27/2016 6/27/2016 5.50 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 11,379.0 11,816.0 12:30 18:00 11379'-11816'MD,6272'TVD,ADT 3.37,Bit 31.93,Jars 83.19,PU 175K, SO 58K,ROT 110K,Tq on 12-13K,off 10K,ECD 12.02,FO 33%,WOB 8- 12K, 140 rpm,275 gpm,2680 psi, Max gas 1178,footage 437'MD. 6/27/2016 6/28/2016 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 11,816.0 12,303.0 18:00 00:00 11816'-12303'MD,6246'TVD,ADT 3.76,Bit 35.69,Jars 86.95,PU 175K, SO 58K,ROT 110K,Tq on 14-16K,off 11K,ECD 12.02, FO 33%,WOB 5- 15K, 140 rpm,265 gpm,2750 psi, Max gas 1421,footage 487'MD. OA 520 psi @ 24:00 hrs. 6/28/2016 6/28/2016 1.50 PROD1 DRILL CIRC T CBU at 260 gpm,2525 psi,FO 33%, 12,303.0 12,303.0 00:00 01:30 100 rpm,Tq 12K,to catch sample of suspected Kalubik formation.Verified drilling into Kalubik.Confer with town to pick open hole side track point of 11,900'MD. Kick w/Drilling CRT 79 sec @ 01:30 hrs. 6/28/2016 6/28/2016 1.25 PROD1 DRILL SMPD T PJSM-TOH f/12303'-11870'MD to 12,303.0 11,870.0 01:30 02:45 position bit to begin troughing w/ OHST point of 11900'MD.PU 170K, SO 70K,ROT 110K,2 bpm,230 bpsi pulling,430 bpsi in the slips, calculated fill 16.2,actual 16.4 bbls. SPR's at 11900'MD,6277'TVD,MW 10.3 ppg,02:45 hrs. #1 @20=680,@30=9000 psi #2 @20=610,@30=890 psi Page 24/35 Report Printed: 7/12/2016 • Operations Summary (with Timelog Depths) 2S-12 C©t ocoPhiliips • Rig: DOYON 141 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) 6/28/2016 6/28/2016 4.25 PROD1 DRILL KOST T Perform OHST w/following trenching 11,870.0 11,900.0 02:45 07:00 sequence 2X at 261 gpm,2410 psi, FO 31%, 150 rpm,Tq 11K- •11870-11900 150ft/hr •11875-11900 150ft/hr •11880-11900 100ft/hr •11885-11900 100ft/hr •11890-11900 50ft/hr •11895-11900 50ft/hr 6/28/2016 6/28/2016 1.25 PROD1 DRILL MPDA T PJSM-change out RCD bearing 11,900.0 11,900.0 07:00 08:15 holding 430 psi on well bore. Mud leaking by element.Element was stretched out from 3-1/8"(new)to 4" ID. 6/28/2016 6/28/2016 2.25 PROD1 DRILL KOST T Continue last pass of trenching 11,900.0 11,900.0 08:15 10:30 sequence at 260 gpm,2410 psi,FO 31%, 150 rpm,Tq 11K. 6/28/2016 6/28/2016 3.50 PROD1 DRILL KOST T Time drill f/11900.62'-11902.65'MD, 11,900.0 11,900.0 10:30 14:00 6625'TVD,PU 170K,SO 70K,ROT 110K,Tq on 11K,off 10K,ECD 11.77, FO 35%,WOB 2-4K, 120-140 rpm, 265 gpm,2500 psi. OA 725 psi @ 12:00 hrs. 6/28/2016 6/28/2016 2.00 PROD1 DRILL KOST T Ream&trough 11898'-11900.65'MD, 11,900.0 11,900.0 14:00 16:00 267 gpm,2500 psi,FO 33%, 100-140 rpm,Tq 12-13K. 6/28/2016 6/28/2016 5.50 PROD1 DRILL KOST T Time drill f/11900.65-11920'MD,PU 11,900.0 11,920.0 16:00 21:30 170K,SO 70K,ROT 110K,Tq on 11K, off 10K, FO 35%,WOB 2-4K, 120-130 rpm,265 gpm,2500 psi. • 6/28/2016 6/29/2016 2.50 PROD1 DRILL DDRL T DDrill 6-3/4"production section f/ 11,920.0 11,991.0 21:30 00:00 11920'-11991'MD,6277'TVD,ADT 4.4,Bit 46.44,Jars 97.7,PU 175K,SO 60K,ROT 110K,Tq on 12-13K,off 10- 11K, ECD 11.86,FO 33%,WOB 5-7K, 130 rpm,265 gpm,2550 psi, Max gas 738,footage 71'MD. OA 700 psi @ 24:00 hrs. SPR's at 11987'MD,6276'TVD,MW 10.3 ppg,23:42 hrs. #1 @20=865-275 bpsi,@30=915- 245 bpsi psi #2 @20=624-276 bpsi,@30=892- 212 bpsi psi 6/29/2016 6/29/2016 3.50 PROD1 DRILL DDRL T DDrill 6-3/4"production section f/ 11,991.0 12,303.0 00:00 03:30 11991'-12303'MD,6304'TVD,ADT 3, Bit 49.44,Jars 100.7,PU 176K,SO 60K,ROT 106K,Tq on 12-13K,off 11K, ECD 11.98,FO 34%,WOB 7- 10K, 140 rpm,265 gpm,2580 psi, Max gas 2553,footage 312'MD. 6/29/2016 6/29/2016 2.25 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 12,303.0 12,485.0 03:30 05:45 12303'-12485'MD,6344'TVD,ADT 1.32,Bit 50.76,Jars 102.02,PU 176K, SO 60K, ROT 106K,Tq on 12-13K,off 11K,ECD 11.98,FO 34%,WOB 7- 10K, 140 rpm,265 gpm,2580 psi, Max gas 2553,footage 182'MD. • 6/29/2016 6/29/2016 0.50 PROD1 DRILL WAIT T Circulate at 261 gpm,2600 psi,FO 12,485.0 12,485.0 05:45 06:15 33%, 130 rpm,Tq 11K,reciprocate pipe.Confer with town Geologists. Page 25/35 Report Printed: 7/12/2016 • C3perations Summary (with Timelog Depths) h 3e 2S-12 CortocoPhi€lips ee1�:ka Rig: DOYON 141 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) 6/29/2016 6/29/2016 5.75 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 12,485.0 12,910.0 06:15 12:00 12485'-12910'MD,6326'TVD,ADT 3.68, Bit 54.44,Jars 105.7,PU 178K, SO 53K, ROT 106K,Tq on 12K,off 11K,ECD 11.99,FO 32%,WOB 8- 10K, 140 rpm,262 gpm,2520 psi, Max gas 873,footage 425'MD. OA 390 psi @ 12:00 hrs. SPR's at 12903'MD,6325'TVD,MW 10.3 ppg, 11:00 hrs. #1 @20=680-260 bpsi,@30=690- 230 bpsi psi #2 @20=690-270 bpsi,@30=970- 230 bpsi psi 6/29/2016 6/29/2016 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 12,910.0 13,410.0 12:00 18:00 12910'-13410'MD,6294'TVD,ADT 4.39,Bit 58.83,Jars 110.09,PU 170K, SO 50K,ROT 106K,Tq on 13-14K,off 11-12K,ECD 11.97,FO 33%,WOB 9- 10K, 140 rpm,260 gpm,2550 psi, Max gas 2715,footage 500'MD. 6/29/2016 6/29/2016 0.50'PROD1 DRILL SMPD T PJSM-TOH f/13410'-13319'MD to 13,410.0 13,319.0 18:00 18:30 change out RCD bearing&MPD lube skid. SPR's at 13406'MD,6285'TVD,MW 10.3 ppg, 18:13 hrs. #1 @20=663-257 bpsi,@30=625- 235 bpsi psi #2 @20=653-287 bpsi,@30=922- 218 bpsi psi 6/29/2016 6/29/2016 1.50 PROD1 DRILL MPDA T PJSM-change out RCD bearing& 13,319.0 13,319.0 18:30 20:00 MPD lube skid.Hold 420 psi on well bore. 6/29/2016 6/29/2016 3.50 PROD1 DRILL MPDA T PJSM-Run new electrical to back 13,319.0 13,319.0 20:00 23:30 6/29/2016 6/30/2016 0.50 PROD1 DRILL REAM T PJSM-wash&ream f/13319'-13410' 13,319.0 13,410.0 23:30 00:00 MD,260 gpm,2500 psi, 140 rpm,Tq 10-11K,FO 33%, PU 170K,SO 60K, ROT 106K. OA 420 psi @ 24:00 hrs. 6/30/2016 6/30/2016 2.25 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 13,410.0 13,600.0 00:00 02:15 13410'-13600'MD,6263'TVD,ADT 1.5,Bit 60.33,Jars 111.59, PU 180K, SO 40K,ROT 107K,Tq on 14K,off 12.5K,ECD 11.96,FO 28%,WOB 10- 15K, 130-140 rpm,263 gpm,2600 psi, Max gas 373,footage 190'MD. 6/30/2016 6/30/2016 1.00 PROD1 DRILL CIRC P CBU at 260 gpm,2600 psi, 140 rpm, 13,600.0 13,600.0 02:15 03:15 Tq 12K,for cuttings sample. 6/30/2016 6/30/2016 0.50 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 13,600.0 13,638.0 03:15 03:45 13600'-13638'MD,6263'TVD, • ADT.5,Bit 60.83,Jars 112.09,PU 180K,SO 35-40K,ROT 107K,Tq on 10-15K,off 13K,ECD 11.94,FO 33%, WOB 10-15K, 130 rpm,262 gpm, 2590 psi,Max gas 390,footage 38' MD. Page 26/35 Report Printed: 7/12/2016 �� • • AY,4 Operations Summary (with Timelog Depths) 2S-12 ConocdPhitllps Rig: DOYON 141 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) 6/30/2016 6/30/2016 1.75 PROD1 CASING CIRC P Circulate cutting samples up& 13,638.0 13,503.0 03:45 05:30 condition hole f/13638'-13503'MD, 260 gpm,2610 psi,FO 33%, 120 rpm, Tq 12K. 6/30/2016 6/30/2016 0.75 PROD1 CASING OWFF P Perform finger print of formation. 13,503.0 13,503.0 05:30 06:15 Reduced back pressure to 370 psi& observe pressure increase to 390 psi. EMW of 11.5 ppg @ 6287'TVD. SPR's at 13406'MD,6285'TVD,MW 10.3 ppg,06:15 hrs. #1 @20=663-257 bpsi,@30=925- 235 bpsi psi #2 @20=653-287 bpsi,@30=922- 218 bpsi psi 6/30/2016 6/30/2016 1.50 PROD1 CASING CIRC P CBU at 260 gpm,2600 psi,FO 33%, 13,503.0 13,503.0 06:15 07:45 60 rpm,Tq 11K,Max gas 3685. 6/30/2016 6/30/2016 4.25 PROD1 CASING BKRM P PJSM-BROOH f/13503'-11523'MD, 13,503.0 11,523.0 07:45 12:00 260 gpm,2575 psi, 130 rpm,Tq 11K, 800 fph,PU 180K,SO 45K,ROT 110K,calculated displacement 10.8, actual 19.5 bbls. OA 250 psi @ 12:00 hrs. 6/30/2016 6/30/2016 6.50 PROD1 CASING BKRM P PJSM-BROOH per MPD trip schedule 11,523.0 8,972.0 12:00 18:30 f/11523'-8972'MD,260 gpm,2300 psi, 130 rpm,Tq 10K,800 fph,PU 155K,SO 85K,ROT 106K,calculated displacement 16.2,actual 21.2 bbls. 6/30/2016 6/30/2016 3.50 PROD1 CASING SMPD P PJSM-TOH w/MPD back pressure f/ 8,972.0 8,214.0 18:30 22:00 8972'-8214'MD,PU 155K,SO 85K, 450 bpsi,calculated displacement 14.2,actual 14.0 bbls.Two minor overpull of 25K thru the Kalubik. 6/30/2016 7/1/2016 2.00 PROD1 CASING CIRC P Circulate casing clean @ 210 gpm, 8,214.0 8,214.0 22:00 00:00 1500 psi,60 rpm,Tq 8K,PU 150K, SO 86K,ROT 117K.SIMOPS weight up brine to 11.9 ppg,&build spacer. OA 450 psi©24:00 hrs. 7/1/2016 7/1/2016 0.75 PROD1 CASING CIRC P PJSM-pump 30 bbls Hi-Vis 11.9 ppg 8,214.0 8,214.0 00:00 00:45 KW brine spacer to the bit,220 gpm, 1550 psi,FO 16%. 7/1/2016 7/1/2016 0.50 PROD1 CASING PMPO P PJSM-pump out of hole spotting Hi- 8,214.0 7,741.0 00:45 01:15 Vis spacer f/8214'-7741'MD,at 2 bpm,450 psi,FO 10%,390 bpsi,2400 fph. 7/1/2016 7/1/2016 0.75 PROD1 CASING DISP P PJSM-displace well to 11.8 ppg brine 7,741.0 7,741.0 01:15 02:00 at 220 gpm, 1400 psi, FO 40%,60• rpm,Tq 6K,PU 145K,SO 93K,ROT 107K.Total displacement 351 bbls. 7/1/2016 7/1/2016 1.25 PROD1 CASING CIRC P C&C mud to an 11.9 ppg MW in/out, 7,741.0 7,741.0 02:00 03:15 at 220 gpm, 1400 psi,FO 40%,60 rpm,Tq 6K. 7/1/2016 7/1/2016 0.75 PROD1 CASING OWFF P Monitor well,circulating across the 7,741.0 7,741.0 03:15 04:00 top.Observe 1.05 bbl gain in 15 minutes,then 1.75 bbls loss in 30 min. Total of.7 bbls loss to the hole. Page 27/35 Report Printed: 7/12/2016 • Operations Summary (with Timelog Depths) by, iI4 7 2S-12 ConocoPhillips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P T-X Operation (fMKS)', End Depth(ftKB) 7/1/2016 7/1/2016 1.50 PROD1 CASING MPDA P PJSM-remove RCD bearing&install 7,741.0 7,741.0 04:00 05:30 trip nipple. Blow down all MPD lines. SIMOPS obtain SPR's&drop 2"OD rabbit w/100'of wire. SPR's at 7786'MD,6032'TVD,MW 11.9 ppg,05:10 hrs. #1 @20=220,@30=560 psi #2 @20=300,@30=540 psi 7/1/2016 7/1/2016 1.50 PROD1 CASING CIRC P Circulate&condition due to mud out 7,741.0 7,741.0 05:30 07:00 of balance @ 182 gpm, 1200 psi,FO 18%,60 rpm,Tq 7K. 7/1/2016 7/1/2016 1.25 PROD1 CASING OWFF P Monitor well,slight flow to static, 7,741.0 7,741.0 07:00 08:15 gain.5 bbls in 45 minutes,30 min static. 7/1/2016 7/1/2016 5.00 PROD1 CASING TRIP P PJSM-TOH f/7741'-420'MD,@ 2500 7,741.0 420.0 08:15 13:15 fph,calculated fill 46.2,actual 55.4 bbls. OA 0 psi @ 12:00 hrs. 7/1/2016 7/1/2016 0.25 PROD1 CASING OWFF P Monitor well,static.SIMOPS hold 420.0 420.0 13:15 13:30 PJSM for laying down BHA 5. 7/1/2016 7/1/2016 1.75 PROD1 CASING BHAH P Lay down BHA 5 per SLB DD. 420.0 0.0 13:30 15:15 7/1/2016 7/1/2016 0.50 PROD1 CASING BHAH P Clear&clean rig floor. 0.0 0.0 15:15 15:45 7/1/2016 7/1/2016 0.75 COMPZN CASING SFTY P Safety stand down,review power point 0.0 0.0 15:45 16:30 of recent incidents around the field. 7/1/2016 7/1/2016 0.75 COMPZN CASING PULD P PJSM-pick up&rack back 5 stands of 0.0 0.0 16:30 17:15 4"HWDP in derrick. 7/1/2016 7/1/2016 1.00 COMPZN CASING WWWH P PJSM- rig up stack washer,wash 0.0 0.0 17:15 18:15 stack,remove wear ring&blow down lines. 7/1/2016 7/1/2016 1.25 COMPZN WHDBOP RURD P PJSM-install test plug,rig up test 0.0 0.0 18:15 19:30 equipment&perform shell test. 7/1/2016 7/1/2016 4.00 COMPZN WHDBOP BOPE P Test BOPE w/3.5&4.5"test joint to 0.0 0.0 19:30 23:30 250/3500 psi for 5 min each.#1:Top pipe rams,CV 1,12,13, 14&manual kill valve.#2:Upper IBOP,HCR kill, CV 9,&11.#3:Lower IBOP,CV 5,8& 10. #4:Dart Valve,CV 4,6&7. #5: FOSV and CV 2. #6:HCR choke&4" kill line Demco valve, #7:Annular preventer tested to 250/2500#8: Lower pipe rams.#9:Blind rams&CV 3.#10:Test manual&super choke w/ 1500 psi. #11:Lower VBR's w/3.5" TJ. #12:Upper VBR's w/3.5"TJ Manual choke&HCR Kill.#13: Annular w/3.5"TJ.Accumulator test: System pressure=2975 psi,Pressure after closing= 1775 psi,200 psi attained after 43 seconds,full pressure attained after 185 seconds. Five bottle nitrogen avg=2000 psi. Test flow out&pit level alarms.Test gas alarms. Test witnessed by AOGCC Rep Chuck Scheve. 7/1/2016 7/2/2016 0.50 COMPZN WHDBOP RURD P PJSM-start rigging down test 0.0 0.0 23:30 00:00 equipment. Page 28/35 Report Printed: 7/12/2016 Ms "i ��� Iterations Summary (with Timelog Depths) `� tF 2S-12 ConocoPhiilips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code rime P-T-XOperation (ftKB) End Depth(ftKB) 7/2/2016 7/2/2016 1.00 COMPZN WHDBOP RURD P PJSM-finish rigging down test 0.0 0.0 00:00 01:00 equipment&blow down lines. Remove test plug&install wear bushing. 7/2/2016 7/2/2016 1.25 COMPZN CASING PULD P PJSM-pick up&rack back 39 joints of 0.0 0.0 01:00 02:15 4"HWDP in the derrick. 7/2/2016 7/2/2016 2.00 COMPZN CASING RURD P PJSM-rig up casing equipment,stage 0.0 0.0 02:15 04:15 Hydroforms,&organize liner jewelry in the pipe shed. • 7/2/2016 7/2/2016 6.25 COMPZN CASING PUTB P PJSM-make up float shoe joint,float 0.0 3,451.0 04:15 10:30 collar joint,WIV&alpha sleeve. Check floats,good.Continue running in the hole w/4.5", 12.6#,L-80, HYD563,liner installing swell packers &frac sleeves per detail f/155'-3451' MD.Fill every 10 joints,calculated displacement 15.5,actual 12.6 bbls. 7/2/2016 7/2/2016 1.00 COMPZN CASING SFTY P Safety stand down,review power point 3,451.0 3,451.0 10:30 11:30 of recent incidents around the field. Refocus on safety. 7/2/2016 7/2/2016 3.00 COMPZN CASING PUTB P Continue running in the hole w/4.5", 3,451.0 5,445.0 11:30 14:30 12.6#,L-80,HYD563,liner installing swell packers&frac sleeves per detail f/3491'-5445'MD.Ran a total of 8 frac sleeves,9 swell packers, 127 Hydroform centralizers&9 stop collars.Fill every 10 joints,calculated displacement 24.5,actual 20 bbls for entire liner run. No remakes or rejected pipe. 7/2/2016 7/2/2016 1.00 COMPZN CASING OTHR P PJSM-make up liner hanger/packer& 5,445.0 5,445.0 14:30 15:30 fill tie back sleeve w/Pal Mix.PU 89K, SO 70K. 7/2/2016 7/2/2016 0.50 COMPZN CASING RURD P PJSM-rig down casing equipment, 5,445.0 5,445.0 15:30 16:00 clear&clean rig floor. 7/2/2016 7/2/2016 2.00 COMPZN CASING RUNL P PJSM-TIH w/liner on 4"DP f/5445'- 5,445.0 8,208.0 16:00 18:00 8208'MD. 7/2/2016 7/2/2016 0.50 COMPZN CASING OWFF P Monitor the well,slight flow to static. 8,208.0 8,208.0 18:00 18:30 7/2/2016 7/2/2016 0.50 COMPZN CASING MPDA P PJSM-remove trip nipple&install 8,208.0 8,208.0 18:30 19:00 RCD bearing. 7/2/2016 7/2/2016 2.00 COMPZN CASING DISP P PJSM-displace to 10.3 ppg FloPro, 8,208.0 8,208.0 19:00 21:00 pump 36 bbls of 11.9 ppg Hi-Vis spacer,followed by 340 bbls of 10.3 ppg FloPro.Pump at 4 bpm,800 psi, FO 24%.Follow back pressure schedule holding 50-300 bpsi. 7/2/2016 7/2/2016 2.50 COMPZN CASING CIRC P C&C mud to reduce mud weight f/ 8,208.0 8,208.0 21:00 23:30 10.5 ppg to 10.3 ppg.212 gpm, 1030 psi,FO 27%,310 bpsi. 7/2/2016 7/3/2016 0.50 COMPZN CASING RUNL P PJSM-obtain parameters,TIH w/liner 8,208.0 8,616.0 23:30 00:00 on 4"DP f/8208'-8616'MD,SO 80K. 7/3/2016 7/3/2016 4.25 COMPZN CASING RUNL P PJSM-TIH w/liner on 4"DP f/8616'- 8,616.0 11,920.0 00:00 04:15 11920'MD,SO 70K.Tag up solid at 11290'MD. Page 29/35 Report Printed: 7/12/2016 trAIN ° Operations Summary (with Timelog Depths) ��... 2S-12 ConocoPhiilips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time '' End Time ': Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 7/3/2016 7/3/2016 2.75 COMPZN CASING RUNL T Pull up V 11920'-11858'MD,stage up 11,920.0 11,920.0 04:15 07:00 pumps to 2 bpm,990 psi.Attempt to wash down into OHST(11900'MD), tagging up at 11920 4 times.On 4th attempt work 9 wraps into string to reorient liner shoe.Tag up again at 11920'MD. 7/3/2016 7/3/2016 2.50 COMPZN CASING RUNL T Wash down f/11920'-12311'MD,2 11,920.0 12,311.0 07:00 09:30 bpm,950 psi,PU 160K,SO 60K.Tag up solid at 12311'MD.(PB1 TD 12303') 7/3/2016 7/3/2016 0.75 COMPZN CASING RUNL T Attempt to wash down at 12311'MD,2 12,311.0 12,311.0 09:30 10:15 bpm,950 psi,PU 160K,SO 60K. Assume liner is in PB1,as its TD was 12303'MD. 7/3/2016 7/3/2016 2.25 COMPZN CASING PMPO T PJSM-pump out of the hole f/12311'- 12,311.0 11,858.0 10:15 12:30 11858'MD,at 2 bpm,950 psi,PU 160K. 7/3/2016 7/3/2016 2.00 COMPZN CASING RUNL T PJSM-attempt to trench ahead of 11,858.0 11,900.0 12:30 14:30 OHST f/11870'-11900'MD at 4 bpm, 950 psi,450 bpsi.PU 160K,SO 75K. Make 7 passes at 180 fph or up to 5K WOB. 7/3/2016 7/3/2016 3.50 COMPZN CASING RUNL T Wash&work through last pass of 11,900.0 12,311.0 14:30 18:00 trenching f/11900'-12311'MD.Tag up at 11900'MD,w/10K then work through to 12311'MD.Tag up 5X with 30K WOB,3 bpm, 1000 psi, PU 160K, SO 65K. 7/3/2016 7/3/2016 2.25 COMPZN CASING PMPO T PJSM-pump out of the hole f/13211'- 12,311.0 11,870.0 18:00 20:15 11870'MD,@ 2 bpm,900 psi,405 bpsi. 7/3/2016 7/3/2016 0.75 COMPZN CASING RUNL T PJSM-attempt to trench ahead of 11,870.0 11,900.0 20:15 21:00 OHST f/11870'-11900'MD at 5 bpm, 1400 psi,450 bpsi.PU 160K,SO 75K. Make 1 passes at 180 fph or up to 5K WOB.Tagged up at 11899'w/5K& pressure up to 1600 psi. 7/3/2016 7/3/2016 0.75 COMPZN CASING PMPO T Work pipe V 11900'-11827'MD, 11,900.0 11,827.0 21:00 21:45 observe pack off&tight hole.Pull 40K over original PU weight.Work pipe up &down staging PU weight to 75K over,to free pipe.Still unable to circulate&observe some 40K overpull.Decision made to pull out of hole to find free spot&establish circulation. 7/3/2016 7/4/2016 2.25 COMPZN CASING PMPO T Pump out of hole V 11827'-11444'MD, 11,827.0 11,444.0 21:45 00:00 0-2 bpm,600-900 psi,400-450 bpsi, PU 160-200K. OA 150 psi @ 24:00 hrs. 109 bbls losses for 24 hrs 7/4/2016 7/4/2016 6.50 COMPZN CASING PMPO T Pump out of hole f/11444'-8234'MD, 11,444.0 8,234.0 00:00 06:30 2 bpm,890 psi,420 bpsi,FO 23%, calculated fill 18.9,actual 28 bbls. 7/4/2016 7/4/2016 3.50 COMPZN CASING CIRC T CBU staging pump up to 5 bpm, 1170 8,234.0 8,234.0 06:30 10:00 psi,reduce volume for displacement. Page 30/35 Report Printed: 7/12/2016 ,.:031.0.. • ..„, , !erations Summary (with Timelog Depths) ilcti.t2K,„,,z1eA:44-,yi4, 2S-12 ConocoPhiilips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time 4 Our(hr) Phase Op Code Activity Code Time P-T-X r Operation MKS) End Depth(ftKB) 7/4/2016 7/4/2016 1.25 COMPZN CASING PMPO T PJSM-pump&spot Hi-Vis KW 11.9 8,234.0 7,765.0 10:00 11:15 ppg brine spacer f/8234'-7765'MD,2 bpm,430 psi,2400 fph. 7/4/2016 7/4/2016 3.50 COMPZN CASING DISP T PJSM-displace well to 11.9 ppg brine 7,765.0 7,765.0 11:15 14:45 at 5 bpm,750 psi,FO 16%. OA 150 psi @ 12:00 hrs. 7/4/2016 7/4/2016 1.00 COMPZN CASING OWFF T Monitor well,2 bbl gain in first 30 7,765.0 7,765.0 14:45 15:45 minutes to static.Observe well static 30 minutes.SIMOPS PJSM for RCD removal. 7/4/2016 7/4/2016 1.50 COMPZN CASING MPDA T Remove RCD&install trip nipple. 7,765.0 7,765.0 15:45 17:15 Blow down MPD lines&TD. SPR's at 7786'MD,6032'TVD,MW 11.9 ppg, 17:15 hrs. #1 @20=480,@30=600 psi #2 @20=420,@30=560 psi 7/4/2016 7/4/2016 3.25 COMPZN CASING PMPO T PJSM-pump out of the hole due to 7,765.0 5,493.0 17:15 20:30 swab f/7765'-5493'MD,2 bpm,280 psi,FO 22%,PU 120K,SO 82K. 7/4/2016 7/4/2016 0.25 COMPZN CASING OWFF T Monitor well,slight drop in 15 minutes. 5,493.0 5,493.0 20:30 20:45 7/4/2016 7/4/2016 0.75 COMPZN CASING RURD T PJSM-rig up casing equipment to lay 5,493.0 5,493.0 20:45 21:30 down 4-1/2"liner. 7/4/2016 7/5/2016 2.50 COMPZN CASING PULL T PJSM-lay down 4-1/2"liner f/54131- 5,493.0 4,182.0 21:30 00:00 4182'MD.Lay down joints 127 to 98; 2 swell packers(OD's 5.9"&5.93");1 frac sleeve(ball size 2.625"). Calculated fill 5.7,actual 4.4 bbls.PU 75K,SO 64K. OA 0 psi @ 24:00 hrs. 7/5/2016 7/5/2016 2.50 COMPZN CASING PULL T Lay down 4-1/2"liner f/4182'-3192' 4,182.0 3,192.0 00:00 02:30 MD.Lay down joints 98 to 74,swell packers F,G,and H and 2 x frac sleeves(ball size 2.563"and 2.50"). Calculated fill 8.5,actual 7.8 bbls. 7/5/2016 7/5/2016 0.50 COMPZN CASING RURD T Clean and clear rig floor. 3,192.0 3,192.0 02:30 03:00 7/5/2016 7/5/2016 1.50 COMPZN CASING PUTB T Run in hole w/4.5", 12.6#,L-80, 3,192.0 3,910.0 03:00 04:30 HYD563 liner installing swell packers &frac sleeves per detail f/3192'-3910' MD. Ran a total of 5 frac sleeves,6 swell packers,88 Hydroform centralizers&8 stop collars. Fill every 10 joints,calculated displacement 3.2, actual 2.8 bbls for modified liner run. No remakes or rejected pipe. 7/5/2016 7/5/2016 0.50 COMPZN CASING RURD T Rig down liner running tools. 3,910.0 3,910.0 04:30 05:00 7/5/2016 7/5/2016 1.75 COMPZN CASING SLPC T Slip and cut 59'of drill line and service 3,910.0 3,910.0 05:00 06:45 top drive. 7/5/2016 7/5/2016 4.00 COMPZN CASING RUNL T Trip in hole w/liner on 4"DP f/3910'- 3,910.0 8,201.0 06:45 10:45 8201'MD. 7/5/2016 7/5/2016 0.50 COMPZN CASING MPDA T Pull trip nipple and install MPD 8,201.0 8,201.0 10:45 11:15 bearing assembly. 7/5/2016 7/5/2016 1.75 COMPZN CASING COND T Prepare pits for displacement and 8,201.0 8,201.0 11:15 13:00 weight up Hi-Vis spacer.Monitor well on trip tank. Page 31/35 Report Printed: 7/12/2016 • Iterations Summary (with Timelog Depths) � ►,., � . 2S-12 ConacoPhilhps Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code` `Time P-T-X Operation MKS)', End Depth(ftKB)}. 7/5/2016 7/5/2016 3.00 COMPZN CASING DISP T Displace to 10.4 ppg FloPro,pump 35 8,201.0 8,201.0 13:00 16:00 bbls of 11.9 ppg Hi-Vis spacer, followed by 340 bbls of 10.4 ppg FloPro.Pump at 4 bpm, 1150 psi decreasing to 950psi,FO 28%.Follow back pressure schedule holding 50- 300 psi on the annulus. 7/5/2016 7/5/2016 3.50 COMPZN CASING RUNL T Strip in hole w/liner on 4"DP stands f/ 8,201.0 11,880.0 16:00 19:30 8201'-11896'MD,PU to liner set depth at 11880'MD.PU 170K SO 80K,Holding 450psi in slips and 400psi out of slips. 7/5/2016 7/5/2016 1.00 COMPZN CASING CIRC P Circ string volume.2.5 bpm, 1060 psi 11,880.0 11,880.0 19:30 20:30 FO=9% 7/5/2016 7/5/2016 3.00 COMPZN CASING PACK P Drop 1.25"WIV closing ball.Pressure 11,880.0 11,880.0 20:30 23:30 up to 3500 psi.Slack off 50K down weight and increase pressure to 4000 psi and hold for 5 min to set hanger. Bleed off pressure and pick up w/5K overpull.Slack off to confirm hanger setting and observed 3'down travel. Reposition liner at set depth.Pressure up to 4000 psi and hold for 5 min. Slack off 55K down weight.Bleed off pressure.Weight fell off and observe string travel up and down. Reposition liner at set depth.Pressure up to 4200 psi.Slack off 50K and hold for 5 min. Bleed off pressure and set 50K down. Pick up 160K and slack off and set 50K down. Unable to hydraulically release from hanger. 7/5/2016 7/6/2016 0.50 COMPZN CASING PACK T Attempt to mechanically release from 11,880.0 11,880.0 23:30 00:00 hanger.Put LH torque in pipe 2 wraps at a time working torque downhole. Total of 10 turns.Torque limit set at 5K. 7/6/2016 7/6/2016 1.00 COMPZN CASING PACK T Attempt to mechanically release from 11,880.0 8,073.0 00:00 01:00 hanger.Put LH torque in pipe 2 wraps at a time working torque downhole. Total of 12 turns total.Torque limit set at 5K.Observe PUW decrease 10klbs to 160k.Pick up 5'to expose dog, rotate 15rpm,Tq 7k,set down to block weight to confirm packer set.TOL estimated @ 8073'MD-will verify when stab in upper completion 7/6/2016 7/6/2016 6.75 COMPZN CASING PACK T Observe communication between 8,073.0 8,073.0 01:00 07:45 annular pressure and drill pipe pressure.Discuss plan forward. Prepare pits for displacing well to 11.9 kill weight brine and build hi-vis spacer. 7/6/2016 7/6/2016 1.25 COMPZN CASING PRTS P Decision made to pressure test liner 8,073.0 8,073.0 07:45 09:00 top packer.R/U and test packer to 3000 psi for 10 minutes,charted- good test.Bleed off pressure and perform negative flow test for 30 minutes-good test. 7/6/2016 7/6/2016 0.50 COMPZN WELLPR OWFF P Observe well for flow-well static 8,073.0 8,073.0 09:00 09:30 Page 32/35 Report Printed: 7/12/2016 Iterations Summary (with Timelog Depths) 2S-12 ConocoPhillips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (MKS) End Depth(ftKB), 7/6/2016 7/6/2016 1.75 COMPZN WELLPR MPDA P Pull MPD bearing assembly,install trip 8,073.0 8,073.0 09:30 11:15 nipple,and blow down MPD skid. 7/6/2016 7/6/2016 6.25 COMPZN WELLPR TRIP T POOH from 8073'to surface,racking 8,073.0 0.0 11:15 17:30 back 4"HWDP and 4"DP stands in derrick,monitoring displacement on the trip tank.Observe all liner running tools at surface and in good condition. Lay out liner running tools. Obtain SPR's at 8064'MD,6240'TVD, MW 10.4 ppg, 11:15 hrs. #1 @20=430 psi,@30=520 psi #2 @20=420 psi,@30=520 psi • 7/6/2016 7/6/2016 0.50 COMPZN WELLPR RURD T Clean and clear rig floor. 0.0 0.0 17:30 18:00 7/6/2016 7/6/2016 3.00 COMPZN WELLPR TRIP T Make up mule shoe and RIH on 4" 0.0 8,065.0 18:00 21:00 HWDP and 4"DP from surface to 8065'MD.P/U=160K S/0=110K Rot=120K. 100 rpm,9K tq. Calc disp=55.1 bbls Act disp=54.7 bbls. 7/6/2016 7/6/2016 1.00 COMPZN WELLPR DISP P PJSM-Pump 35 bbls hi-vis 8.5 ppg 8,065.0 8,065.0 21:00 22:00 seawater spacer followed by 450 bbls 8.5 ppg seawater at 10 bpm,2400 psi. 100 rpm.Reciprocate 60'. No gains/no losses. 7/6/2016 7/6/2016 0.50 COMPZN WELLPR OWFF P Obtain SPR's.Monitor well.Static. 8,065.0 8,065.0 22:00 22:30 Blow down top drive. SPR's at 8054'MD, MW 8.5 ppg, 22:13 hrs. #1 @20=50,@30=160 psi #2 @20=60,@30=160 psi 7/6/2016 7/7/2016 1.50 COMPZN WELLPR PULD P PJSM-Lay down 4"DP f/8065'MD 8,065.0 6,317.0 22:30 00:00 t/6317'MD. Calc disp=8.1 bbls Act disp=8.9 bbls OA=250 psi. 7/7/2016 7/7/2016 5.75 COMPZN WELLPR PULD P PJSM-Lay down 4"DP f/6317'MD to 6,317.0 0.0 00:00 05:45 surface. Lay down mule shoe Calc disp=54.4 bbls Act disp=58.6 bbls 7/7/2016 7/7/2016 0.50 COMPZN WELLPR RURD P Rig up to lay down drillpipe in 0.0 0.0 05:45 06:15 mousehole. 7/7/2016 7/7/2016 5.75 COMPZN WELLPR PULD P PJSM-Lay down 246 jts DP from 0.0 0.0 06:15 12:00 derrick in mousehole.. OA=0 psi. 7/7/2016 7/7/2016 2.00 COMPZN WELLPR PULD P Continue to lay down 84 jts DP from 0.0 0.0 12:00 14:00 derrick in mousehole. 7/7/2016 7/7/2016 0.25 COMPZN WELLPR RURD P Clean and clear rig floor. 0.0 0.0 14:00 14:15 7/7/2016 7/7/2016 0.75 COMPZN RPCOMP WWWH P Pull wearbushing.Make up stack 0.0 0.0 14:15 15:00 washer and flush BOPE.Blow down top drive. 7/7/2016 7/7/2016 1.00 COMPZN RPCOMP RURD P Mobilize casing&completion 0.0 0.0 15:00 16:00 equipment to rig floor.Rig up to run 3.5"upper completion. Page 33/35 Report Printed: 7/12/2016 i Operations Summary (with Timelog Depths) , 2S-12 Conoco Phillips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation tftkB) End Depth(ftK6) 7/7/2016 7/7/2016 0.50 COMPZN RPCOMP PUTB P PJSM-run 3.5",9.3#,L-80,EUE 8RD 0.0 121.0 16:00 16:30 Mod,R2 completion tubing as per detail f/0-121'MD.Pick up WLEG„No -Go Sub, D nipple w/RHC,Premier packer,gauge carrier.Avg MU tq=2240 psi. 7/7/2016 7/7/2016 1.50 COMPZN RPCOMP PRTS P PJSM-Pressure test guage carrier to 121.0 121.0 16:30 18:00 5000 psi for 15 minutes.Test electrical function as per Camco rep. 7/7/2016 7/8/2016 6.00 COMPZN RPCOMP PUTB P PJSM-run 3.5",9.3#,L-80, EUE 8RD 121.0 4,043.0 18:00 00:00 Mod,R2 completion tubing as per detail f/121'-4043'MD.Make up CMU,GLM w/SOV,&2 GLM's.I-wire tested every 1500'MD. Calc disp=13.41 bbls Act disp=14 bbls OA=0 psi. 7/8/2016 7/8/2016 6.00 COMPZN RPCOMP PUTB P Run in hole 3.5",9.3#,L-80,EUE 8RD 4,043.0 8,028.0 00:00 06:00 Mod,R2 completion tubing as per detail f/4043'-8028'MD. I-wire tested every 1500'MD. Calc disp=27.3 bbls Act disp=29.3 bbls 7/8/2016 7/8/2016 0.50 COMPZN RPCOMP PUTB P Tag up on top of liner at 8084'MD and 8,028.0 8,114.0 06:00 06:30 observe shear.Continue slacking off to NoGo at 8114'MD, 11'deep.PU 95K,SO 70K 7/8/2016 7/8/2016 1.25 COMPZN RPCOMP HOSO P Lay down 3 joints#249,250,&251. 8,114.0 8,109.0 06:30 07:45 Pick up 2 x pup joints 10.24'&10.26', 3.5"X 4.5"XO, 1 jt of 4.5"tubing R2, 11"x 4.5"tubing hanger,&landing joint. Total of 253 cannon clamps run in hole. 7/8/2016 7/8/2016 2.25 COMPZN RPCOMP THGR P Test&terminate I-wire.Test control 8,109.0 8,106.0 07:45 10:00 line seals to 5000 psi for 10 minutes. Install clamp on hanger pup&tie off(- wire stub out.Drain stack and land hanger to verify correct position.Pick up 3'for circulation. 7/8/2016 7/8/2016 0.50 COMPZN RPCOMP CRIH P Spot 15 bbls of corrosion inhibited 8,106.0 8,106.0 10:00 10:30 brine,chased with 70 bbls of 8.5 ppg filtered sea water, 168 gpm,350 psi, FO17%. 7/8/2016 7/8/2016 1.25 COMPZN RPCOMP THGR P Drain stack and land hanger at 8,106.0 8,109.7 10:30 11:45 8,109.69'MD,total of 5.16'up from fully located.RILDS and test hanger seals to 5000 psi for 15 minutes, witnessed by CPAI. 7/8/2016 7/8/2016 3.25 COMPZN RPCOMP PRTS P Drop 1.3"OD ball&rod,allowing 15 8,109.7 0.0 11:45 15:00 min to fall.Test 3-1/2"tubing to 4000 psi for 30 minutes. Bleed tubing to 2000 psi.Pressure test IA and tubing hanger to 4000 psi for 30 minutes. Bleed off IA&then tubing pressure. Pressure up IA,observe SOV shear at 2800 psi.Pump through SOV at 42 gpm, 160 psi.Bleed off pressure,rig down lines,and lay out landing joint. Page 34/35 Report Printed: 7/12/2016 • Operations Summary (with Timelog Depths) 2S-12 ConocaPhillips "p- Rig: Rig: DOYON 141 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(ftKE) 7/8/2016 7/8/2016 1.00 COMPZN WHDBOP MPSP P Install 4",type H BPV per Cameron 0.0 0.0 15:00 16:00 Rep&test in the direction of flow to 2500 psi for 30 minutes. 7/8/2016 7/8/2016 0.50 COMPZN WHDBOP OWFF P Monitor well for flow-well static. 0.0 0.0 16:00 16:30 Rig off khighline @ 1600 hrs. 7/8/2016 7/8/2016 3.50 COMPZN WHDBOP MPDA P PJSM-Rig down MPD equipment. 0.0 0.0 16:30 20:00 Remove KatchKan,air valve and RCD.Rig down scaffold. 7/8/2016 7/8/2016 0.50 COMPZN WHDBOP NUND P PJSM-Nipple down BOPE&rack back 0.0 0.0 20:00 20:30 on stump. 7/8/2016 7/8/2016 1.25 COMPZN WHDBOP NUND P Prep adapter for install,feed I-wire 0.0 0.0 20:30 21:45 thru adapter&make up adapter flange. 7/8/2016 7/8/2016 1.75 COMPZN WHDBOP PRTS P Rig up&test SRL seal to 10,000 psi 0.0 0.0 21:45 23:30 for 15 minutes,Test hanger seals, adapter void&top body seals to 5000 psi for 15 minutes.Tests witnessed. 7/8/2016 7/9/2016 0.50 COMPZN WHDBOP NUND P Terminate and perform continuity test 0.0 0.0 23:30 00:00 on I-wire. 7/9/2016 7/9/2016 0.50 COMPZN WHDBOP NUND P Continue continuity test on I-wire. 0.0 0.0 00:00 00:30 7/9/2016 7/9/2016 1.50 COMPZN WHDBOP NUND P NU 10K frac tree and wing valve. 0.0 0.0 00:30 02:00 7/9/2016 7/9/2016 2.50 COMPZN WHDBOP PRTS P RU pressure testing equipment. PT 0.0 0.0 02:00 04:30 the tree to 250 psi for 5 minutes and 10000 psi for 15 minutes(good tests). RD pressure testing equipment. 7/9/2016 7/9/2016 0.50 COMPZN WHDBOP MPSP P Pull the TWC. 0.0 0.0 04:30 05:00 7/9/2016 7/9/2016 1.00 COMPZN WHDBOP FRZP P RU lines and LRS for freeze protect. 0.0 0.0 05:00 06:00 7/9/2016 7/9/2016 2.00 COMPZN WHDBOP FRZP P PJSM. PT lines to 2000 psi. Freeze 0.0 0.0 06:00 08:00 protect the well by pumping 90 bbls down the IA taking returns up the tubing at 1 BPM(ICP=300 psi and FCP=390 psi). SimOps: remove SLB stand pipe SPT. 7/9/2016 7/9/2016 2.00 COMPZN WHDBOP FRZP P Place the tubing and IA in 0.0 0.0 08:00 10:00 communication and allow the well to u -tube/equalize. SimOps: Hook up the kelly hose. ' Work on rig move checklist. 7/9/2016 7/9/2016 1.00 COMPZN WHDBOP MPSP P Install the BPV. With LRS pressure 0.0 0.0 10:00 11:00 up on the IA to 1000 psi for 5 minutes to test the BPV from below in the direction of flow(good test). 7/9/2016 7/9/2016 1.00 DEMOB MOVE RURD P RD lines,suck out the cellar,and 0.0 0.0 11:00 12:00 secure the well. Released the rig from 2S-12 at 12:00 hours. Page 35/35 Report Printed: 7/12/2016 NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-12 2S-12 Definitive Survey Report 05 July, 2016 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-12 Project: Kuparuk River Unit TVD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12 Survey Calculation Method: Minimum Curvature Design: 2S-12 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-12 Well Position +N/-S 0.00 usft Northing: 5,929,968.02 usft Latitude: 70°13'11.380 N +E/-W 0.00 usft Easting: 480,986.10 usft Longitude: 150°9'12.212 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft nr. Wellbore 2S-12 Magnetics Model Name She Date '1�nation PipAn le F (? ngth (1 (fly BGGM2016 6/20/2016 17.97 80.85 57,536 Design 2S-12 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 11,836.99 Vertical S.+eltion Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (off) (°) " ,,,- 27.50 0.00 0.00 226.56 Survey Program Date From To (usft) (usft) Survey,(Wellbole) Tool Name criptiori Survey Date 100.00 975.00 2S-12 Srvy 1-SLB_NSG+BATTERY(2S GYD-GC-SS Gyrodata gyro single shots 6/9/2016 8:37:0 1,013.91 2,787.47 2S-12 Srvy 2-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/8/2016 10:02:C 2,815.78 2,815.78 25-12 Srvy 3-SLB_INC+Filler(2S-12PB INC+TREND Inclinometer+known azi trend 6/13/2016 9:29: 2,908.52 4,219.12 2S-12 Srvy 4-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/13/2016 9:34: 4,310.16 8,178.05 2S-12 Srvy 5-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/15/2016 9:10:, 8,241.66 11,132.17 25-12 Srvy 6-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/23/2016 1:52:' 11,179.20 11,836.99 2S-12PB1 Srvy 7-SLB_MWD+GMAG(2 MWD+IFR-AK-CAZ-SC MWD+I FR AK CAZ SCC 6/27/2016 8:40:' 11,898.68 13,535.44 2S-12 Srvy 8-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+I FR AK CAZ SCC 6/28/2016 10:37 Survey - ,r .,, Map Map Vertical'. 1 ;Inc Ale ND T *N14 +E/-W Northing Easting DLS Section ,, ( ( (usft) (esft) (usft) (f)a,,,- (ft) (°(100') (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,929,968.02 480,986.10 0.00 0.00 UNDEFINED 100.00 0.29 190.76 100.00 -47.50 -0.18 -0.03 5,929,967.84 480,986.07 0.40 0.15 GYD-GC-SS(1) 200.00 0.41 190.63 200.00 52.50 -0.78 -0.15 5,929,967.24 480,985.95 0.12 0.64 GYD-GC-SS(1) 300.00 0.45 195.47 299.99 152.49 -1.51 -0.32 5,929,966.51 480,985.78 0.05 1.27 GYD-GC-SS(1) 400.00 1.00 335.77 399.99 252.49 -1.09 -0.78 5,929,966.93 480,985.32 1.38 1.32 GYD-GC-SS(1) 500.00 2.69 342.00 499.94 352.44 1.93 -1.86 5,929,969.96 480,984.24 1.70 0.02 GYD-GC-SS(1) 600.00 2.85 339.41 599.82 452.32 6.49 -3.46 5,929,974.52 480,982.65 0.20 -1.95 GYD-GC-SS(1) 700.00 5.59 337.49 699.54 552.04 13.32 -6.20 5,929,981.36 480,979.93 2.74 -4.66 GYD-GC-SS(1) 7/5/2016 12:02:56PM Page 2 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-12 Project: Kuparuk River Unit TVD Reference: 2S-12 actual©147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12 Survey Calculation Method: Minimum Curvature Design: 2S-12 Database: OAKEDMP2 Survey Map • Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting, DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 800.00 6.31 336.02 799.00 651.50 22.84 -10.30 5,929,990.89 480,975.86 0.74 -8.23 GYD-GC-SS(1) 900.00 8.69 329.19 898.14 750.64 34.35 -16.41 5,930,002.41 480,969.78 2.54 -11.71 GYD-GC-SS(1) 975.00 10.53 326.13 972.08 824.58 44.91 -23.13 5,930,012.98 480,963.09 2.55 -14.09 GYD-GC-SS(1) 1,013.91 11.75 326.29 1,010.26 862.76 51.16 -27.31 5,930,019.24 480,958.92 3.14 -15.35 MWD+IFR-AK-CAZ-SC(2) 1,107.62 13.67 325.67 1,101.67 954.17 68.24 -38.85 5,930,036.35 480,947.43 2.05 -18.72 MWD+IFR-AK-CAZ-SC(2) 1,200.42 16.08 324.50 1,191.35 1,043.85 87.76 -52.50 5,930,055.91 480,933.83 2.62 -22.23 MWD+IFR-AK-CAZ-SC(2) 1,292.50 19.08 320.32 1,279.13 1,131.63 109.73 -69.52 5,930,077.92 480,916.87 3.53 -24.98 MWD+IFR-AK-CAZ-SC(2) 1,386.06 19.77 318.96 1,367.36 1,219.86 133.44 -89.67 5,930,101.67 480,896.77 0.88 -26.65 MWD+IFR-AK-CAZ-SC(2) 1,479.50 20.24 316.88 1,455.16 1,307.66 157.15 -111.09 5,930,125.44 480,875.41 0.91 -27.40 MWD+IFR-AK-CAZ-SC(2) 1,572.66 24.30 307.63 1,541.38 1,393.88 180.64 -137.31 5,930,148.98 480,849.26 5.75 -24.51 MWD+IFR-AK-CAZ-SC(2) 1,665.16 27.66 303.44 1,624.53 1,477.03 204.10 -170.31 5,930,172.53 480,816.32 4.14 -16.68 MWD+IFR-AK-CAZ-SC(2) 1,756.86 29.76 300.84 1,704.95 1,557.45 227.50 -207.62 5,930,196.02 480,779.08 2.66 -5.69 MWD+IFR-AK-CAZ-SC(2) 1,849.84 32.90 296.17 1,784.38 1,636.88 250.47 -250.11 5,930,219.10 480,736.64 4.27 9.37 MWD+IFR-AK-CAZ-SC(2) 1,943.50 35.44 294.84 1,861.87 1,714.37 273.10 -297.59 5,930,241.85 480,689.23 2.83 28.28 MWD+IFR-AK-CAZ-SC(2) 2,037.33 37.15 294.42 1,937.49 1,789.99 296.25 -348.08 5,930,265.11 480,638.80 1.84 49.03 MW3+IFR-AK-CAZ-SC(2) 2,130.01 38.06 294.03 2,010.91 1,863.41 319.45 -399.66 5,930,288.44 480,587.29 1.01 70.52 MWD+IFR-AK-CAZ-SC(2) 2,222.77 38.76 292.95 2,083.60 1,936.10 342.42 -452.51 5,930,311.54 480,534.50 1.05 93.10 MWD+IFR-AK-CAZ-SC(2) 2,314.68 39.96 293.82 2,154.66 2,007.16 365.56 -506.01 5,930,334.81 480,481.07 1.44 116.03 MWD+IFR-AK-CAZ-SC(2) 2,409.01 41.18 294.41 2,226.31 2,078.81 390.62 -562.00 5,930,360.02 480,425.14 1.36 139.45 MWD+IFR-AK-CAZ-SC(2) 2,502.49 40.81 294.01 2,296.87 2,149.37 415.77 -617.93 5,930,385.31 480,369.28 0.49 162.77 MWD+IFR-AK-CAZ-SC(2) 2,596.33 40.61 293.99 2,368.00 2,220.50 440.67 -673.84 5,930,410.34 480,313.44 0.21 186.25 MWD+IFR-AK-CAZ-SC(2) 2,688.67 40.56 293.51 2,438.13 2,290.63 464.86 -728.83 5,930,434.67 480,258.52 0.34 209.53 MWD+IFR-AK-CAZ-SC(2) 2,787.47 40.93 290.93 2,512.99 2,365.49 489.24 -788.51 5,930,459.19 480,198.90 1.74 236.11 MWD+IFR-AK-CAZ-SC(2) 2,815.78 41.16 291.00 2,534.34 2,386.84 495.89 -805.87 5,930,465.89 480,181.56 0.83 244.14 INC+TREND(3) 2,845.00 41.18 291.36 2,556.33 2,408.83 502.84 -823.81 5,930,472.88 480,163.64 0.82 252.38 MWD+IFR-AK-CAZ-SC(4) 90,314"x13112" 2,908.52 41.23 292.15 2,604.12 2,456.62 518.35 -862.67 5,930,488.49 480,124.82 0.82 269.93 MWD+IFR-AK-CAZ-SC(4) 3,003.43 41.26 291.42 2,675.49 2,527.99 541.57 -920.78 5,930,511.85 480,066.78 0.51 296.15 MWD+IFR-AK-CAZ-SC(4) 3,093.72 41.20 290.99 2,743.39 2,595.89 563.10 -976.25 5,930,533.52 480,011.36 0.32 321.64 MWD+IFR-AK-CAZ-SC(4) 3,189.59 41.13 290.66 2,815.56 2,668.06 585.53 -1,035.24 5,930,556.10 479,952.44 0.24 349.03 MWD+IFR-AK-CAZ-SC(4) 3,281.31 41.07 290.18 2,884.68 2,737.18 606.57 -1,091.74 5,930,577.27 479,896.00 0.35 375.60 MWD+IFR-AK-CAZ-SC(4) 3,377.84 41.03 290.47 2,957.48 2,809.98 628.59 -1,151.19 5,930,599.44 479,836.61 0.20 403.62 MWD+IFR-AK-CAZ-SC(4) 3,472.80 41.11 291.43 3,029.07 2,881.57 650.89 -1,209.45 5,930,621.89 479,778.42 0.67 430.58 MWD+IFR-AK-CAZ-SC(4) 3,566.08 41.08 291.66 3,099.37 2,951.87 673.41 -1,266.48 5,930,644.55 479,721.45 0.17 456.50 MWD+IFR-AK-CAZ-SC(4) 3,659.12 41.06 290.95 3,169.51 3,022.01 695.62 -1,323.43 5,930,666.90 479,664.56 0.50 482.58 MWD+IFR-AK-CAZ-SC(4) 3,751.52 41.08 291.22 3,239.17 3,091.67 717.46 -1,380.07 5,930,688.88 479,607.98 0.19 508.69 MWD+IFR-AK-CAZ-SC(4) 3,844.94 41.07 291.35 3,309.60 3,162.10 739.74 -1,437.26 5,930,711.30 479,550.85 0.09 534.90 MWD+IFR-AK-CAZ-SC(4) 3,935.36 41.02 291.91 3,377.79 3,230.29 761.62 -1,492.45 5,930,733.33 479,495.72 0.41 559.92 MWD+IFR-AK-CAZ-SC(4) 4,029.68 41.15 293.45 3,448.88 3,301.38 785.52 -1,549.64 5,930,757.37 479,438.60 1.08 585.01 MWD+IFR-AK-CAZ-SC(4) 4,122.40 41.05 295.09 3,518.76 3,371.26 810.57 -1,605.20 5,930,782.55 479,383.10 1.17 608.12 MWD+IFR-AK-CAZ-SC(4) 7/5/201612:02:56PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: , NADConversion Local Co-ordinate Reference: Well 2S-12 Project: Kuparuk River Unit TVD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: 2S-12 actual©147.50usfi(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12 Survey Calculation Method: Minimum Curvature Design: 2S-12 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) O (°) (usft) (usft) (usft) (usft) ({(,) (ft) (°/1001 (ft) Survey Tool Name 4,219.12 4114 296.02 3,591.65 3,444.15 838.00 -1,662.56 5,930,810.12 479325.83 0.64 630.91 MWD+IFR-AK-CAZ-SC(4) 4,310.16 41.13 296.51 3,660.22 3,512.72 864.50 -1,716.26 5,930,836.76 479,272.19 0.35 651.68 MWD+IFR-AK-CAZ-SC(5) 4,403.88 41.23 296.66 3,730.75 3,583.25 892.12 -1,771.45 5,930,864.51 479,217.08 0.15 672.76 MWD+IFR-AK-CAZ-SC(5) 4,496.23 41.10 297.00 3,800.28 3,652.78 919.55 -1,825.69 5,930,892.08 479,162.91 0.28 693.28 MWD+IFR-AK-CAZ-SC(5) 4,590.24 41.16 296.38 3,871.09 3,723.59 947.33 -1,880.94 5,930,919.99 479,107.74 0.44 714.29 MWD+IFR-AK-CAZ-SC(5) 4,684.70 41.05 294.14 3,942.27 3,794.77 973.83 -1,937.09 5,930,946.63 479,051.66 1.56 736.85 MWD+IFR-AK-CAZ-SC(5) 4,777.22 41.15 291.95 4,011.99 3,864.49 997.63 -1,993.05 5,930,970.57 478,995.77 1.56 761.11 MWD+IFR-AK-CAZ-SC(5) 4,870.35 41.16 291.07 4,082.11 3,934.61 1,020.10 -2,050.07 5,930,993.18 478,938.81 0.62 787.06 MWD+IFR-AK-CAZ-SC(5) 4,963.26 40.95 289.29 4,152.18 4,004.68 1,041.15 -2,107.34 5,931,014.37 478,881.60 1.28 814.16 MWD+IFR-AK-CAZ-SC(5) 5,057.57 41.04 289.86 4,223.36 4,075.86 1,061.88 -2,165.63 5,931,035.25 478,823.37 0.41 842.23 MWD+IFR-AK-CAZ-SC(5) 5,149.75 41.11 289.10 4,292.85 4,145.35 1,082.08 -2,222.73 5,931,055.59 478,766.32 0.55 869.80 MWD+IFR-AK-CAZ-SC(5) 5,242.58 41.69 287.83 4,362.48 4,214.98 1,101.52 -2,280.96 5,931,075.17 478,708.15 1.10 898.71 MWD+IFR-AK-CAZ-SC(5) 5,336.87 41.74 286.36 4,432.87 4,285.37 1,119.96 -2,340.93 5,931,093.76 478,648.24 1.04 929.57 MWD+IFR-AK-CAZ-SC(5) 5,430.89 39.77 283.85 4,504.09 4,356.59 1,135.98 -2,400.16 5,931,109.92 478,589.04 2.73 961.57 MWD+IFR-AK-CAZ-SC(5) 5,524.43 39.54 279.92 4,576.12 4,428.62 1,148.27 -2,458.55 5,931,122.36 478,530.69 2.69 995.51 MWD+IFR-AK-CAZ-SC(5) 5,616.10 40.41 275.08 4,646.38 4,498.88 1,155.93 -2,516.91 5,931,130.17 478,472.36 3.52 1,032.61 MWD+IFR-AK-CAZ-SC(5) 5,711.57 41.16 271.40 4,718.68 4,571.18 1,159.44 -2,579.15 5,931,133.83 478,410.14 2.64 1,075.39 MWD+IFR-AK-CAZ-SC(5) 5,801.70 41.65 268.75 4,786.29 4,638.79 1,159.51 -2,638.75 5,931,134.06 478,350.55 2.02 1,118.62 MWD+IFR-AK-CAZ-SC(5) 5,897.45 42.64 266.18 4,857.29 4,709.79 1,156.65 -2,702.92 5,931,131.36 478,286.37 2.08 1,167.17 MW1D+IFR-AK-CAZ-SC(5) 5,987.96 43.46 263.66 4,923.43 4,775.93 1,151.17 -2,764.45 5,931,126.04 478,224.83 2.11 1,215.62 MWD+IFR-AK-CAZ-SC(5) 6,081.91 44.83 260.75 4,990.85 4,843.35 1,142.28 -2,829.26 5,931,117.31 478,160.01 2.60 1,268.79 MWD+IFR-AK-CAZ-SC(5) 6,175.61 45.61 258.17 5,056.86 4,909.36 1,130.11 -2,894.64 5,931,105.30 478,094.61 2.12 1,324.63 MWD+IFR-AK-CAZ-SC(5) 6,270.28 45.50 255.51 5,123.16 4,975.66 1,114.72 -2,960.44 5,931,090.09 478,028.78 2.01 1,382.98 MVVD+IFR-AK-CAZ-SC(5) 6,362.71 44.98 251.45 5,188.25 5,040.75 1,096.08 -3,023.33 5,931,071.60 477,965.84 3.17 1,441 47 MWD+IFR-AK-CAZ-SC(5) 6,456.17 44.56 248.02 5,254.61 5,107.11 1,073.29 -3,085.06 5,931,048.98 477,904.06 2.62 1,501.96 MWD+IFR-AK-CAZ-SC(5) 6,548.26 44.41 244.38 5,320.32 5,172.82 1,047.27 -3,144.09 5,931,023.10 477,844.97 2.77 1,562.71 MWD+IFR-AK-CAZ-SC(5) 6,642.77 44.99 241.13 5,387.51 5,240.01 1,016.83 -3,203.17 5,930,992.82 477,785.82 2.50 1,626.54 MWD+IFR-AK-CAZ-SC(5) 6,735.94 45.10 238.50 5,453.35 5,305.85 983.69 -3,260.15 5,930,959.82 477,728.76 2.00 1,690.70 MWD+IFR-AK-CAZ-SC(5) 6,828.03 46.36 236.47 5,517.63 5,370.13 948.23 -3,315.74 5,930,924.51 477,673.09 2.09 1,755.44 MWD+IFR-AK-CAZ-SC(5) 6,919.42 47.82 235.25 5,579.85 5,432.35 910.66 -3,371.14 5,930,887.08 477,617.60 1.87 1,821.50 MWD+IFR-AK-CAZ-SC(5) 7,014.41 49.44 232.79 5,642.64 5,495.14 868.78 -3,428.80 5,930,845.34 477,559.84 2.59 1,892.17 MVVD+IFR-AK-CAZ-SC(5) 7,107.32 51.63 229.74 5,701.70 5,554.20 823.88 -3,484.72 5,930,800.60 477,503.82 3.46 1,963.64 MWD+IFR-AK-CAZ-SC(5) 7,199.97 54.26 226.16 5,757.53 5,610.03 774.35 -3,539.58 5,930,751.20 477,448.84 4.19 2,037.53 MWD+IFR-AK-CAZ-SC(5) 7,291.54 56.22 223.31 5,809.74 5,662.24 720.90 -3,592.50 5,930,697.90 477,395.79 3.33 2,112.70 fvIWD+IFR-AK-CAZ-SC(5) 7,385.34 59.21 219.58 5,859.85 5,712.35 661.46 -3,644.93 5,930,638.59 477,343.21 4.63 2,191.65 MWD+IFR-AK-CAZ-SC(5) 7,478.18 61.89 216.43 5,905.50 5,758.00 597.76 -3,694.67 5,930,575.02 477,293.31 4.13 2,271.57 MWD+IFR-AK-CAZ-SC(5) 7,572.51 64.12 213.35 5,948.33 5,800.83 528.81 -3,742.72 5,930,506.21 477,245.10 3.75 2,353.86 MWD+IFR-AK-CAZ-SC(5) 7,664.72 66.51 211.43 5,986.84 5,839.34 458.07 -3,787.59 5,930,435.58 477,200.06 3.21 2,435.08 MWD+IFR-AK-CAZ-SC(5) 7,759.36 68.37 210.47 6,023.14 5,875.64 383.12 -3,832.53 5,930,360.75 477,154.93 2.18 2,519.25 MVVD+IFR-AK-CAZ-SC(5) 7,851.53 69.77 209.79 6,056.07 5,908.57 308.66 -3,875.74 5,930,286.41 477,111.54 1.67 2,601.82 MWD+IFR-AK-CAZ-SC(5) 7/5/2016 12:02:56PM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-12 Project: Kuparuk River Unit TVD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Site:. Kuparuk 2S Pad MD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Weils', ',4'.:- 2S-12 North Reference: True Wellbo* 2S-12 Survey Calculation Method: Minimum Curvature Design:'.... 2S-12 Database: OAKEDMP2 Stlyi� ti Map Map Vertical MD"`: Inc Jar TVD S', +Nl-S +El-W Northing Easting DLS Section waft) {°) (°) (u , (usft) (usft) (usft) (ft) (ft) (%100') (ft) Survey Tool Name 7,941.56 71.17 208.49 6,086.17 5,938.67 234.55 -3,917.05 5,930,212 41 477,070.05 2.07 2,682.77 MWD+IFR-AK-CAZ-SC(5) 8,035.83 71.70 207.14 6,116.18 5,968.68 155.51 -3,958.74 5,930,133.49 477,028.15 1.47 2,767.40 MWD+IFR-AK-CAZ-SC(5) 8,130.07 72.38 206.98 6,145.24 5,997.74 75.68 -3,999.53 5,930,053.77 476,987.17 0.74 2,851.90 MWD+IFR-AK-CAZ-SC(5) 8,178.05 73.11 207.03 6,159.47 6,011.97 34.86 -4,020.33 5,930,013.00 476,966.27 1.52 2,895.08 MVVD+IFR-AK-CAZ-SC(5) 8,239.00 73.17 207.89 6,177.15 6,029.65 -16.90 -4,047.23 5,929,961.32 476,939.24 1.36 2,950.20 MWD+IFR-AK-CAZ-SC(6) 7-518"x 9-7/8-11" 8,241.66 73.17 207.93 6,177.92 6,030.42 -19.15 -4,048.42 5,929,959.07 476,938.05 1.36 2,952.61 MWD+IFR-AK-CAZ-SC(6) 8,295.57 74.04 207.29 6,193.14 6,045.64 -64.98 -4,072.39 5,929,913.31 476,913.96 1.98 3,001.53 MWD+IFR-AK-CAZ-SC(6) 8,389.70 75.24 207.40 6,218.07 6,070.57 -145.60 -4,114.08 5,929,832.80 476,872.07 1.28 3,087.24 MWD+IFR-AK-CAZ-SC(6) 8,483.50 77.12 206.58 6,240.48 6,092.98 -226.76 -4,155.42 5,929,751.75 476,830.54 2.18 3,173.06 MW1D+IFR-AK-CAZ-SC(6) 8,579.36 78.59 204.50 6,260.65 6,113.15 -311.32 -4,195.81 5,929,667.31 476,789.93 2.62 3,260.53 MWD+IFR-AK-CAZ-SC(6) 8,674.42 81.25 202.65 6,277.28 6,129.78 -397.09 -4,233.23 5,929,581.64 476,752.30 3.39 3,346.68 MWD+IFR-AK-CAZ-SC(6) 8,709.96 83.20 202.53 6,282.09 6,134.59 -429.60 -4,246.76 5,929,549.16 476,738.69 5.50 3,378.85 MVVD+IFR-AK-CAZ-SC(6) 8,769.41 86.34 201.25 6,287.51 6,140.01 -484.52 -4,268.83 5,929,494.30 476,716.49 5.70 3,432.64 MWD+IFR-AK-CAZ-SC(6) 8,865.18 90.31 199.67 6,290.31 6,142.81 -574.19 -4,302.28 5,929,404.72 476,682.81 4.46 3,518.59 MW1D+IFR-AK-CAZ-SC(6) 8,959.33 91.21 197.63 6,289.06 6,141.56 -663.39 -4,332.38 5,929,315.62 476,652.49 2.37 3,601.78 MWD+IFR-AK-CAZ-SC(6) 9,053.67 90.90 197.27 6,287.32 6,139.82 -753.37 -4,360.67 5,929,225.71 476,623.98 0.50 3,684.19 MWD+IFR-AK-CAZ-SC(6) 9,147.99 89.80 195.50 6,286.75 6,139.25 -843.85 -4,387.27 5,929,135.31 476,597.15 2.21 3,765.72 MWD+IFR-AK-CAZ-SC(6) 9,242.15 90.04 196.35 6,286.88 6,139.38 -934.40 -4,413.11 5,929,044.84 476,571.09 0.94 3,846.74 MWD+IFR-AK-CAZ-SC(6) 9,336.56 89.63 191.88 6,287.15 6,139.65 -1,025.93 -4,436.13 5,928,953.37 476,547.84 4.75 3,926.40 MWD+IFR-AK-CAZ-SC(6) 9,430.98 89.56 190.13 6,287.82 6,140.32 -1,118.61 -4,454.15 5,928,860.74 476,529.59 1.85 4,003.21 MWD+IFR-AK-CAZ-SC(6) 9,524.48 89.60 190.07 6,288.50 6,141.00 -1,210.66 -4,470.55 5,928,768.75 476,512.96 0.08 4,078.41 MWD+IFR-AK-CAZ-SC(6) 9,619.64 89.56 190.91 6,289.20 6,141.70 -1,304.23 -4,487.87 5,928,675 23 476,495.40 0.88 4,155.33 MWD+IFR-AK-CAZ-SC(6) 9,713.52 89.60 191.82 6,289.89 6,142.39 -1,396.26 -4,506.37 5,928,583.25 476,476.68 0.97 4,232.04 MWD+IFR-AK-CAZ-SC(6) 9,812.63 89.43 195.05 6,290.73 6,143.23 -1,492.64 -4,529.39 5,928,486.94 476,453.41 3.26 4,315.03 MWD+IFR-AK-CAZ-SC(6) 9,902.41 89.49 194.81 6,291.57 6,144.07 -1,579.39 -4,552.52 5,928,400.26 476,430.07 0.28 4,391.48 MWD+IFR-AK-CAZ-SC(6) 9,996.87 89.49 194.17 6,292.42 6,144.92 -1,670.84 -4,576.16 5,928,308.88 476,406.20 0.68 4,471.52 MWD+IFR-AK-CAZ-SC(6) 10,091.64 89.49 194.22 6,293.26 6,145.76 -1,762.71 -4,599.40 5,928,217.07 476,382.74 0.05 4,551.57 MWD+IFR-AK-CAZ-SC(6) 10,187.06 89.56 193.29 6,294.05 6,146.55 -1,855.39 -4,622.08 5,928,124.46 476,359.82 0.98 4,631.77 MWD+IFR-AK-CAZ-SC(6) 10,282.04 91.01 192.95 6,293.58 6,146.08 -1,947.89 -4,643.64 5,928,032.03 476,338.03 1.57 4,711.02 MWD+IFR-AK-CAZ-SC(6) 10,376.98 90.97 192.27 6,291.94 6,144.44 -2,040.52 -4,664.37 5,927,939.46 476,317.07 0.72 4,789.77 MWD+IFR-AK-CAZ-SC(6) 10,470.97 91.28 192.53 6,290.09 6,142.59 -2,132.30 -4,684.54 5,927,847.74 476,296.67 0.43 4,867.53 MWD+IFR-AK-CAZ-SC(6) 10,565.39 92.13 192.20 6,287.28 6,139.78 -2,224.49 -4,704.75 5,927,755.61 476,276.23 0.97 4,945.59 MWD+IFR-AK-CAZ-SC(6) 10,660.00 92.41 192.68 6,283.53 6,136.03 -2,316.81 -4,725.12 5,927,663.35 476,255.63 0.59 5,023.86 MWD+IFR-AK-CAZ-SC(6) 10,756.09 92.55 192.35 6,279.38 6,131.88 -2,410.53 -4,745.92 5,927,569.70 476,234.59 0.37 5,103.40 MWD+IFR-AK-CAZ-SC(6) 10,849.95 92.38 194.56 6,275.34 6,127.84 -2,501.72 -4,767.74 5,927,478.57 476,212.55 2.36 5,181.95 MWD+IFR-AK-CAZ-SC(6) 10,943.62 90.68 195.88 6,272.84 6,125.34 -2,592.07 -4,792.32 5,927,388.29 476,187.74 2.30 5,261.92 MWD+IFR-AK-CAZ-SC(6) 11,039.03 91.11 194.41 6,271.35 6,123.85 -2,684.15 -4,817.24 5,927,296.28 476,162.59 1.61 5,343.34 MVVD+IFR-AK-CAZ-SC(6) 11,132.17 91.86 194.02 6,268.93 6,121.43 -2,774.41 -4,840.11 5,927,206.09 476,139.50 0.91 5,422.00 MWD+IFR-AK-CAZ-SC(6) 11,179.20 92.00 191.04 6,267.35 6,119.85 -2,820.28 -4,850.30 5,927,160.24 476,129.19 6.34 5,460.95 MWD+IFR-AK-CAZ-SC(7) 7/5/2016 12:02.56PM Page 5 COMPASS 5000.1 Build 74 Schlumberger S Definitive Survey Report company; NADConversion Local Co-ordinate Reference: Well 2S-12 Project Kuparuk River Unit TVD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Stte; Kuparuk 2S Pad MD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Welt; 4: 2S-12 North Reference: True Wlltore 2S-12 Survey Calculation Method: Minimum Curvature Desgn 2S-12 Database: OAKEDMP2 Survey Map Map Vertical f D Inc Azi TVD TVDSS +N/-S +El-W Northing t=asting DLS Section (u (°j (°) (usft) (usft) (usft) (usft) (ft) (ft) (°f100') (ft) Survey Tool Name 11,272.58 92.03 191.92 6,264.07 6,116.57 -2,911.74 -4,868.88 5,927,068.85 476,110.39 0.94 5,537.32 MWD+IFR-AK-CAZ-SC(7) 11,364.13 92.57 192.45 6,260.39 6,112.89 -3,001.15 -4,888.19 5,926,979.49 476,090.86 0.83 5,612.82 MWD+IFR-AK-CAZ-SC(7) 11,460.58 90.62 195.42 6,257.71 6,110.21 -3,094.71 -4,911.40 5,926,886.00 476,067.41 3.68 5,694.01 MWD+IFR-AK-CAZ-SC(7) 11,553.43 87.96 196.50 6,258.86 6,111.36 -3,183.97 -4,936.93 5,926,796.82 476,041.66 3.09 5,773.92 MWD+IFR-AK-CAZ-SC(7) 11,647.75 87.91 199.17 6,262.26 6,114.76 -3,273.69 -4,965.79 5,926,707.18 476,012.57 2.83 5,856.57 MWD+IFR-AK-CAZ-SC(7) 11,741.48 85.37 198.23 6,267.75 6,120.25 -3,362.31 -4,995.79 5,926,618.64 475,982.35 2.89 5,939.29 MWD+IFR-AK-CAZ-SC(7) 11,836.99 87.10 198.18 6,274.02 6,126.52 -3,452.84 -5,025.56 5,926,528.19 475,952.35 1.81 6,023.16 MWD+IFR-AK-CAZ-SC(7) 11,898.68 89.87 196.47 6,275.65 6,128.15 -3,511.70 -5,043.93 5,926,469.38 475,933.85 5.28 6,076.96 MWD+IFR-AK-CAZ-SC(8) 11,931.51 87.99 196.28 6,276.27 6,128.77 -3,543.19 -5,053.18 5,926,437.92 475,924.51 5.76 6,105.34 MWD+IFR-AK-CAZ-SC(8) 12,025.86 85.83 197.14 6,281.35 6,133.85 -3,633.42 -5,080.27 5,926,347.77 475,897.20 2.46 6,187.05 MWD+IFR-AK-CAZ-SC(8) 12,120.35 85.47 197.88 6,288.52 6,141.02 -3,723.27 -5,108.61 5,926,258.00 475,868.63 0.87 6,269.41 MVVD+IFR-AK-CAZ-SC(8) 12,215.50 85.33 196.49 6,296.15 6,148.65 -3,813.88 -5,136.63 5,926,167.47 475,840.39 1.46 6,352.06 MWD+IFR-AK-CAZ-SC(8) 12,308.99 84.58 195.73 6,304.37 6,156.87 -3,903.35 -5,162.48 5,926,078.08 475,814.32 1.14 6,432.34 MWD+IFR-AK-CAZ-SC(8) 12,403.69 82.05 196.54 6,315.39 6,167.89 -3,993.69 -5,188.61 5,925,987.81 475,787.96 2.80 6,513.44 MWD+IFR-AK-CAZ-SC(8) 12,498.18 83.04 196.01 6,327.65 6,180.15 -4,083.63 -5,214.87 5,925,897.95 475,761.48 1.19 6,594.35 MWD+IFR-AK-CAZ-SC(8) 12,592.66 86.21 196.35 6,336.50 6,189.00 -4,173.96 -5,241.07 5,925,807.69 475,735.05 3.37 6,675.49 MWD+IFR-AK-CAZ-SC(8) 12,688.08 91.33 191.73 6,338.55 6,191.05 -4,266.45 -5,264.20 5,925,715.27 475,711.69 7.23 6,755.88 MWD+IFR-AK-CAZ-SC(8) 12,782.79 94.13 189.53 6,334.04 6,186.54 -4,359.41 -5,281.65 5,925,622.36 475,694.01 3.76 6,832.47 MVVD+IFR-AK-CAZ-SC(8) 12,876.25 95.73 190.58 6,326.01 6,178.51 -4,451.09 -5,297.91 5,925,530.73 475,677.53 2.05 6,907.32 MWD+IFR-AK-CAZ-SC(8) 12,968.89 94.94 192.57 6,317.40 6,169.90 -4,541.45 -5,316.41 5,925,440.43 475,658.79 2.30 6,982.89 MWD+IFR-AK-CAZ-SC(8) 13,064.39 94.92 193.45 6,309.19 6,161.69 -4,634.15 -5,337.83 5,925,347.79 475,637.14 0.92 7,062.18 MWD+IFR-AK-CAZ-SC(8) 13,159.17 93.52 193.71 6,302.21 6,154.71 -4,726.03 -5,360.03 5,925,255.98 475,614.72 1.50 7,141.47 MWD+IFR-AK-CAZ-SC(8) 13,254.15 93.95 194.98 6,296.03 6,148.53 -4,817.85 -5,383.51 5,925,164.22 475,591.01 1.41 7,221.66 MWD+IFR-AK-CAZ-SC(8) 13,349.60 95.22 193.48 6,288.40 6,140.90 -4,910.07 -5,406.90 5,925,072.07 475,567.39 2.06 7,302.05 MWD+IFR-AK-CAZ-SC(8) 13,440.01 93.61 194.10 6,281.44 6,133.94 4997.61 -5,428.38 5,924,984.59 475,545.69 1.91 7,377.85 MWD+IFR-AK-CAZ-SC(8) 13,535.44 95.76 194.90 6,273.64 6,126.14 -5,089.69 -5,452.19 5,924,892.59 475,521.65 2.40 7,458.45 MWD+IFR-AK-CAZ-SC(8) 13,638.00 95.76 194.90 6,263.35 6,115.85 -5,188.30 -5,478.43 5,924,794.05 475,495.16 0.00 7,545.31 PROJECTED to TD 7/5/2016 12:02:56PM Page 6 COMPASS 5000.1 Build 74 • NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-12PB1 2S-12PB1 Definitive Survey Report • 05 July, 2016 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-12 Project Kuparuk River Unit ,TVD Reference:- 2S-12 actual @ 147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: , 2S-12 actual©147.50usft(Doyon 141) Well: 2S-12 North Reference: •• •:-7-,•• True Wellbore: 2S-12PB1 Survey Calculation Method: Minimum Curvature Design; 2S-12PB1 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-12 Well Position +NI-S 0.00 usft Northing: 5,929,968.02 usft Latitude: 70°13'11.380 N +EI-W 0.00 usft Easting: 480,986.10 usft Longitude: 150°9'12.212 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore 2S-12PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( (1 PIT) BGGM2016 6/20/2016 17.97 80.85 57,536 Design 2S-12PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.50 Vertical Section: Depth From(TVD) +N!-S +E/-W Direction (usft) (usft) (usft) (0) '','%/A1,' . 27.50 0.00 0.00 195.00 Sur y Program Date Prom To {usft} {usft) Survey(Wellbl ) F Tool Name Description Survey Date 100.00 975.00 2S-12 Srvy 1-SLB_NSG+BATTERY(2S GYD-GC-SS Gyrodata gyro single shots 6/9/2016 8:37:0 1,013.91 2,787.47 2S-12 Srvy 2-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/8/2016 10:02:C 2,815.78 2,815.78 2S-12 Srvy 3-SLB_INC+Filler(2S-12PB INC+TREND Inclinometer+known azi trend 6/13/2016 9:29: 2,908.52 4,219.12 2S-12 Srvy 4-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/13/2016 9:34:, 4,310.16 8,178.05 2S-12 Srvy 5-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/15/2016 9:10: 8,241.66 11,132.17 2S-12 Srvy 6-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/23/2016 1:52: 11,179.20 12,212.25 2S-12PB1 Srvy 7-SLB_MWD+GMAG(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/27/2016 8:40: Survey Map Map Vertical MD Inc Azi TVD TVDSS ` +NI-S +E/-W Northing Easting DLS Section • (usft) ( (6) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,929,968.02 480,986.10 0.00 0.00 UNDEFINED 100.00 0.29 190.76 100.00 -47.50 -0.18 -0.03 5,929,967.84 480,986.07 0.40 0.18 GYD-GC-SS(1) 200.00 0.41 190.63 200.00 52.50 -0.78 -0.15 5,929,967.24 480,985.95 0.12 0.79 GYD-GC-SS(1) 300.00 0.45 195.47 299.99 152.49 -1.51 -0.32 5,929,966.51 480,985.78 0.05 1.54 GYD-GC-SS(1) 400.00 1.00 335.77 399.99 252.49 -1.09 -0.78 5,929,966.93 480,985.32 1.38 1.26 GYD-GC-SS(1) 500.00 2.69 342.00 499.94 352.44 1.93 -1.86 5,929,969.96 480,984.24 1.70 -1.39 GYD-GC-SS(1) 600.00 2.85 339.41 599.82 452.32 6.49 -3.46 5,929,974.52 480,982.65 0.20 -5.38 GYD-GC-SS(1) 700.00 5.59 337.49 699.54 552.04 13.32 -6.20 5,929,981.36 480,979.93 2.74 -11.26 GYD-GC-SS(1) 800.00 6.31 336.02 799.00 651.50 22.84 -10.30 5,929,990.89 480,975.86 0.74 -19.40 GYD-GC-SS(1) 7/5/2016 11:54:52AM Page 2 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-12 Project: Kuparuk River Unit ':TVD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: 2S-12 actual©147.50usft(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12PB1 Survey Calculation Method: ' Minimum Curvature Design: 2S-12PB 1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/$ Northing Easting DLS Section ,,,,, (usft) (°) (°) (usft) (usft) (usk) 5(; ) (ft) (ft) (11003' (ft) ", grey Tool Nail s 900.00 8.69 329 19 898.14 750.64 34.35 -16.41 5,930,002.41 480,969.78 2.54 -28.94 GYD-GC-SS(1) 975.00 10.53 326.13 972.08 824.58 44.91 -23.13 5,930,012.98 480,963.09 2.55 -37.39 GYD-GC-SS(1) 1,013.91 11.75 326.29 1,010.26 862.76 51.16 -27.31 5,930,019.24 480,958.92 3.14 -42.35 MWD+IFR-AK-CAZ-SC(2) 1,107.62 13.67 325.67 1,101.67 954.17 68.24 -38.85 5,930,036.35 480,947.43 2.05 -55.86 MWD+IFR-AK-CAZ-SC(2) 1,200.42 16.08 324.50 1,191.35 1,043.85 87.76 -52.50 5,930,055.91 480,933.83 2.62 -71.18 MWD+IFR-AK-CAZ-SC(2) 1,292.50 19.08 320.32 1,279.13 1,131.63 109.73 -69.52 5,930,077.92 480,916.87 3.53 -88.00 MWD+IFR-AK-CAZ-SC(2) 1,386.06 19.77 318.96 1,367.36 1,219.86 133.44 -89.67 5,930,101.67 480,896.77 0.88 -105.68 MWD+IFR-AK-CAZ-SC(2) 1,479.50 20.24 316.88 1,455.16 1,307.66 157.15 -111.09 5,930,125.44 480,875.41 0.91 -123.05 MWD+IFR-AK-CA2-SC(2) 1,572.66 24.30 307.63 1,541.38 1,393.88 180.64 -137.31 5,930,148.98 480,849.26 5.75 -138.94 MWD+IFR-AK-CAZ-SC(2) 1,665.16 27.66 303.44 1,624.53 1,477.03 204.10 -170.31 5,930,172.53 480,816.32 4.14 -153.06 MWD+IFR-AK-CAZ-SC(2) 1,756.86 29.76 300.84 1,704.95 1,557.45 227.50 -207.62 5,930,196.02 480,779.08 2.66 -166.01 MWD+IFR-AK-CAZ-SC(2) 1,849.84 32.90 296.17 1,784.38 1,636.88 250.47 -250.11 5,930,219.10 480,736.64 4.27 -177.21 M1ND+IFR-AK-CAZ-SC(2) 1,943.50 35.44 294.84 1,861.87 1,714.37 273.10 -297.59 5,930,241.85 480,689.23 2.83 -186.78 MWD+IFR-AK-CAZ-SC(2) 2,037.33 37.15 294.42 1,937.49 1,789.99 296.25 -348.08 5,930,265.11 480,638.80 1.84 -196.06 MWD+IFR-AK-CAZ-SC(2) 2,130.01 38.06 294.03 2,010.91 1,863.41 319.45 -399.66 5,930,288.44 480,587.29 1.01 -205.13 MWD+IFR-AK-CAZ-SC(2) 2,222.77 38.76 292.95 2,083.60 1,936.10 342.42 -452.51 5,930,311.54 480,534.50 1.05 -213.63 MWD+IFR-AK-CAZ-SC(2) 2,314.68 39.96 293.82 2,154.66 2,007.16 365.56 -506.01 5,930,334.81 480,481.07 1.44 -222.14 MWD+IFR-AK-CAZ-SC(2) 2,409.01 41.18 294.41 2,226.31 2,078.81 390.62 -562.00 5,930,360.02 480,425.14 1.36 -231.86 MWD+IFR-AK-CAZ-SC(2) 2,502.49 40.81 294.01 2,296.87 2,149.37 415.77 -617.93 5,930,385.31 480,369.28 0.49 -241.67 MWD+IFR-AK-CAZ-SC(2) 2,596.33 40.61 293.99 2,368.00 2,220.50 440.67 -673.84 5,930,410.34 480,313.44 0.21 -251.25 MWD+IFR-AK-CAZ-SC(2) 2,688.67 40.56 293.51 2,438.13 2,290.63 464.86 -728.83 5,930,434.67 480,258.52 0.34 -260.39 MVVD+IFR-AK-CAZ-SC(2) 2,787.47 40.93 290.93 2,512.99 2,365.49 489.24 -788.51 5,930,459.19 480,198.90 1.74 -268.48 MWD+IFR-AK-CAZ-SC(2) 2,815.78 41.16 291.00 2,534.34 2,386.84 495.89 -805.87 5,930,465.89 480,181.56 0.83 -270.42 INC+TREND(3) 2,845.00 41.18 291.36 2,556.33 2,408.83 502.84 -823.81 5,930,472.88 480,163.64 0.82 -272.49 MWD+IFR-AK-CAZ-SC(4) 40 314"x 131i'2" 2,908.52 41.23 292.15 2,604.12 2,456.62 518.35 -862.67 5,930,488.49 480,124.82 0.82 -277.41 MWD+IFR-AK-CAZ-SC(4) 3,003.43 41.26 291.42 2,675.49 2,527.99 541.57 -920.78 5,930,511.85 480,066.78 0.51 -284.80 MWD+IFR-AK-CAZ-SC(4) 3,093.72 41.20 290.99 2,743.39 2,595.89 563.10 -976.25 5,930,533.52 480,011.36 0.32 -291.24 MWD+IFR-AK-CAZ-SC(4) 3,189.59 41.13 290.66 2,815.56 2,668.06 585.53 -1,035.24 5,930,556.10 479,952.44 0.24 -297.64 MWD+IFR-AK-CAZ-SC(4) 3,281.31 41.07 290.18 2,884.68 2,737.18 606.57 -1,091.74 5,930,577.27 479,896.00 0.35 -303.34 MWD+IFR-AK-CAZ-SC(4) 3,377.84 41.03 290.47 2,957.48 2,809.98 628.59 -1,151.19 5,930,599.44 479,836.61 0.20 -309.22 MWD+IFR-AK-CAZ-SC(4) 3,472.80 41.11 291.43 3,029.07 2,881.57 650.89 -1,209.45 5,930,621.89 479,778.42 0.67 -315.69 MWD+IFR-AK-CAZ-SC(4) 3,566.08 41.08 291.66 3,099.37 2,951.87 673.41 -1,266.48 5,930,644.55 479,721.45 0.17 -322.67 MWD+IFR-AK-CAZ-SC(4) 3,659.12 41.06 290.95 3,169.51 3,022.01 695.62 -1,323.43 5,930,666.90 479,664.56 0.50 -329.39 MWD+IFR-AK-CAZ-SC(4) 3,751.52 41.08 291.22 3,239.17 3,091.67 717.46 -1,380.07 5,930,688.88 479,607.98 0.19 -335.82 MWD+IFR-AK-CAZ-SC(4) 3,844.94 41.07 291.35 3,309.60 3,162.10 739.74 -1,437.26 5,930,711.30 479,550.85 0.09 -342.54 MWD+IFR-AK-CAZ-SC(4) 3,935.36 41.02 291.91 3,377.79 3,230.29 761.62 -1,492.45 5,930,733.33 479,495.72 0.41 -349.40 MVVD+IFR-AK-CAZ-SC(4) 4,029.68 41.15 293.45 3,448.88 3,301.38 785.52 -1,549.64 5,930,757.37 479,438.60 1.08 -357.68 MWD+IFR-AK-CAZ-SC(4) 4,122.40 41.05 295.09 3,518.76 3,371.26 810.57 -1,605.20 5,930,782.55 479,383.10 1.17 -367.50 MWD+IFR-AK-CAZ-SC(4) 4,219.12 41.14 296.02 3,591.65 3,444.15 838.00 -1,662.56 5,930,810.12 479,325.83 0.64 -379.14 M1.ND+IFR-AK-CAZ-SC(4) 7/5/2016 11:54:52AM Page 3 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-12 Project: Kuparuk River Unit TVD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12PB1 Survey Calculation Method: Minimum Curvature Design: 2S-12PB 1 Database: OA KEDM P2 Survey F ,a Map Map Vertical "' M6,-24' Inc ..:=--Mr TND 1VOSS +Nt-S +Ei-W Northing Easting DLS Section (usft) (') (°) (usft) (t1 }.', (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,310.16 41.13 296.51 3,660.22 3,512.72 864.50 -1,716.26 5,930,836.76 479,272 19 0 35 -390.84 MWD+IFR-AK-CAZ-SC(5) 4,403.88 41.23 296.66 3,730.75 3,583.25 892.12 -1,771.45 5,930,864.51 479,217.08 0.15 -403.24 MWD+IFR-AK-CAZ-SC(5) 4,496.23 41.10 297.00 3,800.28 3,652.78 919.55 -1,825.69 5,930,892.08 479,162.91 0.28 -415.70 MWD+IFR-AK-CAZ-SC(5) 4,590.24 41.16 296.38 3,871.09 3,723.59 947.33 -1,880.94 5,930,919.99 479,107.74 0.44 -428.23 tv1WD+IFR-AK-CAZ-SC(5) 4,684.70 41.05 294.14 3,942.27 3,794.77 973.83 -1,937.09 5,930,946.63 479,051.66 1.56 -439.29 MWD+IFR-AK-CAZ-SC(5) 4,777.22 41.15 291.95 4,011.99 3,864.49 997.63 -1,993.05 5,930,970.57 478,995.77 1.56 -447.80 MWD+IFR-AK-CAZ-SC(5) 4,870.35 41.16 291.07 4,082.11 3,934.61 1,020.10 -2,050.07 5,930,993.18 478,938.81 0.62 -454.75 MWD+IFR-AK-CAZ-SC(5) 4,963.26 40.95 289.29 4,152.18 4,004.68 1,041.15 -2,107.34 5,931,014.37 478,881.60 1.28 -460.26 MWD+IFR-AK-CAZ-SC(5) 5,057.57 41.04 289.86 4,223.36 4,075.86 1,061.88 -2,165.63 5,931,035.25 478,823.37 0.41 -465.19 MWD+IFR-AK-CAZ-SC(5) 5,149.75 41.11 289.10 4,292.85 4,145.35 1,082.08 -2,222.73 5,931,055.59 478,766.32 0.55 -469.92 MWD+IFR-AK-CAZ-SC(5) 5,242 58 41.69 287.83 4,362.48 4,214.98 1,101.52 -2,280.96 5,931,075.17 478,708.15 1.10 -473.63 MWD+IFR-AK-CAZ-SC(5) 5,336.87 41.74 286.36 4,432.87 4,285.37 1,119.96 -2,340.93 5,931,093.76 478,648.24 1.04 -475.92 MWD+IFR-AK-CAZ-SC(5) 5,430.89 39.77 283.85 4,504.09 4,356.59 1,135.98 -2,400.16 5,931,109.92 478,589.04 2.73 -476.06 MWD+IFR-AK-CAZ-SC(5) 5,524.43 39.54 279.92 4,576.12 4,428.62 1,148.27 -2,458.55 5,931,122.36 478,530.69 2.69 -472.82 MWD+IFR-AK-CAZ-SC(5) 5,616.10 40.41 275.08 4,646.38 4,498.88 1,155.93 -2,516.91 5,931,130.17 478,472.36 3.52 -465.12 MWD+IFR-AK-CAZ-SC(5) 5,711.57 41.16 271.40 4,718.68 4,571.18 1,159.44 -2,579.15 5,931,133.83 478,410.14 2.64 -452.40 MWD+IFR-AK-CAZ-SC(5) 5,801.70 41.65 268.75 4,786.29 4,638.79 1,159.51 -2,638.75 5,931,134.06 478,350.55 2.02 -437.04 MWD+IFR-AK-CAZ-SC(5) 5,897.45 42.64 266.18 4,857.29 4,709.79 1,156.65 -2,702.92 5,931,131 36 478,286.37 2.08 -417.67 MWD+IFR-AK-CAZ-SC(5) 5,987.96 43.46 263.66 4,923.43 4,775.93 1,151.17 -2,764.45 5,931,126.04 478,224.83 2.11 -396.46 MVVD+IFR-AK-CAZ-SC(5) 6,081.91 44.83 260.75 4,990.85 4,843.35 1,142.28 -2,829.26 5,931,117.31 478,160.01 2.60 -371.09 MWD+IFR-AK-CAZ-SC(5) 6,175.61 45.61 258.17 5,056.86 4,909.36 1,130.11 -2,894.64 5,931,105.30 478,094.61 2.12 -342.41 MWD+IFR-AK-CAZ-SC(5) 6,270.28 45.50 255.51 5,123.16 4,975.66 1,114.72 -2,960.44 5,931,090.09 478,028.78 2.01 -310.52 MWD+IFR-AK-CAZ-SC(5) 6,362.71 44.98 251.45 5,188.25 5,040.75 1,096.08 -3,023.33 ,5,931,071.60 477,965.84 3.17 -276.23 MWD+IFR-AK-CAZ-SC(5) 6,456.17 44.56 248.02 5,254.61 5,107.11 1,073.29 -3,085.06 5,931,048.98 477,904.06 2.62 -238.25 MWD+IFR-AK-CAZ-SC(5) 6,548.26 44.41 244.38 5,320.32 5,172.82 1,047.27 -3,144.09 5,931,023.10 477,844.97 2.77 -197.83 MWD+IFR-AK-CAZ-SC(5) 6,642.77 44.99 241.13 5,387.51 5,240.01 1,016.83 -3,203.17 5,930,992.82 477,785.82 2.50 -153.14 MWD+IFR-AK-CAZ-SC(5) 6,735.94 45.10 238.50 5,453.35 5,305.85 983.69 -3,260.15 5,930,959.82 477,728.76 2.00 -106.38 MWD+IFR-AK-CAZ-SC(5) 6,828.03 46.36 236.47 5,517.63 5,370.13 948.23 -3,315.74 5,930,924.51 477,673.09 2.09 -57.75 MWD+IFR-AK-CAZ-SC(5) 6,919.42 47.82 235.25 5,579.85 5,432.35 910.66 -3,371.14 5,930,887.08 477,617.60 1.87 -7.12 MWD+IFR-AK-CAZ-SC(5) 7,014.41 49.44 232.79 5,642.64 5,495.14 868.78 -3,428.80 5,930,845.34 477,559.84 2.59 48.27 MWD+IFR-AK-CAZ-SC(5) 7,107.32 51.63 229.74 5,701.70 5,554.20 823.88 -3,484.72 5,930,800.60 477,503.82 3.46 106.10 MWD+IFR-AK-CAZ-SC(5) 7,199.97 54.26 226.16 5,757.53 5,610.03 774.35 -3,539.58 5,930,751.20 477,448.84 4.19 168.15 MWD+IFR-AK-CAZ-SC(5) 7,291.54 56.22 223.31 5,809.74 5,662.24 720.90 -3,592.50 5,930,697.90 477,395.79 3.33 233.47 MVVD+IFR-AK-CAZ-SC(5) 7,385.34 59.21 219.58 5,859.85 5,712.35 661.46 -3,644.93 5,930,638.59 477,343.21 4.63 304.46 MWD+IFR-AK-CAZ-SC(5) 7,478.18 61.89 216.43 5,905.50 5,758.00 597.76 -3,694.67 5,930,575.02 477,293.31 4.13 378.86 MWD+IFR-AK-CAZ-SC(5) 7,572.51 64.12 213.35 5,948.33 5,800.83 528.81 -3,742.72 5,930,506.21 477,245.10 3.75 457.89 MVVD+IFR-AK-CAZ-SC(5) 7,664.72 66.51 211.43 5,986.84 5,839.34 458.07 -3,787.59 5,930,435.58 477,200.06 3.21 537.84 MWD+IFR-AK-CAZ-SC(5) 7,759.36 68.37 210.47 6,023.14 5,875.64 383.12 -3,832.53 5,930,360.75 477,154.93 2.18 621.87 MWD+IFR-AK-CAZ-SC(5) 7,851.53 69.77 209.79 6,056.07 5,908.57 308.66 -3,875.74 5,930,286.41 477,111.54 1.67 704.97 MWD+IFR-AK-CAZ-SC(5) 7,941.56 71.17 208.49 6,086.17 5,938.67 234.55 -3,917.05 5,930,212.41 477,070.05 2.07 787.25 MWD+IFR-AK-CAZ-SC(5) 7/5/2016 11:54:52AM Page 4 COMPASS 5000.1 Build 74 111 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-12 Project Kuparuk River Unit TVD Reference: 2S-12 actual©147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference; 2S-12 actual @ 147.50usft(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12PB1 Survey Calculation Method: Minimum Curvature Design: 2S-12PB1 Database: OAKEDMP2 Survey , Map Map Vertical MD Inc Az{ TVD TVDSS' +W +E/-W Northing Easting DLS Section (usft) (°) {°} (usft) {usft) {us(t) {usft) (ft) (ft) (°1001 (ft) Survey Tool Name 8,035.83 71.70 207.14 6,116.18 5,968.68 155.51 -3,958.74 5,930,133.49477,028.15 1.47 874.38 MWD+IFR-AK-CAZ-SC(5) 8,130.07 72.38 206.98 6,145.24 5,997.74 75.68 -3,999.53 5,930,053.77 476,987.17 0.74 962.05 MVD+IFR-AK-CAZ-SC(5) 8,178.05 73.11 207.03 6,159.47 6,011.97 34.86 -4,020.33 5,930,013.00 476,966.27 1.52 1,006.87 MWD+IFR-AK-CAZ-SC(5) 8,239.00 73.17 207.89 6,177.15 6,029.65 -16.90 -4,04723 5,929,961.32 476,939.24 1.36 1,063.83 MWD+IFR-AK-CAZ-SC(6) x 971841' 8,241.66 73.17 207.93 6,177 92 6,030.42 -19.15 -4,048.42 5,929,959 07 476,938.05 1.36 1,066.31 MVVD+IFR-AK-CAZ-SC(6) 8,295.57 74.04 207.29 6,193.14 6,045.64 -64.98 -4,072.39 5,929,913.31 476,913.96 1.98 1,116.78 MWD+IFR-AK-CAZ-SC(6) 8,389.70 75.24 207.40 6,218.07 6,070.57 -145.60 -4,114.08 5,929,832.80 476,872.07 1.28 1,205.44 MWD+IFR-AK-CAZ-SC(6) 8,483.50 77.12 206.58 6,240.48 6,092.98 -226.76 -4,155.42 5,929,751.75 476,830.54 2.18 1,294.54 MWD+IFR-AK-CAZ-SC(6) 8,579.36 78.59 204.50 6,260.65 6,113.15 -311.32 -4,195.81 5,929,667.31 476,789.93 2.62 1,386.66 MWD+IFR-AK-CAZ-SC(6) 8,674.42 81.25 202.65 6,277.28 6,129.78 -397.09 -4,233.23 5,929,581.64 476,752.30 3.39 1,479.20 MWD+IFR-AK-CAZ-SC(6) 8,709.96 83.20 202.53 6,282.09 6,134.59 -429.60 -4,246.76 5,929,549.16 476,738.69 5.50 1,514.10 MWD+IFR-AK-CAZ-SC(6) 8,769.41 86.34 201.25 6,287.51 6,140.01 -484.52 -4,268.83 5,929,494.30 476,716.49 5.70 1,572.87 MWD+IFR-AK-CAZ-SC(6) 8,865.18 90.31 199.67 6,290.31 6,142.81 -574.19 -4,302.28 5,929,404.72 476,682.81 4.46 1,668.14 MVVD+IFR-AK-CAZ-SC(6) 8,959.33 91.21 197.63 6,289.06 6,141.56 -663.39 -4,332.38 5,929,315.62 476,652.49 2.37 1,762.09 MWD+IFR-AK-CAZ-SC(6) 9,053.67 90.90 197.27 6,287.32 6,139.82 -753.37 -4,360.67 5,929,225.71 476,623.98 0.50 1,856.32 MWD+IFR-AK-CAZ-SC(6) 9,147.99 89.80 195.50 6,286.75 6,139.25 -843.85 -4,387.27 5,929,135.31 476,597.15 2.21 1,950.61 MWD+IFR-AK-CAZ-SC(6) 9,242.15 90.04 196.35 6,286.88 6,139.38 -934.40 -4,413.11 5,929,044.84 476,571.09 0.94 2,044.76 MWD+IFR-AK-CAZ-SC(6) 9,336.56 89.63 191.88 6,287.15 6,139.65 -1,025.93 -4,436.13 5,928,953.37 476,547.84 4.75 2,139.13 MWD+IFR-AK-CAZ-SC(6) 9,430.98 89.56 190.13 6,287.82 6,140.32 -1,118.61 -4,454.15 5,928,860.74 476,529.59 1.85 2,233.31 MWD+IFR-AK-CAZ-SC(6) 9,524.48 89.60 190.07 6,288.50 6,141.00 -1,210.66 -4,470.55 5,928,768.75 476,512.96 0.08 2,326.47 MWD+IFR-AK-CAZ-SC(6) 9,619.64 89.56 190.91 6,289.20 6,141.70 -1,304.23 -4,487.87 5,928,675.23 476,495.40 0.88 2,421.33 MWD+IFR-AK-CAZ-SC(6) 9,713.52 89.60 191.82 6,289.89 6,142.39 -1,396.26 -4,506.37 5,928,583.25 476,476.68 0.97 2,515.02 MVVD+IFR-AK-CAZ-SC(6) 9,812.63 89.43 195.05 6,290.73 6,143.23 -1,492.64 -4,529.39 5,928,486.94 476,453.41 3.26 2,614.08 MWD+IFR-AK-CAZ-SC(6) 9,902.41 89.49 194.81 6,291.57 6,144.07 -1,579.39 -4,552.52 5,928,400.26 476,430.07 0.28 2,703.85 MWD+IFR-AK-CAZ-SC(6) 9,996.87 89.49 194.17 6,292.42 6,144.92 -1,670.84 -4,576.16 5,928,308.88 476,406.20 0.68 2,798.30 MVVD+IFR-AK-CAZ-SC(6) 10,091 64 89.49 194.22 6,293.26 6,145.76 -1,762.71 -4,599.40 5,928,217.07 476,382.74 0.05 2,893.06 MWD+IFR-AK-CAZ-SC(6) 10,187.06 89.56 193.29 6,294.05 6,146.55 -1,855.39 -4,622.08 5,928,124.46 476,359.82 0.98 2,988.45 MWD+IFR-AK-CAZ-SC(6) 10,282.04 91.01 192.95 6,293.58 6,146.08 -1,947.89 -4,643.64 5,928,032.03 476,338.03 1.57 3,083.38 MWD+IFR-AK-CAZ-SC(6) 10,376.98 90.97 192.27 6,291.94 6,144.44 -2,040.52 -4,664.37 5,927,939.46 476,317.07 0.72 3,178.22 MWD+IFR-AK-CAZ-SC(6) 10,470.97 91.28 192.53 6,290.09 6,142.59 -2,132.30 -4,684.54 5,927,847.74 476,296.67 0.43 3,272.10 MWD+IFR-AK-CAZ-SC(6) 10,565.39 92.13 192.20 6,287.28 6,139.78 -2,224.49 -4,704.75 5,927,755.61 476,276.23 0.97 3,366.37 MWD+IFR-AK-CAZ-SC(6) 10,660.00 92.41 192.68 6,283.53 6,136.03 -2,316.81 -4,725.12 5,927,663.35 476,255.63 0.59 3,460.82 MWD+IFR-AK-CAZ-SC(6) 10,756.09 92.55 192.35 6,279.38 6,131.88 -2,410.53 -4,745.92 5,927,569.70 476,234.59 0.37 3,556.72 M1M3+IFR-AK-CAZ-SC(6) 10,849.95 92.38 194.56 6,275.34 6,127.84 -2,501.72 -4,767.74 5,927,478.57 476,212.55 2.36 3,650.46 MWD+IFR-AK-CAZ-SC(6) 10,943.62 90.68 195.88 6,272.84 6,125.34 -2,592.07 -4,792.32 5,927,388.29 476,187.74 2.30 3,744.09 MWD+IFR-AK-CAZ-SC(6) 11,039.03 91.11 194.41 6,271.35 6,123.85 -2,684.15 -4,817.24 5,927,296.28 476,162.59 1.61 3,839.48 MWD+IFR-AK-CAZ-SC(6) 11,132.17 91.86 194.02 6,268.93 6,121.43 -2,774.41 -4,840.11 5,927,206.09 476,139.50 0.91 3,932.58 MWD+IFR-AK-CAZ-SC(6) 11,179.20 92.00 191.04 6,267.35 6,119.85 -2,820.28 -4,850.30 5,927,160.24 476,129.19 6.34 3,979.54 MWD+IFR-AK-CAZ-SC(7) 11,272.58 92.03 191.92 6,264.07 6,116.57 -2,911.74 -4,868.88 5,927,068.85 476,110.39 0.94 4,072.68 MWD+IFR-AK-CAZ-SC(7) 7/5/2016 11:54:52AM Page 5 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-12 Project Kuparuk River Unit IVD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12PB1 Survey Calculation Method: Minimum Curvature Design: 2S-12PB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS` +NIS +EI-W Northing Easting DLS Section (usft) (°) () (usft). " (usft) (usft) (usft) (ft) (ft) (°!100') (ft) Survey Tool Name 11,364.13 92.57 192.45 6,260 39 6,112.89 -3,00115 -4,888.19 5,926,979.49 476,090.86 0.83 4,164.05 MWD+IFR-AK-CAZ-SC(7) 11,460.58 90.62 195.42 6,257.71 6,110.21 -3,094.71 -4,911.40 5,926,886.00 476,067.41 3.68 4,260.43 MWD+IFR-AK-CAZ-SC(7) 11,553.43 87.96 196.50 6,258.86 6,111.36 -3,183.97 -4,936.93 5,926,796.82 476,041.66 3.09 4,353.25 MWD+IFR-AK-CAZ-SC(7) 11,647.75 87.91 199.17 6,262.26 6,114.76 -3,273.69 -4,965.79 5,926,707.18 476,012.57 2.83 4,447.38 MWD+IFR-AK-CAZ-SC(7) 11,741.48 85.37 198.23 6,267.75 6,120.25 -3,362.31 -4,995.79 5,926,618.64 475,982.35 2.89 4,540.75 MWD+IFR-AK-CAZ-SC(7) 11,836.99 87.10 198.18 6,274.02 6,126.52 -3,452.84 -5,025.56 5,926,528.19 475,952.35 1.81 4,635.90 MWD+IFR-AK-CAZ-SC(7) 11,930.46 92.12 194.94 6,274.66 6,127.16 -3,542.39 -5,052.19 5,926,438.72 475,925.50 6.39 4,729.29 MWD+IFR-AK-CAZ-SC(7) 12,024.65 94.99 192.86 6,268.82 6,121.32 -3,633.63 -5,074.77 5,926,347.55 475,902.69 3.76 4,823.27 MWD+IFR-AK-CAZ-SC(7) 12,119.05 95.19 192.42 6,260.44 6,112.94 -3,725.38 -5,095.35 5,926,255.86 475,881.89 0.51 4,917.21 MWD+IFR-AK-CAZ-SC(7) 12,212.25 95.11 193.25 6,252.08 6,104.58 -3,815.88 -5,115.97 5,926,165.42 475,861.04 0.89 5,009.97 MWD+IFR-AK-CAZSC(7) 12,303.00 95.11 193.25 6,243.99 6,096.49 -3,903.87 -5,136.69 5,926,077.49 475,840.11 0.00 5,100.32 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and or well position objectives have been achieved. Li Yes L No l have checked to the best of my ability that the following data is correct: Surface Coordinates '' Declination & Convergence iJ CRS Survey Corrections U Survey Tool Codes Digitally grreatrvvrcert Osara DN:rm=YncerttOsara. Vincent Osara e-Schhsm9:ergerr.au=Seliuribrrgw emat=vosaraesit.+mrr,s=lt5 SLB DE: Date 2016.07.06 t2:13:e10e 0' WirtmesaniatuwasOniman Client Representative: >". lila 1..1. Date' O5-iui-2016 7/5/2018 11:54:52AM Page 6 COMPASS 5000.1 Build 74 Cement Detail Report • ' i==& 0 2S-12 Con a3.4%1 lips i. Fds,ks String: Conductor Cement Job: DRILLING ORIGINAL, 6/7/2016 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Conductor Cement 12/6/2014 13:47 12/6/2014 18:11 2S-12 Comment Cemented in 2 stages with Dowell. Approx 10 bbls and 61.8 bbls=71.8 bbls.Top of cement 5'below pad level(Bottom of 6'dia x 5'tall cellar box) Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Conductor Cement Cement Conductor 95.6 107.5 Yes 0.0 No No 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) 0 0 0.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cemented 16"conductor w/Dowell Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) AS1 93.1 105.0 61 AS1 10.1 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.'s) Thickening Time(hr) CmprStr 1(psi) 0.93 3.54 15.70 2.75 Additives Additive Type Concentration Conc Unit label D110 Retarder 0.01 gal/sx Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Conductor Cement Cement Conductor 32.5 95.6 Yes 0.0 No No 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) 1 3 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment • Cemented 16"conductor w/Dowell Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) AS1 Cement 93.1 30.0 373 AS1 61.8 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 0.93 3.54 15.70 2.75 Additives Additive Type Concentration Conc Unit label D110 0.01 gal/sx • Page 1/1 Report Printed: 7/19/2016 • Cement Detail Report WVISMS 2S-12 +Conoco hhill ps String:' Surface Casing Cement Job: DRILLING ORIGINAL, 6/7/2016 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 6/10/2016 22:15 6/11/2016 02:45 2S-12 Comment Test lines to 4000 psi. Pump 15 bbls 8.35 ppg CW-100. Pump 75 bbls 10.5 ppg MPII w/red dye at 4.5 bpm. Drop bottom plug. Pumped 400 bbls 11 ppg LiteCRETE lead cement at 6 bpm/150 psi increasing to 490 psi. No indication of shear Reciprocate pipe 10'with full returns.Observe 30k drop in SOW with 350 bbls of lead pumped away-land hanger for remaining portion of job. Pumped 60 bbls 15.8 ppg Class G tail cement at 5 bpm/550 psi.Shut down,drop top plug, and line up to divert all returns to the cellar. Kicked top plug out with 3 bbls of tail cement followed by 10 bbls of H20. Swapped to rig pumps and displaced cement @ 3 bpm w/270 psi increasing to 550 psi pump pressure.3 bpm was max rate that trucks could manage sucking out of the cellar.Observed cement at surface 35 bbls into displacement. Bumped plug©2510 strokes, FCP=550 psi. Pressured up to 1100 psi and held for 5 min then bled off and checked floats- floats held.CIP @ 02:45 am.218 bbls of cement returned to surface. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement Bring cement returns to 29.6 2,846.4 No 218.0 Yes Yes surface Q Pump[nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 550.0 1,100.0 Yes 10.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Test lines to 4000 psi. Pump 15 bbls 8.35 ppg CW-100. Pump 75 bbls 10.5 ppg MPII w/red dye at 4.5 bpm. Drop bottom plug. Pumped 400 bbls 11 ppg LiteCRETE lead cement at 6 bpm/150 psi increasing to 490 psi. No indication of shear Reciprocate pipe 10'with full returns.Observe 30k drop in SOW with 350 bbls of lead pumped away-land hanger for remaining portion of job. Pumped 60 bbls 15.8 ppg Class G tail cement at 5 bpm/550 psi.Shut down,drop top plug, and line up to divert all returns to the cellar. Kicked top plug out with 3 bbls of tail cement followed by 10 bbls of H20.Swapped to rig pumps and displaced cement @ 3 bpm w/270 psi increasing to 550 psi pump pressure.3 bpm was max rate that trucks could manage sucking out of the cellar.Observed cement at surface 35 bbls into displacement. Bumped plug©2510 strokes, FCP=550 psi. Pressured up to 1100 psi and held for 5 min then bled off and checked floats- floats held.CIP @ 02:45 am.218 bbls of cement returned to surface. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 29.6 2,346.4 1,214 LiteCRETE 400.0 Yield(ft5sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.85 6.14 11.00 5.75 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC 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 Cement 2,346.4 2,846.4 288 Class G 60.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.17 5.03 15.80 4.75 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Page 1/1 Report Printed: 7/19/2016 •Drilam Cement Detail Report &Wens 2S-12 sConoceit�hdljps String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 6/7/2016 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 6/20/2016 07:15 6/20/2016 16:00 2S-12 Comment Pump 5 bbls of H2O&PT lines to 900/4000 psi.Pump 40 bbls of 12.5 ppg MPII at 5 bpm,455 psi. Drop bypass plug. Pump 136.9 bbls of 15.8 ppg Class G+ cement at 4.5 bpm,400 psi dropping to 225 psi. Drop top plug. Pump 10 bbls of H2O at 5 bpm,301 psi. Displace with 10.0 ppg LSND mud at 5-7 bpm,200 psi increasing to 1050 psi.Slow to 3 bpm,925 psi prior to bumping plug, PU 206K,SO 106K. Bump plug with 3590 strokes, FCP=980 psi. Pressure up to 1480 psi (500 psi over FCP)for 5 min.Check floats-good.CIP 0930 hrs. Pressure up to open stage collar,observe shift @ 3020 psi. Note-No returns to surface throughout the job Establish circulation through stage collar w/1 bpm,410 psi,50%losses.Stage up to 5 bpm,420 psi and observe full returns.Shut down pumps and observe well breathing back. Resume circulation and stage up to 6.5 bpm,520 psi. SIMOPS PJSM for 2nd stage held. Note:Small amount of MPII returns were observed @-2800 strokes. Pump 44.9 bbls of 12.5 ppg MPII at 5 bpm, 151 psi. Pump 62.8 bbls of 15.8 ppg Class G+cement w/1 lb/bbl CemNet LCM added©3.5 bpm,20 psi. Drop closing plug. Pump 10.4 bbls of H2O at 5 bpm,20 psi. Displace with 10.0 ppg LSND mud at 5 bpm, 125 psi increasing to 660 psi. Decrease rate to 3 bpm, FCP =550 psi prior to bumping plug. Bump plug with 2535 strokes&pressure up to 1800 psi,holding for 5 min. Observed stage collar shift closed @ 1500 psi.CIP 16:00 hrs. Bleed off pressure in 500 psi increments and confirm that stage collar is closed. No losses observed. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing 6,752.0 8,250.0 No Yes Yes 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) 5 5 5 980.0 980.0 Yes 15.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pump 5 bbls of H2O&PT lines to 900/4000 psi. Pump 40 bbls of 12.5 ppg MPII at 5 bpm,455 psi. Drop bypass plug. Pump 136.9 bbls of 15.8 ppg Class G+ cement at 4.5 bpm,400 psi dropping to 225 psi.Drop top plug. Pump 10 bbls of H2O at 5 bpm,301 psi. Displace with 10.0 ppg LSND mud at 5-7 bpm,200 psi increasing to 1050 psi.Slow to 3 bpm,925 psi prior to bumping plug, PU 206K,SO 106K. Bump plug with 3590 strokes, FCP=980 psi. Pressure up to 1480 psi (500 psi over FCP)for 5 min.Check floats-good.CIP 0930 hrs. Pressure up to open stage collar,observe shift @ 3020 psi. Note-No returns to surface throughout the job Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 6,752.0 8,250.0 663 G 136.9 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 5.06 15.80 230.0 4.50 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 Control D146 0.8 %BWOC Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing 5,181.0 5,822.0 No 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) 4 5 5 550.0 550.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pump 44.9 bbls of 12.5 ppg MPII at 5 bpm, 151 psi. Pump 62.8 bbls of 15.8 ppg Class G+cement w/1 lb/bbl CemNet LCM added @ 3.5 bpm,20 psi. Drop closing plug. Pump 10.4 bbls of H2O at 5 bpm,20 psi. Displace with 10.0 ppg LSND mud at 5 bpm, 125 psi increasing to 660 psi. Decrease rate to 3 bpm, FCP =550 psi prior to bumping plug. Bump plug with 2535 strokes&pressure up to 1800 psi,holding for 5 min.Observed stage collar shift closed @ 1500 psi.CIP 16:00 hrs. Bleed off pressure in 500 psi increments and confirm that stage collar is closed.No losses observed. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 5,181.0 5,822.0 302 G 62.8 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.17 5.10 15.80 120.0 4.28 Page 1/2 Report Printed: 7/19/2016 DreSne Cement Detail Report ='4 a Mies 2S-12 ConocoPhitlipss String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 6/7/2016 00:00 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 Control D146 0.8 %BWOC • Page 2/2 Report Printed: 7/19/2016 y or T4 • 1,1 �� //74 s THE STATE, Alaska Oil and Gas , N i t4 oLAS KA Conservation Commission 5 }FI '� 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 0.0-. -NO, Fax: 907.276.7542 www.aogcc.alaska.gov Mick Davasher Completions Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2S-12 Permit to Drill Number: 216-074 Sundry Number: 316-358 Dear Mr. Davasher: 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, l-Rte _ Cathy P Foerster Chair DATED this Ay of July, 2016. RBDMS JUL 2 2 2016 • • RECEIVED STATE OF ALASKA JUL 11 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION brS 1 6::.f 1 ` APPLICATION FOR SUNDRY APPROVALS AOGC C' 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate LI 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 El Development 0 216-074 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-103-20743-00-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2S-12 Will planned perforations require a spacing exception? Yes ❑ No 0 9. Property Designation(Lease Number): 10.Field/Pool(s): ADL 2677, 2681 Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 13,638' 6,263' 4,400 Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 107' 107' Surface 2,860' 10-3/4" 2,843' 2,565' Intermediate 8,210' 7-5/8" 8,239' 6,177' Production Liner 3,805' 4-1/2" 11,878' 6,275' 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 8,100' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): LEM Installation,no SSSV 8,004'MD,6,110'TVD 12.Attachments: Proposal Summary El Wellbore schematic El 13.Well Class after proposed work: Detailed Operations Program El BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 3.1,1411:1-6- 21-S�cy-I6 Commencing Operations: Gpw OIL 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown El Abandoned El 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Mick Davasher @ 907-265-6870 Email mick.j.davasher(cr�cop.com Printed Name Mick Davasher Title: Completions Engineer t 11/ 21b Signature Phone 907-265-6870 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \Lt- 35� Plug Integrity ❑ BOP Test❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No L] Spacing Exception Required? Yes EI No f Subsequent Form Required: /Q ` 40 + RBDMS JUL 2 2 2016 () APPROVED BY ��� Approved by: �_ COMMISSIONER THE COMMISSION Date:7-C .../4 7L �//q7//4—/2016 `I'CU3 ill /f . . c *J 7/t -/2oi Roved 1 "" Submit Form and Form 10-403 Revised 11/2015 application i5 lid for 12 months from the date of approval. Attachments in Duplicate III • 2S-1 2 ConocoPhall• ips Grassroots Horizontal A-Sand Producer IWellbore Schematic(wp10.1 —D141 RKB) 'CAMERON Last Edited: 4-'A"tree,top joint is 4-W 12.6#IBTM Davasher 7/8/16 16"Conductor to-107.5' E.' a i a E 13.5"Surface Hole 3-%"x 1-%"Camco MMG GLM Base West Sak:2,797'MDI 2,519'TVD I Surface Casing 10-3/4"45.5#L-80 Hydril 563 2,845 MD/2,569'TVD(41.6° INC) R 9-7/8"x 11"Intermediate Hole A Tubing', id 3-1/2" 9.3#L-80 EUE 8RD-MOD Z ii GLM w/ —' SOV c *;„mom-- 2n°Stage TOC= 500'MD above C-37 Formation at 5,272'MD Weatherford Stage Collar:5,772'MD C-37:5,772 MD 14,747'TVD '''''<'% SeMd i 1'Stage TOC: Top of Bermuda/Calm formation) Growler-AA:6,051'MD 14,955'TVD Baker2.812"CMU Sliding Caim:6,817 MD 15,487 ND 110E S lit UUUU Sleeve ]]�� SLB DH: ,' �� 3-%"x 7-518",Premier Packer Bermuda:6,951'MDI 5,571'TVD It ' 1 s� c_ 111,.11‘/23'"275"D Nipple ri _— —o. HRZ:7,693'MD/5,967'TVD Kalubik:8,048'MD I6,107'TVD '0 5.75"x 4-'d'Swell Packer Kupa ruk C:8,744'MDI 6,272'TVD I— Kuparuk A4:8,833'MDI 6,282'TVD-11.2 ppg 7-5/8"x 5-'/:"Baker ZXP - Ilet Shoe I d Packer/Flex Lock LinerIt I/ - I a Hanger(8,073'MD/6133' Andw TVD) •••,____�___`_.__.-®-'--.-.-'--'--'-�-- Al2hee aslve � rn Y TD:13,638'MD/6,263'ND Jntermediate Casing Production Liner; 6-3/4" Production Hole 7-5/8"29.7#L-80 Hyd563 Casing 4-1/2"12.6#L-80 HYD563 8,239'MD/6,177'TVD(78° INC) 11,878'MD/6,275'TVD s • 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). • r 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.Wharton@conocophillips.com To: Operator and Owners (shown on Exhibit 2) Re: Notice pursuant to 20 AAC 25.283 (1) 2S-12 Well Kuparuk River Unit, Alaska ADL 25603, KRU Tract 90 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-12 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about July 7, 2016. This Notice is being provided pursuant to 20 AAC 25.283. The Well has been drilled as a directional well on lease ADL 25603, KRU Tract 90: Surface Location: 3081' FNL, 1584' FEL, Section 17, T10N, RO8E, UM Target Location: 3638' FNL, 592' FEL, Section 18, T1 ON, RO8E, UM Bottomhole Location: 2990' FNL, 1798' FEL, Section 19, T10N, 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, eu„Lx Paul Wharton Staff Landman cc: Mick Davasher Rebecca Swensen it 0 • 2S-12 Hydraulic Fracturing Notice Letter Julye 7, 2016 Page 2 Exhibit 1 P :6.1u'IE ._._. ConocoPhillips Alaska, Inc. 2S-12 N Lease Plat l C 015 0-3 045 0.6 25-1311 23-13 25-11 M;les ADL390680 1A0L025590� 25-54 25-07 f Southern / Mihir It ch Kuparuk River �,,,,. `/2 mile radius Unit 1 from Well 1j` 25-01 r 2S-12 . '7 '2S-04P81- ,� -- • 25-131.131 I T1ON R7E ADL380051 ADLO. 603 ADL025EC4 ON R8E .; . 3-304 / ' 7 J, J'i 2s of 2L-301 25-03P31 • 25-08 25-10 • Frac Points :. 35-03 _.. 2S-12 Open Interval 2S-12 Trajectory ADL025608 ADL025607 ®1/2 Mi. Frac Point Radius 1/2 Mi.Trajectory Radius Well Within Trajectory Radius --Kuparuk PA El BRPC Lease r_ QL'PAI Lease _ __�..��.---�___.._________..�...� • • 2S-12 Hydraulic Fracturing Notice Letter Julye 7,2016 Page 3 Exhibit 2 Mineral Owners: Operator: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1220 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Erik Keskula, Manager, NS Development Non-Operators: BP Exploration (Alaska) Inc. P.O. Box 196612 900 E. Benson Boulevard (Zip 99508) Anchorage, AK 99519-6612 Attention: Mr. 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 • TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Paul K.Wharton Request of ConocoPhillips Alaska, Inc. for ) Hydraulic fracturing for the 2S-12 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 July 7,2016, 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 7'h day of July,2016. Paul K.Wharton STATE OF ALASKA ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 71h day of July, 2016, by Paul K.Wharton. STATE OF ALASKA 4Notary Public, State of Alaska NOTARY PUBLIC if REBECCA SWENSEN + nr, C mmi sign EFxXpnires: 7,2 ty my commission Aug.27.2016 • 0 Section 2 — Plat 20 AAC 25.283 (a)(2) Plat 1: 2S-12 Landowners ConocoPhillips Ale2Ka,Inc. 2S-12 N Lease Plat 25.730 23.13 25.11 f A.CL350880 fi r o AD25590 f' k 1� i }'r 12-.a - Southern � 1 Miluveach i r' Unit Kuparuk River rr Unit I; / YEW *W1 yrt _ , t tJ fi 25-12 1 1.. X25 54ps;-_ ..-.,, '`=- ZSl34tai '.7, �\ 4 t `I�1i f 11\ �. TION R7E —+ :_i� \ '' / \I ACL18005I ADLD• ,.3 \ ADL025604 ON R8E ' ‘Y, 1 / 1 , Jil 2d - IFF))f 2�3D7 +�r25-03Ps1 /1 +t 25-08 7 2}-. �r t •Frac Points 1 .. -_ 253 -- -2S-12 Open Interval —2S-12 Trajectory ADL025e08 - L32 ? 0 7 0112 Mi.Frac Point Radius 0112 Mi.Trajectory Radius Well Within Trajectory R adiu s --Ku pa ruk PA ❑BRPC Lease OCPAI Lease :. I -- . • Table 1: Wells within .5 miles _WELL NAME STATUS WELL TYPE 2L-301 ACTIVE INJ 2L-304 ACTIVE PROD 2S-01 ACTIVE PROD 2S-02 ACTIVE PROD 2S-03 ACTIVE PROD 2S-03PB1 PA EXPEND 2S-04 ACTIVE PROD 2S-04PB1 PA EXPEND 2S-07 ACTIVE PROD 2S-08 ACTIVE PROD 2S-10 ACTIVE PROD 2S-11 ACTIVE PROD 2S-13 PROP SVC 2S-13L1 PROP SVC 2S-13PB1 PA EXPEND SECTION 3 — FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. None as per Aquifer Exemption Title 40 CFR 147.102(b)(3), "That portions of the aquifers on the North Slope described by a 1/4 mile area beyond and lying directly below the Kuparuk River Unit oil and gas producing field". ,I • • 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. • 0 SECTION 6 — ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(a)(6) Casing & Cement Assessments: The 10-3/4" casing cement pump report on 6/11/2016 & 6/12/2016 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 11 ppg Lead Deep Crete cement and 15.8 ppg tail cement. Full returns were seen throughout the job. The plug bumped at 1,100 psi and the floats were checked and they held. The 7-5/8" casing cement report on 6/20/2016 shows that the job was pumped without full returns. The first stage was pumped with 15.8 ppg class G cement. Partial returns were seen throughout the job. The plug bumped at 500 psi and the floats were checked and they held. The second stage was pumped with 15.8 ppg class G cement. Partial returns were seen throughout the job. The plug bumped at 1800 psi and the floats were checked and they held. A sonic log was run on the first stage job showing the TOC at 5,840' indicating adequate cement. 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 6/13/2016 the 10 & 3/4" casing was pressure tested to 3500 psi. On 6/23/2016 the 7 & 5/8" casing was pressure tested to 3500 psi. The 7 5/8" casing will be pressure tested to 4000psi prior to frac. AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 4,600 Annulus pressure during frac 3,600 Annulus PRV setpoint during frac 3,700 7 5/8"Annulus pressure test 4,000 3 1/2" Tubing pressure Test 5,000 Nitrogen PRV 7,505 Highest pump trip 7,305 • • 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 a)7 Based/Tattle ' 1 g 0 Tale Tark a) yr UI, 78;1►.a 0.11)81 7.3 L 11aeC1 N \f1414 Et" F2 ra 1111� ca 5mrul dwnd v Pop-Off Tart :3 Pop-0Off 1101 Pum Truck ACV N ca L] J -r Frac Pump h.1 — Frac Pump Frac Pump N iJ— N —f -- - Fr. Pur-ip Frac Pump Frac Pump I • 10K Frac Tree Note. Dimensional iinforniaiion reftEctad co this drawrrng.are estimated ¢ncasurerrie,rtts OfIly.. i 63QT15 Rim _,--i-,.... i F I .,Ii I 4'1002 4"1002 edi 4-1116' 10,000# 4-1/16' 10,O00 ,,: , 4. : 411111, Ilk: : '' 1±1; iIt '4 • .:I. I ' 1 4" 1502 4-1/16' 10,000# Hydraulic 56_94" .. mismoss 4-1/16' 10,000# I nk 4-1/16' 10,000#! ConocoPhillips '°'CAMERON Drill Site 2S-101(Frac rice E=HEr•1 12-30-is At 116204O-C.-2 • • Wellhead with 10K Frac Tree Dirnemional irsidirration Ticc<ieti 5 5 O5 c Hn drawiriii aro( ile-oleo MeaStirementsortiv 111-1111.: 41O02 4"2002 4- /1b.' 1 U,CXXIC ‘..-6 /1-1/16 10.0000 • t 124.08" 10,UOUtt x2" 1507 4-1t1o* 10.000/ ifirAulor 5b94 11111111'" 184.45" 4-1/16' 10.000: AI% - t 4-1/16' 10,o0co 4P4p. 1 ILEL 11731" 1 11" 5.0001 16—: Ill! —2-1/16"5,0001 ti.1111111111 I nig II. s• 11; ?-1116* 5.000# 21.7S' g 111:Q-II I 8 7nt, Top al /.12" L (inductor t to Oho or han9er i PI- 7-116 --.1/41" ConocoPhillips .0 OAL) 4-1/2* eCAMERON Drill Site 2S-Produce- WF 10K'free STEPHEN 12-30-15 1162040-D • 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 125' TVT at the heel, with the top of the Kuparuk A at -6,116' TVDSS (8,595' MD) and 100' TVT at the toe of the well, with the top Kuparuk A at -6,127' TVDSS. The Kuparuk A interval is composed of multiple packages of very fine grained, quartz rich sandstone, separated by laterally continuous shale interbeds. The estimated fracture pressure for the Kuparuk A is 13.1 ppg. The overlying confining zone has an overall thickness of 298' TVT (967' MD) and consists of HRZ and Kalubik mudstones. Top HRZ was encountered at -5,812' TVDSS (7,599' 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 -6,220' TVDSS at the heel (the Miluveach interval was not penetrated in the 2S-12 wellbore). • . SECTION 10 — LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing & Cement assessments for all wells that transect the confining zone: 2S-04: The 7-5/8" casing cement report on 10/18/2015 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 717 psi and the floats were checked and they held. 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 10.0 ppg mud. The plug bumped at 1,400 psi and the floats were checked and they held. 2S-11: The 7-5/8" casing cement pump report on 3/12/2016 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg cement, displaced with 9.9 ppg mud. The plug bumped at 1,215 psi and the floats were checked and they held. 2S-13: The 7-5/8" casing cement pump report on 12/27/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg cement, displaced with 11.8 ppg mud. The plug bumped at 1,200 psi and the floats were checked and they held. • S Z .O .O .D 22.2 0un N N N O y m M N m a S a n m O N 0 la s amm — «(4 — E Q N Q Q QN pw c u v — — �Oeel S Q v Yc u «c c Ycf c f c 2 0 2 E Nt S G _ rO aW d TA m m p m— m « p Z m5LO 0 z p Ill Na NaG I;l;lNa NNa na n2 .- pH « QQS a LI1 li. pC a C m m 0 M m a 'n N '^m y Y N A V U SA U a t7 0 V' d m A m h t7 o 6 6 4 W !� Ln N E Lel em U N u a a a .ma hf U V u '� O U a W .�'i t7 ". co a no a a Z' O O - u a a a OE N t9 'g t7 h a co ao N tri 17t m y 00 co co H O 00 N N 0 0 2 ac ti •in N+ Ln E ^ .-I w N N O '� N H s 8 ti i.i .=i h atn r' ^ to m m co m m til m m CO m r m n m m m to ad Y YIrn 0u 'O a ^aOl0 D O a 01 a 0 a 0 Y0 .. as f Oa 2 2 Y Y Oaf 0 'f 0 ni Ua crzs 72 g 19.:. $N as as aps as m O O 1 a731 a Oon to 00 ^ cci. 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Z N n CV N N N O n N H N ti) 3 N N • 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 6 mapped faults that transect the Kuparuk A interval and enter the confining zone within one half mile radius of the wellbore trajectory for 2S-12. The north-south trending faults east of 2S-08 terminate between the HRZ and C-35 in lithology that consists of silts and shales in this area with an estimated fracture pressure of -16 ppg. Two faults intersect the 2S-12 wellbore. Fault#1 terminates within the confining layer. Fault #2 terminates at the C-35. The C-35 in this area consists of shales and siltstone lithologies with an estimated fracture pressure of—16ppg. Two faults intersect the 2S-08 wellbore. Fault #2 in 2S-08 may correspond to Fault#2 in 2S-12. Faults #1 terminates prior to the C-35. No losses were observed at any of the fault crossings during drilling of the 2S-12 or 2S-08 lateral sections. 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-12 Faults MD SSTVD Throw Fault#1 (A4/A4) 10013 6145 5(DTS) Fault#2 (A4/A4) 11291 6116 10(DTN) 2S-08 Faults MD SSTVD Throw Fault#1(A4/A4) 8612 6158 10(DTS) Fault#2(A4/A4) 10140 6132 10(DTN) The effective fracture length is estimated to be 420'. All of the fractures will be longitudinal, running parallel to the 2S-12 wellbore. If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults will not interfere with containment. *M. 06Jul16 ConocoPhillips p Alaska, Inc. 2S-12 N Fault Analysis 0 0.1 0.2 0.3 0.4 Miles ADL390680 2S-13L1 28-11 7 8 ADL025589 AD Q5590 2S-04 Southern Miluveach Kuparuk River Unit Unit '' 13 18 2S-12 17 16 2S 2S13PB1 2S-04PB1- 2S-13 4/0014./ ADLO-5603 ADL025604 ADL380051 I I 19 I 20 24 I I O Frac Points K. — Faults Within Confining Zone 2Sj08 -- 2S-12 Drilled not Lined — 2S-12 Drilled and Lined ❑ 1/2 Mi. Frac Point Radius ADL025608 1/2 Mi. Trajectory Radius ADL025607 Well Within Frac Point Radius -- Kuparuk PA ❑ BRPC Lease FI CPAI Lease • • SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) 2S-12 was completed in 2016 as horizontal producer in the Kuparuk A sand formation. 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 18 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. 10,000 bbls are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU HES Frac Equipment. 7. PT Surface lines to 9,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 500 bbl breakdown stage (35# linear gel) according to the pump schedule. Bring pumps up to maximum rate of 25 BPM as quick as possible, pressure permitting. Increase annulus pressure to 3,500 psi. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. 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SIeneI 9leneI I O LIe^euZlnieLul O 0 • • Hydraulic Fracturing Fluid Product Component Information Disclosure Fracture Date 2016-07-06 State: Alaska County: Harrison Bay API Number: 5010320743 CONOCO PHILLIPS Operator Name:NORTH SLOPE EBUS Well Name and Number: 25-12 Longitude: -150.15 Latitude: 70.22 Long/Lat Projection: Production Type: True Vertical Depth(TVD): m Total Water Volume(gal)': 398,225 • Hydraulic Fracturing Fluid Composition: Chemical Maximum Abstract Maximum Ingredient Ingredient Ingredient Mass Trade Name Supplier Purpose Ingredients Service Concentration in Additive Concentration in lbs Comments Number(CAS (%by mass)** HF Fluid(%by #) mass)** Sea Water Operator Base Fluid NA NA LOU.00% 63.16329% 3337115 Density=8.380 BE-6 MICROBIOCIDE, CL-22110,CL-31 CROSSLINKER LOSURF-300D, MO-67,OPTIFLO- II DELAYED Additive,Biocide, RELEASE Breaker,Crosslinker, BREAKER Geling Agent OPTFLO-111 Halliburton Microbiocide,Non- NA NA0 NA DELAYED ionic Surfactant pH RELEASE Control Additive, BREAKER SAND- Proppam COMMON WHITE- 100 MESH,SSA-2, 2500 LB SACK, SP BREAKER, WG-36 GELLING AGENT 16/20 CarboLite CarboCeramcs Proppant NA NA 0 NA Silica Flour Halliburton Proppant NA NA0 NA LVT-200 penreco Additive NA NA 0 NA 1,2,4 Trimethylbenzene 95-63-6 1.00% 0.00075% 30 2-Brorno-2-nitro-1,3-propanediol 52-51-7 100.00% 0.00150% 60 Denise Tuck Halliburton,3000 Acrylate polymer Confidential 1.00% 0.00102% 42 N.Sam Houston Pkwy E.,Houston, TX 77032,281- 871-6226 Ammonium persulfate 7727-54-0 100.00% 0.02230% 896 Bentonite,benzyl(hydrogenated tallow alkyl)dimethylammonium 121888-68-4 5.00% 0.01734% 696 stearate complex Borate salts Confidential 60.00% 0.06199% 2468 Ceramic Materials and Wares, 66402-68-4 100.00% 19.95293% 600000 chemicals Crystalline silica,quart 14808-60-7 100.00% 1.07166% 43005 Crystalline Silica,Quartz 14808-60-7 0.10% 0.00035% 14 Cured acrylic resin Confidential 30.00% 0.00669% 269 Ethanol 64-17-5 60.00% 0.04475% 1796 Guar gum 9000-30-0 100.00% 0.34677% 13915 Heavy aromatic petroleum naphtha 64742-94-5 30.00% 0.02238% 896 Hydrotreated Distillate.Light.C5-16 64742-47-8 100.00% 0.17220% 6910 Naphthalene 91-20-3 5.00% 0.00373% 150 Oxyalkylated phenolic resin Confidential 30.00% 0.02983% 1198 Poly(oxy-1,2-ethanediyl),alpha-(4- nonylphenyl)-omega-hydroxy-, 127087-87-0 5.00% 0.00373% 150 branched Potassium formate 590-29-4 60.00% 0.06149% 2468 Potassium hydronde 1310-58-3 5.00% 0.00238% 96 Potassium metaborate 13709-94-9 60.00% 0.02855% 1146 Silica gel 112926-00-8 1.00% 0.00347% 140 Solium carboxymethyl cellulose 9004-32-4 1.00% 0.00102% 42 Sodium chloride 7647-14-5 1.00% 0.00154% 63 Sodiumglycollate 2836-32-0 1.00% 0.00102% 42 Sodium hydroxide 1310.73-2 30.00% 0.01540% 619 Sodium persufate 7775-27-1 100.00% 0.00015% 6 Sodium sulfate 7757-82-6 0.10% 0.00000% 1 Surfactant mixture Confidential 1.00% 0.00694% 280 Water 7732-18-5 100.00% 0.11064% 4441 *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. h2 All component information listed was obtained from the supplier's Material Safety Data Sheets(MSDS).As such,the Operator is not responsible for inaccurate and/or incomplete information.My questions regarding the content of the MSDS should be directed to the supplier who provided it.The Occupational Safety and Health Administration's(OSHA)regulations govern the criteria for the disclosure of this information.Please note that Federal Law protects"proprietary",'trade secret",and"confidential business information"and the criteria for how this information is reported on an MSDS is subject to 29 CFR 1910.1200()and Appendix D. • . 2S- 12 Kuparuk A Sand Multi-stage Frac Model Frac Design Stage -6 Stage a Elapsed Stage F6id Clean Stage Cum Oesn Proppant Slurry Cum Slurry Cum Sl rry.BBL Cean mud Tene.mm:ss Tme.mm;ss VOIGAI VOZ.GAL Cac.PPA Proppant.l8 Rate.B8144 Rate..BBL,M 0:00 24:05 Hylic G_35a_225_81con_.5 25000.00 28000.00 White Frac 100 Mesh 0.25 6250.00 25.00 602.00 24.72 '2405 450 HybaG 35a_225_ncon_.5 5000.00 30000.00 CARBOLITE 16/20 1.00 11250.00 25.00 726.37 23.93 MEI 20503 7.47 HyborG_35i_2252Wmn_.5 7500.00 37500.00 CARBOLIZE 16/20 2.00 26250.00 25.00 920.90 22.95 '3650 6:35 HybarG_35s_22524can_.5 8000.00 45500.00 CARBOLITE 16/20 3.00 50250.01 25.00 1136.92 22.04 MIMI 4529 5:49 H5b906_35a_225 Vlcon_.5 8000.00 53500.00 CARBOLITE 16/20 3.50 78250.00 25.00 1357.19 21.62 5k17 7:52 4yborG_35s 225_Ymn_.5 7000.00 60500.00 CARBOLIZE 16/20 4.00 106250.00 25.00 1553.65 21.21 LO209 6140. HyborG_35*225_hlcan_5 7000.00 67500.01 CARBOLITE 16/20 0.00 106250.00 25.00 1720.32 25.00 Total 1:08:49 67500.01 106250.00 1720.32 Totals (6 stages) 35# Hybor G - 379,829 gal 35# Linear - 9,836 gal 16/20 Carbolite - 600,000 lbs 100 mesh sand - 37,500 lbs • Model Results Stage N o. Stage Size TVD Top TVD Btrn Propped 1 Height(ft) Avg. (Ib) (ft) (ft) Length(ft)E Width (in) 1-6 100,000 6310 6400 420 90 0.17 • Disclaimer Notice: - This model was generated using commercially available modeling software and is based on engineering estimates of reservoir properties. ConocoPhillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results, • • SECTION 13 — POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through 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.) • • MO N t m m m m m m m � m1m 1 3 o0 C. Y Y Y Y �C Y Y Y O 0 Y 0 0 c-i Ea °- a a a a a 0.. U0 I °- U U >- U 00 ca m_ I a, 0 N i O a) a, s v 0 c`o N o u, �O IN▪ 3 0 3 0 CU Q O w, 0 0 0 c-I ^ 0 ,_ o 1, -� .-' 'C Y r' a p 4.4 V M C t0 0 3 .O' a) S M O N 2 N _ p V Z p v ` O co O O N +' C, p O O � s n M I M p M m d ^ N'IC N N j ^4-1 d" C t^A U Q V L �` U Lo .-i Y 3 �" d' I CO `- a) Cuo • 'ao Q `� v ▪ = o a) ti co 4 ▪ • Q N .3 IA= cuaU—+ 3a)+ O E p .- _0! 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D a y Ln L Z °' v) -a a, 3 i s a � 'a vs iv =O o) 3 < L 0 0 Q Z 0CA a 0 — a O L.� , a 0 C. a ',c bA 4Cu O U to cn �:, O asv) a E L) o a. v • • Loepp, Victoria T (DOA) From: Davasher, Mick J <MickJ.Davasher@conocophillips.com> Sent: Monday,July 18, 2016 11:14 AM To: Loepp,Victoria T(DOA) Subject: RE: KRU 2S-12(PTD 216-074) Fracture Stimulation AOR SS Attachments: 2S-12 Frac Stim AOR Spreadsheet.xlsx Follow Up Flag: Follow up Flag Status: Flagged Victoria, Please find attached SS detailing the wells within the fracture stimulation AOR for KRU 2S-12. Regards, Mick Mick Davasher Senior Wells Engineer ConocoPhillips Alaska, Inc. 700 G Street;ATO-1592;Anchorage,AK 99501 907-265-6870(office)907-223-8074(mobile) From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday,July 18, 2016 8:59 AM To: Davasher, Mick J<Mick.J.Davasher@conocophillips.com> Subject: [EXTERNAL)KRU 2S-12(PTD 216-074) Fracture Stimulation AOR SS Mick, Please fill out the attached SS for wells within the fracture stimulation AOR for KRU 2S-12. 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.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepo@alaska.gov 1 • • eSli gn Ln In NN N \ iOa a\ a .-i w 13 op � C op W Ea °' -N CI O u « m c «Z.' c « o f c c o c N a 0vc 3a0 o \ oro ; 7) 8 afi a o vtmo2 V Z a ? a E. a s o « ~ o,. • 13 g u$ N v g $ N$ n S i § ai a mw a aaa0., E f en m t`$ u a, m O y A m 7 au u 0 w O O 1 OD 00 M. 00 N 00nm IV m N — u0 N E A V nE 0. ao � m O �n a � '^ n a� mn n ZNn� O � O ONO a ao W °o m m m o0 00 00 y• N O V ui 03 LA ei r Ili "'i `� 1.D Ili V, l7 '� ao .may •tri .1 N NNin E l0 .-1 N N N - N C -75 ' 0 o ~ N d .cif a A. ti CO m m m m m - M N - m m m in V m A 00 C U@i', N Q �! 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In N in \ Z q 1� N N N N N N N N N a N O O O 0 O z z z z z a 2 a i a a a au a• N 'i N 00 n 0 V d en e `2 .i O O O O O .i O N en a e r W N N N N N N N N CV 3 N N • • Bettis, Patricia K (DOA) From: Davasher, Mick J <Mick.J.Davasher@conocophillips.com> Sent: Wednesday, July 13, 2016 10:50 AM To: Bettis, Patricia K(DOA) Subject: RE: KRU 2S-12 (PTD 216-074): Sundry Application Attachments: 2S-12_fault_analysis_06jul16_v2.pdf Patricia, Please find attached a plat showing all faults within 1/2 mile radius of the KRU 2S-12 wellbore. I believe what was provided in Section 11 covers your question. Let me know if you require more. Regards, Mick Mick Davasher Senior Wells Engineer ConocoPhillips Alaska, Inc. 700 G Street;ATO-1592:Anchorage,AK 99501 907-265-6870(office)907-223-8074(mobile) From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Tuesday,July 12, 2016 11:02 AM To: Davasher, Mick J <Mick.J.Davasher@conocophillips.com> Subject: [EXTERNAL]KRU 2S-12 (PTD 216-074): Sundry Application Good morning Mick, Please provide a plat that shows the all faults within 1/2 mile radius of the KRU 2S-12 wellbore. This plat should include wellbore trajectories of all wells on the 2S-Pad. Please provide a discussion of the distance of the projected fracture wings to the nearest faults that do not intersect KRU 2S-12. 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 1 CONFIDENTIALITY NOTICE:This e-mail Osage, including any attachments,contains in•ation 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. 2 • ! Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Tuesday, July 12, 2016 11:02 AM To: Davasher, Mick J (Mick.J.Davasher@conocophillips.com) Subject: KRU 2S-12 (PTD 216-074): Sundry Application Good morning Mick, Please provide a plat that shows the all faults within 1/2 mile radius of the KRU 2S-12 wellbore. This plat should include wellbore trajectories of all wells on the 2S-Pad. Please provide a discussion of the distance of the projected fracture wings to the nearest faults that do not intersect KRU 2S-12. 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. 1 RECEIVED 21 6074 JULIM 2016 • 2 7 _5n AOGCC SchlumbergerDrilling & Measurements Transmittal#: 18JUL16-SPO1 DATA LOGGED MWD/LWD LogProduct Delivery -1/2.A2oifc ivt. K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2S-12 Date Dispatched: 18-Jul-16 Job#: 16AKA0106 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 6 Contents on CD N/A VISION*Service 2" MD 107' - 13638' x x VISION*Service T TVD 107' -6263.35' x x VISION*Service 2'TVDSS 107' -6263.35' x x VISION*Service 5-MD 107' - 13638' x x VISION*Service 5-TVD 107' -6263.35' x x VISION*Service 5'TVDSS 107' -6263.35' 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(@conocophillips.com AlaskaPTSPrintCenter(aslb.com Tom Osterkamp Attn:Stephanie Pacillo 907-263-4795 /17)/)../d242-0 �/��, j2_ ..Received By: 216074 • 27 3 $ 9 JUL 18 2515 FINAL AOGCC NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-12 2S-12 Definitive Survey Report 05 July, 2016 NAD 27 0 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-12 Project: Kuparuk River Unit TVD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: 25-12 actual @ 147.50usft(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12 Survey Calculation Method: Minimum Curvature Design: 2S-12 Database: OAKE DM P2 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-12 Well Position +N/-S 0.00 usft Northing: 5,929,968.02 usft Latitude: 70°13'11.380 N +El-W 0.00 usft Easting: 480,986.10 usft Longitude: 150°9'12.212 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore 2S-12 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2016 6/20/2016 17.97 80.85 57,536 Design 2S-12 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 11,836.99 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 27.50 0.00 0.00 226.56 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 100.00 975.00 2S-12 Srvy 1-SLB_NSG+BATTERY(2S GYD-GC-SS Gyrodata gyro single shots 6/9/2016 8:37:0 1,013.91 2,787.47 2S-12 Srvy 2-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/8/2016 10:02:C 2,815.78 2,815.78 2S-12 Srvy 3-SLB_INC+Filler(2S-12PB INC+TREND Inclinometer+known azi trend 6/13/2016 9:29: 2,908.52 4,219.12 2S-12 Srvy 4-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/13/2016 9:34: 4,310.16 8,178.05 2S-12 Srvy 5-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/15/2016 9:10: 8,241.66 11,132.17 2S-12 Srvy 6-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/23/2016 1:52: 11,179.20 11,836.99 2S-12PB1 Srvy 7-SLB_MWD+GMAG(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/27/2016 8:40: 11,898.68 13,535.44 2S-12 Srvy 8-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/28/2016 10:37 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) ("/100') (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,929,968.02 480,986.10 0.00 0.00 UNDEFINED 100.00 0.29 190.76 100.00 -47.50 -0.18 -0.03 5,929,967.84 480,986.07 0.40 0.15 GYD-GC-SS(1) 200.00 0.41 190.63 200.00 52.50 -0.78 -0.15 5,929,967.24 480,985.95 0.12 0.64 GYD-GC-SS(1) 300.00 0.45 195.47 299.99 152.49 -1.51 -0.32 5,929,966.51 480,985.78 0.05 1.27 GYD-GC-SS(1) 400.00 1.00 335.77 399.99 252.49 -1.09 -0.78 5,929,966.93 480,985.32 1.38 1.32 GYD-GC-SS(1) 500.00 2.69 342.00 499.94 352.44 1.93 -1.86 5,929,969.96 480,984.24 1.70 0.02 GYD-GC-SS(1) 600.00 2.85 339.41 599.82 452.32 6.49 -3.46 5,929,974.52 480,982.65 0.20 -1.95 GYD-GC-SS(1) 700.00 5.59 337.49 699.54 552.04 13.32 -6.20 5,929,981.36 480,979.93 2.74 -4.66 GYD-GC-SS(1) 7/5/2016 12:02:56PM Page 2 COMPASS 5000.1 Build 74 , • • Sc hi urn berger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-12 Project: Kuparuk River Unit TVD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12 Survey Calculation Method: Minimum Curvature Design: 2S-12 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 800.00 6.31 336.02 799.00 651.50 22.84 -10.30 5,929,990.89 480,975.86 0.74 -8.23 GYD-GC-SS(1) 900.00 8.69 329.19 898.14 750.64 34.35 -16.41 5,930,002.41 480,969.78 2.54 -11.71 GYD-GC-SS(1) 975.00 10.53 326.13 972.08 824.58 44.91 -23.13 5,930,012.98 480,963.09 2.55 -14.09 GYD-GC-SS(1) 1,013.91 11.75 326.29 1,010.26 862.76 51.16 -27.31 5,930,019.24 480,958.92 3.14 -15.35 MWD+IFR-AK-CAZ-SC(2) 1,107.62 13.67 325.67 1,101.67 954.17 68.24 -38.85 5,930,036.35 480,947.43 2.05 -18.72 MWD+IFR-AK-CAZ-SC(2) 1,200.42 16.08 324.50 1,191.35 1,043.85 87.76 -52.50 5,930,055.91 480,933.83 2.62 -22.23 MWD+IFR-AK-CAZ-SC(2) 1,292.50 19.08 320.32 1,279.13 1,131.63 109.73 -69.52 5,930,077.92 480,916.87 3.53 -24.98 MWD+IFR-AK-CAZ-SC(2) 1,386.06 19.77 318.96 1,367.36 1,219.86 133.44 -89.67 5,930,101.67 480,896.77 0.88 -26.65 MWD+IFR-AK-CAZ-SC(2) 1,479.50 20.24 316.88 1,455.16 1,307.66 157.15 -111.09 5,930,125.44 480,875.41 0.91 -27.40 MWD+IFR-AK-CAZ-SC(2) 1,572.66 24.30 307.63 1,541.38 1,393.88 180.64 -137.31 5,930,148.98 480,849.26 5.75 -24.51 MWD+IFR-AK-CAZ-SC(2) 1,665.16 27.66 303.44 1,624.53 1,477.03 204.10 -170.31 5,930,172.53 480,816.32 4.14 -16.68 MWD+IFR-AK-CAZ-SC(2) 1,756.86 29.76 300.84 1,704.95 1,557.45 227.50 -207.62 5,930,196.02 480,779.08 2.66 -5.69 MWD+IFR-AK-CAZ-SC(2) 1,849.84 32.90 296.17 1,784.38 1,636.88 250.47 -250.11 5,930,219.10 480,736.64 4.27 9.37 MWD+IFR-AK-CAZ-SC(2) 1,943.50 35.44 294.84 1,861.87 1,714.37 273.10 -297.59 5,930,241.85 480,689.23 2.83 28.28 MWD+IFR-AK-CAZ-SC(2) 2,037.33 37.15 294.42 1,937.49 1,789.99 296.25 -348.08 5,930,265.11 480,638.80 1.84 49.03 MWD+IFR-AK-CAZ-SC(2) 2,130.01 38.06 294.03 2,010.91 1,863.41 319.45 -399.66 5,930,288.44 480,587.29 1.01 70.52 MWD+IFR-AK-CAZ-SC(2) 2,222.77 38.76 292.95 2,083.60 1,936.10 342.42 -452.51 5,930,311.54 480,534.50 1.05 93.10 MWD+IFR-AK-CAZ-SC(2) 2,314.68 39.96 293.82 2,154.66 2,007.16 365.56 -506.01 5,930,334.81 480,481.07 1.44 116.03 MWD+IFR-AK-CAZ-SC(2) 2,409.01 41.18 294.41 2,226.31 2,078.81 390.62 -562.00 5,930,360.02 480,425.14 1.36 139.45 MWD+IFR-AK-CAZ-SC(2) 2,502.49 40.81 294.01 2,296.87 2,149.37 415.77 -617.93 5,930,385.31 480,369.28 0.49 162.77 MWD+IFR-AK-CAZ-SC(2) 2,596.33 40.61 293.99 2,368.00 2,220.50 440.67 -673.84 5,930,410.34 480,313.44 0.21 186.25 MWD+IFR-AK-CAZ-SC(2) 2,688.67 40.56 293.51 2,438.13 2,290.63 464.86 -728.83 5,930,434.67 480,258.52 0.34 209.53 MWD+IFR-AK-CAZ-SC(2) 2,787.47 40.93 290.93 2,512.99 2,365.49 489.24 -788.51 5,930,459.19 480,198.90 1.74 236.11 MWD+IFR-AK-CAZ-SC(2) 2,815.78 41.16 291.00 2,534.34 2,386.84 495.89 -805.87 5,930,465.89 480,181.56 0.83 244.14 INC+TREND(3) 2,845.00 41.18 291.36 2,556.33 2,408.83 502.84 -823.81 5,930,472.88 480,163.64 0.82 252.38 n NOT an Actual Survey 10 3/4"x 13 1/2" 2,908.52 41.23 292.15 2,604.12 2,456.62 518.35 -862.67 5,930,488.49 480,124.82 0.82 269.93 MWD+IFR-AK-CAZ-SC(4) 3,003.43 41.26 291.42 2,675.49 2,527.99 541.57 -920.78 5,930,511.85 480,066.78 0.51 296.15 MWD+IFR-AK-CAZ-SC(4) 3,093.72 41.20 290.99 2,743.39 2,595.89 563.10 -976.25 5,930,533.52 480,011.36 0.32 321.64 MWD+IFR-AK-CAZ-SC(4) 3,189.59 41.13 290.66 2,815.56 2,668.06 585.53 -1,035.24 5,930,556.10 479,952.44 0.24 349.03 MWD+IFR-AK-CAZ-SC(4) 3,281.31 41.07 290.18 2,884.68 2,737.18 606.57 -1,091.74 5,930,577.27 479,896.00 0.35 375.60 MWD+IFR-AK-CAZ-SC(4) 3,377.84 41.03 290.47 2,957.48 2,809.98 628.59 -1,151.19 5,930,599.44 479,836.61 0.20 403.62 MWD+IFR-AK-CAZ-SC(4) 3,472.80 41.11 291.43 3,029.07 2,881.57 650.89 -1,209.45 5,930,621.89 479,778.42 0.67 430.58 MWD+IFR-AK-CAZ-SC(4) 3,566.08 41.08 291.66 3,099.37 2,951.87 673.41 -1,266.48 5,930,644.55 479,721.45 0.17 456.50 MWD+IFR-AK-CAZ-SC(4) 3,659.12 41.06 290.95 3,169.51 3,022.01 695.62 -1,323.43 5,930,666.90 479,664.56 0.50 482.58 MWD+IFR-AK-CAZ-SC(4) 3,751.52 41.08 291.22 3,239.17 3,091.67 717.46 -1,380.07 5,930,688.88 479,607.98 0.19 508.69 MWD+IFR-AK-CAZ-SC(4) 3,844.94 41.07 291.35 3,309.60 3,162.10 739.74 -1,437.26 5,930,711.30 479,550.85 0.09 534.90 MWD+IFR-AK-CAZ-SC(4) 3,935.36 41.02 291.91 3,377.79 3,230.29 761.62 -1,492.45 5,930,733.33 479,495.72 0.41 559.92 MWD+IFR-AK-CAZ-SC(4) 4,029.68 41.15 293.45 3,448.88 3,301.38 785.52 -1,549.64 5,930,757.37 479,438.60 1.08 585.01 MWD+IFR-AK-CAZ-SC(4) 4,122.40 41.05 295.09 3,518.76 3,371.26 810.57 -1,605.20 5,930,782.55 479,383.10 1.17 608.12 MWD+IFR-AK-CAZ-SC(4) 7/5/2016 12:02:56PM Page 3 COMPASS 5000.1 Build 74 • Schlurnber 9er • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-12 Project: Kuparuk River Unit TVD Reference: 25-12 actual @ 147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12 Survey Calculation Method: Minimum Curvature Design: 2S-12 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) (°1100') (ft) Survey Tool Name 4,219.12 41.14 296.02 3,591.65 3,444.15 838.00 -1,662.56 5,930,810.12 479,325.83 0.64 630.91 MWD+IFR-AK-CAZ-SC(4) 4,310.16 41.13 296.51 3,660.22 3,512.72 864.50 -1,716.26 5,930,836.76 479,272.19 0.35 651.68 MWD+IFR-AK-CAZ-SC(5) 4,403.88 41.23 296.66 3,730.75 3,583.25 892.12 -1,771.45 5,930,864.51 479,217.08 0.15 672.76 MWD+IFR-AK-CAZ-SC(5) 4,496.23 41.10 297.00 3,800.28 3,652.78 919.55 -1,825.69 5,930,892.08 479,162.91 0.28 693.28 MWD+IFR-AK-CAZ-SC(5) 4,590.24 41.16 296.38 3,871.09 3,723.59 947.33 -1,880.94 5,930,919.99 479,107.74 0.44 714.29 MWD+IFR-AK-CAZ-SC(5) 4,684.70 41.05 294.14 3,942.27 3,794.77 973.83 -1,937.09 5,930,946.63 479,051.66 1.56 736.85 MWD+IFR-AK-CAZ-SC(5) 4,777.22 41.15 291.95 4,011.99 3,864.49 997.63 -1,993.05 5,930,970.57 478,995.77 1.56 761.11 MWD+IFR-AK-CAZ-SC(5) 4,870.35 41.16 291.07 4,082.11 3,934.61 1,020.10 -2,050.07 5,930,993.18 478,938.81 0.62 787.06 MWD+IFR-AK-CAZ-SC(5) 4,963.26 40.95 289.29 4,152.18 4,004.68 1,041.15 -2,107.34 5,931,014.37 478,881.60 1.28 814.16 MWD+IFR-AK-CAZ-SC(5) 5,057.57 41.04 289.86 4,223.36 4,075.86 1,061.88 -2,165.63 5,931,035.25 478,823.37 0.41 842.23 MWD+IFR-AK-CAZ-SC(5) 5,149.75 41.11 289.10 4,292.85 4,145.35 1,082.08 -2,222.73 5,931,055.59 478,766.32 0.55 869.80 MWD+IFR-AK-CAZ-SC(5) 5,242.58 41.69 287.83 4,362.48 4,214.98 1,101.52 -2,280.96 5,931,075.17 478,708.15 1.10 898.71 MWD+IFR-AK-CAZ-SC(5) 5,336.87 41.74 286.36 4,432.87 4,285.37 1,119.96 -2,340.93 5,931,093.76 478,648.24 1.04 929.57 MWD+IFR-AK-CAZ-SC(5) 5,430.89 39.77 283.85 4,504.09 4,356.59 1,135.98 -2,400.16 5,931,109.92 478,589.04 2.73 961.57 MWD+IFR-AK-CAZ-SC(5) 5,524.43 39.54 279.92 4,576.12 4,428.62 1,148.27 -2,458.55 5,931,122.36 478,530.69 2.69 995.51 MWD+IFR-AK-CAZ-SC(5) 5,616.10 40.41 275.08 4,646.38 4,498.88 1,155.93 -2,516.91 5,931,130.17 478,472.36 3.52 1,032.61 MWD+IFR-AK-CAZ-SC(5) 5,711.57 41.16 271.40 4,718.68 4,571.18 1,159.44 -2,579.15 5,931,133.83 478,410.14 2.64 1,075.39 MWD+IFR-AK-CAZ-SC(5) 5,801.70 41.65 268.75 4,786.29 4,638.79 1,159.51 -2,638.75 5,931,134.06 478,350.55 2.02 1,118.62 MWD+IFR-AK-CAZ-SC(5) 5,897.45 42.64 266.18 4,857.29 4,709.79 1,156.65 -2,702.92 5,931,131.36 478,286.37 2.08 1,167.17 MWD+IFR-AK-CAZ-SC(5) 5,987.96 43.46 263.66 4,923.43 4,775.93 1,151.17 -2,764.45 5,931,126.04 478,224.83 2.11 1,215.62 MWD+IFR-AK-CAZ-SC(5) 6,081.91 44.83 260.75 4,990.85 4,843.35 1,142.28 -2,829.26 5,931,117.31 478,160.01 2.60 1,268.79 MWD+IFR-AK-CAZ-SC(5) 6,175.61 45.61 258.17 5,056.86 4,909.36 1,130.11 -2,894.64 5,931,105.30 478,094.61 2.12 1,324.63 MWD+IFR-AK-CAZ-SC(5) 6,270.28 45.50 255.51 5,123.16 4,975.66 1,114.72 -2,960.44 5,931,090.09 478,028.78 2.01 1,382.98 MWD+IFR-AK-CAZ-SC(5) 6,362.71 44.98 251.45 5,188.25 5,040.75 1,096.08 -3,023.33 5,931,071.60 477,965.84 3.17 1,441.47 MWD+IFR-AK-CAZ-SC(5) 6,456.17 44.56 248.02 5,254.61 5,107.11 1,073.29 -3,085.06 5,931,048.98 477,904.06 2.62 1,501.96 MWD+IFR-AK-CAZ-SC(5) 6,548.26 44.41 244.38 5,320.32 5,172.82 1,047.27 -3,144.09 5,931,023.10 477,844.97 2.77 1,562.71 MWD+IFR-AK-CAZ-SC(5) 6,642.77 44.99 241.13 5,387.51 5,240.01 1,016.83 -3,203.17 5,930,992.82 477,785.82 2.50 1,626.54 MWD+IFR-AK-CAZ-SC(5) 6,735.94 45.10 238.50 5,453.35 5,305.85 983.69 -3,260.15 5,930,959.82 477,728.76 2.00 1,690.70 MWD+IFR-AK-CAZ-SC(5) 6,828.03 46.36 236.47 5,517.63 5,370.13 948.23 -3,315.74 5,930,924.51 477,673.09 2.09 1,755.44 MWD+IFR-AK-CAZ-SC(5) 6,919.42 47.82 235.25 5,579.85 5,432.35 910.66 -3,371.14 5,930,887.08 477,617.60 1.87 1,821.50 MWD+IFR-AK-CAZ-SC(5) 7,014.41 49.44 232.79 5,642.64 5,495.14 868.78 -3,428.80 5,930,845.34 477,559.84 2.59 1,892.17 MWD+IFR-AK-CAZ-SC(5) 7,107.32 51.63 229.74 5,701.70 5,554.20 823.88 -3,484.72 5,930,800.60 477,503.82 3.46 1,963.64 MWD+IFR-AK-CAZ-SC(5) 7,199.97 54.26 226.16 5,757.53 5,610.03 774.35 -3,539.58 5,930,751.20 477,448.84 4.19 2,037.53 MWD+IFR-AK-CAZ-SC(5) 7,291.54 56.22 223.31 5,809.74 5,662.24 720.90 -3,592.50 5,930,697.90 477,395.79 3.33 2,112.70 MWD+IFR-AK-CAZ-SC(5) 7,385.34 59.21 219.58 5,859.85 5,712.35 661.46 -3,644.93 5,930,638.59 477,343.21 4.63 2,191.65 MWD+IFR-AK-CAZ-SC(5) 7,478.18 61.89 216.43 5,905.50 5,758.00 597.76 -3,694.67 5,930,575.02 477,293.31 4.13 2,271.57 MWD+IFR-AK-CAZ-SC(5) 7,572.51 64.12 213.35 5,948.33 5,800.83 528.81 -3,742.72 5,930,506.21 477,245.10 3.75 2,353.86 MWD+IFR-AK-CAZ-SC(5) 7,664.72 66.51 211.43 5,986.84 5,839.34 458.07 -3,787.59 5,930,435.58 477,200.06 3.21 2,435.08 MWD+IFR-AK-CAZ-SC(5) 7,759.36 68.37 210.47 6,023.14 5,875.64 383.12 -3,832.53 5,930,360.75 477,154.93 2.18 2,519.25 MWD+IFR-AK-CAZ-SC(5) 7,851.53 69.77 209.79 6,056.07 5,908.57 308.66 -3,875.74 5,930,286.41 477,111.54 1.67 2,601.82 MWD+IFR-AK-CAZ-SC(5) 7/5/2016 12:02:56PM Page 4 COMPASS 5000.1 Build 74 0 III Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-12 Project: Kuparuk River Unit TVD Reference: 2S-12 actual©147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12 Survey Calculation Method: Minimum Curvature Design: 2S-12 Database: OAKE DM P2 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 7,941.56 71.17 208.49 6,086.17 5,938.67 234.55 -3,917.05 5,930,212.41 477,070,05 2.07 2,682.77 MWD+IFR-AK-CAZ-SC(5) 8,035.83 71.70 207.14 6,116.18 5,968.68 155.51 -3,958.74 5,930,133.49 477,028.15 1.47 2,767.40 MWD+1FR-AK-CAZ-SC(5) 8,130.07 72.38 206.98 6,145.24 5,997.74 75.68 -3,999.53 5,930,053.77 476,987.17 0.74 2,851.90 MWD+IFR-AK-CAZ-SC(5) 8,178.05 73.11 207.03 6,159.47 6,011.97 34.86 -4,020.33 5,930,013.00 476,966.27 1.52 2,895.08 MWD+IFR-AK-CAZ-SC(5) 8,239.00 73.17 207.89 6,177.15 6,029.65 -16.90 -4,047.23 5,929,961.32 476,939.24 1.36 2,950.20 NOT an Actual Survey 7-5/8"x 9-7/8-11" 8,241.66 73.17 207.93 6,177.92 6,030.42 -19.15 -4,048.42 5,929,959.07 476,938.05 1.36 2,952.61 MWD+IFR-AK-CAZ-SC(6) 8,295.57 74.04 207.29 6,193.14 6,045.64 -64.98 -4,072.39 5,929,913.31 476,913.96 1.98 3,001.53 MWD+IFR-AK-CAZ-SC(6) 8,389.70 75.24 207.40 6,218.07 6,070.57 -145.60 -4,114.08 5,929,832.80 476,872.07 1.28 3,087.24 MWD+IFR-AK-CAZ-SC(6) 8,483.50 77.12 206.58 6,240.48 6,092.98 -226.76 -4,155.42 5,929,751.75 476,830.54 2.18 3,173.06 MWD+IFR-AK-CAZ-SC(6) 8,579.36 78.59 204.50 6,260.65 6,113.15 -311.32 -4,195.81 5,929,667.31 476,789.93 2.62 3,260.53 MWD+IFR-AK-CAZ-SC(6) 8,674.42 81.25 202.65 6,277.28 6,129.78 -397.09 -4,233.23 5,929,581.64 476,752.30 3.39 3,346.68 MWD+IFR-AK-CAZ-SC(6) 8,709.96 83.20 202.53 6,282.09 6,134.59 -429.60 -4,246.76 5,929,549.16 476,738.69 5.50 3,378.85 MWD+1FR-AK-CAZ-SC(6) 8,769.41 86.34 201.25 6,287.51 6,140.01 -484.52 -4,268.83 5,929,494.30 476,716.49 5.70 3,432.64 MWD+1FR-AK-CAZ-SC(6) 8,865.18 90.31 199.67 6,290.31 6,142.81 -574.19 -4,302.28 5,929,404.72 476,682.81 4.46 3,518.59 MWD+IFR-AK-CAZ-SC(6) 8,959.33 91.21 197.63 6,289.06 6,141.56 -663.39 -4,332.38 5,929,315.62 476,652.49 2.37 3,601.78 MWD+IFR-AK-CAZ-SC(6) 9,053.67 90.90 197.27 6,287.32 6,139.82 -753.37 -4,360.67 5,929,225.71 476,623.98 0.50 3,684.19 MWD+IFR-AK-CAZ-SC(6) 9,147.99 89.80 195.50 6,286.75 6,139.25 -843.85 -4,387.27 5,929,135.31 476,597.15 2.21 3,765.72 MWD+IFR-AK-CAZ-SC(6) 9,242.15 90.04 196.35 6,286.88 6,139.38 -934.40 -4,413.11 5,929,044.84 476,571.09 0.94 3,846.74 MWD+1FR-AK-CAZ-SC(6) 9,336.56 89.63 191.88 6,287.15 6,139.65 -1,025.93 -4,436.13 5,928,953.37 476,547.84 4.75 3,926.40 MWD+IFR-AK-CAZ-SC(6) 9,430.98 89.56 190.13 6,287.82 6,140.32 -1,118.61 -4,454.15 5,928,860.74 476,529.59 1.85 4,003.21 MWD+IFR-AK-CAZ-SC(6) 9,524.48 89.60 190.07 6,288.50 6,141.00 -1,210.66 -4,470.55 5,928,768.75 476,512.96 0.08 4,078.41 MW0+IFR-AK-CAZ-SC(6) 9,619.64 89.56 190.91 6,289.20 6,141.70 -1,304.23 -4,487.87 5,928,675.23 476,495.40 0.88 4,155.33 MWD+IFR-AK-CAZ-SC(6) 9,713.52 89.60 191.82 6,289.89 6,142.39 -1,396.26 -4,506.37 5,928,583.25 476,476.68 0.97 4,232.04 MWD+IFR-AK-CAZ-SC(6) 9,812.63 89.43 195.05 6,290.73 6,143.23 -1,492.64 -4,529.39 5,928,486.94 476,453.41 3.26 4,315.03 MWD+IFR-AK-CAZ-SC(6) 9,902.41 89.49 194.81 6,291.57 6,144.07 -1,579.39 -4,552.52 5,928,400.26 476,430.07 0.28 4,391.48 MWD+IFR-AK-CAZ-SC(6) 9,996.87 89.49 194.17 6,292.42 6,144.92 -1,670.84 -4,576.16 5,928,308.88 476,406.20 0.68 4,471.52 MWD+IFR-AK-CAZ-SC(6) 10,091.64 89.49 194.22 6,293.26 6,145.76 -1,762.71 -4,599.40 5,928,217.07 476,382.74 0.05 4,551.57 MWD+IFR-AK-CAZ-SC(6) 10,187.06 89.56 193.29 6,294.05 6,146.55 -1,855.39 -4,622.08 5,928,124.46 476,359.82 0.98 4,631.77 MWD+IFR-AK-CAZ-SC(6) 10,282.04 91.01 192.95 6,293.58 6,146.08 -1,947.89 -4,643.64 5,928,032.03 476,338.03 1.57 4,711.02 MW0+IFR-AK-CAZ-SC(6) 10,376.98 90.97 192.27 6,291.94 6,144.44 -2,040.52 -4,664.37 5,927,939.46 476,317,07 0,72 4,789.77 MWD+IFR-AK-CAZ-SC(6) 10,470.97 91.28 192.53 6,290.09 6,142.59 -2,132.30 -4,684.54 5,927,847.74 476,296.67 0.43 4,867.53 MWD+1FR-AK-CAZ-SC(6) 10,565.39 92.13 192.20 6,287.28 6,139.78 -2,224.49 -4,704.75 5,927,755,61 476,276.23 0.97 4,945.59 MWD+1FR-AK-CAZ-SC(6) 10,660.00 92.41 192.68 6,283.53 6,136.03 -2,316.81 -4,725.12 5,927,663.35 476,255.63 0.59 5,023.86 MWD+IFR-AK-CAZ-SC(6) 10,756.09 92.55 192.35 6,279.38 6,131.88 -2,410.53 -4,745.92 5,927,569.70 476,234.59 0.37 5,103.40 MWD+IFR-AK-CAZ-SC(6) 10,849.95 92.38 194.56 6,275.34 6,127.84 -2,501.72 -4,767.74 5,927,478.57 476,212.55 2.36 5,181.95 MWD+IFR-AK-CAZ-SC(6) 10,943.62 90.68 195.88 6,272.84 6,125.34 -2,592.07 -4,792.32 5,927,388.29 476,187.74 2.30 5,261.92 MWD+IFR-AK-CAZ-SC(6) 11,039.03 91.11 194.41 6,271.35 6,123.85 -2,684.15 -4,817.24 5,927,296.28 476,162.59 1.61 5,343.34 MWD+IFR-AK-CAZ-SC(6) 11,132.17 91.86 194.02 6,268.93 6,121.43 -2,774.41 -4,840.11 5,927,206.09 476,139.50 0.91 5,422.00 MWD+IFR-AK-CAZ-SC(6) 11,179.20 92.00 191.04 6,267.35 6,119.85 -2,820.28 -4,850.30 5,927,160.24 476,129.19 6.34 5,460.95 MWD+IFR-AK-CAZ-SC(7) 7/52016 12:02:56PM Page 5 COMPASS 5000.1 Build 74 • • Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-12 Project: Kuparuk River Unit TVD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12 Survey Calculation Method: Minimum Curvature Design: 2S-12 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-5 +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,272.58 92.03 191.92 6,264.07 6,116.57 -2.911.74 -4,868.88 5.927,068.85 476.110.39 0.94 5,537.32 MWD+IFR-AK-CAZ-SC(7) 11,364.13 92.57 192.45 6,260.39 6,112.89 -3,001.15 -4,888.19 5,926,979.49 476,090.86 0.83 5,612.82 MWD+IFR-AK-CAZ-SC(7) 11,460.58 90.62 195.42 6,257.71 6,110.21 -3,094.71 -4,911.40 5,926,886.00 476,067.41 3.68 5,694.01 MWD+IFR-AK-CAZ-SC(7) 11,553.43 87.96 196.50 6,258.86 6,111.36 -3,183.97 -4,936.93 5,926,796.82 476,041.66 3.09 5,773.92 MWD+IFR-AK-CAZ-SC(7) 11,647.75 87.91 199.17 6,262.26 6,114.76 -3,273.69 -4,965.79 5,926,707.18 476,012.57 2.83 5,856.57 MWD+IFR-AK-CAZ-SC(7) 11,741.48 85.37 198.23 6,267.75 6,120.25 -3,362.31 -4,995.79 5,926,618.64 475,982.35 2.89 5,939.29 MWD+IFR-AK-CAZ-SC(7) 11,836.99 87.10 198.18 6,274.02 6,126.52 -3,452.84 -5,025.56 5,926,528.19 475,952.35 1.81 6,023.16 Tie-in to 2S-12PB J 11,898.68 89.87 196.47 6,275.65 6,128.15 -3,511.70 -5,043.93 5,926,469.38 475,933.85 5.28 6,076.96 MWD+IFR-AK-CAZ-SC(8) 11,931.51 87.99 196.28 6,276.27 6,128.77 -3,543.19 -5,053.18 5,926,437.92 475,924.51 5.76 6,105.34 MWD+IFR-AK-CAZ-SC(8) 12,025.86 85.83 197.14 6,281.35 6,133.85 -3,633.42 -5,080.27 5,926,347.77 475,897.20 2.46 6,187.05 MWD+IFR-AK-CAZ-SC(8) 12,120.35 85.47 197.88 6,288.52 6,141.02 -3,723.27 -5,108.61 5,926,258.00 475,868.63 0.87 6,269.41 MWD+IFR-AK-CAZ-SC(8) 12,215.50 85.33 196.49 6,296.15 6,148.65 -3,813.88 -5,136.63 5,926,167.47 475,840.39 1.46 6,352.06 MWD+IFR-AK-CAZ-SC(8) 12,308.99 84.58 195.73 6,304.37 6,156.87 -3,903.35 -5,162.48 5,926,078.08 475,814.32 1.14 6,432.34 MWD+IFR-AK-CAZ-SC(8) 12,403.69 82.05 196.54 6,315.39 6,167.89 -3,993.69 -5,188.61 5,925,987.81 475,787.96 2.80 6,513.44 MWD+IFR-AK-CAZ-SC(8) 12,498.18 83.04 196.01 6,327.65 6,180.15 -4,083.63 -5,214.87 5,925,897.95 475,761.48 1.19 6,594.35 MWD+IFR-AK-CAZ-SC(8) 12,592.66 86.21 196.35 6,336.50 6,189.00 -4,173.96 -5,241.07 5,925,807.69 475,735.05 3.37 6,675.49 MWD+IFR-AK-CAZ-SC(8) 12,688.08 91.33 191.73 6,338.55 6,191.05 -4,266.45 -5,264.20 5,925,715.27 475,711.69 7.23 6,755.88 MWD+IFR-AK-CAZ-SC(8) 12,782.79 94.13 189.53 6,334.04 6,186.54 -4,359.41 -5,281.65 5,925,622.36 475,694.01 3.76 6,832.47 MWD+IFR-AK-CAZ-SC(8), 12,876.25 95.73 190.58 6,326.01 6,178.51 -4,451.09 -5,297.91 5,925,530.73 475,677.53 2.05 6,907.32 MWD+IFR-AK-CAZ-SC(8) 12,968.89 94.94 192.57 6,317.40 6,169.90 -4,541.45 -5,316.41 5,925,440.43 475,658.79 2.30 6,982.89 MWD+IFR-AK-CAZ-SC(8) 13,064.39 94.92 193.45 6,309.19 6,161.69 -4,634.15 -5,337.83 5,925,347.79 475,637.14 0.92 7,062.18 MWD+IFR-AK-CAZ-SC(8) 13,159.17 93.52 193.71 6,302.21 6,154.71 -4,726.03 -5,360.03 5,925,255.98 475,614.72 1.50 7,141.47 MWD+IFR-AK-CAZ-SC(8) 13,254.15 93.95 194.98 6,296.03 6,148.53 -4,817.85 -5,383.51 5,925,164.22 475,591.01 1.41 7,221.66 MWD+IFR-AK-CAZ-SC(8) 13,349.60 95.22 193.48 6,288.40 6,140.90 -4,910.07 -5,406.90 5,925,072.07 475,567.39 2.06 7,302.05 MWD+IFR-AK-CAZ-SC(8) 13,440.01 93.61 194.10 6,281.44 6,133.94 -4,997.61 -5,428.38 5,924,984.59 475,545.69 1.91 7,377.85 MWD+IFR-AK-CAZ-SC(8) 13,535.44 95.76 194.90 6,273.64 6,126.14 -5,089.69 -5,452.19 5,924,892.59 475,521.65 2.40 7,458.45 MWD+IFR-AK-CAZ-SC(8) 13,638.00 95.76 194.90 6,263.35 6,115.85 -5,188.30 -5,478.43 5,924,794.05 475,495.16 0.00 7,545.31 PROJECTED to TD 7/5/2016 12:02:56PM 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: O Surface Coordinates D Declination & Convergence [J GRS Survey Corrections D Survey Tool Codes Digitally signed by-Vincent(Nara ra Vincent Os a ra o:Sch=Vmerger,cent u= a=Schlumberger,ou=Schlumberger. email=vvsaraiesb corn c=lS SLB DE: Date:2016.07.0512:13:07-08'00' Daniel Bearden .�v,es.«" " }��n YHOwflw;a:Mplsyw UJ Piro Client Representative: ""V1.001143416M Date: 05-Jul-2016 216074 • • '1' 3 8 9 RECEIVED JUL 18 MS FINAL AOGCC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad 2S-12 2S-12 Definitive Survey Report 05 July, 2016 NAD 83 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-12 Project: Kuparuk River Unit TVD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12 Survey Calculation Method: Minimum Curvature Design: 2S-12 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-12 Well Position +NI-S 0.00 usft Northing: 5,929,717.61 usft Latitude: 70°13'10.259 N +E/-W 0.00 usft Easting: 1,621,019.42 usft Longitude: 150°9'23.362 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore 2S-12 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2016 6/20/2016 17.97 80.85 57,536 Design 2S-12 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 11,836.99 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 27.50 0.00 0.00 226.56 Survey Program Date 7/5/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 100.00 975.00 2S-12 Srvy 1-SLB_NSG+BATTERY(2S GYD-GC-SS Gyrodata gyro single shots 6/9/2016 8:37:5 1,013.91 2,787.47 2S-12 Srvy 2-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/8/2016 10:02:: 2,815.78 2,815.78 2S-12 Srvy 3-SLB_INC+Filler(2S-12PB INC+TREND Inclinometer+known azi trend 6/13/2016 9:29: 2,908.52 4,219.12 2S-12 Srvy 4-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/13/2016 9:34:. 4,310.16 8,178.05 2S-12 Srvy 5-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/15/2016 9:10: 8,241.66 11,132.17 2S-12 Srvy 6-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/23/2016 1:52: 11,179.20 11,836.99 2S-12PB1 Srvy 7-SLB_MWD+GMAG(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/27/2016 8:40: 11,898.68 13,535.44 2S-12 Srvy 8-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/28/2016 10:37 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 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,929,717.61 1,621,019.42 0.00 0.00 UNDEFINED 100.00 0.29 190.76 100.00 -47.50 -0.18 -0.03 5,929,717.43 1,621,019.39 0.40 0.15 GYD-GC-SS(1) 200.00 0.41 190.63 200.00 52.50 -0.78 -0.15 5,929,716.83 1,621,019.27 0.12 0.64 GYD-GC-SS(1) 300.00 0.45 195.47 299.99 152.49 -1.51 -0.32 5,929,716.10 1,621,019.10 0.05 1.27 GYD-GC-SS(1) 400.00 1.00 335.77 399.99 252.49 -1.09 -0.78 5,929,716.51 1,621,018.64 1.38 1.32 GYD-GC-SS(1) 500.00 2.69 342.00 499.94 352.44 1.93 -1.86 5,929,719.54 1,621,017.56 1.70 0.02 GYD-GC-SS(1) 600.00 2.85 339.41 599.82 452.32 6.49 -3.46 5,929,724.11 1,621,015.98 0.20 -1.95 GYD-GC-SS(1) 700.00 5.59 337.49 699.54 552.04 13.32 -6.20 5,929,730.94 1,621,013.25 2.74 -4.66 GYD-GC-SS(1) 7/5/2016 10:44:17AM Page 2 COMPASS 5000.1 Build 74 • II Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-12 Project: Kuparuk River Unit TVD Reference: 2S-12 actual©147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12 Survey Calculation Method: Minimum Curvature Design: 2S-12 Database: OAKE DM P2 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 800.00 6.31 336.02 799.00 651.50 22.84 -10.30 5,929,740.47 1,621,009.18 0.74 -8.23 GYD-GC-SS(1) 900.00 8.69 329.19 898.14 750.64 34.35 -16.41 5,929,752.00 1,621,003.11 2.54 -11.71 GYD-GC-SS(1) 975.00 10.53 326.13 972.08 824.58 44.91 -23.13 5,929,762.57 1,620,996.41 2.55 -14.09 GYD-GC-SS(1) 1,013.91 11.75 326.29 1,010.26 862.76 51.16 -27.31 5,929,768.83 1,620,992.25 3.14 -15.35 MWD+IFR-AK-CAZ-SC(2) 1,107.62 13.67 325.67 1,101.67 954.17 68.24 -38.85 5,929,785.94 1,620,980.75 2.05 -18.72 MWD+IFR-AK-CAZ-SC(2) 1,200.42 16.08 324.50 1,191.35 1,043.85 87.76 -52.50 5,929,805.49 1,620,967.16 2.62 -22.23 MWD+IFR-AK-CAZ-SC(2) 1,292.50 19.08 320.32 1,279.13 1,131.63 109.73 -69.52 5,929,827.51 1,620,950.19 3.53 -24.98 MWD+IFR-AK-CAZ-SC(2) 1,386.06 19.77 318.96 1,367.36 1,219.86 133.44 -89.67 5,929,851.26 1,620,930.10 0.88 -26.65 MWD+IFR-AK-CAZ-SC(2) 1,479.50 20.24 316.88 1,455.16 1,307.66 157.15 -111.09 5,929,875.03 1,620,908.74 0.91 -27.40 MWD+IFR-AK-CAZ-SC(2) 1,572.66 24.30 307.63 1,541.38 1,393.88 180.64 -137.31 5,929,898.58 1,620,882.59 5.75 -24.51 MWD+IFR-AK-CAZ-SC(2) 1,665.16 27.66 303.44 1,624.53 1,477.03 204.10 -170.31 5,929,922.12 1,620,849.65 4.14 -16.68 MWD+IFR-AK-CAZ-SC(2) 1,756.86 29.76 300.84 1,704.95 1,557.45 227.50 -207.62 5,929,945.61 1,620,812.41 2.66 -5.69 MWD+IFR-AK-CAZ-SC(2) 1,849.84 32.90 296.17 1,784.38 1,636.88 250.47 -250.11 5,929,968.70 1,620,769.98 4.27 9.37 MWD+IFR-AK-CAZ-SC(2) 1,943.50 35.44 294.84 1,861.87 1,714.37 273.10 -297.59 5,929,991.45 1,620,722.56 2.83 28.28 MWD+IFR-AK-CAZ-SC(2) 2,037.33 37.15 294.42 1,937.49 1,789.99 296.25 -348.08 5,930,014.72 1,620,672.14 1.84 49.03 MWD+IFR-AK-CAZ-SC(2) 2,130.01 38.06 294.03 2,010.91 1,863.41 319.45 -399.66 5,930,038.05 1,620,620.63 1.01 70.52 MWD+IFR-AK-CAZ-SC(2) 2,222.77 38.76 292.95 2,083.60 1,936.10 342.42 -452.51 5,930,061.15 1,620,567.84 1.05 93.10 MWD+IFR-AK-CAZ-SC(2) 2,314.68 39.96 293.82 2,154.66 2,007.16 365.56 -506.01 5,930,084.42 1,620,514.41 1.44 116.03 MWD+IFR-AK-CAZ-SC(2) 2,409.01 41.18 294.41 2,226.31 2,078.81 390.62 -562.00 5,930,109.63 1,620,458.49 1.36 139.45 MWD+IFR-AK-CAZ-SC(2) 2,502.49 40.81 294.01 2,296.87 2,149.37 415.77 -617.93 5,930,134.92 1,620,402.63 0.49 162.77 MWD+IFR-AK-CAZ-SC(2) 2,596.33 40.61 293.99 2,368.00 2,220.50 440.67 -673.84 5,930,159.96 1,620,346.78 0.21 186.25 MWD+IFR-AK-CAZ-SC(2) 2,688.67 40.56 293.51 2,438.13 2,290.63 464.86 -728.83 5,930,184.29 1,620,291.87 0.34 209.53 MWD+IFR-AK-CAZ-SC(2) 2,787.47 40.93 290.93 2,512.99 2,365.49 489.24 -788.51 5,930,208.82 1,620,232.25 1.74 236.11 MWD+IFR-AK-CAZ-SC(2) 2,815.78 41.16 291.00 2,534.34 2,386.84 495.89 -805.87 5,930,215.51 1,620,214.91 0.83 244.14 INC+TREND(3) 2,845.00 41.18 291.36 2,556.33 2,408.83 502.84 -823.81 5,930,222.51 1,620,196.99 0.82 252.38 NOT an Actual Survey 10 3/4"x 13 1/2" 2,908.52 41.23 292.15 2,604.12 2,456.62 518.35 -862.67 5,930,238.12 1,620,158.17 0.82 269.93 MWD+IFR-AK-CAZ-SC(4) 3,003.43 41.26 291.42 2,675.49 2,527.99 541.57 -920.78 5,930,261.49 1,620,100.13 0.51 296.15 MWD+IFR-AK-CAZ-SC(4) 3,093.72 41.20 290.99 2,743.39 2,595.89 563.10 -976.25 5,930,283.15 1,620,044.72 0.32 321.64 MWD+IFR-AK-CAZ-SC(4) 3,189.59 41.13 290.66 2,815.56 2,668.06 585.53 -1,035.24 5,930,305.74 1,619,985.80 0.24 349.03 MWD+IFR-AK-CAZ-SC(4) 3,281.31 41.07 290.18 2,884.68 2,737.18 606.57 -1,091.74 5,930,326.92 1,619,929.35 0.35 375.60 MWD+IFR-AK-CAZ-SC(4) 3,377.84 41.03 290.47 2,957.48 2,809.98 628.59 -1,151.19 5,930,349.09 1,619,869.97 0.20 403.62 MWD+IFR-AK-CAZ-SC(4) 3,472.80 41.11 291.43 3,029.07 2,881.57 650.89 -1,209.45 5,930,371.54 1,619,811.77 0.67 430.58 MWD+IFR-AK-CAZ-SC(4) 3,566.08 41.08 291.66 3,099.37 2,951.87 673.41 -1,266.48 5,930,394.20 1,619,754.81 0.17 456.50 MWD+IFR-AK-CAZ-SC(4) 3,659.12 41.06 290.95 3,169.51 3,022.01 695.62 -1,323.43 5,930,416.55 1,619,697.92 0.50 482.58 MWD+IFR-AK-CAZ-SC(4) 3,751.52 41.08 291.22 3,239.17 3,091.67 717.46 -1,380.07 5,930,438.53 1,619,641.34 0.19 508.69 MWD+IFR-AK-CAZ-SC(4) 3,844.94 41.07 291.35 3,309.60 3,162.10 739.74 -1,437.26 5,930,460.96 1,619,584.21 0.09 534.90 MWD+IFR-AK-CAZ-SC(4) 3,935.36 41.02 291.91 3,377.79 3,230.29 761.62 -1,492.45 5,930,482.99 1,619,529.08 0.41 559.92 MWD+IFR-AK-CAZ-SC(4) 4,029.68 41.15 293.45 3,448.88 3,301.38 785.52 -1,549.64 5,930,507.03 1,619,471.96 1.08 585.01 MWD+IFR-AK-CAZ-SC(4) 4,122.40 41.05 295.09 3,518.76 3,371.26 810.57 -1,605.20 5,930,532.22 1,619,416.47 1.17 608.12 MWD+IFR-AK-CAZ-SC(4) 7/5/2016 10:44:17AM Page 3 COMPASS 5000.1 Build 74 • II • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-12 Project: Kuparuk River Unit TVD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12 Survey Calculation Method: Minimum Curvature Design: 2S-12 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 4.219.12 41.14 296.02 3,591.65 3,444.15 838.00 -1,662.56 5,930,559.79 1,619,359.19 0.64 630.91 MWD+IFR-AK-CAZ-SC(4) 4,310.16 41.13 296.51 3,660.22 3,512.72 864.50 -1,716.26 5,930,586.43 1,619,305.56 0.35 651.68 MWD+IFR-AK-CAZ-SC(5) 4,403.88 41.23 296.66 3,730.75 3,583.25 892.12 -1,771.45 5,930,614.18 1,619,250.45 0.15 672.76 MWD+IFR-AK-CAZ-SC(5) 4,496.23 41.10 297.00 3,800.28 3,652.78 919.55 -1,825.69 5,930,641.76 1,619,196.29 0.28 693.28 MWD+IFR-AK-CAZ-SC(5) 4,590.24 41.16 296.38 3,871.09 3,723.59 947.33 -1,880.94 5,930,669.67 1,619,141.11 0.44 714.29 MWD+IFR-AK-CAZ-SC(5) 4,684.70 41.05 294.14 3,942.27 3,794.77 973.83 -1,937.09 5,930,696.31 1,619,085.03 1.56 736.85 MWD+IFR-AK-CAZ-SC(5) 4,777.22 41.15 291.95 4,011.99 3,864.49 997.63 -1,993.05 5,930,720.25 1,619,029.14 1.56 761.11 MWD+IFR-AK-CAZ-SC(5) 4,870.35 41.16 291.07 4,082.11 3,934.61 1,020.10 -2,050.07 5,930,742.87 1,618,972.18 0.62 787.06 MWD+IFR-AK-CAZ-SC(5) 4,963.26 40.95 289.29 4,152.18 4,004.68 1,041.15 -2,107.34 5,930,764.07 1,618,914.97 1.28 814.16 MWD+IFR-AK-CAZ-SC(5) 5,057.57 41.04 289.86 4,223.36 4,075.86 1,061.88 -2,165.63 5,930,784.94 1,618,856.74 0.41 842.23 MWD+IFR-AK-CAZ-SC(5) 5,149.75 41.11 289,10 4,292.85 4,145.35 1,082.08 -2,222.73 5,930,805.28 1,618,799.70 0.55 869.80 MWD+IFR-AK-CAZ-SC(5) 5,242.58 41.69 287.83 4,362.48 4,214.98 1,101.52 -2,280.96 5,930,824.87 1,618,741.53 1.10 898.71 MWD+IFR-AK-CAZ-SC(5) 5,336.87 41.74 286.36 4,432.87 4,285.37 1,119.96 -2,340.93 5,930,843.46 1,618,681.62 1.04 929.57 MWD+IFR-AK-CAZ-SC(5) 5,430.89 39.77 283.85 4,504.09 4,356.59 1,135.98 -2,400.16 5,930,859.63 1,618,622.43 2.73 961.57 MWD+IFR-AK-CAZ-SC(5) 5,524.43 39.54 279.92 4,576.12 4,428.62 1,148.27 -2,458.55 5,930,872.07 1,618,564.08 2.69 995.51 MWD+IFR-AK-CAZ-SC(5) 5,616.10 40.41 275.08 4,646.38 4,498.88 1,155.93 -2,516.91 5,930,879.88 1,618,505.75 3.52 1,032.61 MWD+IFR-AK-CAZ-SC(5) 5,711.57 41.16 271.40 4,718.68 4,571.18 1,159.44 -2,579.15 5,930,883.55 1,618,443.52 2.64 1,075.39 MWD+IFR-AK-CAZ-SC(5) 5,801.70 41.65 268.75 4,786.29 4,638.79 1,159.51 -2,638.75 5,930,883.78 1,618,383.93 2.02 1,118,62 MWD+IFR-AK-CAZ-SC(5) 5,897.45 42.64 266.18 4,857.29 4,709.79 1,156.65 -2,702.92 5,930,881.09 1,618,319.75 2.08 1,167.17 MWD+IFR-AK-CAZ-SC(5) 5,987.96 43.46 263.66 4,923.43 4,775.93 1,151.17 -2,764.45 5,930,875.76 1,618,258.22 2.11 1,215.62 MWD+IFR-AK-CAZ-SC(5) 6,081.91 44.83 260.75 4,990.85 4,843.35 1,142.28 -2,829.26 5,930,867.04 1,618,193.39 2.60 1,268.79 MWD+IFR-AK-CAZ-SC(5) 6,175.61 45.61 258.17 5,056.86 4,909.36 1,130.11 -2,894.64 5,930,855.03 1,618,127.99 2.12 1,324.63 MWD+IFR-AK-CAZ-SC(5) 6,270.28 45.50 255.51 5,123.16 4,975.66 1,114.72 -2,960.44 5,930,839.82 1,618,062.16 2.01 1,382.98 MWD+IFR-AK-CAZ-SC(5) 6,362.71 44.98 251.45 5,188.25 5,040.75 1,096.08 -3,023.33 5,930,821,34 1,617,999.22 3.17 1,441.47 MWD+IFR-AK-CAZ-SC(5) 6,456.17 44.56 248.02 5,254.61 5,107.11 1,073.29 -3,085.06 5,930,798.72 1,617,937.43 2.62 1,501.96 MWD+IFR-AK-CAZ-SC(5) 6,548.26 44.41 244.38 5,320.32 5,172.82 1,047.27 -3,144.09 5,930,772.84 1,617,878.35 2.77 1,562.71 MWD+IFR-AK-CAZ-SC(5) 6,642.77 44.99 241.13 5,387.51 5,240.01 1,016.83 -3,203.17 5,930,742.56 1,617,819.20 2.50 1,626.54 MWD+IFR-AK-CAZ-SC(5) 6,735.94 45.10 238.50 5,453.35 5,305.85 983.69 -3,260.15 5,930,709,57 1,617,762.14 2.00 1,690.70 MWD+IFR-AK-CAZ-SC(5) 6,828.03 46.36 236.47 5,517.63 5,370.13 948.23 -3,315.74 5,930,674.26 1,617,706.46 2.09 1,755.44 MWD+IFR-AK-CAZ-SC(5) 6,919.42 47.82 235.25 5,579.85 5,432.35 910.66 -3,371.14 5,930,636.84 1,617,650.97 1.87 1,821.50 MWD+IFR-AK-CAZ-SC(5) 7,014.41 49.44 232.79 5,642.64 5,495.14 868.78 -3,428.80 5,930,595.10 1,617,593.21 2.59 1,892.17 MWD+IFR-AK-CAZ-SC(5) 7,107.32 51.63 229.74 5,701.70 5,554.20 823.88 -3,484.72 5,930,550.36 1,617,537.18 3.46 1,963.64 MWD+IFR-AK-CAZ-SC(5) 7,199.97 54.26 226.16 5,757.53 5,610.03 774.35 -3,539.58 5,930,500.97 1,617,482.20 4.19 2,037.53 MWD+IFR-AK-CAZ-SC(5) 7,291.54 56.22 223.31 5,809.74 5,662.24 720.90 -3,592.50 5,930,447.67 1,617,429.15 3.33 2,112.70 MWD+IFR-AK-CAZ-SC(5) 7,385.34 59.21 219.58 5,859.85 5,712.35 661.46 -3,644.93 5,930,388.36 1,617,376.57 4.63 2,191.65 MWD+IFR-AK-CAZ-SC(5) 7,478.18 61.89 216.43 5,905.50 5,758.00 597.76 -3,694.67 5,930,324.79 1,617,326.67 4.13 2,271.57 MWD+IFR-AK-CAZ-SC(5) 7,572.51 64.12 213.35 5,948.33 5,800.83 528.81 -3,742.72 5,930,255.98 1,617,278.45 3.75 2,353.86 MWD+IFR-AK-CAZ-SC(5) 7,664.72 66.51 211.43 5,986.84 5,839.34 458.07 -3,787.59 5,930,185.36 1,617,233.40 3.21 2,435.08 MWD+IFR-AK-CAZ-SC(5) 7,759.36 68.37 210.47 6,023.14 5,875.64 383.12 -3,832.53 5,930,110.53 1,617,188.28 2.18 2,519.25 MWD+IFR-AK-CAZ-SC(5) 7,851.53 69.77 209.79 6,056.07 5,908.57 308.66 -3,875.74 5,930,036.19 1,617,144.88 1.67 2,601.82 MWD+IFR-AK-CAZ-SC(5) 7/5/2016 10:44:17AM Page 4 COMPASS 5000.1 Build 74 • • • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-12 Project: Kuparuk River Unit TVD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12 Survey Calculation Method: Minimum Curvature Design: 2S-12 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 7,941.56 71.17 208.49 6,086.17 5,938.67 234.55 -3,917.05 5,929,962.20 1,617,103.38 2.07 2,682.77 MWD+IFR-AK-CAZ-SC(5) 8,035.83 71.70 207.14 6,116.18 5,968.68 155.51 -3,958.74 5,929,883.28 1,617,061.49 1.47 2,767.40 MWD+IFR-AK-CAZ-SC(5) 8,130.07 72.38 206.98 6,145.24 5,997.74 75.68 -3,999.53 5,929,803.56 1,617,020.50 0.74 2,851.90 MWD+IFR-AK-CAZ-SC(5) 8,178.05 73.11 207.03 6,159.47 6,011.97 34.86 -4,020.33 5,929,762.79 1,616,999.59 1.52 2,895.08 MWD+IFR-AK-CAZ-SC(5) ` 8,239.00 73.17 207.89 6,177.15 6,029.65 -16.90 4,047.23 5,929,711.11 1,616,972.57 1.36 2,950.20 NOT an Actual Survey 7-5/8"x 9-7/8-11" 8241.66 73.17 207.93 6,177.92 6,030.42 -19.15 -4,048.42 5,929,708.86 1,616,971.37 1.36 2,952.61 MWD+IFR-AK-CAZ-SC(6) 8,295.57 74.04 207.29 6,193.14 6,045.64 -64.98 -4,072.39 5,929,663.10 1,616,947.28 1.98 3,001.53 MWD+IFR-AK-CAZ-SC(6) 8,389.70 75.24 207.40 6,218.07 6,070.57 -145.60 -4,114.08 5,929,582.59 1,616,905.39 1.28 3,087.24 MWD+IFR-AK-CAZ-SC(6) 8,483.50 77.12 206.58 6,240.48 6,092.98 -226.76 -4,155.42 5,929,501.54 1,616,863.85 2.18 3,173.06 MWD+IFR-AK-CAZ-SC(6) 8,579.36 78.59 204.50 6,260.65 6,113.15 -311.32 -4,195.81 5,929,417.10 1,616,823.24 2.62 3,260.53 MWD+IFR-AK-CAZ-SC(6) 8,674.42 81.25 202.65 6,277.28 6,129.78 -397.09 -4,233.23 5,929,331.44 1,616,785.60 3.39 3,346.68 MWD+IFR-AK-CAZ-SC(6) 8,709.96 83.20 202.53 6,282.09 6,134.59 -429.60 -4,246.76 5,929,298.97 1,616,772.00 5.50 3,378.85 MWD+IFR-AK-CAZ-SC(6) 8,769.41 86.34 201.25 6,287.51 6,140.01 -484.52 -4,268.83 5,929,244.10 1,616,749.79 5.70 3,432.64 MWD+IFR-AK-CAZ-SC(6) 8,865.18 90.31 199.67 6,290.31 6,142.81 -574.19 -4,302.28 5,929,154.53 1,616,716.11 4.46 3,518.59 MWD+IFR-AK-CAZ-SC(6) 8,959.33 91.21 197.63 6,289.06 6,141.56 -663.39 -4,332.38 5,929,065.42 1,616,685.78 2.37 3,601.78 MWD+IFR-AK-CAZ-SC(6) 9,053.67 90.90 197.27 6,287.32 6,139.82 -753.37 -4,360.67 5,928,975.52 1,616,657.27 0.50 3,684.19 MWD+IFR-AK-CAZ-SC(6) 9,147.99 89.80 195.50 6,286.75 6,139.25 -843.85 -4,387.27 5,928,885.11 1,616,630.43 2.21 3,765.72 MWD+IFR-AK-CAZ-SC(6) 9,242.15 90.04 196.35 6,286.88 6,139.38 -934.40 -4,413.11 5,928,794.65 1,616,604.37 0.94 3,846.74 MWD+IFR-AK-CAZ-SC(6) 9,336.56 89.63 191.88 6,287.15 6,139.65 -1,025.93 -4,436.13 5,928,703.18 1,616,581.12 4.75 3,926.40 MWD+IFR-AK-CAZ-SC(6) 9,430.98 89.56 190.13 6,287.82 6,140.32 -1,118.61 -4,454.15 5,928,610.56 1,616,562.86 1.85 4,003.21 MWD+IFR-AK-CAZ-SC(6) 9,524.48 89.60 190.07 6,288.50 6,141.00 -1,210.66 -4,470.55 5,928,518.56 1,616,546.23 0.08 4,078.41 MWD+IFR-AK-CAZ-SC(6) 9,619.64 89.56 190.91 6,289.20 6,141.70 -1,304.23 -4,487.87 5,928,425.05 1,616,528.66 0.88 4,155.33 MWD+IFR-AK-CAZ-SC(6) 9,713.52 89.60 191.82 6,289.89 6,142.39 -1,396.26 -4,506.37 5,928,333.07 1,616,509.93 0.97 4,232.04 MWD+IFR-AK-CAZ-SC(6) 9,812.63 89.43 195.05 6,290.73 6,143.23 -1,492.64 -4,529.39 5,928,236.76 1,616,486.66 3.26 4,315.03 MWD+IFR-AK-CAZ-SC(6) 9,902.41 89.49 194.81 6,291.57 6,144.07 -1,579.39 -4,552.52 5,928,150.08 1,616,463.31 0.28 4,391.48 MWD+IFR-AK-CAZ-SC(6) 9,996.87 89.49 194.17 6,292.42 6,144.92 -1,670.84 -4,576.16 5,928,058.70 1,616,439.44 0.68 4,471.52 MWD+IFR-AK-CAZ-SC(6) 10,091.64 89.49 194.22 6,293.26 6,145.76 -1,762.71 -4,599.40 5,927,966.89 1,616,415.97 0.05 4,551.57 MWD+IFR-AK-CAZ-SC(6) 10,187.06 89.56 193.29 6,294.05 6,146.55 -1,855.39 -4,622.08 5,927,874.28 1,616,393.05 0.98 4,631.77 MWD+IFR-AK-CAZ-SC(6) 10,282.04 91.01 192.95 6,293.58 6,146.08 -1,947.89 -4,643.64 5,927,781.85 1,616,371.25 1.57 4,711.02 MWD+IFR-AK-CAZ-SC(6) 10,376.98 90.97 192.27 6,291.94 6,144.44 -2,040.52 -4,664.37 5,927,689.28 1,616,350.29 0.72 4,789.77 MWD+IFR-AK-CAZ-SC(6) 10,470.97 91.28 192.53 6,290.09 6,142.59 -2,132.30 -4,684.54 5,927,597.56 1,616,329.88 0.43 4,867.53 MWD+IFR-AK-CAZ-SC(6) 10,565.39 92.13 192.20 6,287.28 6,139.78 -2,224.49 -4,704.75 5,927,505.43 1,616,309.44 0.97 4,945.59 MWD+IFR-AK-CAZ-SC(6) 10,660.00 92.41 192.68 6,283.53 6,136.03 -2,316.81 -4,725.12 5,927,413.18 1,616,288.84 0.59 5,023.86 MWD+IFR-AK-CAZ-SC(6) 10,756.09 92.55 192.35 6,279.38 6,131.88 -2,410.53 -4,745.92 5,927,319.52 1,616,267.79 0.37 5,103.40 MWD+IFR-AK-CAZ-SC(6) 10,849.95 92.38 194.56 6,275.34 6,127.84 -2,501.72 -4,767.74 5,927,228.40 1,616,245.74 2.36 5,181.95 MWD+IFR-AK-CAZ-SC(6) 10,943.62 90.68 195.88 6,272.84 6,125.34 -2,592.07 -4,792.32 5,927,138.12 1,616,220.93 2.30 5,261.92 MWD+IFR-AK-CAZ-SC(6) 11,039.03 91.11 194.41 6,271.35 6,123.85 -2,684.15 -4,817.24 5,927,046.11 1,616,195.78 1.61 5,343.34 MWD+IFR-AK-CAZ-SC(6) 11,132.17 91.86 194.02 6,268.93 6,121.43 -2,774.41 -4,840.11 5,926,955.92 1,616,172.68 0.91 5,422.00 MWD+IFR-AK-CAZ-SC(6) _ 11,179.20 92.00 191.04 6,267.35 6,119.85 -2,820.28 -4,850.30 5,926,910.08 1,616,162.37 6.34 5,460.95 MWD+IFR-AK-CAZ-SC(7) 7/5/2016 10:44:17AM Page 5 COMPASS 5000.1 Build 74 • • Sc hlurnber9 er • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-12 Project: Kuparuk River Unit TVD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12 Survey Calculation Method: Minimum Curvature Design: 2S-12 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 11,272.58 92.03 191.92 6,264.07 6,116.57 -2,911.74 -4,868.88 5,926.818.68 1.616,143.56 0.94 5,537.32 MWD+IFR-AK-CAZ-SC(7) 11,364.13 92.57 192.45 6,260.39 6,112.89 -3,001.15 -4,888.19 5,926,729.32 1,616,124.03 0.83 5,612.82 MWD+IFR-AK-CAZ-SC(7) 11,460.58 90.62 195.42 6,257.71 6,110.21 -3,094.71 -4,911.40 5,926,635.83 1,616,100.57 3.68 5,694.01 MWD+IFR-AK-CAZ-SC(7) 11,553.43 87.96 196.50 6,258.86 6,111.36 -3,183.97 -4,936.93 5,926,546.65 1,616,074.82 3.09 5,773.92 MWD+IFR-AK-CAZ-SC(7) 11,647.75 87.91 199.17 6,262.26 6,114.76 -3,273.69 -4,965.79 5,926,457.01 1,616,045.73 2.83 5,856.57 MWD+IFR-AK-CAZ-SC(7) 11,741.48 85.37 198.23 6,267.75 6,120.25 -3,362.31 -4,995.79 5,926,368.48 1,616,015.51 2.89 5,939.29 MWD+IFR-AK-CAZ-SC(7) 11,836.99 87.10 198.18 6,274.02 6,126.52 -3,452.84 -5,025.56 5,926,278.04 1,615,985.50 1.81 6,023.16 Tie-in to 2S-12PB1 11,898.68 89.87 196.47 6,275.65 6,128.15 -3,511.70 -5,043.93 5,926,219.23 1,615,966.99 5.28 6,076.96 MWD+IFR-AK-CAZ-SC(8) 11,931.51 87.99 196.28 6,276.27 6,128.77 -3,543.19 -5,053.18 5,926,187.76 1,615,957.66 5.76 6,105.34 MWD+IFR-AK-CAZ-SC(8) 12,025.86 85.83 197.14 6,281.35 6,133.85 -3,633.42 -5,080.27 5,926,097.61 1,615,930.34 2.46 6,187.05 MWD+IFR-AK-CAZ-SC(8) 12,120.35 85.47 197.88 6,288.52 6,141.02 -3,723.27 -5,108.61 5,926,007.84 1,615,901.77 0.87 6,269.41 MWD+IFR-AK-CAZ-SC(8) 12,215.50 85.33 196.49 6,296.15 6,148.65 -3,813.88 -5,136.63 5,925,917.32 1,615,873.52 1.46 6,352.06 MWD+IFR-AK-CAZ-SC(8) 12,308.99 84.58 195.73 6,304.37 6,156.87 -3,903.35 -5,162.48 5,925,827.92 1,615,847.45 1.14 6,432.34 MWD+IFR-AK-CAZ-SC(8) 12 403.69 82.05 196.54 6,315.39 6,167.89 -3,993.69 -5,188.61 5,925,737.66 1615821.08 2.80 6,513.44 MWD+IFR-AK-CAZ-SC(8) 12,498.18 83.04 196.01 6,327.65 6,180.15 -4,083.63 -5,214.87 5,925,647.80 1,615,794.60 1.19 6,594.35 MWD+IFR-AK-CAZ-SC(8) 12,592.66 86.21 196.35 6,336.50 6,189.00 -4,173.96 -5,241.07 5,925,557.55 1,615,768.16 3.37 6,675.49 MWD+IFR-AK-CAZ-SC(8) 12,688.08 91.33 191.73 6,338.55 6,191.05 -4,266.45 -5,264.20 5,925,465.12 1,615,744.80 7.23 6,755.88 MWD+IFR-AK-CAZ-SC(8) 12,782.79 94.13 189.53 6,334.04 6,186.54 -4,359.41 -5,281.65 5,925,372.21 1,615,727.11 3.76 6,832.47 MWD+IFR-AK-CAZ-SC(8) 12,876.25 95.73 190.58 6,326.01 6,178.51 -4,451.09 -5,297.91 5,925,280.59 1,615,710.62 2.05 6,907.32 MWD+IFR-AK-CAZ-SC(8) 12,968.89 94.94 192.57 6,317.40 6,169.90 -4,541.45 -5,316.41 5,925,190.28 1,615,691.89 2.30 6,982.89 MWD+IFR-AK-CAZ-SC(8) 13,064.39 94.92 193.45 6,309.19 6,161.69 -4,634.15 -5,337.83 5,925,097.65 1,615,670.23 0.92 7,062.18 MWD+IFR-AK-CAZ-SC(8) 13,159.17 93.52 193.71 6,302.21 6,154.71 -4,726.03 -5,360.03 5,925,005.83 1,615,647.80 1.50 7,141.47 MWD+IFR-AK-CAZ-SC(8) 13,254.15 93.95 194.98 6,296.03 6,148.53 -4,817.85 -5,383.51 5,924,914.08 1,615,624.09 1.41 7,221.66 MWD+IFR-AK-CAZ-SC(8) 13,349.60 95.22 193.48 6,288.40 6,140.90 -4,910.07 -5,406.90 5,924,821.93 1,615,600.46 2.06 7,302.05 MWD+IFR-AK-CAZ-SC(8) 13,440.01 93.61 194.10 6,281.44 6,133.94 -4,997.61 -5,428.38 5,924,734.46 1,615,578.76 1.91 7,377.85 MWD+IFR-AK-CAZ-SC(8) 13,535.44 95.76 194.90 6,273.64 6,126.14 -5,089.69 -5,452.19 5,924,642.45 1,615,554.71 2.40 7,458.45 MWD+IFR-AK-CAZ-SC(8) 13,638.00 95.76 194.90 6,263.35 6,115.85 -5,188.30 -5,478.43 5,924,543.92 1,615,528.22 0.00 7,545.31 PROJECTED to TD 7/5/2016 10:44:17AM Page 6 COMPASS 5000.1 Build 74 • • Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. L Yes L No have checked to the best of my ability that the following data is correct: 0 Surface Coordinates LI Declination & Convergence EJ CRS Survey Corrections 0 Survey Tool Codes Digitaiysigned byVincent{hxa DRI:al=Vincent©san, Vincent Osara o=Schlumbetger,ou=5chlutte1, email=wsankssIbmm,r-US SLB DE: nese:2016.07A512:13:07-OM Daniel Bearden Mtn Des ....re ..�, Mtn ....re a lAp��q uaLNO•1S Client Representative: ,e. �..s y.�mwrus ur x om Date: 05-Jul-2016 RWEIVED • 21 6074 JUL 182016 27390 S chiumberer ►(�GC(� Transmittal#: 18JUL16-SPO2 g Drilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery Z rza.noiCo ,,i K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2S-12PB1 Date Dispatched: 18-Jul-16 Job#: 16AKA0106 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 6 Contents on CD N/A VISION*Service 2" MD 107' - 12303' x x VISION*Service 2"TVD 107' -6243.99' x x VISION*Service 2"TVDSS 107' -6243.99' x x VISION*Service 5"MD 107' -12303' x x VISION*Service 5'TVD 107' -6243.99' x x VISION*Service 5'TVDSS 107' -6243.99' x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Tom.Osterkamp(c�conocophillips.com AlaskaPTSPrintCenter(a�slb.com Tom Osterkamp Attn: Stephanie Pacillo 907-263-4795 Received By: 1# 2,1Las2LI 6,, ek • • 216074 27 390 RECEIVED JUL .L 8 2016 FINAL AOGCC NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-12PB1 2S-12PB1 Definitive Survey Report 05 July, 2016 NAD 27 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-12 Project: Kuparuk River Unit TVD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12PB1 Survey Calculation Method: Minimum Curvature Design: 2S-12PB1 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-12 Well Position +N/-S 0.00 usft Northing: 5,929,968.02 usft Latitude: 70°13'11.380 N +E/-W 0.00 usft Easting: 480,986.10 usft Longitude: 150°9'12.212 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore 2S-12PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (1 (nT) BGGM2016 6/20/2016 17.97 80.85 57,536 Design 2S-12PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 27.50 0.00 0.00 195.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 100.00 975.00 2S-12 Srvy 1-SLB_NSG+BATTERY(2S GYD-GC-SS Gyrodata gyro single shots 6/9/2016 8:37:0 1,013.91 2,787.47 2S-12 Srvy 2-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/8/2016 10:02:C 2,815.78 2,815.78 2S-12 Srvy 3-SLB_INC+Filler(2S-12PB INC+TREND Inclinometer+known azi trend 6/13/2016 9:29: 2,908.52 4,219.12 2S-12 Srvy 4-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/13/2016 9:34: 4,310.16 8,178.05 2S-12 Srvy 5-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/15/2016 9:10: 8,241.66 11,132.17 2S-12 Srvy 6-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/23/2016 1:52: 11,179.20 12,212.25 2S-12PB1 Srvy 7-SLB_MWD+GMAG(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/27/2016 8:40: 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 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,929,968.02 480,986.10 0.00 0.00 UNDEFINED 100.00 0.29 190.76 100.00 -47.50 -0.18 -0.03 5,929,967.84 480,986.07 0.40 0.18 GYD-GC-SS(1) 200.00 0.41 190.63 200.00 52.50 -0.78 -0.15 5,929,967.24 480,985.95 0.12 0.79 GYD-GC-SS(1) 300.00 0.45 195.47 299.99 152.49 -1.51 -0.32 5,929,966.51 480,985.78 0.05 1.54 GYD-GC-SS(1) 400.00 1.00 335.77 399.99 252.49 -1.09 -0.78 5,929,966.93 480,985.32 1.38 1.26 GYD-GC-SS(1) 500.00 2.69 342.00 499.94 352.44 1.93 -1.86 5,929,969.96 480,984.24 1.70 -1.39 GYD-GC-SS(1) 600.00 2.85 339.41 599.82 452.32 6.49 -3.46 5,929,974.52 480,982.65 0.20 -5.38 GYD-GC-SS(1) 700.00 5.59 337.49 699.54 552.04 13.32 -6.20 5,929,981.36 480,979.93 2.74 -11.26 GYD-GC-SS(1) 800.00 6.31 336.02 799.00 651.50 22.84 -10.30 5,929,990.89 480,975.86 0.74 -19.40 GYD-GC-SS(1) 7/5/2016 11:54:52AM Page 2 COMPASS 5000.1 Build 74 . • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-12 Project: Kuparuk River Unit TVD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12PB1 Survey Calculation Method: Minimum Curvature Design: 2S-12PB1 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) (°/100') (ft) Survey Tool Name 900.00 8.69 329.19 898.14 750.64 34.35 -16.41 5,930,002.41 480,969.78 2.54 -28.94 GYD-GC-SS(1) 975.00 10.53 326.13 972.08 824.58 44.91 -23.13 5,930,012.98 480,963.09 2.55 -37.39 GYD-GC-SS(1) 1,013.91 11.75 326.29 1,010.26 862.76 51.16 -27.31 5,930,019.24 480,958.92 3.14 -42.35 MWD+IFR-AK-CAZ-SC(2) 1,107.62 13.67 325.67 1,101.67 954.17 68.24 -38.85 5,930,036.35 480,947.43 2.05 -55.86 MWD+IFR-AK-CAZ-SC(2) 1,200.42 16.08 324.50 1,191.35 1,043.85 87.76 -52.50 5,930,055.91 480,933.83 2.62 -71.18 MWD+IFR-AK-CAZ-SC(2) 1,292.50 19.08 320.32 1,279.13 1,131.63 109.73 -69.52 5,930,077.92 480,916.87 3.53 -88.00 MWD+IFR-AK-CAZ-SC(2) 1,386.06 19.77 318.96 1,367.36 1,219.86 133.44 -89.67 5,930,101.67 480,896.77 0.88 -105.68 MWD+IFR-AK-CAZ-SC(2) 1,479.50 20.24 316.88 1,455.16 1,307.66 157.15 -111.09 5,930,125.44 480,875.41 0.91 -123.05 MWD+IFR-AK-CAZ-SC(2) 1,572.66 24.30 307.63 1,541.38 1,393.88 180.64 -137.31 5,930,148.98 480,849.26 5.75 -138.94 MWD+IFR-AK-CAZ-SC(2) 1,665.16 27.66 303.44 1,624.53 1,477.03 204.10 -170.31 5,930,172.53 480,816.32 4.14 -153.06 MWD+IFR-AK-CAZ-SC(2) 1,756.86 29.76 300.84 1,704.95 1,557.45 227.50 -207.62 5,930,196.02 480,779.08 2.66 -166.01 MWD+IFR-AK-CAZ-SC(2) 1,849.84 32.90 296.17 1,784.38 1,636.88 250.47 -250.11 5,930,219.10 480,736.64 4.27 -177.21 MWD+IFR-AK-CAZ-SC(2) 1,943.50 35.44 294.84 1,861.87 1,714.37 273.10 -297.59 5,930,241.85 480,689.23 2.83 -186.78 MWD+IFR-AK-CAZ-SC(2) 2,037.33 37.15 294.42 1,937.49 1,789.99 296.25 -348.08 5,930,265.11 480,638.80 1.84 -196.06 MWD+IFR-AK-CAZ-SC(2) 2,130.01 38.06 294.03 2,010.91 1,863.41 319.45 -399.66 5,930,288.44 480,587.29 1.01 -205.13 MWD+IFR-AK-CAZ-SC(2) 2,222.77 38.76 292.95 2,083.60 1,936.10 342.42 -452.51 5,930,311.54 480,534.50 1.05 -213.63 MWD+IFR-AK-CAZ-SC(2) 2,314.68 39.96 293.82 2,154.66 2,007.16 365.56 -506.01 5,930,334.81 480,481.07 1.44 -222.14 MWD+IFR-AK-CAZ-SC(2) 2,409.01 41.18 294.41 2,226.31 2,078.81 390.62 -562.00 5,930,360.02 480,425.14 1.36 -231.86 MWD+IFR-AK-CAZ-SC(2) 2,502.49 40.81 294.01 2,296.87 2,149.37 415.77 -617.93 5,930,385.31 480,369.28 0.49 -241.67 MWD+IFR-AK-CAZ-SC(2) 2,596.33 40.61 293.99 2,368.00 2,220.50 440.67 -673.84 5,930,410.34 480,313.44 0.21 -251.25 MWD+IFR-AK-CAZ-SC(2) 2,688.67 40.56 293.51 2,438.13 2,290.63 464.86 -728.83 5,930,434.67 480,258.52 0.34 -260.39 MWD+IFR-AK-CAZ-SC(2) 2,787.47 40.93 290.93 2,512.99 2,365.49 489.24 -788.51 5,930,459.19 480,198.90 1.74 -268.48 MWD+IFR-AK-CAZ-SC(2) 2,815.78 41.16 291.00 2,534.34 2,386.84 495.89 -805.87 5,930,465.89 480,181.56 0.83 -270.42 INC+TREND(3) 2,845.00 41.18 291.36 2,556.33 2,408.83 502.84 -823.81 5,930,472.88 480,163.64 0.82 -27249 NOT an Actual Survey ) 103/4"x131/2" 2,908.52 41.23 292.15 2,604.12 2,456.62 518.35 -862.67 5,930,488.49 480,124.82 0.82 -277.41 MWD+IFR-AK-CAZ-SC(4) 3,003.43 41.26 291.42 2,675.49 2,527.99 541.57 -920.78 5,930,511.85 480,066.78 0.51 -284.80 MWD+IFR-AK-CAZ-SC(4) 3,093.72 41.20 290.99 2,743.39 2,595.89 563.10 -976.25 5,930,533.52 480,011.36 0.32 -291.24 MWD+IFR-AK-CAZ-SC(4) 3,189.59 41.13 290.66 2,815.56 2,668.06 585.53 -1,035.24 5,930,556.10 479,952.44 0.24 -297.64 MWD+IFR-AK-CAZ-SC(4) 3,281.31 41.07 290.18 2,884.68 2,737.18 606.57 -1,091.74 5,930,577.27 479,896.00 0.35 -303.34 MWD+IFR-AK-CAZ-SC(4) 3,377.84 41.03 290.47 2,957.48 2,809.98 628.59 -1,151.19 5,930,599.44 479,836.61 0.20 -309.22 MWD+IFR-AK-CAZ-SC(4) 3,472.80 41.11 291.43 3,029.07 2,881.57 650.89 -1,209.45 5,930,621.89 479,778.42 0.67 -315.69 MWD+IFR-AK-CAZ-SC(4) 3,566.08 41.08 291.66 3,099.37 2,951.87 673.41 -1,266.48 5,930,644.55 479,721.45 0.17 -322.67 MWD+IFR-AK-CAZ-SC(4) 3,659.12 41.06 290.95 3,169.51 3,022.01 695.62 -1,323.43 5,930,666.90 479,664.56 0.50 -329.39 MWD+IFR-AK-CAZ-SC(4) 3,751.52 41.08 291.22 3,239.17 3,091.67 717.46 -1,380.07 5,930,688.88 479,607.98 0.19 -335.82 MWD+IFR-AK-CAZ-SC(4) 3,844.94 41.07 291.35 3,309.60 3,162.10 739.74 -1,437.26 5,930,711.30 479,550.85 0.09 -342.54 MWD+IFR-AK-CAZ-SC(4) 3,935.36 41.02 291.91 3,377.79 3,230.29 761.62 -1,492.45 5,930,733.33 479,495.72 0.41 -349.40 MWD+IFR-AK-CAZ-SC(4) 4,029.68 41.15 293.45 3,448.88 3,301.38 785.52 -1,549.64 5,930,757.37 479,438.60 1.08 -357.68 MWD+IFR-AK-CAZ-SC(4) 4,122.40 41.05 295.09 3,518.76 3,371.26 810.57 -1,605.20 5,930,782.55 479,383.10 1.17 -367.50 MWD+IFR-AK-CAZ-SC(4) 4,219.12 41.14 296.02 3,591.65 3,444.15 838.00 -1,662.56 5,930,810.12 479,325.83 0.64 -379.14 MWD+IFR-AK-CAZ-SC(4) 7/5/2016 11:54:52AM Page 3 COMPASS 5000.1 Build 74 III • Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-12 Project: Kuparuk River Unit TVD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12PB1 Survey Calculation Method: Minimum Curvature Design: 2S-12PB1 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 4,310.16 41.13 296.51 3,660.22 3,512.72 864.50 -1,716.26 5,930,836.76 479,272 19 0.35 -390.84 MWD+IFR-AK-CAZ-SC(5) 4,403.88 41.23 296.66 3,730.75 3,583.25 892.12 -1,771.45 5,930,864.51 479,217.08 0.15 -403.24 MWD+IFR-AK-CAZ-SC(5) 4,496.23 41.10 297.00 3,800.28 3,652.78 919.55 -1,825.69 5,930,892.08 479,162.91 0.28 -415.70 MWD+IFR-AK-CAZ-SC(5) 4,590.24 41.16 296.38 3,871.09 3,723.59 947.33 -1,880.94 5,930,919.99 479,107.74 0.44 -428.23 MWD+IFR-AK-CAZ-SC(5) 4,684.70 41.05 294.14 3,942.27 3,794.77 973.83 -1,937.09 5,930,946.63 479,051.66 1.56 -439.29 MWD+IFR-AK-CAZ-SC(5) 4,777.22 41.15 291.95 4,011.99 3,864.49 997.63 -1,993.05 5,930,970.57 478,995.77 1.56 -447.80 MWD+IFR-AK-CAZ-SC(5) 4,870.35 41.16 291.07 4,082.11 3,934.61 1,020.10 -2,050.07 5,930,993.18 478,938.81 0.62 -454.75 MWD+IFR-AK-CAZ-SC(5) 4,963.26 40.95 289.29 4,152.18 4,004.68 1,041.15 -2,107.34 5,931,014.37 478,881.60 1.28 -460.26 MWD+IFR-AK-CAZ-SC(5) 5,057.57 41.04 289.86 4,223.36 4,075.86 1,061.88 -2,165.63 5,931,035.25 478,823.37 0.41 -465.19 MWD+IFR-AK-CAZ-SC(5) 5,149.75 41.11 289.10 4,292.85 4,145.35 1,082.08 -2,222.73 5,931,055.59 478,766.32 0.55 -469.92 MWD+IFR-AK-CAZ-SC(5) 5,242.58 41.69 287.83 4,362.48 4,214.98 1,101.52 -2,280.96 5,931,075.17 478,708.15 1.10 -473.63 MWD+IFR-AK-CAZ-SC(5) 5,336.87 41.74 286.36 4,432.87 4,285.37 1,119.96 -2,340.93 5,931,093.76 478,648.24 1.04 -475.92 MWD+IFR-AK-CAZ-SC(5) 5,430.89 39.77 283.85 4,504.09 4,356.59 1,135.98 -2,400.16 5,931,109.92 478,589.04 2.73 -476.06 MWD+IFR-AK-CAZ-SC(5) 5,524.43 39.54 279.92 4,576.12 4,428.62 1,148.27 -2,458.55 5,931,122.36 478,530.69 2.69 -472.82 MWD+IFR-AK-CAZ-SC(5) 5,616.10 40.41 275.08 4,646.38 4,498.88 1,155.93 -2,516.91 5,931,130.17 478,472.36 3.52 -465.12 MWD+IFR-AK-CAZ-SC(5) 5,711.57 41.16 271.40 4,718.68 4,571.18 1,159.44 -2,579.15 5,931,133.83 478,410.14 2.64 -452.40 MWD+IFR-AK-CAZ-SC(5) 5,801.70 41.65 268.75 4,786.29 4,638.79 1,159.51 -2,638.75 5,931,134.06 478,350.55 2.02 -437.04 MWD+IFR-AK-CAZ-SC(5) 5,897.45 42.64 266.18 4,857.29 4,709.79 1,156.65 -2,702.92 5,931,131.36 478,286.37 2.08 -417.67 MWD+IFR-AK-CAZ-SC(5) 5,987.96 43.46 263.66 4,923.43 4,775.93 1,151.17 -2,764.45 5,931,126.04 478,224.83 2.11 -396.46 MWD+IFR-AK-CAZ-SC(5) 6,081.91 44.83 260.75 4,990.85 4,843.35 1,142.28 -2,829.26 5,931,117.31 478,160.01 2.60 -371.09 MWD+IFR-AK-CAZ-SC(5) 6,175.61 45.61 258.17 5,056.86 4,909.36 1,130.11 -2,894.64 5,931,105.30 478,094.61 2.12 -342.41 MWD+IFR-AK-CAZ-SC(5) 6,270.28 45.50 255.51 5,123.16 4,975.66 1,114.72 -2,960.44 5,931,090.09 478,028.78 2.01 -310.52 MWD+IFR-AK-CAZ-SC(5) 6,362.71 44.98 251.45 5,188.25 5,040.75 1,096.08 -3,023.33 5,931,071.60 477,965.84 3.17 -276.23 MWD+IFR-AK-CAZ-SC(5) 6,456.17 44.56 248.02 5,254.61 5,107.11 1,073.29 -3,085.06 5,931,048.98 477,904.06 2.62 -238.25 MWD+IFR-AK-CAZ-SC(5) 6,548.26 44.41 244.38 5,320.32 5,172.82 1,047.27 -3,144.09 5,931,023.10 477,844.97 2.77 -197.83 MWD+IFR-AK-CAZ-SC(5) 6,642.77 44.99 241.13 5,387.51 5,240.01 1,016.83 -3,203.17 5,930,992.82 477,785.82 2.50 -153.14 MWD+IFR-AK-CAZ-SC(5) 6,735.94 45.10 238.50 5,453.35 5,305.85 983.69 -3,260.15 5,930,959.82 477,728.76 2.00 -106.38 MWD+IFR-AK-CAZ-SC(5) 6,828.03 46.36 236.47 5,517.63 5,370.13 948.23 -3,315.74 5,930,924.51 477,673.09 2.09 -57.75 MWD+IFR-AK-CAZ-SC(5) 6,919.42 47.82 235.25 5,579.85 5,432.35 910.66 -3,371.14 5,930,887.08 477,617.60 1.87 -7.12 MWD+IFR-AK-CAZ-SC(5) 7,014.41 49.44 232.79 5,642.64 5,495.14 868.78 -3,428.80 5,930,845.34 477,559.84 2.59 48.27 MWD+IFR-AK-CAZ-SC(5) 7,107.32 51.63 229.74 5,701.70 5,554.20 823.88 -3,484.72 5,930,800.60 477,503.82 3.46 106.10 MWD+IFR-AK-CAZ-SC(5) 7,199.97 54.26 226.16 5,757.53 5,610.03 774.35 -3,539.58 5,930,751.20 477,448.84 4.19 168.15 MWD+IFR-AK-CAZ-SC(5) 7,291.54 56.22 223.31 5,809.74 5,662.24 720.90 -3,592.50 5,930,697.90 477,395.79 3.33 233.47 MWD+IFR-AK-CAZ-SC(5) 7,385.34 59.21 219.58 5,859.85 5,712.35 661.46 -3,644.93 5,930,638.59 477,343.21 4.63 304.46 MWD+IFR-AK-CAZ-SC(5) 7,478.18 61.89 216.43 5,905.50 5,758.00 597.76 -3,694.67 5,930,575.02 477,293.31 4.13 378.86 MWD+IFR-AK-CAZ-SC(5) 7,572.51 64.12 213.35 5,948.33 5,800.83 528.81 -3,742.72 5,930,506.21 477,245.10 3.75 457.89 MWD+IFR-AK-CAZ-SC(5) 7,664.72 66.51 211.43 5,986.84 5,839.34 458.07 -3,787.59 5,930,435.58 477,200.06 3.21 537.84 MWD+IFR-AK-CAZ-SC(5) 7,759.36 68.37 210.47 6,023.14 5,875.64 383.12 -3,832.53 5,930,360.75 477,154.93 2.18 621.87 MWD+IFR-AK-CAZ-SC(5) 7,851.53 69.77 209.79 6,056.07 5,908.57 308.66 -3,875.74 5,930,286.41 477,111.54 1.67 704.97 MWD+IFR-AK-CAZ-SC(5) 7,941.56 71.17 208.49 6,086.17 5,938.67 234.55 -3,917.05 5,930,212.41 477,070.05 2.07 787.25 MWD+IFR-AK-CAZ-SC(5) 7/5/2016 11:54:52AM Page 4 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-12 Project: Kuparuk River Unit TVD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12PB1 Survey Calculation Method: Minimum Curvature Design: 2S-12PB 1 Database: OAKE DM P2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,035.83 71.70 207.14 6,116.18 5,968.68 155.51 -3,958.74 5,930,133.49 477,028.15 1.47 874.38 MWD+IFR-AK-CAZ-SC(5) 8,130.07 72.38 206.98 6,145.24 5,997.74 75.68 -3,999.53 5,930,053.77 476,987.17 0.74 962.05 MWD+IFR-AK-CAZ-SC(5) 8,178.05 73.11 207.03 6,159.47 6,011.97 34.86 -4,020.33 5,930,013.00 476,966.27 1.52 1,006.87 MWD+IFR-AK-CAZ-SC(5) 8,239.00 73.17 207.89 6,177.15 6,029.65 -16.90 -4,047.23 5,929,961.32 476,939.24 1.36 1,063.83 NOT an Actual Survey 7-518"x 9-7/8-11" 8,241.66 73.17 207.93 6,177.92 6,030.42 -19.15 -4,048.42 5,929,959.07 476,938.05 1.36 1,066.31 MWD+IFR-AK-CAZ-SC(6) 8,295.57 74.04 207.29 6,193.14 6,045.64 -64.98 -4,072.39 5,929,913.31 476,913.96 1.98 1,116.78 MWD+IFR-AK-CAZ-SC(6) 8,389.70 75.24 207.40 6,218.07 6,070.57 -145.60 -4,114.08 5,929,832.80 476,872.07 1.28 1,205.44 MWD+IFR-AK-CAZ-SC(6) 8,483.50 77.12 206.58 6,240.48 6,092.98 -226.76 -4,155.42 5,929,751.75 476,830.54 2.18 1,294.54 MWD+IFR-AK-CAZ-SC(6) 8,579.36 78.59 204.50 6,260.65 6,113.15 -311.32 -4,195.81 5,929,667.31 476,789.93 2.62 1,386.66 MWD+IFR-AK-CAZ-SC(6) 8,674.42 81.25 202.65 6,277.28 6,129.78 -397.09 -4,233.23 5,929,581.64 476,752.30 3.39 1,479.20 MWD+IFR-AK-CAZ-SC(6) 8,709.96 83,20 202.53 6,282.09 6,134.59 -429.60 -4,246.76 5,929,549.16 476,738.69 5.50 1,514.10 MWD+IFR-AK-CAZ-SC(6) 8,769.41 86.34 201.25 6,287.51 6,140.01 -484.52 -4,268.83 5,929,494.30 476,716.49 5.70 1,572.87 MWD+IFR-AK-CAZ-SC(6) 8,865.18 90.31 199.67 6,290.31 6,142.81 -574.19 -4,302.28 5,929,404.72 476,682.81 4.46 1,668.14 MWD+IFR-AK-CAZ-SC(6) 8,959.33 91.21 197.63 6,289.06 6,141.56 -663.39 -4,332.38 5,929,315.62 476,652.49 2.37 1,762.09 MWD+IFR-AK-CAZ-SC(6) 9,053.67 90.90 197.27 6,287.32 6,139.82 -753.37 -4,360.67 5,929,225.71 476,623.98 0.50 1,856.32 MWD+IFR-AK-CAZ-SC(6) 9,147.99 89.80 195.50 6,286.75 6,139.25 -843.85 -4,387.27 5,929,135.31 476,597.15 2.21 1,950.61 MWD+IFR-AK-CAZ-SC(6) 9,242.15 90.04 196.35 6,286.88 6,139.38 -934.40 -4,413.11 5,929,044.84 476,571.09 0.94 2,044.76 MWD+IFR-AK-CAZ-SC(6) 9,336.56 89.63 191.88 6,287.15 6,139.65 -1,025.93 -4,436.13 5,928,953.37 476,547.84 4,75 2,139.13 MWD+IFR-AK-CAZ-SC(6) 9,430.98 89.56 190.13 6,287.82 6,140.32 -1,118.61 -4,454.15 5,928,860.74 476,529.59 1.85 2,233.31 MWD+IFR-AK-CAZ-SC(6) 9,524.48 89.60 190.07 6,288.50 6,141.00 -1,210.66 -4,470.55 5,928,768.75 476,512.96 0.08 2,326.47 MWD+IFR-AK-CAZ-SC(6) 9,619.64 89.56 190.91 6,289.20 6,141.70 -1,304.23 -4,487.87 5,928,675.23 476,495.40 0.88 2,421.33 MWD+IFR-AK-CAZ-SC(6) 9,713.52 89.60 191.82 6,289.89 6,142.39 -1,396.26 -4,506.37 5,928,583.25 476,476.68 0.97 2,515.02 MWD+IFR-AK-CAZ-SC(6) 9,812.63 89.43 195.05 6,290.73 6,143.23 -1,492.64 -4,529.39 5,928,486.94 476,453.41 3.26 2,614.08 MWD+IFR-AK-CAZ-SC(6) 9,902.41 89.49 194.81 6,291.57 6,144.07 -1,579.39 -4,552.52 5,928,400.26 476,430.07 0.28 2,703.85 MWD+IFR-AK-CAZ-SC(6) 9,996.87 89.49 194.17 6,292.42 6,144.92 -1,670.84 -4,576.16 5,928,308.88 476,406.20 0.68 2,798.30 MWD+IFR-AK-CAZ-SC(6) 10,091.64 89.49 194.22 6,293.26 6,145.76 -1,762.71 -4,599.40 5,928,217.07 476,382.74 0.05 2,893.06 MWD+IFR-AK-CAZ-SC(6) 10,187.06 89.56 193.29 6,294.05 6,146.55 -1,855.39 -4,622.08 5,928,124.46 476,359.82 0.98 2,988.45 MWD+IFR-AK-CAZ-SC(6) 10,282.04 91.01 192.95 6,293.58 6,146.08 -1,947.89 -4,643.64 5,928,032.03 476,338.03 1.57 3,083.38 MWD+IFR-AK-CAZ-SC(6) 10,376.98 90.97 192.27 6,291.94 6,144.44 -2,040.52 -4,664.37 5,927,939.46 476,317.07 0.72 3,178.22 MWD+IFR-AK-CAZ-SC(6) 10,470.97 91.28 192.53 6,290.09 6,142.59 -2,132.30 -4,684.54 5,927,847.74 476,296.67 0.43 3,272.10 MWD+IFR-AK-CAZ-SC(6) 10,565.39 92.13 192.20 6,287.28 6,139.78 -2,224.49 -4,704.75 5,927,755.61 476,276.23 0.97 3,366.37 MWD+IFR-AK-CAZ-SC(6) 10,660.00 92.41 192.68 6,283.53 6,136.03 -2,316.81 -4,725.12 5,927,663.35 476,255.63 0.59 3,460.82 MWD+IFR-AK-CAZ-SC(6) 10,756.09 92.55 192.35 6,279.38 6,131.88 -2,410.53 -4,745.92 5,927,569.70 476,234.59 0.37 3,556.72 MWD+IFR-AK-CAZ-SC(6) 10,849.95 92.38 194.56 6,275.34 6,127.84 -2,501.72 -4,767.74 5,927,478.57 476,212.55 2.36 3,650.46 MWD+IFR-AK-CAZ-SC(6) 10,943.62 90.68 195.88 6,272.84 6,125.34 -2,592.07 -4,792.32 5,927,388.29 476,187.74 2.30 3,744.09 MWD+IFR-AK-CAZ-SC(6) 11,039.03 91.11 194.41 6,271.35 6,123.85 -2,684.15 -4,817.24 5,927,296.28 476,162.59 1.61 3,839.48 MWD+IFR-AK-CAZ-SC(6) 11,132.17 91,86 194.02 6,268.93 6,121.43 -2,774.41 -4,840.11 5,927,206.09 476,139.50 0.91 3,932.58 MWD+IFR-AK-CAZ-SC(6) 11,179.20 92.00 191.04 6,267.35 6,119.85 -2,820.28 -4,850.30 5,927,160.24 476,129.19 6.34 3,979.54 MWD+IFR-AK-CAZ-SC(7) 11,272.58 92.03 191.92 6,264.07 6,116.57 -2,911.74 -4,868.88 5,927,068.85 476,110.39 0.94 4,072.68 MWD+IFR-AK-CAZ-SC(7) 7/5/2016 11:54:52AM Page 5 COMPASS 5000.1 Build 74 • • Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-12 Project: Kuparuk River Unit TVD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12PB1 Survey Calculation Method: Minimum Curvature Design: 2S-12PB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +Ni-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,364.13 92.57 192.45 6,260.39 6,112.89 -3,001.15 -4,888.19 5,926,979.49 476,090.86 0.83 4,164.05 MWD+IFR-AK-CAZ-SC(7) I, 11,460.58 90.62 195.42 6,257.71 6,110.21 -3,094.71 -4,911.40 5,926,886.00 476,067.41 3.68 4,260.43 MWD+IFR-AK-CAZ-SC(7) 11,553.43 87.96 196.50 6,258.86 6,111.36 -3,183.97 -4,936.93 5,926,796.82 476,041.66 3.09 4,353.25 MWD+IFR-AK-CAZ-SC(7) 11,647.75 87.91 199.17 6,262.26 6,114.76 -3,273.69 -4,965.79 5,926,707.18 476,012.57 2.83 4,447.38 MWD+IFR-AK-CAZ-SC(7) 11,741.48 85.37 198.23 6,267.75 6,120.25 -3,362.31 -4,995.79 5,926,618.64 475,982.35 2.89 4,540.75 MWD+IFR-AK-CAZ-SC(7) 11,836.99 87.10 198.18 6,274.02 6,126.52 -3,452.84 -5,025.56 5,926,528.19 475,952.35 1.81 4,635.90 MWD+IFR-AK-CAZ-SC(7) • 11,930.46 92.12 194.94 6,274.66 6,127.16 -3,542.39 -5,052.19 5,926,438.72 475,925.50 6.39 4,729.29 MWD+IFR-AK-CAZ-SC(7) • 12,024.65 94.99 192.86 6,268.82 6,121.32 -3,633.63 -5,074.77 5,926,347.55 475,902.69 3.76 4,823.27 MWD+IFR-AK-CAZ-SC(7) 12,119.05 95.19 192.42 6,260.44 6,112.94 -3,725.38 -5,095.35 5,926,255.86 475,881.89 0.51 4,917.21 MWD+IFR-AK-CAZ-SC(7) 12,212.25 95.11 193.25 6,252.08 6,104.58 -3,815.88 -5,115.97 5,926,165.42 475,861.04 0.89 5,009.97 MWD+IFR-AK-CAZ-SC(7) 12,303.00 95.11 193.25 6,243.99 6,096.49 -3,903.87 -5,136.69 5,926,077.49 475,840.11 0.00 5,100.32 PROJECTED to TD • Final Definitive Survey Verified and Signed-off All targets and'or well position objectives have been achieved. L Yes L No I have checked to the best of my ability that the following data is correct: Li Surface Coordinates L7 Declination & Convergence GRS Survey Corrections j] Survey Tool Codes Digitalh signedM YincentCsara DN:rn-Vmcent Gnra. Vincent O s a ra Schlumberger.w=5d9umbe pec. einaiknearaosibrogrt c.=us SLB DE: Dale 2016.470512:13:07-0500' Client Representative: Daniel Bearden .� _.. 05-1ul-2016 Date: 7/5/2016 11.54:52AM Page 6 COMPASS 5000.1 Build 74 21 6074 27 390 RECEIVED JUL 182016 FINAL AQGCC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad 2S-12PB1 2S-12PB1 Definitive Survey Report 05 July, 2016 NAD 83 • i Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-12 Project: Kuparuk River Unit TVD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12PB1 Survey Calculation Method: Minimum Curvature Design: 2S-12PB1 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-12 Well Position +N/-S 0.00 usft Northing: 5,929,717.61 usft Latitude: 70°13'10.259 N +EI-W 0.00 usft Easting: 1,621,019.42 usft Longitude: 150°9'23.362 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore 2S-12PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2016 6/20/2016 17.97 80.85 57,536 Design 2S-12PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 27.50 0.00 0.00 195.00 Survey Program Date 7/5/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 100.00 975.00 2S-12 Srvy 1-SLB_NSG+BATTERY(2S GYD-GC-SS Gyrodata gyro single shots 6/9/2016 8:37:5 1,013.91 2,787.47 2S-12 Srvy 2-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/8/2016 10:02:2 2,815.78 2,815.78 2S-12 Srvy 3-SLB_INC+Filler(2S-12PB INC+TREND Inclinometer+known azi trend 6/13/2016 9:29: 2,908.52 4,219.12 2S-12 Srvy 4-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/13/2016 9:34:. 4,310.16 8,178.05 2S-12 Srvy 5-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/15/2016 9:10: 8,241.66 11,132.17 2S-12 Srvy 6-SLB_MWD+GMAG(2S-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/23/2016 1:52: 11,179.20 12,212.25 2S-12PB1 Srvy 7-SLB_MWD+GMAG(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/27/2016 8:40: 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 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,929,717.61 1,621,019.42 0.00 0.00 UNDEFINED 100.00 0.29 190.76 100.00 -47.50 -0.18 -0.03 5,929,717.43 1,621,019.39 0.40 0.18 GYD-GC-SS(1) 200.00 0.41 190.63 200.00 52.50 -0.78 -0.15 5,929,716.83 1,621,019.27 0.12 0.79 GYD-GC-SS(1) 300.00 0.45 195.47 299.99 152.49 -1.51 -0.32 5,929,716.10 1,621,019.10 0.05 1.54 GYD-GC-SS(1) 400.00 1.00 335.77 399.99 252.49 -1.09 -0.78 5,929,716.51 1,621,018.64 1.38 1.26 GYD-GC-SS(1) 500.00 2.69 342.00 499.94 352.44 1.93 -1.86 5,929,719.54 1,621,017.56 1.70 -1.39 GYD-GC-SS(1) 600.00 2.85 339.41 599.82 452.32 6.49 -3.46 5,929,724.11 1,621,015.98 0.20 -5.38 GYD-GC-SS(1) 700.00 5.59 337.49 699.54 552.04 13.32 -6.20 5,929,730.94 1,621,013.25 2.74 -11.26 GYD-GC-SS(1) 800.00 6.31 336.02 799.00 651.50 22.84 -10.30 5,929,740.47 1,621,009.18 0.74 -19.40 GYD-GC-SS(1) 7/5/2016 10:27:17AM Page 2 COMPASS 5000.1 Build 74 • Schlum rge r S be Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-12 Project: Kuparuk River Unit TVD Reference: 2S-12 actual©147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12PB1 Survey Calculation Method: Minimum Curvature Design: 2S-12 P B 1 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) (°/100') (ft) Survey Tool Name 900.00 8.69 329.19 898.14 750.64 34.35 -16.41 5,929,752.00 1,621,003.11 2.54 -28.94 GYD-GC-SS(1) 975.00 10.53 326.13 972.08 824.58 44.91 -23.13 5,929,762.57 1,620,996.41 2.55 -37.39 GYD-GC-SS(1) 1,013.91 11.75 326.29 1,010.26 862.76 51.16 -27.31 5,929,768.83 1,620,992.25 3.14 -42.35 MWD+IFR-AK-CAZ-SC(2) 1,107.62 13.67 325.67 1,101.67 954.17 68.24 -38.85 5,929,785.94 1,620,980.75 2.05 -55.86 MWD+IFR-AK-CAZ-SC(2) 1,200.42 16.08 324.50 1,191.35 1,043.85 87.76 -52.50 5,929,805.49 1,620,967.16 2.62 -71.18 MWD+IFR-AK-CAZ-SC(2) 1,292.50 19.08 320.32 1,279.13 1,131.63 109.73 -69.52 5,929,827.51 1,620,950.19 3.53 -88.00 MWD+IFR-AK-CAZ-SC(2) 1,386.06 19.77 318.96 1,367.36 1,219.86 133.44 -89.67 5,929,851.26 1,620,930.10 0.88 -105.68 MWD+IFR-AK-CAZ-SC(2) 1,479.50 20.24 316.88 1,455.16 1,307.66 157.15 -111.09 5,929,875.03 1,620,908.74 0.91 -123.05 MWD+IFR-AK-CAZ-SC(2) 1,572.66 24.30 307.63 1,541.38 1,393.88 180.64 -137.31 5,929,898.58 1,620,882.59 5.75 -138.94 MWD+IFR-AK-CAZ-SC(2) 1,665.16 27.66 303.44 1,624.53 1,477.03 204.10 -170.31 5,929,922.12 1,620,849.65 4.14 -153.06 MWD+IFR-AK-CAZ-SC(2) 1,756.86 29.76 300.84 1,704.95 1,557.45 227.50 -207.62 5,929,945.61 1,620,812.41 2.66 -166.01 MWD+IFR-AK-CAZ-SC(2) 1,849.84 32.90 296.17 1,784.38 1,636.88 250.47 -250.11 5,929,968.70 1,620,769.98 4.27 -177.21 MWD+IFR-AK-CAZ-SC(2) 1,943.50 35.44 294.84 1,861.87 1,714.37 273.10 -297.59 5,929,991.45 1,620,722.56 2.83 -186.78 MWD+IFR-AK-CAZ-SC(2) 2,037.33 37.15 294.42 1,937.49 1,789.99 296.25 -348.08 5,930,014.72 1,620,672.14 1.84 -196.06 MWD+IFR-AK-CAZ-SC(2) 2,130.01 38.06 294.03 2,010.91 1,863.41 319.45 -399.66 5,930,038.05 1,620,620.63 1.01 -205.13 MWD+IFR-AK-CAZ-SC(2) 2,222.77 38.76 292.95 2,083.60 1,936.10 342.42 -452.51 5,930,061.15 1,620,567.84 1.05 -213.63 MWD+IFR-AK-CAZ-SC(2) 2,314.68 39.96 293.82 2,154.66 2,007.16 365.56 -506.01 5,930,084.42 1,620,514.41 1.44 -222.14 MWD+IFR-AK-CAZ-SC(2) 2,409.01 41.18 294.41 2,226.31 2,078.81 390.62 -562.00 5,930,109.63 1,620,458.49 1.36 -231.86 MWD+IFR-AK-CAZ-SC(2) 2,502.49 40.81 294.01 2,296.87 2,149.37 415.77 -617.93 5,930,134.92 1,620,402.63 0.49 -241.67 MWD+IFR-AK-CAZ-SC(2) 2,596.33 40.61 293.99 2,368.00 2,220.50 440.67 -673.84 5,930,159.96 1,620,346.78 0.21 -251.25 MWD+IFR-AK-CAZ-SC(2) 2,688.67 40.56 293.51 2,438.13 2,290.63 464.86 -728.83 5,930,184.29 1,620,291.87 0.34 -260.39 MWD+IFR-AK-CAZ-SC(2) 2,787.47 40.93 290.93 2,512.99 2,365.49 489.24 -788.51 5,930,208.82 1,620,232.25 1.74 -268.48 MWD+IFR-AK-CAZ-SC(2) 2,815.78 41.16 291.00 2,534.34 2,386.84 495.89 -805.87 5,930,215.51 1,620,214.91 0.83 -270.42 INC+TREND(3) 2,845.00 41.18 291.36 2,556.33 2,408.83 502.84 -823.81 5,930,222.51 1,620,196.99 0.82 -272.49 NOT an Actual Survey ) 10 3/4"x 13 1/2" 2,908.52 41.23 292.15 2,604.12 2,456.62 518.35 -862.67 5,930,238.12 1,620,158.17 0.82 -277.41 MWD+IFR-AK-CAZ-SC(4) 3,003.43 41.26 291.42 2,675.49 2,527.99 541.57 -920.78 5,930,261.49 1,620,100.13 0.51 -284.80 MWD+IFR-AK-CAZ-SC(4) 3,093.72 41.20 290.99 2,743.39 2,595.89 563.10 -976.25 5,930,283.15 1,620,044.72 0.32 -291.24 MWD+IFR-AK-CAZ-SC(4) 3,189.59 41.13 290.66 2,815.56 2,668.06 585.53 -1,035.24 5,930,305.74 1,619,985.80 0.24 -297.64 MWD+IFR-AK-CAZ-SC(4) 3,281.31 41.07 290.18 2,884.68 2,737.18 606.57 -1,091.74 5,930,326.92 1,619,929.35 0.35 -303.34 MWD+IFR-AK-CAZ-SC(4) 3,377.84 41.03 290.47 2,957.48 2,809.98 628.59 -1,151.19 5,930,349.09 1,619,869.97 0.20 -309.22 MWD+IFR-AK-CAZ-SC(4) 3,472.80 41.11 291.43 3,029.07 2,881.57 650.89 -1,209.45 5,930,371.54 1,619,811.77 0.67 -315.69 MWD+IFR-AK-CAZ-SC(4) 3,566.08 41.08 291.66 3,099.37 2,951.87 673.41 -1,266.48 5,930,394.20 1,619,754.81 0.17 -322.67 MWD+IFR-AK-CAZ-SC(4) 3,659.12 41.06 290.95 3,169.51 3,022.01 695.62 -1,323.43 5,930,416.55 1,619,697.92 0.50 -329.39 MWD+IFR-AK-CAZ-SC(4) 3,751.52 41.08 291.22 3,239.17 3,091.67 717.46 -1,380.07 5,930,438.53 1,619,641.34 0.19 -335.82 MWD+IFR-AK-CAZ-SC(4) 3,844.94 41.07 291.35 3,309.60 3,162.10 739.74 -1,437.26 5,930,460.96 1,619,584.21 0.09 -342.54 MWD+IFR-AK-CAZ-5C(4) 3,935.36 41.02 291.91 3,377.79 3,230.29 761.62 -1,492.45 5,930,482.99 1,619,529.08 0.41 -349.40 MWD+IFR-AK-CAZ-SC(4) 4,029.68 41.15 293.45 3,448.88 3,301.38 785.52 -1,549.64 5,930,507.03 1,619,471.96 1.08 -357.68 MW0+IFR-AK-CAZ-SC(4) 4,122.40 41.05 295.09 3,518.76 3,371.26 810.57 -1,605.20 5,930,532.22 1,619,416.47 1.17 -367.50 MWD+IFR-AK-CAZ-SC(4) 4,219.12 41.14 296.02 3,591.65 3,444.15 838.00 -1,662.56 5,930,559.79 1,619,359.19 0.64 -379.14 MWD+IFR-AK-CAZ-SC(4) 7/5/2016 10:27:17AM Page 3 COMPASS 5000.1 Build 74 • 0 Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-12 Project: Kuparuk River Unit TVD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12PB1 Survey Calculation Method: Minimum Curvature Design: 2S-12PB1 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 4,310.16 41.13 296,51 3,660.22 3,512.72 864.50 -1,716.26 5,930,586.43 1,619,305.56 0.35 -390.84 MWD+IFR-AK-CAZ-SC(5) 4,403.88 41.23 296.66 3,730.75 3,583.25 892.12 -1,771.45 5,930,614.18 1,619,250.45 0.15 -403.24 MWD+IFR-AK-CAZ-SC(5) 4,496.23 41.10 297.00 3,800.28 3,652.78 919.55 -1,825.69 5,930,641.76 1,619,196.29 0.28 -415.70 MWD+IFR-AK-CAZ-SC(5) 4,590.24 41.16 296.38 3,871.09 3,723.59 947.33 -1,880.94 5,930,669.67 1,619,141.11 0.44 -428.23 MWD+IFR-AK-CAZ-SC(5) 4,684.70 41.05 294.14 3,942.27 3,794.77 973.83 -1,937.09 5,930,696.31 1,619,085.03 1.56 -439.29 MWD+IFR-AK-CAZ-SC(5) 4,777.22 41.15 291.95 4,011.99 3,864.49 997.63 -1,993.05 5,930,720.25 1,619,029.14 1.56 -447.80 MWD+IFR-AK-CAZ-SC(5) 4,870.35 41.16 291.07 4,082.11 3,934.61 1,020.10 -2,050.07 5,930,742.87 1,618,972.18 0.62 -454.75 MWD+IFR-AK-CAZ-SC(5) 4,963.26 40.95 289.29 4,152.18 4,004.68 1,041.15 -2,107.34 5,930,764.07 1,618,914.97 1.28 -460.26 MWD+IFR-AK-CAZ-SC(5) 5,057.57 41.04 289.86 4,223.36 4,075.86 1,061.88 -2,165.63 5,930,784.94 1,618,856.74 0.41 -465.19 MWD+IFR-AK-CAZ-SC(5) 5,149.75 41.11 289.10 4,292.85 4,145.35 1,082.08 -2,222.73 5,930,805.28 1,618,799.70 0.55 -469.92 MWD+IFR-AK-CAZ-SC(5) 5,242.58 41.69 287.83 4,362.48 4,214.98 1,101.52 -2,280.96 5,930,824.87 1,618,741.53 1.10 -473.63 MWD+IFR-AK-CAZ-SC(5) 5,336.87 41.74 286.36 4,432.87 4,285.37 1,119.96 -2,340.93 5,930,843.46 1,618,681.62 1.04 -475.92 MWD+IFR-AK-CAZ-SC(5) 5,430.89 39.77 283.85 4,504.09 4,356.59 1,135.98 -2,400.16 5,930,859.63 1,618,622.43 2.73 -476.06 MWD+IFR-AK-CAZ-SC(5) 5,524.43 39.54 279.92 4,576.12 4,428.62 1,148.27 -2,458.55 5,930,872.07 1,618,564,08 2.69 -472.82 MWD+IFR-AK-CAZ-SC(5) 5,616.10 40.41 275.08 4,646.38 4,498.88 1,155.93 -2,516.91 5,930,879.88 1,618,505.75 3.52 -465.12 MWD+IFR-AK-CAZ-SC(5) 5,711.57 41.16 271.40 4,718.68 4,571.18 1,159.44 -2,579.15 5,930,883.55 1,618,443.52 2.64 -452.40 MWD+IFR-AK-CAZ-SC(5) 5,801.70 41.65 268.75 4,786.29 4,638.79 1,159.51 -2,638.75 5,930,883.78 1,618,383.93 2.02 -437.04 MWD+IFR-AK-CAZ-SC(5) 5,897.45 42.64 266.18 4,857.29 4,709.79 1,156.65 -2,702,92 5,930,881.09 1,618,319.75 2.08 -417.67 MWD+IFR-AK-CAZ-SC(5) 5,987.96 43.46 263.66 4,923.43 4,775.93 1,151.17 -2,764.45 5,930,875.76 1,618,258.22 2.11 -396.46 MWD+IFR-AK-CAZ-SC(5) 6,081.91 44.83 260.75 4,990.85 4,843.35 1,142.28 -2,829.26 5,930,867.04 1,618,193.39 2.60 -371.09 MWD+IFR-AK-CAZ-SC(5) 6,175.61 45.61 258.17 5,056.86 4,909.36 1,130.11 -2,894.64 5,930,855.03 1,618,127,99 2.12 -342.41 MWD+IFR-AK-CAZ-SC(5) 6,270.28 45.50 255.51 5,123.16 4,975.66 1,114.72 -2,960.44 5,930,839.82 1,618,062.16 2.01 -310.52 MWD+IFR-AK-CAZ-SC(5) 6,362.71 44.98 251.45 5,188.25 5,040.75 1,096.08 -3,023.33 5,930,821.34 1,617,999.22 3.17 -276.23 MWD+IFR-AK-CAZ-SC(5) 6,456.17 44.56 248.02 5,254.61 5,107.11 1,073.29 -3,085.06 5,930,798.72 1,617,937.43 2.62 -238.25 MWD+IFR-AK-CAZ-SC(5) 6,548.26 44.41 244.38 5,320.32 5,172.82 1,047.27 -3,144.09 5,930,772.84 1,617,878.35 2.77 -197.83 MWD+IFR-AK-CAZ-SC(5) 6,642.77 44.99 241.13 5,387.51 5,240.01 1,016.83 -3,203.17 5,930,742.56 1,617,819.20 2.50 -153.14 MWD+1FR-AK-CAZ-SC(5) 6,735.94 45.10 238.50 5,453.35 5,305.85 983.69 -3,260.15 5,930,709.57 1,617,762.14 2.00 -106.38 MWD+IFR-AK-CAZ-SC(5) 6,828.03 46.36 236.47 5,517.63 5,370.13 948.23 -3,315.74 5,930,674.26 1,617,706.46 2.09 -57.75 MWD+IFR-AK-CAZ-SC(5) 6,919.42 47.82 235.25 5,579.85 5,432.35 910.66 -3,371.14 5,930,636.84 1,617,650.97 1.87 -7.12 MWD+IFR-AK-CAZ-SC(5) 7,014.41 49.44 232.79 5,642.64 5,495.14 868.78 -3,428.80 5,930,595.10 1,617,593.21 2.59 48.27 MWD+IFR-AK-CAZ-SC(5) 7,107.32 51.63 229.74 5,701.70 5,554.20 823.88 -3,484.72 5,930,550.36 1,617,537.18 3.46 106.10 MWD+IFR-AK-CAZ-SC(5) 7,199.97 54.26 226.16 5,757.53 5,610.03 774.35 -3,539.58 5,930,500.97 1,617,482.20 4.19 168.15 MWD+IFR-AK-CAZ-SC(5) 7,291.54 56.22 223.31 5,809.74 5,662.24 720.90 -3,592.50 5,930,447.67 1,617,429.15 3.33 233.47 MWD+IFR-AK-CAZ-SC(5) 7,385.34 59.21 219.58 5,859.85 5,712.35 661.46 -3,644.93 5,930,388.36 1,617,376.57 4.63 304.46 MWD+IFR-AK-CAZ-SC(5) 7,478.18 61.89 216.43 5,905.50 5,758.00 597.76 -3,694.67 5,930,324.79 1,617,326.67 4.13 378.86 MWD+IFR-AK-CAZ-SC(5) 7,572.51 64.12 213.35 5,948.33 5,800.83 528.81 -3,742.72 5,930,255.98 1,617,278.45 3.75 457.89 MWD+IFR-AK-CAZ-SC(5) 7,664.72 66.51 211.43 5,986.84 5,839.34 458.07 -3,787.59 5,930,185.36 1,617,233.40 3.21 537.84 MWD+IFR-AK-CAZ-SC(5) 7,759.36 68.37 210.47 6,023.14 5,875.64 383.12 -3,832.53 5,930,110.53 1,617,188.28 2.18 621.87 MWD+IFR-AK-CAZ-SC(5) 7,851.53 69,77 209,79 6,056.07 5,908.57 308.66 -3,875.74 5,930,036.19 1,617,144,88 1,67 704.97 MWD+IFR-AK-CAZ-SC(5) 7,941.56 71.17 208.49 6,086.17 5,938.67 234.55 -3,917.05 5,929,962.20 1,617,103.38 2.07 787.25 MWD+IFR-AK-CAZ-SC(5) 7/5/2016 10:27:17AM Page 4 COMPASS 5000.1 Build 74 • • • Schlurnberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-12 Project: Kuparuk River Unit TVD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: 2S-12 actual @ 147.S0usft(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12PB1 Survey Calculation Method: Minimum Curvature Design: 2S-12PB1 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) (0/100') (ft) Survey Tool Name 8,035.83 71.70 207.14 6.116.18 5,968.68 155.51 -3,958.74 5,929,883.28 1,617,061.49 1.47 874.38 MWD+IFR-AK-CAZ-SC(5) 8,130.07 72.38 206.98 6,145.24 5,997.74 75.68 -3,999.53 5,929,803.56 1,617,020.50 0.74 962.05 MWD+IFR-AK-CAZ-SC(5) 8,178.05 73.11 207.03 6,159.47 6,011.97 34.86 -4,020.33 5,929,762.79 1,616,999.59 1.52 1,006.87 MWD+IFR-AK-CAZ-SC(5) 8,239.00 73.17 207.89 6,177.15 6,029.65 -16.90 -4,047.23 5,929,711.11 1,616,972.57 1.36 1.063.83 NOT an Actual Survey) 7-5/8"x 9-7/8-11" 8,241.66 73.17 207.93 6,177.92 6,030.42 -19.15 -4,048.42 5,929,708.86 1,616,971.37 1.36 1,066.31 MWD+IFR-AK-CAZ-SC(6) 8,295.57 74.04 207.29 6,193.14 6,045.64 -64.98 -4,072.39 5,929,663.10 1,616,947.28 1.98 1,116.78 MWD+IFR-AK-CAZ-SC(6) I 8,389.70 75.24 207.40 6,218.07 6,070.57 -145.60 -4,114.08 5,929,582.59 1,616,905.39 1.28 1,205.44 MWD+IFR-AK-CAZ-SC(6) 8,483.50 77.12 206.58 6,240.48 6,092.98 -226.76 -4,155.42 5,929,501.54 1,616,863.85 2.18 1,294.54 MWD+IFR-AK-CAZ-SC(6) 8,579.36 78.59 204.50 6,260.65 6,113.15 -311.32 -4,195.81 5,929,417.10 1,616,823.24 2.62 1,386.66 MWD+IFR-AK-CAZ-SC(6) 8,674.42 81.25 202.65 6,277.28 6,129.78 -397.09 -4,233.23 5,929,331.44 1,616,785.60 3.39 1,479.20 MWD+IFR-AK-CAZ-SC(6) 8,709.96 83.20 202.53 6,282.09 6,134.59 -429.60 -4,246.76 5,929,298.97 1,616,772.00 5.50 1,514.10 MWD+IFR-AK-CAZ-SC(6) 8,769.41 86.34 201.25 6,287.51 6,140.01 -484.52 -4,268.83 5,929,244.10 1,616,749.79 5.70 1,572.87 MWD+IFR-AK-CAZ-SC(6) 8,865.18 90.31 199.67 6,290.31 6,142.81 -574.19 -4,302.28 5,929,154.53 1,616,716.11 4.46 1,668.14 MWD+IFR-AK-CAZ-SC(6) 8,959.33 91.21 197.63 6,289.06 6,141.56 -663.39 -4,332.38 5,929,065.42 1,616,685.78 2.37 1,762.09 MWD+IFR-AK-CAZ-SC(6) 9,053.67 90.90 197.27 6,287.32 6,139.82 -753.37 -4,360.67 5,928,975.52 1,616,657.27 0.50 1,856.32 MWD+IFR-AK-CAZ-SC(6) 9,147.99 89.80 195.50 6,286.75 6,139.25 -843.85 -4,387.27 5,928,885.11 1,616,630.43 2.21 1,950.61 MWD+IFR-AK-CAZ-SC(6) 9,242.15 90.04 196.35 6,286.88 6,139.38 -934.40 -4,413.11 5,928,794.65 1,616,604.37 0.94 2,044.76 MWD+IFR-AK-CAZ-SC(6) . 9,336.56 89.63 191.88 6,287.15 6,139.65 -1,025.93 -4,436.13 5,928,703.18 1,616,581.12 4.75 2,139.13 MWD+IFR-AK-CAZ-SC(6) 9,430.98 89.56 190.13 6,287.82 6,140.32 -1,118.61 -4,454.15 5,928,610.56 1,616,562.86 1.85 2,233.31 MWD+IFR-AK-CAZ-SC(6) 9,524.48 89.60 190.07 6,288.50 6,141.00 -1,210.66 -4,470.55 5,928,518.56 1,616,546.23 0.08 2,326.47 MWD+IFR-AK-CAZ-SC(6) 9,619.64 89.56 190.91 6,289.20 6,141.70 -1,304.23 -4,487.87 5,928,425.05 1,616,528.66 0.88 2,421.33 MWD+IFR-AK-CAZ-SC(6) 9,713.52 89.60 191.82 6,289.89 6,142.39 -1,396.26 -4,506.37 5,928,333.07 1,616,509.93 0.97 2,515.02 MWD+IFR-AK-CAZ-SC(6) 9,812.63 89.43 195.05 6,290.73 6,143.23 -1,492.64 -4,529.39 5,928,236.76 1,616,486.66 3.26 2,614.08 MWD+IFR-AK-CAZ-SC(6) 9,902.41 89.49 194.81 6,291.57 6,144.07 -1,579.39 -4,552.52 5,928,150.08 1,616,463.31 0.28 2,703.85 MWD+IFR-AK-CAZ-SC(6) 9,996.87 89.49 194.17 6,292.42 6,144.92 -1,670.84 -4,576.16 5,928,058.70 1,616,439.44 0.68 2,798.30 MWD+IFR-AK-CAZ-SC(6) 10,091.64 89.49 194.22 6,293.26 6,145.76 -1,762.71 -4,599.40 5,927,966.89 1,616,415.97 0.05 2,893.06 MWD+IFR-AK-CAZ-SC(6) 10,187.06 89.56 193.29 6,294.05 6,146.55 -1,855.39 -4,622.08 5,927,874.28 1,616,393.05 0.98 2,988.45 MWD+IFR-AK-CAZ-SC(6) 10,282.04 91.01 192.95 6,293.58 6,146.08 -1,947.89 -4,643.64 5,927,781.85 1,616,371.25 1.57 3,083.38 MWD+IFR-AK-CAZ-SC(6) 10,376.98 90.97 192.27 6,291.94 6,144.44 -2,040.52 -4,664.37 5,927,689.28 1,616,350.29 0.72 3,178.22 MWD+IFR-AK-CAZ-SC(6) 10,470.97 91.28 192.53 6,290.09 6,142.59 -2,132.30 -4,684.54 5,927,597.56 1,616,329.88 0.43 3,272.10 MWD+IFR-AK-CAZ-SC(6) 10,565.39 92.13 192.20 6,287.28 6,139.78 -2,224.49 -4,704.75 5,927,505.43 1,616,309.44 0.97 3,366.37 MWD+IFR-AK-CAZ-SC(6) 10,660.00 92.41 192.68 6,283.53 6,136.03 -2,316.81 -4,725.12 5,927,413.18 1,616,288.84 0.59 3,460.82 MWD+IFR-AK-CAZ-SC(6) 10,756.09 92.55 192.35 6,279.38 6,131.88 -2,410.53 -4,745.92 5,927,319.52 1,616,267.79 0.37 3,556.72 MWD+IFR-AK-CAZ-SC(6) 10,849.95 92.38 194.56 6,275.34 6,127.84 -2,501.72 -4,767.74 5,927,228.40 1,616,245.74 2.36 3,650.46 MWD+IFR-AK-CAZ-SC(6) 10,943.62 90.68 195.88 6,272.84 6,125.34 -2,592.07 -4,792.32 5,927,138.12 1,616,220.93 2.30 3,744.09 MWD+IFR-AK-CAZ-SC(6) 11,039.03 91.11 194.41 6,271.35 6,123.85 -2,684.15 -4,817.24 5,927,046.11 1,616,195.78 1.61 3,839.48 MWD+IFR-AK-CAZ-SC(6) 11,132.17 91.86 194.02 6,268.93 6,121.43 -2,774.41 -4,840.11 5,926,955.92 1,616,172.68 0.91 3,932.58 MWD+IFR-AK-CAZ-SC(6) 11,179.20 92.00 191.04 6,267.35 6,119.85 -2,820.28 -4,850.30 5,926,910.08 1,616,162.37 6.34 3,979.54 MWD+IFR-AK-CAZ-SC(7) 11,272.58 92.03 191.92 6,264.07 6,116.57 -2,911.74 -4,868.88 5,926,818.68 1,616,143.56 0.94 4,072.68 MWD+IFR-AK-CAZ-SC(7) 7/5/2016 10:27:17AM Page 5 COMPASS 5000.1 Build 74 • • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-12 Project: Kuparuk River Unit TVD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: 2S-12 actual @ 147.50usft(Doyon 141) Well: 2S-12 North Reference: True Wellbore: 2S-12PB1 Survey Calculation Method: Minimum Curvature Design: 2S-12PB1 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) (°/100') (ft) Survey Tool Name 11,364.13 92.57 192.45 6,260.39 6,112.89 -3,001.15 -4,888.19 5,926,729.32 1,616,124.03 0.83 4,164.05 MWD+IFR-AK-CAZ-SC(7) 11,460.58 90.62 195.42 6,257.71 6,110.21 -3,094.71 -4,911.40 5,926,635.83 1,616,100.57 3.68 4,260.43 MWD+IFR-AK-CAZ-SC(7) 11,553.43 87.96 196.50 6,258.86 6,111.36 -3,183.97 -4,936.93 5,926,546.65 1,616,074.82 3.09 4,353.25 MWD+IFR-AK-CAZ-SC(7) 11,647.75 87.91 199.17 6,262.26 6,114.76 -3,273.69 -4,965.79 5,926,457.01 1,616,045.73 2.83 4,447.38 MWD+IFR-AK-CAZ-SC(7) 11,741.48 85.37 198.23 6,267.75 6,120.25 -3,362.31 -4,995.79 5,926,368.48 1,616,015.51 2.89 4,540.75 MWD+IFR-AK-CAZ-SC(7) 11,836.99 87.10 198.18 6,274.02 6,126.52 -3,452.84 -5,025.56 5,926,278.04 1,615,985.50 1.81 4,635.90 MWD+IFR-AK-CAZ-SC(7) 11,930.46 92.12 194.94 6,274.66 6,127.16 -3,542.39 -5,052.19 5,926,188.56 1,615,958.65 6.39 4,729.29 MWD+IFR-AK-CAZ-SC(7) 12,024.65 94.99 192.86 6,268.82 6,121.32 -3,633.63 -5,074.77 5,926,097.39 1,615,935.83 3.76 4,823.27 MWD+IFR-AK-CAZ-SC(7) 12,119.05 95.19 192.42 6,260.44 6,112.94 -3,725.38 -5,095.35 5,926,005.70 1,615,915.02 0.51 4,917.21 MWD+IFR-AK-CAZ-SC(7) 12,212.25 95.11 193.25 6,252.08 6,104.58 -3,815.88 -5,115.97 5,925,915.26 1,615,894.17 0.89 5,009.97 MWD+IFR-AK-CAZ-SC(7) 12,303.00 95.11 193.25 6,243.99 6,096.49 -3,903.87 -5,136.69 5,925,827.34 1,615,873.23 0.00 5,100.32 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. Lyes LNC I have checked to the best of my ability that the following data is correct: Li Surface Coordinates CJ Declination & Convergence L] GRS Survey Corrections f] Survey Tool Codes Digitally signed by Vincent Osan DN:cm-Vincent Osara Vincent O s a ra°_Sctdumberger ev'Schlumberger. emit=vosaratsslbwm c=US SLB DE: Date:2016.07.0512:1307 0e'00' Client Representative' Daniel Bearden .w.,, ,�r r.•.a Date: 05-Jul-2016 7/5/2016 10:27:17AM Page 6 COMPASS 5000.1 Build 74 p-,--9 2_/6 Loepp, Victoria T (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Tuesday,June 28,2016 12:52 PM To: Loepp,Victoria T(DOA) Subject: 2S-12 PTD 216-074 Follow Up Flag: Follow up Flag Status: Flagged Victoria We need to perform an open hole sidetrack in the 2S-12 production lateral due to drilling out of zone. We drilled to 12,303' MD,we will pull back and perform the OHST at+1- 11,900' MD in order to re-enter the Kuparuk A4 sand to drill to TD. What kind of paperwork should I submit to the AOGCC to make sure I'm in compliance? Thanks Scott 1 L OF � • Alaska Oil and Gas • ewP\ I%%, ,v THE STATE F ..t o f'® T AcKA Conservation Commission 333 West Seventh Avenue 41 '..2 Anchorage, Alaska 995W-3572 _ GOVERNOR BILL WALKER Main: 907.279.1433 O -*Q. 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-12 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-074 Surface Location: 3080.5' FNL, 1584.2' FEL, SEC. 17, T1ON, R8E,UM Bottomhole Location: 467.8' FNL, 2520.4' FEL, SEC. 30, T1ON, R8E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Pi� Cathy P. Foerster Chair DATED this 2 day of June, 2016. 'i T • MAY 3 1 2016STATE OF ALASKA �F.Ve 5 All OIL AND GAS CONSERVATION COMMON ED AOG CC PERMIT TO DRILL 20 AAC 25.005 la.Type of Work: 1 b.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp ❑ lc.Specify if well is proposed for: Drill ❑✓ 'Lateral ❑ Stratigraphic Test ❑ Development-Oil ❑., • Service- Winj ❑ Single Zone ❑✓ - Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket ❑� • Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska,Inc. • Bond No. 59-52-180 - KRU 2S-12 ^ 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 16,498' TVD: , 6,344 Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 3080.5'FNL, 1584.2'FEL,Sec 17,T1 ON,R8E,UM ADL025603,ADL025608 Kuparuk River Oil Pool . Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 3521.1'FNL,559.5'FEL,Sec18,T1ON,R8E,UM 2677,2681 6/11/2016 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 467.8'FNL,2520.4'FEL,Sec30,T1ON,R8E,UM • 5035 2585.16'from ADL380053 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 147.5 • 15.Distance to Nearest Well Open Surface: x-480,986.1' y-5,929,968.0' Zone-4 ' GL Elevation above MSL(ft): 120 to Same Pool: 1961.04'f/2S-08 16.Deviated wells: Kickoff depth: 500 feet ' 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 90 degrees , Downhole: 3660 ' Surface: 3032 • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5# H-40 Welded 80' 27' 27' 107' 107' pre-driven,cement to surface 13.5" 10.75" 45.5# L-80 Hydril 563 2837' 27' 27' 2864' 2569' 1224 sx 11 ppg lead&271 sx 15.8 ppg tail 9.875" 7.625" 29.7# L-80 Hydril 563 8247' 27' 27' 8274' 6177' 615 sx 1st stg,205 sx 2nd stg classG 6.75" 4.5" 12.6# L-80 IBTM 8398' 8100' 6124' 16498' 6344' N/A-liner 3.5" 9.3# L-80 Hydril 563 8073' 27' 27' 8100' 6124' N/A-tubing 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch Q Seabed Report ❑ Drilling Fluid Program ❑ Q X20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date ,.5 2 e?/^/ 22.I hereby certify that the foregoing is true and the procedure approved herein will not Scott Brunswick @ 263-4249 be deviated from without prior written approval. Contact scott.a.brunswickcop.com Email Printed Name G.L.Alvord Title Alaska Drilling Manager Signature , `,\ 6_ ( Phone 265-6120 Date 6-13( (z 0 i is Commission Use Only Permit to Drill API Number: Permit ApprovalSee cover letter for other Number: "C 1( ''v 'y 50- 101"••40?413- pp-CD Date: (p(a I,,..Q requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: RIS Other: Samples req'd: Yes ElNog] Mud log req'd:Yes❑ No[t]' sop fie-5/ to ,35-0 0 ns) 1 H2S measures: Yes E f No❑ Directional svy req'd:Yes atNo❑ it-n nvl a r �Jreyrr> tlY frS� fo 2500,519 / Spacing eption req'd: Yes❑ No 12 Inclination-only svy req'd:Yes❑ No IZ' Post initial injection MIT req'd:Yes❑ No❑ APPROVED BY Approved by: 9 ,h1-_ COMMISSIONER THE COMMISSION Date: 6 -2- g v 6/Z//6 -N (O 1 f'i4' 6f /6 Submit Form and Form 10-401 evised 11/2015) OliRIr tttA fionths from the date of approval(20 AAC 25.606(g)) Attachments in Duplicate Application for Permit to Drill,Well 2S-12 Saved:24-May-16 Post Office Box 100360 Anchorage,Alaska 99510-0360 ConocoPhillips Phone(907)265-6935 Email: Scott.A.Brunswick(c conocophillips.com May 24,2016 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill Well 2S-12,A Kuparuk A4 Sand Producer—Update for rig change to Doyon 141 / 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 June 116,2016.It is planned to use rig Doyon 141. / 2S-12 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+/-2,864' MD/2,569' TVD. The intermediate section will be drilled with 9-7/8"x 11"bit/Under Reamer and run 7-5/8"casing to 8,274'MD/6,177' TVD. The production hole will be drilled with 6-3/4"bit and run 4- 1/2"slotted liner to+/- 16,498'MD/6,344'TVD.An under reamer will be run in the production hole to enlarge the hole to 7-1/2"from the 7-5/8"casing shoe to+/- 100' MD into the Kuparuk sand to mitigate liner running trouble due to the shale. 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 Scott Brunswick at 263-4249 (scott.a.brunswick@conocophillips.com)or Chip Alvord at 265-6120. Sincerely, 11/ Scott Brunswick Drilling Engineer 11, i Application for Permit to Drill Document ' , • &Wesly • Kuparuk Well 2S-12 conacoP,up5 Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 2S-12 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill nmst 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 identrfiing the property and the property's owners and showing (A)the coordinates of the proposed location of the nett 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 3080.5' FNL, 1584.2' FEL, Sec 17, T1ON,R008E,UM NGS Coordinates RKB Elevation 147.5'AMSL Northings: 5,929,968.02' Eastings: 480,986.1' Pad Elevation 120'AMSL Location at surface Casing 2566.8' FNL,2405.1 FEL, Sec 17,T1ON,R008E,UM NGS Coordinates Measured Depth, RKB: 2,864' Northings: 5,930,483.69'Eastings: 480,165.03' Total Vertical Depth, RKB: 2,569' Total Vertical Depth, SS: 2,422' Location at intremediate 3091.1' FNL,395.9 FEL, Sec 18,T1ON,R008E,UM Casing NGS Coordinates Measured Depth, RKB: 8,274' Northings: 5,929,968.73'Eastings: 476,894.83' Total Vertical Depth, RKB: 6,177' Total Vertical Depth, SS: 6,030' Location at Top of 3521.1'FNL, 559.5' FEL, Sec 18,T1ON,R008E,UM Productive Interval (Kuparuk C4 Sand) NGS Coordinates Measured Depth, RKB: 8,744' Northings: 5,929,539.33'Eastings: 476,731.52' Total Vertical Depth, RKB: 6,272' Total Vertical Depth, SS: 6,125' Location at Total Depth 467.8' FNL, 2520.4' FEL, Sec 30,T1ON,R008E,UM NGS Coordinates Measured Depth, RKB: 16,498' Northings: 5,922,039.66'Eastings: 474,774.41' Total Vertical Depth, RKB: 6,344' Total Vertical Depth, SS: 6,197' and (D)other information required by 20 AAC 25.050(1): 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 (I)include a plat,dramrn to a suitable scale,showing the path of the proposed-cellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well: Please see Attachment: Directional Plan And (2)for all-cells within 200 feet of the proposed wellbore • S (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(ROPE)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 141. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must he 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-12 is calculated using an estimated maximum reservoir pressure of 3,660 psi (11.2 ppg (6282' RKB TVD), based on 2S-11 development well), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A4 sand at 6,282' TVD (WP09): A Sand Estimated. BHP = 3,660 psi A Sand estimated depth(WP10) = 6,282' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 628 psi (6,282' TVD * 0.10 psi/ft) MPSP =BHP—gas column =3,032 psi (3,660 psi—629psi) (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 cones,and cones that have a propensity for differential sticking; See attached 2S-12 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 AAC 25.030,and a description of any slotted liner,pre-perforated liner.or screen to be installed Casing and Cement Program Casing and Cementing Program Csg/Tbg OD Hole Weight Length Top MD/TVD Btm MD/TVD (in) f) (Ib/ft) Grade Conn. (ft) ( ) (ft) Cement Program • 16 24 62.5 H-40 Welded 80 Surf 107/107 Existing Hydril Cement to Surface with 10-3/4 13-1/2 45.5 L-80 563 2,837 Surf 2,864/2,569 1,224 sx DeepCRETE Lead 11.0 ppg, 271 sx Class G Tail Slurry 15.8 ppg Stage 1: 615 sx Class G at 15.8 ppg w/ 9-7/8 Hydril TOC at 6,827 MD 7-5/8 X 29.7 L-80 8,247 Surf 8,274/6,177 Stage 2: 205 sx Class G at 15.8 ppg w/ 11 563 TOC at 5,282 MD 4 1/2 6-3/4 12.6 L-80 IBTM 8,398 8,100/6,124 16,498/6,344 Uncemented Liner with Frac Sleeves 10-3/4" Surface casing run to 2,864' MD/2,569'TVD Cement from 2,864' MD to 2,364'(500' of tail)with 15.8 ppg Class G,and from 2,364'to surface with 11 ppg DeepCrete.Assume 250%excess annular volume in permafrost and 50%excess below the permafrost(1428' MD),zero excess in 16"conductor. Lead slurry from 2,378' MD to surface with Arctic Lite Crete @ 11 ppg Conductor (107'—0')X 1.339 ft3/ft X 1.0(0%excess) = 144 ft3 Permafrost to Conductor (1,428'—107') X 0.3634 ft3/ft X 3.5(250%excess)= 1,681 ft3 Top of Tail to Permafrost (2,364'—1,428')X 0.3634 ft3/ft X 1.5(50%excess) =511 ft3 Total Volume= 144+ 1,681 +511 =2,336 ft3=> 1,224sx of 11 ppg DeepCrete @ 1.91 ft3/sk Tail slurry from 2,864' MD to 2,364' MD with 15.8 ppg Class G Shoe to Top of Tail (2,864—2,364')X 0.3634 ft3/ft X 1.50(50%excess) =273 ft3 Shoe Joint (80')X 0.5313 ft3/ft X 1.0(0%excess) =43 ft3 Total Volume=273+43=316 ft3=>271 sx of 15.8 ppg Class G @ 1.17 ft3/sk 7-5/8"Intermediate casing run to 8,274'MD/6,177'TVD Pt stage slurry designed to be at the top of Bermuda/Cairn Formation at 6,817'MD/5,487' TVD.Top of 2nd stage slurry is designed to be at 5,272' MD,which is 500' MD above the C-37 top at 5,772' MD/4,747' TVD.Assume 40% excess annular volume. 1st Stage slurry from 8,274' MD to 6,817' MD with 15.8ppg Class G+additives Shoe to Top of Cement (8,274'—6,817')X 0.3425 ft3/ft X 1.40(40%excess) =699 ft3 Shoe Joint (80')X 0.2483 ft3/ft X 1.0(0%excess) =20 ft3 Total Volume=699+20=719 ft3=>615 sx of 15.8 ppg Class G @ 1.17 ft3/sk 2"d Stage slurry from 5,772' MD to 5,272' MD with 15.8ppg Class G+additives S Stage Collar to Top of Cement (5,772—5,272)X 0.3425 ft3/ft X 1.40(40%excess) =240 ft3 Total Volume=240 ft3=>205sx of 15.8 ppg Class G @ 1.17 ft3/sk Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items.except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); Please reference attached diverter schematic for Doyon 141 on 2S pad slot 12. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Mud Program Summary Surface Intermediate Production 9-7/8"x 11" 13-1/2" Hole Hole 6-3/4" Hole 10-3/4" Casing 7-5/8" Casing 4-1/2" Liner Spud LSND FloPro Mud System (WBM) (WBM) (WBM) Density 9.3- 10 9.6-10.5 10.3-11.9 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 141 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 conmaission 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 141. Install Annular with 16"diverter line and function test. 2. Spud and directionally drill 13.5"hole to casing point at+/-2,864' MD/2,569' TVD as per directional plan (wp10). Survey with MWD, Gamma,Resistivity,Gyro. J 3. Run and cement 10-3/4",45.5#,L80,Hyd-563 casing to surface. Displace cement with mud. Evacuate top 2 feet of cement from annulus for sealant job(post rig.) 4. In the event cement returns are not seen at surface,perform a top job. Notify AOGCC if this occurs. 5. Remove diverter system,install and test 13-5/8"x 5,000 psi BOP's to 3500 psi(annular preventer to 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 11"Under Reamer and directionally drill to the top of the HRZ 9. Install RCD bearing at this time for use of MPD if necessary. 10. Directionally drill to intermediate TD of 8,274' MD/6,177' TVD,wellsite geologist will call intermediate TD. Circulate and rotate at maximum rates until shakers are clean,minimum of 3 bottoms up. 11. POOH on elevators. Closely monitor drag and address any problem areas by dropping below and circulating/rotating to clean up. 12. Lay down intermediate BHA and rack back 5"DP 13. Run 7-5/8",29.7#L80,Hydril 563 casing from surface to TD at 8,274' MD. 14. Pump two stage cement job as per Schlumberger proposal. Top of first stage to be 6,817'MD(top of Cairn formation),top of second stage to be 5,272'MD(500' above C37). 15. Flush 10-3/4"x 7-5/8"annulus with water,followed by diesel to freeze protect. 16. Lay down 5"DP. 17. PU 4"DP,6-3/4"bit,RSS, and Under Reamer assembly(Gamma,resistivity,Periscope,and neutron density) 18. RIH and clean out cement to 100' above shoe. Test intermediate casing to 3500 psi for 30 minutes. 19. 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. 20. Swap mud over to 10.3 ppg FloPro mud system,using MPD to hold near constant BHP of-11.8 ppg on the heel (for shale stability). 21. Perform selective shale under ream procedure opening shale section to 7.5" 22. Drop RFID chips&close the reamer once BHA has entered sand. 23. Directionally drill 6-3/4"hole geosteering through the Kuparuk A4 sand to TD-16,498' MD as per directional plan(wp10). 24. Circulate hole clean and POOH. 25. Lay down production BHA. 26. PU and run 4-1/2", 12.6#liner. The top of liner will be placed at 8,100' MD,allowing for 150' of overlap in the 7-5/8"casing. • • 27. Set liner hanger. Slackoff and set liner top packer. 28. Monitor well for flow for 15 minutes 29. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes,chart results. 30. Flow check well for 30 minutes and POOH 31. Run 3-1/2"upper completion. 32. Nipple down BOPE,nipple up tree and test. 33. Freeze protect well with diesel and install BPV. 34. RDMO. 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 he accompanied b}'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 • S 2S-1 2 ConocoPhillips Grassroots Horizontal A-Sand Producer Proposed Wellbore Schematic(wp10—D141 RKB) 'CAMERON Last Edited: • 4-r°tree,top pet is4-i°126#IBTM Brunswick 5/24/16 ,. _ 16"Conductor to-107.5' 13.5" Surface Hole �1 � Base West Sak:2,797'MD/2,519'ND 3'/:"x 1-1A"Camco MMG GLM — C '' Surface Casing 10-3/4"45.5#L-80 Hydril 563 2,864' MD/2,569'TVD(41.6° INC) 9-7/8"x 11" Intermediate Hole .n 4 Tubing: 3-1/2" 9.3#L-80 EUE 8RD-MOD GLM w/ 1 SOV 11, ; y .o,,,,,_4____ 2"2 Stage TOC= 500'MD above C-37 Formation at 5,272'MD 1111111 tt Weatherford Stage Collar:5,772'MD C-37:5,772 MD/4,747'ND -*4-- Iz.g.x 1'Stage TOC: Top of Bermuda/Cairn formation) Growler-AA:6,051'MD 64,955'TVD ii Baker 2.812"CMU Sliding Cairn:6,817'MD/5,487'TVD Sleeve SLB DH c " r_ 3-1A"x 7-5/8",Premier Packer Bermuda:6,951'MD/5,571'TVD 40, ".;;:,„,.83-%"2.75"D Nipple ,- HRZ:7,693'MD/5,967'ND • Kalubik:8,048'MD/6,107'ND 5.75"x 4-%"Swell Packer '�•• ••• Kuparuk C:8 744'MD/6 272'ND Kuparuk A4:8.833'MD/6,282'ND-11.2 ppg a ;1111; _---__�».»«—�«._--_•-4-% Silver ro 7-5/8"x 5-%"Baker Liner RuI R.Ch ter d Packer/Flex Lock Liner .,� Hanger(8,100'MD/6133' ••• ® wiN`rtd� To IIN 11111 Alpha N TD:16,498'MD/6,344'TVD Intermediate Casing Production Liner: 6-3/4" Production Hole 7-5/8"29.7#L-80 Hyd563 Casing 4-1/2"12.6#L-80 HYD563 8,274' MD/6,177'TVD(74° INC) 16,498' MD/6,344'TVD • 0 .y O O 0 —0 0 N j� W w a am O C = GO CCc 0 oe - . —o _ R _ X Q 000 , �\t ON 00rb 0 Oy x o O —0 N as y� W O to0oO o N Cs....* 0 w 1 CO S 0 7 w rani SD N MOM U , ..M CO , _ N , M _0 CO C1 X .: i co Iona W El , 1 ' Lo �' - I ON � CO C.) 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Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-12 Project: Kuparuk River Unit TVD Reference: Plan: 120+27.5 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Plan: 120+27.5 @ 147.50usft(Doyon141) Well: Plan:2S-12 North Reference: True Wellbore: Plan:2S-12 Survey Calculation Method: Minimum Curvature Design: 2S-12wp10[Bull] 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-12 Well Position +N/-S usft Northing: usfl Latitude: +EI-W usft Easting: usfl Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 120.00 usft Wellbore Plan:2S-12 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2016 7/1/2016 17.95 80.85 57,536 Design 2S-12wp10[Bull] Audit Notes: Extended lateral by 2000ft,updated survey program-VO(02/11/2015) Version: Phase: PLAN Tie On Depth: 27.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 27.50 0.00 0.00 195.00 Survey Tool Program Date 5/24/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 27.50 550.00 2S-12wp10[Bull](Plan:2S-12) INC+TREND Inclinometer+known azi trend 550.00 1,550.00 2S-12wp10[Bull](Plan:2S-12) MWD MWD-Standard 550.00 2,864.08 2S-12wp10[Bull](Plan:2S-12) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 39.00 700.00 2S-12wp10[But](Plan:2S-12) GYD-GC-MS Gyrodata gyrocompassing m/s 2,864.08 4,364.08 2S-12wp10[Bull](Plan:2S-12) MWD MWD-Standard 2,864.08 8,274.15 2S-12wp10[Bull](Plan:2S-12) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,274.15 9,771.72 2S-12wp10[Bull](Plan:2S-12) MWD MWD-Standard 8,274.15 16,498.03 2S-12wp10[Bull](Plan:2S-12) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) 0100usft) (0) (usft) 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 -47.50 0.00 0.00 0.48 107.50 0.00 0.00 107.50 -40.00 0.00 0.00 1.65 16"x 42" 200.00 0.00 0.00 200.00 52.50 0.00 0.00 1.65 5/24/2016 1:51:54PM Page 2 COMPASS 5000.1 Build 74 411/ 1110 Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-12 Project: Kuparuk River Unit TVD Reference: Plan: 120+27.5 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Plan: 120+27.5 @ 147.50usft(Doyon141) Well: Plan:2S-12 North Reference: True Wellbore: Plan:2S-12 Survey Calculation Method: Minimum Curvature Design: 2S-12wp10[Bull] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (°) (usft) 277.50 0.00 0.00 277.50 130.00 0.00 0.00 2.70 top T-3 Sand 300.00 0.00 0.00 300.00 152.50 0.00 0.00 2.70 357.50 0.00 0.00 357.50 210.00 0.00 0.00 3.72 K-15 Marker 400.00 0.00 0.00 400.00 252.50 0.00 0.00 3.72 500.00 0.00 0.00 500.00 352.50 0.00 0.00 4.73 KOP:Start 1.5°/100'DLS,345°TF,for 100.01' 600.00 1.50 345.00 599.99 452.49 1.50 345.00 5.22 600.01 1.50 345.00 600.00 452.50 1.50 0.00 5.22 Start 2.5°/100'DLS,-10°TF,for 301.48' 700.00 3.99 338.74 699.87 552.37 2.50 -10.00 5.22 800.00 6.48 337.30 799.44 651.94 2.50 -3.75 5.23 900.00 8.98 336.65 898.52 751.02 2.50 -2.31 5.25 901.49 9.02 336.64 900.00 752.50 2.50 -1.67 5.25 Adjust TF to-30°,for 473.28' 1,000.00 11.22 330.30 996.97 849.47 2.50 -30.00 5.28 1,100.00 13.54 326.00 1,094.64 947.14 2.50 -23.76 5.34 1,200.00 15.92 322.95 1,191.35 1,043.85 2.50 -19.55 5.43 1,300.00 18.33 320.68 1,286.91 1,139.41 2.50 -16.60 5.57 1,374.77 20.15 319.33 1,357.50 1,210.00 2.50 -14.43 5.71 Hold for 106.52' 1,400.00 20.15 319.33 1,381.19 1,233.69 0.00 0.00 5.76 1,428.03 20.15 319.33 1,407.50 1,260.00 0.00 0.00 5.96 Base permafrost(?) 1,481.29 20.15 319.33 1,457.50 1,310.00 0.00 0.00 5.96 Start 3.5°/100'DLS,-44.82°TF,for 713.58' 1,500.00 20.62 318.02 1,475.04 1,327.54 3.50 -44.82 6.00 1,600.00 23.27 311.90 1,567.80 1,420.30 3.50 -43.59 5.49 1,700.00 26.12 307.01 1,658.66 1,511.16 3.50 -37.91 5.57 1,800.00 29.09 303.04 1,747.27 1,599.77 3.50 -33.47 5.67 1,900.00 32.17 299.76 1,833.31 1,685.81 3.50 -29.95 5.80 1,902.58 32.25 299.68 1,835.50 1,688.00 3.50 -27.12 5.96 Top W Sak(W Sak D) 2,000.00 35.32 297.00 1,916.46 1,768.96 3.50 -27.06 5.96 2,100.00 38.52 294.64 1,996.40 1,848.90 3.50 -24.83 6.15 2,194.86 41.59 292.69 2,069.01 1,921.51 3.50 -22.94 6.36 Hold for 3009.91' 2,200.00 41.59 292.69 2,072.85 1,925.35 0.00 0.00 6.38 2,300.00 41.59 292.69 2,147.64 2,000.14 0.00 0.00 6.64 2,400.00 41.59 292.69 2,222.43 2,074.93 0.00 0.00 6.93 2,500.00 41.59 292.69 2,297.21 2,149.71 0.00 0.00 7.24 2,600.00 41.59 292.69 2,372.00 2,224.50 0.00 0.00 7.56 2,700.00 41.59 292.69 2,446.79 2,299.29 0.00 0.00 7.91 2,797.22 41.59 292.69 2,519.50 2,372.00 0.00 0.00 8.26 Base W Sak 5/24/2016 1:51:54PM Page 3 COMPASS 5000.1 Build 74 I S . Schlurnberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-12 Project: Kuparuk River Unit TVD Reference: Plan: 120+27.5 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Plan: 120+27.5 @ 147.50usft(Doyon141) Well: Plan:2S-12 North Reference: True Wellbore: Plan:2S-12 Survey Calculation Method: Minimum Curvature Design: 2S-12wp10[Bull] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 2,800.00 41.59 292.69 2,521.58 2,374.08 0.00 0.00 8.26 2,864.08 41.59 292.69 2,569.50 2,422.00 0.00 0.00 7.08 10-3/4"x 13-1/2" 2,900.00 41.59 292.69 2,596.37 2,448.87 0.00 0.00 7.08 3,000.00 41.59 292.69 2,671.15 2,523.65 0.00 0.00 7.27 3,100.00 41.59 292.69 2,745.94 2,598.44 0.00 0.00 7.62 3,200.00 41.59 292.69 2,820.73 2,673.23 0.00 0.00 8.13 3,299.97 41.59 292.69 2,895.50 2,748.00 0.00 0.00 8.76 C-80 3,300.00 41.59 292.69 2,895.52 2,748.02 0.00 0.00 8.76 3,400.00 41.59 292.69 2,970.31 2,822.81 0.00 0.00 9.50 3,500.00 41.59 292.69 3,045.09 2,897.59 0.00 0.00 10.30 3,600.00 41.59 292.69 3,119.88 2,972.38 0.00 0.00 11.18 3,700.00 41.59 292.69 3,194.67 3,047.17 0.00 0.00 12.09 3,800.00 41.59 292.69 3,269.46 3,121.96 0.00 0.00 13.05 3,900.00 41.59 292.69 3,344.25 3,196.75 0.00 0.00 14.03 4,000.00 41.59 292.69 3,419.03 3,271.53 0.00 0.00 15.04 4,100.00 41.59 292.69 3,493.82 3,346.32 0.00 0.00 16.07 4,200.00 41.59 292.69 3,568.61 3,421.11 0.00 0.00 17.12 4,300.00 41.59 292.69 3,643.40 3,495.90 0.00 0.00 18.18 4,400.00 41.59 292.69 3,718.19 3,570.69 0.00 0.00 10.22 4,500.00 41.59 292.69 3,792.97 3,645.47 0.00 0.00 10.57 4,600.00 41.59 292.69 3,867.76 3,720.26 0.00 0.00 10.93 4,700.00 41.59 292.69 3,942.55 3,795.05 0.00 0.00 11.30 4,800.00 41.59 292.69 4,017.34 3,869.84 0.00 0.00 11.68 4,900.00 41.59 292.69 4,092.13 3,944.63 0.00 0.00 12.06 5,000.00 41.59 292.69 4,166.91 4,019.41 0.00 0.00 12.45 5,011.48 41.59 292.69 4,175.50 4,028.00 0.00 0.00 12.84 C-50 5,100.00 41.59 292.69 4,241.70 4,094.20 0.00 0.00 12.84 5,200.00 41.59 292.69 4,316.49 4,168.99 0.00 0.00 13.24 5,204.77 41.59 292.69 4,320.06 4,172.56 0.00 0.00 13.26 Start 2.5°/100'DLS,-99.29°TF,for 3661.06' 5,300.00 41.26 289.13 4,391.47 4,243.97 2.50 -99.29 13.54 5,395.65 41.04 285.51 4,463.50 4,316.00 2.50 -96.61 13.70 C-40 5,400.00 41.04 285.34 4,466.78 4,319.28 2.50 -93.89 13.70 5,500.00 40.94 281.53 4,542.28 4,394.78 2.50 -93.76 13.81 5,600.00 40.96 277.72 4,617.82 4,470.32 2.50 -90.89 13.88 5,700.00 41.11 273.92 4,693.26 4,545.76 2.50 -88.01 13.90 5,772.08 41.29 271.20 4,747.50 4,600.00 2.50 -85.14 13.88 C-37 5,800.00 41.38 270.15 4,768.46 4,620.96 2.50 -83.09 13.88 5,900.00 41.78 266.43 4,843.28 4,695.78 2.50 -82.30 13.82 6,000.00 42.29 262.77 4,917.56 4,770.06 2.50 -79.52 13.72 5/24/2016 1:51:54PM Page 4 COMPASS 5000.1 Build 74 • • . Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-12 Project: Kuparuk River Unit TVD Reference: Plan: 120+27.5 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Plan: 120+27.5 @ 147.50usft(Doyon141) Well: Plan:2S-12 North Reference: True Wellbore: Plan:2S-12 Survey Calculation Method: Minimum Curvature Design: 2S-12wp10[Bull] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 6,051.41 42.60 260.93 4,955.50 4,808.00 2.50 -76.81 13.60 Growler-AA 6,100.00 42.92 259.20 4,991.18 4,843.68 2.50 -75.44 13.60 6,200.00 43.65 255.71 5,063.98 4,916.48 2.50 -74.17 13.46 6,300.00 44.49 252.33 5,135.84 4,988.34 2.50 -71.64 13.31 6,400.00 45.43 249.04 5,206.61 5,059.11 2.50 -69.20 13.14 6,500.00 46.45 245.87 5,276.16 5,128.66 2.50 -66.88 12.98 6,600.00 47.56 242.81 5,344.36 5,196.86 2.50 -64.67 12.82 6,700.00 48.75 239.86 5,411.07 5,263.57 2.50 -62.58 12.67 6,800.00 50.01 237.01 5,476.18 5,328.68 2.50 -60.61 12.54 6,817.66 50.24 236.52 5,487.50 5,340.00 2.50 -58.76 12.42 Top Cairn 6,900.00 51.34 234.28 5,539.55 5,392.05 2.50 -58.45 12.42 6,951.55 52.05 232.91 5,571.50 5,424.00 2.50 -57.03 12.33 Top Bermuda 7,000.00 52.73 231.64 5,601.07 5,453.57 2.50 -56.18 12.33 7,098.10 54.15 229.15 5,659.50 5,512.00 2.50 -55.41 12.27 Base Bermuda 7,100.00 54.18 229.10 5,660.61 5,513.11 2.50 -53.92 12.27 7,153.29 54.97 227.79 5,691.50 5,544.00 2.50 -53.90 12.23 C-35 7,200.00 55.68 226.66 5,718.08 5,570.58 2.50 -53.13 12.23 7,300.00 57.22 224.30 5,773.35 5,625.85 2.50 -52.49 12.23 7,400.00 58.81 222.02 5,826.31 5,678.81 2.50 -51.19 12.26 7,500.00 60.44 219.82 5,876.88 5,729.38 2.50 -49.98 12.32 7,600.00 62.10 217.69 5,924.96 5,777.46 2.50 -48.87 12.41 7,693.35 63.68 215.76 5,967.50 5,820.00 2.50 -47.84 12.54 Top HRZ 7,700.00 63.79 215.63 5,970.44 5,822.94 2.50 -46.96 12.54 7,800.00 65.51 213.62 6,013.25 5,865.75 2.50 -46.90 12.71 7,900.00 67.26 211.67 6,053.31 5,905.81 2.50 -46.04 12.90 8,000.00 69.03 209.77 6,090.53 5,943.03 2.50 -45.26 13.13 8,048.37 69.90 208.86 6,107.50 5,960.00 2.50 -44.55 13.38 Upper Kalubik(base HRZ) 8,100.00 70.82 207.91 6,124.85 5,977.35 2.50 -44.24 13.38 8,200.00 72.63 206.09 6,156.21 6,008.71 2.50 -43.92 13.66 8,266.92 73.85 204.90 6,175.50 6,028.00 2.50 -43.35 13.94 Lower Kalubik(K-1 mkr) 8,274.15 73.99 204.77 6,177.50 6,030.00 2.50 -43.00 13.94 7-5/8"X 9-7/8"by 11" 8,300.00 74.46 204.31 6,184.53 6,037.03 2.50 -42.97 13.94 8,400.00 76.30 202.56 6,209.77 6,062.27 2.50 -42.84 14.30 8,500.00 78.15 200.84 6,231.89 6,084.39 2.50 -42.40 14.80 8,600.00 80.01 199.14 6,250.83 6,103.33 2.50 -42.02 15.42 8,700.00 81.88 197.46 6,266.56 6,119.06 2.50 -41.70 16.16 5/24/2016 1:51:54PM Page 5 COMPASS 5000.1 Build 74 • S . Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-12 Project: Kuparuk River Unit ND Reference: Plan: 120+27.5 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Plan: 120+27.5 @ 147.50usft(Doyon141) Well: Plan:2S-12 North Reference: True Wellbore: Plan:2S-12 Survey Calculation Method: Minimum Curvature Design: 2S-12wp10[Bull] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (0) (usft) 8,744.34 82.72 196.72 6,272.50 6,125.00 2.50 -41.43 16.99 Kuparuk C(Top C4) 8,800.00 83.76 195.80 6,279.05 6,131.55 2.50 -41.34 16.99 8,833.39 84.39 195.25 6,282.50 6,135.00 2.50 -41.23 17.58 A4 8,865.83 85.00 194.71 6,285.50 6,138.00 2.50 -41.17 17.58 Hold for 30' 8,895.83 85.00 194.71 6,288.11 6,140.61 0.00 0.00 17.90 Start 4°/100'DLS,0.04°TF,for 124.51' 8,900.00 85.17 194.71 6,288.47 6,140.97 4.00 0.04 17.94 9,000.00 89.17 194.71 6,293.41 6,145.91 4.00 0.04 18.96 9,020.34 89.98 194.71 6,293.57 6,146.07 4.00 0.04 19.17 Hold for 5646.33' 9,100.00 89.98 194.71 6,293.59 6,146.09 0.00 0.00 20.03 9,200.00 89.98 194.71 6,293.63 6,146.13 0.00 0.00 21.15 9,300.00 89.98 194.71 6,293.66 6,146.16 0.00 0.00 22.32 9,400.00 89.98 194.71 6,293.70 6,146.20 0.00 0.00 23.51 9,500.00 89.98 194.71 6,293.73 6,146.23 0.00 0.00 24.74 9,600.00 89.98 194.71 6,293.76 6,146.26 0.00 0.00 25.99 9,700.00 89.98 194.71 6,293.80 6,146.30 0.00 0.00 27.26 9,800.00 89.98 194.71 6,293.83 6,146.33 0.00 0.00 16.62 9,900.00 89.98 194.71 6,293.87 6,146.37 0.00 0.00 17.01 10,000.00 89.98 194.71 6,293.90 6,146.40 0.00 0.00 17.40 10,100.00 89.98 194.71 6,293.94 6,146.44 0.00 0.00 17.81 10,200.00 89.98 194.71 6,293.97 6,146.47 0.00 0.00 18.22 10,300.00 89.98 194.71 6,294.00 6,146.50 0.00 0.00 18.64 10,400.00 89.98 194.71 6,294.04 6,146.54 0.00 0.00 19.07 10,500.00 89.98 194.71 6,294.07 6,146.57 0.00 0.00 19.51 10,600.00 89.98 194.71 6,294.11 6,146.61 0.00 0.00 19.96 10,700.00 89.98 194.71 6,294.14 6,146.64 0.00 0.00 20.41 10,800.00 89.98 194.71 6,294.18 6,146.68 0.00 0.00 20.87 10,900.00 89.98 194.71 6,294.21 6,146.71 0.00 0.00 21.33 11,000.00 89.98 194.71 6,294.24 6,146.74 0.00 0.00 21.80 11,100.00 89.98 194.71 6,294.28 6,146.78 0.00 0.00 22.28 11,200.00 89.98 194.71 6,294.31 6,146.81 0.00 0.00 22.76 11,300.00 89.98 194.71 6,294.35 6,146.85 0.00 0.00 23.24 11,400.00 89.98 194.71 6,294.38 6,146.88 0.00 0.00 23.73 11,500.00 89.98 194.71 6,294.41 6,146.91 0.00 0.00 24.22 11,600.00 89.98 194.71 6,294.45 6,146.95 0.00 0.00 24.71 11,700.00 89.98 194.71 6,294.48 6,146.98 0.00 0.00 25.21 11,800.00 89.98 194.71 6,294.52 6,147.02 0.00 0.00 25.72 11,900.00 89.98 194.71 6,294.55 6,147.05 0.00 0.00 26.22 12,000.00 89.98 194.71 6,294.59 6,147.09 0.00 0.00 26.73 12,100.00 89.98 194.71 6,294.62 6,147.12 0.00 0.00 27.24 12,200.00 89.98 194.71 6,294.65 6,147.15 0.00 0.00 27.75 5/24/2016 1:51:54PM Page 6 COMPASS 5000.1 Build 74 Schlurnberger S . Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-12 Project: Kuparuk River Unit TVD Reference: Plan: 120+27.5 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Plan: 120+27.5 @ 147.50usft(Doyon141) Well: Plan:2S-12 North Reference: True Wellbore: Plan:2S-12 Survey Calculation Method: Minimum Curvature Design: 2S-12wp10[Bull] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (0) (usft) 12,300.00 89.98 194.71 6,294.69 6,147.19 0.00 0.00 28.27 12,400.00 89.98 194.71 6,294.72 6,147.22 0.00 0.00 28.79 12,500.00 89.98 194.71 6,294.76 6,147.26 0.00 0.00 29.31 12,600.00 89.98 194.71 6,294.79 6,147.29 0.00 0.00 29.83 12,700.00 89.98 194.71 6,294.83 6,147.33 0.00 0.00 30.36 12,800.00 89.98 194.71 6,294.86 6,147.36 0.00 0.00 30.88 12,900.00 89.98 194.71 6,294.89 6,147.39 0.00 0.00 31.41 13,000.00 89.98 194.71 6,294.93 6,147.43 0.00 0.00 31.94 13,100.00 89.98 194.71 6,294.96 6,147.46 0.00 0.00 32.48 13,200.00 89.98 194.71 6,295.00 6,147.50 0.00 0.00 33.01 13,300.00 89.98 194.71 6,295.03 6,147.53 0.00 0.00 33.54 13,400.00 89.98 194.71 6,295.07 6,147.57 0.00 0.00 34.08 13,500.00 89.98 194.71 6,295.10 6,147.60 0.00 0.00 34.62 13,600.00 89.98 194.71 6,295.13 6,147.63 0.00 0.00 35.16 13,700.00 89.98 194.71 6,295.17 6,147.67 0.00 0.00 35.70 13,800.00 89.98 194.71 6,295.20 6,147.70 0.00 0.00 36.24 13,900.00 89.98 194.71 6,295.24 6,147.74 0.00 0.00 36.78 14,000.00 89.98 194.71 6,295.27 6,147.77 0.00 0.00 37.32 14,100.00 89.98 194.71 6,295.31 6,147.81 0.00 0.00 37.87 14,200.00 89.98 194.71 6,295.34 6,147.84 0.00 0.00 38.41 14,300.00 89.98 194.71 6,295.37 6,147.87 0.00 0.00 38.96 14,400.00 89.98 194.71 6,295.41 6,147.91 0.00 0.00 39.51 14,500.00 89.98 194.71 6,295.44 6,147.94 0.00 0.00 40.05 14,600.00 89.98 194.71 6,295.48 6,147.98 0.00 0.00 40.60 14,666.67 89.98 194.71 6,295.50 6,148.00 0.00 0.00 40.97 Start 1°/100'DLS,-145.19°TF,for 200.55' 14,700.00 89.71 194.52 6,295.59 6,148.09 1.00 -145.19 41.03 14,800.00 88.89 193.95 6,296.82 6,149.32 1.00 -145.19 40.91 14,867.23 88.33 193.57 6,298.45 6,150.95 1.00 -145.19 40.83 Start 0.01°/100'DLS,18.08°TF,for 1630.8' 14,900.00 88.34 193.57 6,299.40 6,151.90 0.01 18.08 40.91 15,000.00 88.34 193.57 6,302.30 6,154.80 0.01 18.08 41.42 15,100.00 88.35 193.57 6,305.19 6,157.69 0.01 18.08 41.94 15,200.00 88.35 193.57 6,308.07 6,160.57 0.01 18.08 42.47 15,300.00 88.36 193.58 6,310.94 6,163.44 0.01 18.08 42.99 15,400.00 88.37 193.58 6,313.80 6,166.30 0.01 18.08 43.52 15,500.00 88.37 193.58 6,316.64 6,169.14 0.01 18.08 44.05 15,600.00 88.38 193.58 6,319.48 6,171.98 0.01 18.08 44.58 15,700.00 88.38 193.58 6,322.31 6,174.81 0.01 18.08 45.12 15,800.00 88.39 193.59 6,325.12 6,177.62 0.01 18.08 45.65 15,900.00 88.39 193.59 6,327.93 6,180.43 0.01 18.08 46.19 16,000.00 88.40 193.59 6,330.73 6,183.23 0.01 18.08 46.73 16,100.00 88.41 193.59 6,333.51 6,186.01 0.01 18.08 47.28 16,200.00 88.41 193.59 6,336.29 6,188.79 0.01 18.08 47.82 5/24/2016 1:51:54PM Page 7 COMPASS 5000.1 Build 74 • • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-12 Project: Kuparuk River Unit TVD Reference: Plan: 120+27.5 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Plan: 120+27.5 @ 147.50usft(Doyon141) Well: Plan:2S-12 North Reference: True Wellbore: Plan:2S-12 Survey Calculation Method: Minimum Curvature Design: 2S-12wp10[Bull] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (0) (usft) 16,300.00 88.42 193.60 6,339.05 6,191.55 0.01 18.08 48.37 16,400.00 88.42 193.60 6,341.81 6,194.31 0.01 18.08 48.92 16,498.03 88.43 193.60 6,344.50 6,197.00 0.01 18.08 49.46 TD:16498.03'MD,6344.5'TVD 5/24/2016 1:51:54PM Page 8 COMPASS 5000.1 Build 74 • Schlurnberger • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-12 Project: Kuparuk River Unit TVD Reference: Plan: 120+27.5 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Plan: 120+27.5 @ 147.50usft(Doyon141) Well: Plan:2S-12 North Reference: True Wellbore: Plan:2S-12 Survey Calculation Method: Minimum Curvature Design: 2S-12wp10[Bull] Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") C') 16,498.03 6,344.50 4-1/2"x 6-3/4" 4-1/2 6-3/4 2,864.08 2,569.50 10-3/4"x 13-1/2" 10-3/4 13-1/2 8,274.15 6,177.50 7-5/8"X 9-7/8"by 11" 7-5/8 11 107.50 107.50 16"x 42" 16 42 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 8,266.92 6,175.50 Lower Kalubik(K-1 mkr) 5,772.08 4,747.50 C-37 6,951.55 5,571.50 Top Bermuda 1,902.58 1,835.50 Top W Sak(W Sak D) 8,833.39 6,282.50 A4 3,299.97 2,895.50 C-80 7,098.10 5,659.50 Base Bermuda 5,395.65 4,463.50 C-40 8,744.34 6,272.50 Kuparuk C(Top C4) 6,817.66 5,487.50 Top Cairn 277.50 277.50 top T-3 Sand 8,048.37 6,107.50 Upper Kalubik(base HRZ) 357.50 357.50 K-15 Marker 7,153.29 5,691.50 C-35 2,797.22 2,519.50 Base W Sak 1,428.03 1,407.50 Base permafrost(?) 6,051.41 4,955.50 Growler-AA 7,693.35 5,967.50 Top HRZ 5,011.48 4,175.50 C-50 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 500.00 500.00 0.00 0.00 KOP:Start 1.5°/100'DLS,345°TF,for 100.01' 600.01 600.00 1.26 -0.34 Start 2.5°/100'DLS,-10°TF,for 301.48' 901.49 900.00 26.81 -10.74 Adjust TF to-30°,for 473.28' 1,374.77 1,357.50 123.01 -78.81 Hold for 106.52' 1,481.29 1,457.50 150.84 -102.71 Start 3.5°/100'DLS,-44.82°TF,for 713.58' 2,194.86 2,069.01 338.38 -406.14 Hold for 3009.91' 5,204.77 4,320.06 1,109.17 -2,249.56 Start 2.5°/100'DLS,-99.29°TF,for 3661.06' 8,865.83 6,285.50 -555.99 -4,286.50 Hold for 30' 8,895.83 6,288.11 -584.89 -4,294.08 Start 4°/100'DLS,0.04°TF,for 124.51' 9,020.34 6,293.57 -705.17 -4,325.66 Hold for 5646.33' 14,666.67 6,295.50 -6,166.34 -5,759.77 Start 1°/100'DLS,-145.19°TF,for 200.55' 14,867.23 6,298.45 -6,360.78 -5,808.76 Start 0.01°/100'DLS, 18.08°TF,for 1630.8' 16,498.03 6,344.50 -7,945.33 -6,191.64 TD: 16498.03'MD,6344.5'TVD Checked By: Approved By: Date: 5/24/2016 1:51:54PM Page 9 COMPASS 5000.1 Build 74 • 4110 2S-12wp10 Surface Location in, CPAI Coordinate Converter From: To: Datum: 1NAD83 ,- Region: i i alaska zi Datum: INAD27 ••• Region: i ialaska ...1 Latitude/Longitude 'Decimal Degrees •• ---j' r Latitude/Longitude [Decimal Degrees zi UTM Zone: r---- r South r UTM Zone: I 1True r South • State Plane Zone: 14 .-:,.1 Units: us_ft zi (•"" State Plane Zone: 4 , Units: 111571., _.,1 Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: Ending Coordinates: X: 11621019.42 X: 1 480986.096754427 'Ti: 15929717.61 Y: 1 5929968.02452396 I 1 I 11- Transform i Quit Help I L 2S-12wp10 Intermediate Casing I CPA: Coo-dinate Com..erter ..' I ---- —''''' ' - From: To: Datum: iiNAD83 •• Region: 1 alaska ..- Datum: NAD271w.i Region: Jalaska z,i 1 _I Latitude/Longitude !Decimal Degrees z.l. r Latitude/Longitude Decimal Degrees Id UTM Zone: 1 r South C UTM Zone: True 1-- South ri" State Plane Zone: !4 .„.. Units: us4F-E, 1:'•- State Plane Zone: "4 :, Units: Legal Description(NAD27 only) ( Legal Description(NAD27 only) Starting Coordinates:- Ending Coordinates: X: 11616928.39 X: ) 476894.977928799 1 Y: 1542671843 Y: I 5929968.90301358 Transform i Quit I Help i 1 1 I 0 I2S-12wp10 Top of Production Horizon A4 I rfi CPA: Coo-dinate Converter _____ From: - To: Datum: 1NAD83 -. Region: Ialaska ...7 Datum: NAD27I , Region: lalaska ..-1 ..._ ,1---- Latitude/Longitude [Decimal Degrees .r r Latitude/Longitude [Decimal Degrees , •:---- UTM Zone: 1 E South (- UTM Zone: True 1--- South •-• State Plane Zone: 1I Units: 1-7-1-3us.. , r.- State Plane Zone: 14...--,1 Units: ru7:f"r r Legal Description(NAD27 only) C Legal Description(NAD27 only) . 1 _ .. . Starting Coordinates: Ending Coordinates: X: FI6167410.37 X: 478766.843461 E3 Y: 15929203.88 Y: 1 5929454.36634109 Transform Quit Help .•• i... 2S-1 2wp1 0 TD En CPA: Coo-ciinate Converter From: To: .• Datum: 1NAD83 .---, Region: lalaska _LI Datum: INAD27 ,ir Region: lalaska ..zi Latitude/Longitude Dal Degrees C Latitude/Longitude 1-127-71—ecimal Degrees r- I—ecimjj .. ''-- UTM Zone: I j South C UTM Zone: ITrue I— South ,•..i. State Plane Zone: ri-----,11 Units: jus-ft ..• t'S- State Plane Zone: 4 ,I Units: pi— .,D. •--- Legal Description(NAD27 only) r Legal Description(NAD27 only) Starting Coordinates: Ending Coordinates: X: 11614808 X: 1 474774.406415763 Y: 15921789 Y: 1 5922039.66453123 ....„ _ Transform Quit I Help ,.. • • l 2S-12wp10 Surface Location I CPA[Coordinate Converter From: , To: Datum: NAD 83 w Region: alaska Datum: I w Re ion: IhdAD27 9 alaska Latitude/Longitude g fi Latitude/Longitude _._. 9 Decimal Degrees w 9 Decimal Degrees UTM Zone: __.---- r' South #' UTM Zone: IT rue E E South r "; State Plane Zone:I'' w l Units: us-fk t" State Plane Zone: R------;-1 Units: us fk C' '_-gal il ':r;ription(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: Legal Description X: 11621019.42 Township: `_._____ Ran e: 1010 N 9 1008 E 15929717.61 Meridian: IL1 Section:117 FNL 13080.4556 FEL 11584.2179 Transform , Quit I Help I 2S-12wp10 Intermediate Casing I CPA: ier "dv . „ .. . ., - I O i U s:s- -v n CPA:Coordinate.e Ccn:ier � From: To: I Datum: NA 83 +', Region: lalaska Datum: NAD27 Region: alaska Latitude/Longitude (Decimal Degrees CI t"` Latitude/Longitude Decimal Degrees w • - UTM Zone: I f- South C UTM Zone: ;True South (..is State State Plane Zone: — Units: us-ft w C State Plane Zone: q w�1 Units: rus-ft C Legal Description(NAD27 only) a Legal Description(NAD27 only) Starting Coordinates: Legal Description X: 1616928.39wrt----c, Township: 010 N Range: 1008 ( Y: 1592971843_.__._..___.._ Meridian: L1 5ection:118 FNL w 13090.9817 FEL 1395.76695 I Transform Quit I Help I 0 1 2S-12wp10 Top of Production Horizon A4 r n CPA: Coo-dinate Converter . = 1 El 1., From: To: Datum: INAD83 /1 Region: Ialaska ..71 Datum: NAD27: ••• Region: ralaska .1." C Latitude/LongitudeDegrees ID •ecimal 7. r Latitude/Longitude Decimal Degrees ----- ..- :... C• UTM Zone: 1— I-- South C UTM Zone: [True 1- South 6- State Plane Zone:14---cl Units: 11..ft .„. C State Plane Zone: [4 , Units: ru;iTa.„1. I _.. C Lecal Description(NAD27 only) (ilLegal Description(NAD27 only) Starting Coordinates:- Legal Description x: ii 616740.37 Township: 1010 IN , Range: 1--- 1008 1173. Y: )5929203.88 Meridian: Section:11 8 IFNE-; 13606.1486 IFITI 1584.07208 Transform Quit I Help I r 2S-12wp10 TD in CPA: Coo-dinate Converter 1. czr 1 E3 Irrowa,.1 From: To: Datum: 1NAD83 ...11 Region: Ialaska ..... 1 Datum: NAD27- .-I Region: lalaska ... C Latitude/Longitude lDecimal Degrees -C1 Latitude/Longitude Decimal1Degrees ...d _ . r- UTM Zone: I r South r UTM Zone: IT rue r South 4- State Plane Zone: Ft .D, Units: 11-ft 1r ( State Plane Zone: 1-4---71. Units: Fit w - ( Legal Description(NAD27 only) 4 Legal Description(NAD27 only) Starting Coordinates: Legal Description l X: 11614808 Township: 1010 i -,A. Rangel Fti5-8— FE-771 •:l: } 1 l Y: 15921789 Meridian: 17----.71 S ection:[30 IF-NE , 1467.76800 FEL -,• 12520.432-1 't I ..............._......__. . . . . , Transform Quit I Help .• I • 2S-12 Drilling Hazards Summary 13-1/2"Hole/10-3/4" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low If observed-control drill,reduce pump rates,reduce drilling fluid temperatures,Additions of Lecithin. Anti-collision 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"x 11"Hole/7-5/8"Casing Interval Event Risk Level Mitigation Strategy Shale stability Moderate For the unstable HRZ and Kalubik shales with high inclination control 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—12.5 ppg in Tarn 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. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is higher than expected. 6-3/4"Hole/4-1/2"Liner Interval Event Risk Level Mitigation Strategy High ECD and swabbing with higher Moderate Condition mud prior to trips. Monitor ECD's with PWD tool while MW's required drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is higher than expected. Lost Circulation Moderate Use PWD and TAD to monitor hole cleaning. Reduced pump rates, adjust mud rheology,add LCM. Use GKA LC decision tree. Use of MPD will allow lower mud weights to reduce ECD while shutting on connections to prevent any potential influx. Stuck pipe Moderate Good hole cleaning,stabilized BHA,proper mud weight to minimize differential stuck,PWD monitor ECD. Hole swabbing on trips Moderate Monitor proper hole fill while tripping,good hole cleaning.Backream out to intermediate shoe,then utilize MPD to strip out and eliminate swab. • • Z gV O F 4 i iym C 2 Z 5 F PN C m - U = Ca m II o � -D < oN m r cn O I —I 0 o D Z < .8 m ;O a uu o V_ O I I A z A ' p N r F O p n 161. C N E. O J Ai—,r 111111111" lig , ZO , _ pp p _ `, iCn 5 p p NM �\` 4 w /— ill D P ® a ® o I N o 0 N -i n ® a o o I El® a 8 ,0 ® g —0111( ® a gI is >— � 8 El = _ D n y a 75 a yr i �- o m ; 0' ® >— oN N j c D O s— D a xi c. D 12: Z N 0 0 m PTD z! —o Loepp, Victoria T (DOA) From: Brunswick,Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Tuesday, May 31, 2016 8:20 AM To: Loepp,Victoria T(DOA) Subject: 2S-12 PTD Application Follow Up Flag: Follow up Flag Status: Flagged Victoria Due to the rig changing from Doyon 142 to Doyon 141 to drill the 2S-12 well, I've updated the permit application pack (Ann will mark it as revised)to match MD&RKB ND for the well and will be sending it over this morning to make sure you have that paperwork. Given the quick progress they are making on the current well 2S-05,there is a chance the rig will be ready to move to 25-12 this coming Monday June 6th Thx Scott 1 RECIVED . , STATE OF ALASKA AlkA OIL AND GAS CONSERVATION COMI ION MAY 1 2 2016 PERMIT TO DRILL 20 AAC 25.005 G''LG la.Type of Work: lb.Proposed Well Class: Exploratory-Gas El Service- WAG ❑ Service-Disp ❑ i c.Specify if well is p .posed for: Drill Q• Lateral ❑ Stratigraphic Test ❑ Development-Oil CI. Service- Winj ❑ Single Zone LI- Coalbed Gas ❑ as Hydrates ❑ Redrill❑ Reentry❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal IN Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q • Single Well ❑ 11.Well Nam: and Number: ConocoPhillips Alaska,Inc. - Bond No. 59-52-180 : KRU 2S-12 , 3.Address: 6.Proposed Depth: 12.Field/"ool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 16,507 - TVD: • 6,356 Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 3080.5'FNL, 1584.2'FEL,Sec 17,T1ON,R8E,UM • ADL025603,ADL025608 - Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 3.Approximate Spud Date: 3521.1'FNL,559.5'FEL,Sec18,T1ON,R8E,UM 2677,2681 6/11/2016 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 467.8'FNL,2520.4'FEL,Sec30,T1ON,R8E,UM 5035 2585.16'from ADL380053 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-480,986.1' y-5,929,968.0' Zone-4 - GL Elevation above MSL(ft): 1 to Same Pool: 1961.04'f/2S-08 16.Deviated wells: Kickoff depth: ' 500 feet 17.Maximum Potential Pressures in sig(see 20 AAC 25.035) Maximum Hole Angle: • 90 degrees Downhole: 3670 • Surface: 3041 • 18.Casing Program: Specifications Top - Setting Depth Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD D TVD (including stage data) 24" 16" 62.5# H-40 Welded 79' 39' 39' 11: 118' pre-driven,cement to surface 13.5" 10.75" 45.5# L-80 Hydril 563 2839' 39' 39' 878' 2581' 1232 sx 11 ppg lead&271 sx 15.8 ppg tail 9.875" 7.625" 29.7# L-80 Hydril 563 8245' 39' 39' 8284' 6189' 615 sx 1st stg,205 sx 2nd stg classG 6.75" 4.5" 12.6# L-80 IBTM 8407' 8100' 6133' 16507' 6356' N/A-liner 3.5" 9.3# L-80 Hydril 563 8061' 39' 39' 8100' 6133' N/A-tubing 19. PRESENT WELL CONDITION SUMMARY(To be completed for R,•rill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effie,`.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size • Cement Volume MD TVD Conductor/Structural Surface f Intermediate Production Liner Perforation Depth MD(ft): i Perforation Depth TVD(ft): . 20. Attachments: Property Plat ❑ BOP Skett JrDrilling Program Q Time v.Depth Plot 0 Shallow Hazard Analysis Diverter Sk,t., Q Seabed Report ❑ Drilling Fluid Program ❑ ` 20 AAC 25.050 requirements2 21. Verbal Approval: Commission Representative: Nov Date 5,- 11---/ , 22. I hereby certify that the foregoing is true and e pro,'-du - approved herein will not Scott Brunswick @ 263-4249 `% be deviated from without prior written approval. Contact scott.a.brunswick(a�cop.com Email Printed Name G.L..A�lvord Title Alaska Drilling Manager Signature ,� /.-( Phone 265-6120 Date '' . 1 i .(20(G f Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: (216 - 074 50- 103-20413'00-Oc) Date: requirements. Conditions of approval: I ox is checked,well may not be used to explore for,test,or produce coalbed urethan ,gas hydrates,or gas contained in shales: 4 Other: by fits J- �o 00 035 / Samples req'd: Yes No[ Mud log req'd:Yes El No 21 f jt-2,n U I a 7 p YC V evi Per- e`� - .to ?rG d SH2S measures: Yes No nom' Directional svy req'd:Yes[� No❑ Spaci�ig ex9eption req'd: Yes❑ No u Inclination-only svy req'd:Yes❑ No[� Post initial injection MIT req'd:Yes❑ No E APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ?KO .5-114K. Submit Form and Form 10-401(Revised 11/2015) OTRpIrGiivNf months from the fate of,approval(20 AAC 25.005(g)) Attachments in Duplicate • i Application for Permit to Drill,Well 2S-12 Saved: 11-May-16 Post Office Box 100360 Anchorage,Alaska 99510-0360 ConocoPhillips Phone(907)265-6935 ! Email: Scott.A.Brunswickc conocophillips.com May 11,2016 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 MAY 12 2016 Re: Application for Permit to Drill Well 2S-12,A Kuparuk A4 Sand Producer AOGCC Dear Commissioner: ConocoPhillips Alaska, Inc.hereby applies for a permit to drill an onshore grassroots producer well from the 2S pad. The expected spud date for this well is June 11th,2016. It is planned to use rig Doyon 142. 2S-12horizontal - " S is1panned to be a well in the Kuparuk A4 sand. The surface section will be drilled with 13 1/2 bit and run 10-3/4"casing to+/-2,878' MD/2,581' TVD.The intermediate section will be drilled with 9-7/8"x 11"bit/Under Reamer and run 7-5/8"casing to 8,284'MD/6,189'TVD.The production hole will be drilled with 6-3/4"bit and run 4- 1/2"slotted liner to+/- 16,507'MD/6,356'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 Scott Brunswick at 263-4249 (scott.a.brunswick(a,conocophillips.com)or Chip Alvord at 265-6120. Sincerely, i Scott Brunswick Drilling Engineer • • Application for Permit to Drill Documentimmtabi Kuparuk Well 2S-12 conocoPhinlps Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 2S-12 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 owner's 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 stuface,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 3080.5' FNL, 1584.2' FEL, Sec 17, T1ON,R008E,UM NGS Coordinates RKB Elevation 159'AMSL Northings: 5,929,968.02' Eastings: 480,986.1' Pad Elevation 120'AMSL Location at surface Casing 2566.8' FNL,2405.1 FEL, Sec 17,T1ON,R008E,UM NGS Coordinates Measured Depth, RKB: 2,878' Northings: 5,930,483.69'Eastings: 480,165.03' Total Vertical Depth, RKB: 2,581' Total Vertical Depth, SS: 2,422' Location at intremediate 3091.1' FNL,395.9 FEL, Sec 18,T1ON,R008E,UM Casing NGS Coordinates Measured Depth, RKB: 8,284' Northings: 5,929,968.73'Eastings: 476,894.83' Total Vertical Depth, RKB: 6,189' Total Vertical Depth, SS: 6,030' Location at Top of 3521.1' FNL, 559.5'FEL, Sec 18,T1ON,R008E,UM Productive Interval (Kuparuk C4 Sand) NGS Coordinates Measured Depth, RKB: 8,753' Northings: 5,929,539.33'Eastings: 476,731.52' Total Vertical Depth, RKB: 6,284' Total Vertical Depth, SS: 6,125' Location at Total Depth 467.8'FNL, 2520.4' FEL, Sec 30,T1ON,R008E,UM NGS Coordinates Measured Depth, RKB: 16,507' Northings: 5,922,039.66'Eastings: 474,774.41' Total Vertical Depth, RKB: 6,356' Total Vertical Depth, SS: 6,197' 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 • i (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(BOPS)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037,as applicable; Please reference BOP schematics on file for Doyon 142. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied be 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-12 is calculated using an estimated maximum reservoir pressure of 3,670 psi (11.2 ppg (6302' RKB TVD), based on 2S-11 development well), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A4 sand at 6,294' TVD (WP09): A Sand Estimated. BHP = 3,670 psi A Sand estimated depth(WP09) = 6,294' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 629 psi (6,294' TVD * 0.10 psi/ft) MPSP =BHP—gas column =3,041 psi (3,670 psi—629psi) (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-12 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: (51a description of the procedure for conducting formation integrity tests.as required under 20 AAC 25.030 : A procedure is on file with the commission for performing LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre perforated liner,or screen to be installed Casing and Cement Program Casing and Cementing Program Csg/Tbg OD Hole Weight Length Top MD/TVD Btm MD/TVD (in) Pn) (Ib/ft) Grade Conn. (ft) (ft) (ft) Cement Program 16 24 62.5 H-40 Welded 78 Surf 118/118 Existing S i Hydril Cement to Surface with 10-3/4 13-1/2 45.5 L-80 563 2,839 Surf 2,878/2,581 1,232 sx DeepCRETE Lead 11.0 ppg, 271 sx Class G Tail Slurry 15.8 ppg Stage 1: 615 sx Class G at 15.8 ppg w/ 9-7/8 Hydril TOC at 6,827 MD 7-5/8 X 29.7 L-80 563 8,245 Surf 8,284/6,189 Stage 2: 205 sx Class G at 15.8 ppg w/ 11 TOC at 5,282 MD 4 1/2 6-3/4 12.6 L-80 IBTM 8,407 8,100/6,133 16,507/6,356 Uncemented Liner with Frac Sleeves 10-3/4"Surface casing run to 2,878'MD/2,581'TVD Cement from 2,878' MD to 2,378'(500' of tail)with 15.8 ppg Class G,and from 2,378'to surface with 11 ppg DeepCrete.Assume 250%excess annular volume in permafrost and 50%excess below the permafrost(1440'MD),zero excess in 16"conductor. Lead slurry from 2,378' MD to surface with Arctic Lite Crete @ 11 ppg Conductor (118'—0')X 1.339 ft3/ft X 1.0(0%excess) = 158 ft3 Permafrost to Conductor (1,440'—118') X 0.3634 ft3/ft X 3.5(250%excess)= 1,682 ft3 Top of Tail to Permafrost (2,378'—1,440')X 0.3634 ft3/ft X 1.5(50%excess) =512 ft3 Total Volume= 158+ 1,682+512=2,352 ft3=> 1,232sx of 11 ppg DeepCrete @ 1.91 ft3/sk Tail slurry from 2,878' MD to 2,378' MD with 15.8 ppg Class G Shoe to Top of Tail (2,878—2,378')X 0.3634 ft3/ft X 1.50(50%excess) =273 ft3 Shoe Joint (80')X 0.5313 ft3/ft X 1.0(0%excess) =43 ft3 Total Volume=273+43=316 ft3=>271 sx of 15.8 ppg Class G @ 1.17 ft3/sk 7-5/8"Intermediate casing run to 8,284' MD/6,189' TVD 15t stage slurry designed to be at the top of Bermuda/Cairn Formation at 6,827' MD/5,499' TVD.Top of 2m stage slurry is designed to be at 5,282' MD,which is 500' MD above the C-37 top at 5,782'MD/4,759' TVD.Assume 40% excess annular volume. 1st Stage slurry from 8,284' MD to 6,827' MD with 15.8ppg Class G+additives Shoe to Top of Cement (8,284'—6,827')X 0.3425 ft3/ft X 1.40(40%excess) =699 ft3 Shoe Joint (80')X 0.2483 ft3/ft X 1.0(0%excess) =20 ft3 Total Volume=699+20=719 ft3=>615 sx of 15.8 ppg Class G @ 1.17 ft3/sk 2"d Stage slurry from 5,782' MD to 5,282' MD with 15.8ppg Class G+additives Stage Collar to Top of Cement (5,782—5,282)X 0.3425 ft3/ft X 1.40(40%excess) =240 ft3 • • Total Volume=240 ft3=>205sx of 15.8 ppg Class G @ 1.17 ft3/sk Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); Please reference attached diverter schematic for Doyon 142 on 2S pad slot 12. 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 FloPro Mud System (WBM) (WBM) (WBM) Density 9.3- 10 9.6-10.5 10.3-11.5 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 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A -Application is not for an exploratory or stratigraphic test well. I 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 he 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 a • 1. Move in/rig up Doyon Rig 142. Install Annular with 16"diverter line and function test. 2. Spud and directionally drill 13.5"hole to casing point at+/-2,878' MD/2,581'TVD as per directional plan (wp9). 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. Notify AOGCC if this occurs. 5. Remove diverter system,install and test 13-5/8"x 5,000 psi BOP's to 3500 psi(annular preventer to 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 11"Under Reamer and directionally drill to the top of the HRZ 9. Install RCD bearing at this time for use of MPD if necessary. 10. Directionally drill to intermediate TD of 8,284' MD/6,189' TVD,wellsite geologist will call intermediate TD. Circulate and rotate at maximum rates until shakers are clean,minimum of 3 bottoms up. 11. POOH on elevators. Closely monitor drag and address any problem areas by dropping below and circulating/rotating to clean up. 12. Lay down intermediate BHA and rack back 5"DP 13. Run 7-5/8",29.7#L80,Hydril 563 casing from surface to TD at 8,284' MD. 14. Pump two stage cement job as per Schlumberger proposal. Top of first stage to be 6,827' MD(top of Cairn formation),top of second stage to be 5,282' MD(500' above C37). 15. Flush 10-3/4"x 7-5/8"annulus with water,followed by diesel to freeze protect. 16. Lay down 5"DP. 17. PU 4"DP,6-3/4"bit,RSS,and Under Reamer assembly(Gamma,resistivity,Periscope,and neutron density) 18. RIH and clean out cement to 100' above shoe. Test intermediate casing to 3500 psi for 30 minutes. 19. 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. 20. Swap mud over to 10.3 ppg FloPro mud system,using MPD to hold near constant BHP of-11.8 ppg on the heel (for shale stability). 21. Perform selective shale under ream procedure opening shale section to 7.5" 22. Drop RFID chips&close the reamer once BHA has entered sand. 23. Directionally drill 6-3/4"hole geosteering through the Kuparuk A4 sand to TD-16,507'MD as per directional plan(wp9). 24. Circulate hole clean and POOH. 25. Lay down production BHA. 26. PU and run 4-1/2", 12.6#liner. The top of liner will be placed at-8,100' MD,allowing for 150' of overlap in the 7-5/8"casing. • 27. Set liner hanger. Slackoff and set liner top packer. 28. Monitor well for flow for 15 minutes 29. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes,chart results. 30. Flow check well for 30 minutes and POOH 31. Run 3-1/2"upper completion. 32. Nipple down BOPE,nipple up tree and test. 33. Freeze protect well with diesel and install BPV. 34. RDMO. 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 nmd and cuttings and a statement of whether the operator intends to request authorisation under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (1R-18 or new facilities at DS1B). All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well,or stored,tested for hazardous substances,and(if free of hazardous substances)used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Well Schematic Attachment 2 Diverter Layout Diagram Attachment 3 Directional Plan Attachment 4 Drilling Hazards Summary • 0 2S-12 ConocoPhillips Grassroots Horizontal A-Sand Producer Proposed Wellbore Schematic(wp9) `� ,,, 'CAMERON Last Edited:' Brunswick 3/11/16 i '::, -"°.�, 4-%"tree,topjoint is 4-W 12.6#IBTM k'v a ,�`•� 16"Conductor to-118' gs ; 1 s` I 13.5" Surface Hole t ` i ' 3'/z"x 1-'/2"Camco MMG GLM Base West Sak:2,811'MD/2,531'TVD — Surface Casing 10-3/4"45.5#L-80 Hydril 563 2,878' MD/2,581'TVD(41.5` INC) ;, 9-7/8"x 11" Intermediate Hole Tubing: 3-1/2" 9.3#L-80 EUE 8RD-MOD T c_ GLM wl .1 SOV 2"Stage TOC= 500'MD above C-37 Formation at 5,282'MD 11111111 ''..--'3Weatherford Stage Collar:5,782'MD C-37:5,782 MD/4,759'ND iii 1'Stage TOC: Top of Bermuda/Cairn formation) Growler-AA:6,062'MD/4,967'IVO ,41 Baker 2.812"CMU Sliding Cairn:6,827'MD/5,499'ND Sleeve SLB DHc - — �_ 3-%"x 7-5/8",Premier Packer Bermuda:6,961'MD/5,583'TVD lift 3-1/2"2.75"D Nipple HRZ:7,702'MD/5,979'ND • Kalubik:8,057'MD/6,119'TVD _ 5.75"x 4-1/."Swell Packer IIS x.. •••` Kuparuk C:8,753'MD 16,284'ND Kuparuk A4:8,842'MD/6,294'ND-11.2 ppg ' ' -;-111-; n Pack / 4O3 ti,;,,.. ' Vviwd� T. ND) ilt III III Alpha TD:16,507'MD/6,356'ND Intermediate Casing Production Liner: 6-3/4" Production Hole 7-518"29.7#L-80 Hyd563 Casing 4-1/2"12.6#L-80 IBTM with Torque Rings 8,284' MD/6,189'TVD (74° INC) 16,507' MD/6,356'TVD • • ggo C Z c c i N u F N 1— ?,-' > N m N L.1 m A r o O , 0. o D Z 1O , m 0 q v � g g J� O_ I rn 1 rel I1i._ G �1 a•F A '_:' 1 =. ❑�u ` 0 ,` � v w• .,f ` n N\�` i OF, 0 1.501q 5 .%1111411 Elm pp �, o a cD a®T ® o 1/4.° N U, i O ® a . Q ® O O IF m ® H v v ID Po P�. 0 i Di j -I -- 3 n o 1 033 4r D 0 0 D m w O J � . O Z A T I I I T T / m • • DI 2S-12w 09 Bull 6.814 Plan Summary Top Bermuda C-35 Top HRZ _ Top Calm ase Be uda Upper Kalubik(base HRZ) - GB ( Y 5_ 1--- Top W Sak(W Sak D) $ , _5 K-4.5 Marker i C-37 Growler-bA i i r i Lower Kalubik(K-1 mkr) '.. lop Ti and - -. :; , , , I/ .' --- Kuparuk C(Top C4) - 30 0, 'permafrost(?, -‘ , ,'"' ,4,-q_---- A4 To, • -II / C-80 C_50 I. ,B se W Bak 1, I7-5/8"X 9-703"by 11"I - , t I I 0 >� I 1 .„- r I� i i I f i I i I I i I I 0 'r, 0 I 0 4000 8000 12000 16000 �L� I� 16" 42" 110.3/4"x 13-1/21 Measured Depth IIIIII�,�►� 'I oma._--_ Geodetic Datum: North American Datum 1983 ' -3 _0�'p116"x 42'1 Depth Reference: Plan:120+39 @ 159.00usft(Doyon 142) 'ZV Rig: Doyon 142 'M oc 10-3/4"x 13-12'1 o _ r N ti �c, I7-5/8"X 9-7/8"by 11"I 14-12"x 6-3/4" .. 6 5, O ` p cp° °,§, of o 0 0 0 0 0 0 g o C) , 0/ Ni m O O M b 4D -9 I I I I I I 1, I I I I I I I I I I I I 1 39 _..., 500 0 1500 3000 4500 6000 7500 9000 10500 12000 13500 0 500 - 690 Horizontal Departure r ---.--120; 30 690 - 870 330 ..-- '•....:...... ,r. .._; 870 - 1060 1060 - 1240 a -47S3i5WPO2 ° 3-14wp09.3[Whale] _ 1200 - 1430 To_ 60 70090 1430 - 1610 o. _. _ R",.a . ._ ... .. 1610 - 1800 2S-11 U) _.. � , iii '"°"°`° 429°611800 - 2410 b - ;- el 2E-10 ", 24 3030 Permit Pack 3 - 3640 U 30 3640 - 4250 O270 -: ` 90 4250 4860 I2 via- ., U '/ ]zs-,aJ 4860 - 5470 N e y ! 5470 - 6090 I I I I I 1 I I I ' ! 6090 -6700 6700 - 7930 0 2500 5000 7500 10000 12500 15000 240 10; p4".,,ai. ��' ���� !i 1s0 7930 - 9150 SURVEY PROGRAM [/s wed I''r'-=.•,....1... ♦�• Izs Mk 9150 - 1o3e0 1117, �!•1qn( ���i� 10380 - 11600 epth From Depth To Survey/Plan Tool =cm in. ' a. tj��41 39.00 700.00 2S-12wp09[Bull](Plan:2S-12) GYD-GC-SS Pad Elevation: 120.00 210 '�' 1$� 150 11600 - 12830 700.00 1700.00 2S-12w 09 Bull Plan:2S-12) MWD :ea,s�rozI r� 12830 14060 700.00 2877.89 2S-12wp09[Bull](Plan.2S-12) MWD+IFR-AK-CAZ-SC 180 ® 14060 15280 2877.89 4377.89 2S-12wp09[Bull](Plan.2S-12) MWD CASING DETAILS 15280 - 16507 2877.89 8283.22 2S-12wp09[Bull](Plan:2S-12) MWD+IFR-AK-CAZ-SC TVD MD Name SII 8283.22 9783.22 2S-12wp09[Bull](Plan:2S-12) MWD 119,00 119.00 16"x 42" Magnetic Model: BGGM2015 T 8283.22 16506.90 2S-12wp09[Bull](Plan:2S-12) MWD+IFR-AK-CAZ-SC 2581.00 2877.89 10-3/4"x 13-12" Magnetic Model Date: 27-Apr-16 A 6189.00 8283.22 7-5/8"X 9-7/8"by 11" Magnetic Declination: 18.23° 6356.00 16506.90 4-12"x 6-3/4" To convert a Magnetic Direction to a True Direction,Add 18.23°East SECTION DETAILS II m 7jg 1-3 Sand Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 2 500.00 0.00 0.00 500.00 0.00 0.00 0,00 0.00 0.00 KOP:Start 1.5°/100'DLS,345°TF,for 100.01' K-15 Marker 3 600.01 1.50 345.00 600.00 1.26 -0.34 1.50 345.00 -1.13 Start 2.51100'DLS,-10°TF,for 301.48' 4 901.49 9.02 336.64 900.00 26.81 -10.74 2.50 -10.00 -23.11 Adjust TF to-30°,for 485.54' 5 1387.03 20.44 319.13 1369.00 126.23 -81.58 2.50 -30.00 -100.82 Hold for 106.72' 1419.0 6 1493.75 20.44 319.13 1469.00 154.42 -105.98 0.00 0.00 -121.73 Start 3.5°/100'DLS,-45.12°TF for 704.62' 7 2198.37 41.52 292.84 2072.24 340.24 -406.72 3.50 -45.12 -223.38 Hold for 3017.17' Base permafrost(?, 8 5215.54 41.52 292.64 4331.23 1110.02 -2252.71 0.00 0.00 -489.15 Start 2.51100'DLS,-99.25°TF,for 3659.16' 11847.0 9 8874.70 85.00 194.71 6297.00 -555.99 -4286.50 2.50 -99.25 1646.47 20-Bull 01.Heel 042716 PB Hold for 30' 10 8904.70 85.00 194.71 6299.61 -584.89 -4294.08 0.00 0.00 1676.36 Start 41100'DLS,0.04°TF,for 124.51' Top W Sak(W Sak 2) 11 9029.21 89.98 194.71 6305.07 -705.17 -4325.66 4.00 0.04 1800.70 Hold for 5646.33' 12 14675.54 89.98 194.71 6307.00 -6166.34 -5759.77 0.00 0.00 7446.97 25-Bull 2.Toe Start 11100'DLS,-145.19°TF,for 200.55' '2531.0 13 14878.09 88.33 193.57 6309.95 -6360,78 -5808.76 1.00 -145.19 7647.46 Start 0.011100'DLS,18.08°TF,for 1630.8' Base W Sak 14 16506.90 88.43 193.60 6356.00 -7945.33 -6191.64 0.01 18.08 9277.12 25-Bull 3.Toe 021815 PB TD:16506.9'MD,6356'TVD 2907.0 C-80 Updated surface Changed rig, and Moved reservoir Adjusted casing 41870 heel target 200' depths. i c-50 location from as- thus the RKB. 9 p 44750 G4U0 built. South along ;44907 azimuth. �5 Growler-AA S.IMie5ergiw a 5g9 77Cgg-'3p5 • tl/411Uk`C 414Ca NkORZ) II By 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 collision avoid nce Plan as set out in the audit pack 'approve it as the basis for the final well plan and wet/si a drawings I alto acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance Prepared by: Checked by: Accepted by: Approved by: Brij Potnis Nate Beck Ifeanyi Ifesie Bottrell,Brunswick N In Oa. W • Q 3 o a 0 co z Nor ing (3000 usft/in) N cc o co J N O. N Y VJ _ o th t o N O /�_` N N O O E _ N O O co co —....44- M N M O co O n. th N O Ch 3 3 _ —_ N m`z' _ N o I a. Mml y - lt N N L- 9 J TO CU N N N V :i` c0 INN O M N �i1 co N a. N�� co \\12 N (n fp M �r c,c0 a.N _ ai fl ..iii to - Q CO , M CL _ V co N :C.......: ..E.N N M 7 _ liopp--. 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N • - Q 1' ` 1 ifr co1 I 7 x o 0 0 x o 0 0 0 LO szt" C:) Ln o LIT( 8 Ie3!1JeA anal • • [AnB160dAAZ6 ZI__L099I•___A I 00091 M G _x x N OO69L 0c) 0 ■� —2 ♦ma ti V CD 000171. __ CO 00 CD 0 CO Li-5 rd C 0 '410 0002 L _ CD (73 0 U ' a) - , _ r� L U Q 000.E Y - op M -CC ~ 0 W N u z X � , o0 a) w , a 000Q 6 _, CY) as R.. 0 J N oafs N o CD LO 1 , 1 . 0O0B N • I I I o N- Lo N 0 l'-- 0 0 0 x— N CO CO co CO u}daa Irr3!TleA CO co co afJI • • I E ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-12 Plan: 2S-12 Plan: 2S-12wp09 [Bull] Standard Proposal Report 27 April, 2016 41, II I I, 7 • • SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan:2S-12 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:120+39 @ 159.00usft(Doyon 142) Project: Kuparuk River Unit MD Reference: Plan:120+39 @ 159.00usft(Doyon 142) , Site: Kuparuk 2S Pad North Reference: True Well: Plan:2S-12 Survey Calculation Method: Minimum Curvature , Wellbore: Plan:2S-12 Design: 2S-12wp09[Bull] 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: From: Map Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Well Plan:2S-12 Well Position +N/-S 0.00 usft +E/-W 0.00 usft Position Uncertainty 0.00 usft Ground Level: 120.00 usft Wellbore Plan:2S-12 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) l 1,1ir!,1,; lh (0) (nT) BGGM2015 4/27/2016 18.23 80.86 57,482 ar Design 2S-12wp09[Bull] Audit Notes: Extended lateral by 2000ft,updated survey program-VO(02/11/2015) Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 39.00 0.00 0.00 195.00 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (usft) (0) (0) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (0) 39.00 0.00 0.00 39.00 -120.00 0.00 0.00 0.00 0.00 0.00 0.00 500.00 0.00 0.00 500.00 341.00 0.00 0.00 0.00 0.00 0.00 0.00 600.01 1.50 345.00 600.00 441.00 1.26 -0.34 1.50 1.50 0.00 345.00 901.49 9.02 336.64 900.00 741.00 26.81 -10.74 2.50 2.49 -2.77 -10.00 1,387.03 20.44 319.13 1,369.00 1,210.00 126.23 -81.58 2.50 2.35 -3.61 -30.00 1,493.75 20.44 319.13 1,469.00 1,310.00 154.42 -105.98 0.00 0.00 0.00 0.00 2,198.37 41.52 292.64 2,072.24 1,913.24 340.24 -406.72 3.50 2.99 -3.76 -45.12 5,215.54 41.52 292.64 4,331.23 4,172.23 1,110.02 -2,252.71 0.00 0.00 0.00 0.00 8,874.70 85.00 194.71 6,297.00 6,138.00 -555.99 -4,286.50 2.50 1.19 -2.68 -99.25 8,904.70 85.00 194.71 6,299.61 6,140.61 -584.89 -4,294.08 0.00 0.00 0.00 0.00 9,029.21 89.98 194.71 6,305.07 6,146.07 -705.17 -4,325.66 4.00 4.00 0.00 0.04 14,675.54 89.98 194.71 6,307.00 6,148.00 -6,166.34 -5,759.77 0.00 0.00 0.00 0.00 14,876.09 88.33 193.57 6,309.95 6,150.95 -6,360.78 -5,808.76 1.00 -0.82 -0.57 -145.19 16,506.90 88.43 193.60 6,356.00 6,197.00 -7,945.33 -6,191.64 0.01 0.01 0.00 18.08 4/27/2016 2:11:57PM Page 2 COMPASS 5000.1 Build 74 • • SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan:2S-12 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:120+39 @ 159.0ousft(Doyon 142) Project: Kuparuk River Unit MD Reference: Plan:120+39 @ 159.O0usft(Doyon 142) Site: Kuparuk 2S Pad North Reference: True Well: Plan:2S-12 Survey Calculation Method: Minimum Curvature Wellbore: Plan:2S-12 Design: 2S-12wp09[Bull] ,, Planned Survey the line before it. Measured Vertical Depth Inclination Azimuth Depth TVDss +N/-5 +E/-W DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) -120.00 39.00 0.00 0.00 39.00 -120.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 -59.00 0.00 0.00 0.00 0.00 119.00 0.00 0.00 119.00 -40.00 0.00 0.00 0.00 0.00 16"x 42" 200.00 0.00 0.00 200.00 41.00 0.00 0.00 0.00 0.00 289.00 0.00 0.00 289.00 130.00 0.00 0.00 0.00 0.00 top T-3 Sand 300.00 0.00 0.00 300.00 141.00 0.00 0.00 0.00 0.00 369.00 0.00 0.00 369.00 210.00 0.00 0.00 0.00 0.00 K-15 Marker 400.00 0.00 0.00 400.00 241.00 0.00 0.00 0.00 0.00 500.00 0.00 0.00 500.00 341.00 0.00 0.00 0.00 0.00 KOP:Start 1.5°/100'DLS,345°TF,for 100.01' 600.00 1.50 345.00 599.99 440.99 1.26 -0.34 1.50 -1.13 600.01 1.50 345.00 600.00 441.00 1.26 -0.34 1.50 -1.13 Start 2.5°/100'DLS,-10°TF,for 301.48' 700.00 3.99 338.74 699.87 540.87 5.77 -1.94 2.50 -5.07 800.00 6.48 337.30 799.44 640.44 14.22 -5.38 2.50 -12.34 900.00 8.98 336.65 898.52 739.52 26.59 -10.65 2.50 -22.93 901.49 9.02 336.64 900.00 741.00 26.81 -10.74 2.50 -23.11 Adjust TF to-30°,for 485.54' 1,000.00 11.22 330.30 996.97 837.97 42.22 -18.55 2.50 -35.98 1,100.00 13.54 326.00 1,094.64 935.64 60.38 -29.92 2.50 -50.58 1,200.00 15.92 322.95 1,191.35 1,032.35 81.04 -44.73 2.50 -66.70 1,300.00 18.33 320.68 1,286.91 1,127.91 104.15 -62.96 2.50 -84.31 1,387.03 20.44 319.13 1,369.00 1,210.00 126.23 -81.58 2.50 -100.82 Hold for 106.72' 1,400.00 20.44 319.13 1,381.15 1,222.15 129.66 -84.55 0.00 -103.36 1,440.39 20.44 319.13 1,419.00 1,260.00 140.33 -93.78 0.00 -111.27 Base permafrost(?) 1,493.75 20.44 319.13 1,469.00 1,310.00 154.42 -105.98 0.00 -121.73 Start 3.5°/100'DLS,-45.12°TF,for 704.62' 1,500.00 20.60 318.69 1,474.85 1,315.85 156.07 -107.42 3.50 -122.95 1,600.00 23.21 312.43 1,567.64 1,408.64 182.59 -133.58 3.50 -141.79 1,700.00 26.02 307.42 1,658.55 1,499.55 209.22 -165.56 3.50 -159.24 1,800.00 28.98 303.34 1,747.25 1,588.25 235.87 -203.23 3.50 -175.23 1,900.00 32.03 299.97 1,833.40 1,674.40 262.44 -246.45 3.50 -189.71 1,916.08 32.53 299.48 1,847.00 1,688.00 266.70 -253.91 3.50 -191.89 Top W Sak(W Sak D) 2,000.00 35.16 297.13 1,916.70 1,757.70 288.82 -295.06 3.50 -202.61 2,100.00 38.34 294.71 1,996.81 1,837.81 314.93 -348.88 3.50 -213.90 2,198.37 41.52 292.64 2,072.24 1,913.24 340.24 -406.72 3.50 -223.38 Hold for 3017.17' 2,200.00 41.52 292.64 2,073.46 1,914.46 340.65 -407.71 0.00 -223.52 2,300.00 41.52 292.64 2,148.33 1,989.33 366.17 -468.89 0.00 -232.33 4/27/2016 2:11:57PM Page 3 COMPASS 5000.1 Build 74 • • SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan:2S-12 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:120+39 @ 159.00usft(Doyon 142) Project Kuparuk River Unit MD Reference: Plan:120+39 @ 159.00usft(Doyon 142) Site: Kuparuk 2S Pad North Reference: True Well: Plan:2S-12 Survey Calculation Method: Minimum Curvature Wellbore: Plan:2S-12 Design: 2S-12wp09[Bull] Planned Survey Measured Vertical Depth Inclination Azimuth Depth < TVDss +N/-S +E/-W DLS Vert Section (usft) (^) (°) (usft) usft< (usft) (usft) 2,064.20 2,400.00 41.52 292.64 2,223.20 2,064.20 391.68 -530.08 0.00 -241.14 2,500.00 41.52 292.64 2,298.07 2,139.07 417.19 -591.26 0.00 -249.95 2,600.00 41.52 292.64 2,372.94 2,213.94 442.71 -652.44 0.00 -258.76 2,700.00 41.52 292.64 2,447.82 2,288.82 468.22 -713.63 0.00 -267.57 2,800.00 41.52 292.64 2,522.69 2,363.69 493.73 -774.81 0.00 -276.38 2,811.10 41.52 292.64 2,531.00 2,372.00 496.57 -781.60 0.00 -277.35 Base W Sak 2,877.89 41.52 292.64 2,581.00 2,422.00 513.61 -822.46 0.00 -283.24 10-3/4"x 13-1/2" 2,900.00 41.52 292.64 2,597.56 2,438.56 519.25 -835.99 0.00 -285.18 3,000.00 41.52 292.64 2,672.43 2,513.43 544.76 -897.18 0.00 -293.99 3,100.00 41.52 292.64 2,747.30 2,588.30 570.28 -958.36 0.00 -302.80 3,200.00 41.52 292.64 2,822.17 2,663.17 595.79 -1,019.54 0.00 -311.61 3,300.00 41.52 292.64 2,897.04 2,738.04 621.30 -1,080.72 0.00 -320.42 3,313.30 41.52 292.64 2,907.00 2,748.00 624.69 -1,088.86 0.00 -321.59 C-80 3,400.00 41.52 292.64 2,971.91 2,812.91 646.82 -1,141.91 0.00 -329.23 3,500.00 41.52 292.64 3,046.79 2,887.79 672.33 -1,203.09 0.00 -338.04 3,600.00 41.52 292.64 3,121.66 2,962.66 697.84 -1,264.27 0.00 -346.85 3,700.00 41.52 292.64 3,196.53 3,037.53 723.36 -1,325.46 0.00 -355.65 3,800.00 41.52 292.64 3,271.40 3,112.40 748.87 -1,386.64 0.00 -364.46 3,900.00 41.52 292.64 3,346.27 3,187.27 774.38 -1,447.82 0.00 -373.27 4,000.00 41.52 292.64 3,421.14 3,262.14 799.90 -1,509.01 0.00 -382.08 4,100.00 41.52 292.64 3,496.01 3,337.01 825.41 -1,570.19 0.00 -390.89 4,200.00 41.52 292.64 3,570.88 3,411.88 850.92 -1,631.37 0.00 -399.70 4,300.00 41.52 292.64 3,645.76 3,486.76 876.44 -1,692.55 0.00 -408.51 4,400.00 41.52 292.64 3,720.63 3,561.63 901.95 -1,753.74 0.00 -417.32 4,500.00 41.52 292.64 3,795.50 3,636.50 927.46 -1,814.92 0.00 -426.12 4,600.00 41.52 292.64 3,870.37 3,711.37 952.98 -1,876.10 0.00 -434.93 4,700.00 41.52 292.64 3,945.24 3,786.24 978.49 -1,937.29 0.00 -443.74 4,800.00 41.52 292.64 4,020.11 3,861.11 1,004.00 -1,998.47 0.00 -452.55 4,900.00 41.52 292.64 4,094.98 3,935.98 1,029.52 -2,059.65 0.00 -461.36 5,000.00 41.52 292.64 4,169.85 4,010.85 1,055.03 -2,120.84 0.00 -470.17 5,022.90 41.52 292.64 4,187.00 4,028.00 1,060.87 -2,134.85 0.00 -472.19 C-50 5,100.00 41.52 292.64 4,244.73 4,085.73 1,080.54 -2,182.02 0.00 -478.98 5,200.00 41.52 292.64 4,319.60 4,160.60 1,106.06 -2,243.20 0.00 -487.79 5,215.54 41.52 292.64 4,331.23 4,172.23 1,110.02 -2,252.71 0.00 -489.15 Start 2.5°/100'DLS,-99.25°TF,for 3659.16' 5,300.00 41.22 289.47 4,394.62 4,235.62 1,130.08 -2,304.79 2.50 -495.05 5,400.00 40.99 285.69 4,469.98 4,310.98 1,149.93 -2,367.44 2.50 -498.01 5,406.65 40.98 285.43 4,475.00 4,316.00 1,151.10 -2,371.64 2.50 -498.05 C-40 5,500.00 40.87 281.87 4,545.54 4,386.54 1,165.53 -2,431.04 2.50 -496.62 5,600.00 40.89 278.05 4,621.16 4,462.16 1,176.85 -2,495.48 2.50 -490.88 4/27/2016 2:11:57PM Page 4 COMPASS 5000.1 Build 74 • • SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan:2S-12 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:120+39 @ 159.00usft(Doyon 142) Project: Kuparuk River Unit MD Reference: Plan:120+39 @ 159.O0usft(Doyon 142) Site: " Kuparuk 2S Pad North Reference: True Well: Plan:2S-12 Survey Calculation Method: Minimum Curvature Wellbore: Plan:2S-12 Design: 2S-12wp09[Bull] Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/-S +EI-W DLS Vert Section (usft) (0) (0) (usft) usft (usft) (usft) 4,537.69 5,700.00 41.03 274.25 4,696.69 4,537.69 1,183.87 -2,560.63 2.50 -480.79 5,782.72 41.24 271.12 4,759.00 4,600.00 1,186.41 -2,614.97 2.50 -469.19 C-37 5,800.00 41.29 270.47 4,771.99 4,612.99 1,186.57 -2,626.36 2.50 -466.39 5,900.00 41.68 266.74 4,846.92 4,687.92 1,184.95 -2,692.56 2.50 -447.69 6,000.00 42.18 263.07 4,921.33 4,762.33 1,179.01 -2,759.09 2.50 -424.73 6,061.81 42.55 260.85 4,967.00 4,808.00 1,173.18 -2,800.33 2.50 -408.43 Growler-AA 6,100.00 42.80 259.49 4,995.08 4,836.08 1,168.76 -2,825.83 2.50 -397.56 6,200.00 43.53 255.99 5,068.03 4,909.03 1,154.23 -2,892.65 2.50 -366.22 6,300.00 44.36 252.59 5,140.04 4,981.04 1,135.43 -2,959.43 2.50 -330.78 6,400.00 45.29 249.30 5,210.98 5,051.98 1,112.41 -3,026.04 2.50 -291.31 6,500.00 46.31 246.12 5,280.71 5,121.71 1,085.21 -3,092.34 2.50 -247.87 6,600.00 47.41 243.04 5,349.09 5,190.09 1,053.88 -3,158.22 2.50 -200.56 6,700.00 48.60 240.08 5,416.01 5,257.01 1,018.48 -3,223.55 2.50 -149.46 6,800.00 49.86 237.23 5,481.32 5,322.32 979.08 -3,288.20 2.50 -94.66 6,827.52 50.21 236.46 5,499.00 5,340.00 967.54 -3,305.86 2.50 -78.95 Top Cairn 6,900.00 51.18 234.48 5,544.91 5,385.91 935.75 -3,352.06 2.50 -36.28 6,961.33 52.03 232.85 5,583.00 5,424.00 907.27 -3,390.77 2.50 1.24 Top Bermuda 7,000.00 52.57 231.84 5,606.65 5,447.65 888.57 -3,415.00 2.50 25.57 7,100.00 54.01 229.29 5,666.43 5,507.43 837.64 -3,476.89 2.50 90.78 7,107.79 54.13 229.10 5,671.00 5,512.00 833.52 -3,481.66 2.50 96.00 Base Bermuda 7,162.94 54.95 227.74 5,703.00 5,544.00 803.71 -3,515.27 2.50 133.50 C-35 7,200.00 55.51 226.84 5,724.13 5,565.13 783.06 -3,537.63 2.50 159.23 7,300.00 57.05 224.47 5,779.65 5,620.65 724.92 -3,597.10 2.50 230.78 7,400.00 58.64 222.19 5,832.87 5,673.87 663.34 -3,655.18 2.50 305.30 7,500.00 60.26 219.99 5,883.70 5,724.70 598.43 -3,711.76 2.50 382.64 7,600.00 61.93 217.85 5,932.04 5,773.04 530.32 -3,766.74 2.50 462.66 7,700.00 63.62 215.78 5,977.80 5,818.80 459.13 -3,820.01 2.50 545.20 7,702.71 63.66 215.73 5,979.00 5,820.00 457.16 -3,821.42 2.50 547.47 Top HRZ 7,800.00 65.34 213.77 6,020.88 5,861.88 385.01 -3,871.46 2.50 630.12 7,900.00 67.09 211.82 6,061.22 5,902.22 308.09 -3,921.01 2.50 717.24 8,000.00 68.86 209.92 6,098.73 5,939.73 228.53 -3,968.56 2.50 806.40 8,057.55 69.89 208.84 6,119.00 5,960.00 181.59 -3,994.98 2.50 858.57 Upper Kalubik(base HRZ) 8,100.00 70.65 208.06 6,133.33 5,974.33 146.46 -4,014.01 2.50 897.43 8,200.00 72.46 206.24 6,164.97 6,005.97 62.05 -4,057.29 2.50 990.17 8,276.00 73.85 204.88 6,187.00 6,028.00 -3.56 -4,088.67 2.50 1,061.67 Lower Kalubik(K-1 mkr) 4/27/2016 2:11:57PM Page 5 COMPASS 5000.1 Build 74 • • SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan:2S-12 X Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:120+39 @ 159.O0usft(Doyon 142) Project: Kuparuk River Unit MD Reference: Plan:120+39 @ 159.00usft(Doyon 142) Site: Kuparuk 2S Pad North Reference: True i' Well: Plan:2S-12 Survey Calculation Method: Minimum Curvature Wellbore: Plan:2S-12 ib Design: 2S-12wp09[Bull] Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/-S +E/-W DLS Vert Section (usft) (e) (°) >(usft) usft (usft) (usft) 6,030.00 8,283.22 73.98 204.75 6,189.00 6,030.00 -9.86 -4,091.58 2.50 1,068.50 7-5/8"X 9-7/8"by 11" 8,300.00 74.29 204.46 6,193.59 6,034.59 -24.54 -4,098.30 2.50 1,084.42 8,400.00 76.13 202.71 6,219.12 6,060.12 -113.14 -4,136.97 2.50 1,180.01 8,500.00 77.98 200.98 6,241.53 6,082.53 -203.60 -4,173.23 2.50 1,276.77 8,600.00 79.84 199.29 6,260.76 6,101.76 -295.72 -4,207.00 2.50 1,374.50 8,700.00 81.71 197.61 6,276.79 6,117.79 -389.35 -4,238.23 2.50 1,473.02 8,753.22 82.71 196.72 6,284.00 6,125.00 -439.74 -4,253.79 2.50 1,525.72 Kuparuk C(Top C4) 8,800.00 83.59 195.94 6,289.58 6,130.58 -484.31 -4,266.85 2.50 1,572.14 8,842.25 84.39 195.25 6,294.00 6,135.00 -524.78 -4,278.15 2.50 1,614.16 A4 8,874.70 85.00 194.71 6,297.00 6,138.00 -555.99 -4,286.50 2.50 1,646.47 Hold for 30' 8,900.00 85.00 194.71 6,299.21 6,140.21 -580.37 -4,292.90 0.00 1,671.67 8,904.70 85.00 194.71 6,299.61 6,140.61 -584.89 -4,294.08 0.00 1,676.36 Start 4°/100'DLS,0.04°TF,for 124.51' 9,000.00 88.81 194.71 6,304.76 6,145.76 -676.92 -4,318.25 4.00 1,771.50 9,029.21 89.98 194.71 6,305.07 6,146.07 -705.17 -4,325.66 4.00 1,800.70 Hold for 5646.33' 9,100.00 89.98 194.71 6,305.09 6,146.09 -773.64 -4,343.64 0.00 1,871.49 9,200.00 89.98 194.71 6,305.12 6,146.12 -870.36 -4,369.04 0.00 1,971.49 9,300.00 89.98 194.71 6,305.16 6,146.16 -967.08 -4,394.44 0.00 2,071.49 9,400.00 89.98 194.71 6,305.19 6,146.19 -1,063.80 -4,419.84 0.00 2,171.49 9,500.00 89.98 194.71 6,305.23 6,146.23 -1,160.52 -4,445.24 0.00 2,271.49 9,600.00 89.98 194.71 6,305.26 6,146.26 -1,257.24 -4,470.64 0.00 2,371.49 9,700.00 89.98 194.71 6,305.30 6,146.30 -1,353.96 -4,496.04 0.00 2,471.49 9,800.00 89.98 194.71 6,305.33 6,146.33 -1,450.68 -4,521.44 0.00 2,571.49 9,900.00 89.98 194.71 6,305.36 6,146.36 -1,547.40 -4,546.84 0.00 2,671.48 10,000.00 89.98 194.71 6,305.40 6,146.40 -1,644.12 -4,572.23 0.00 2,771.48 10,100.00 89.98 194.71 6,305.43 6,146.43 -1,740.85 -4,597.63 0.00 2,871.48 10,200.00 89.98 194.71 6,305.47 6,146.47 -1,837.57 -4,623.03 0.00 2,971.48 10,300.00 89.98 194.71 6,305.50 6,146.50 -1,934.29 -4,648.43 0.00 3,071.48 10,400.00 89.98 194.71 6,305.53 6,146.53 -2,031.01 -4,673.83 0.00 3,171.48 10,500.00 89.98 194.71 6,305.57 6,146.57 -2,127.73 -4,699.23 0.00 3,271.48 10,600.00 89.98 194.71 6,305.60 6,146.60 -2,224.45 -4,724.63 0.00 3,371.48 10,700.00 89.98 194.71 6,305.64 6,146.64 -2,321.17 -4,750.03 0.00 3,471.47 10,800.00 89.98 194.71 6,305.67 6,146.67 -2,417.89 -4,775.43 0.00 3,571.47 10,900.00 89.98 194.71 6,305.71 6,146.71 -2,514.61 -4,800.82 0.00 3,671.47 11,000.00 89.98 194.71 6,305.74 6,146.74 -2,611.33 -4,826.22 0.00 3,771.47 11,100.00 89.98 194.71 6,305.77 6,146.77 -2,708.05 -4,851.62 0.00 3,871.47 11,200.00 89.98 194.71 6,305.81 6,146.81 -2,804.77 -4,877.02 0.00 3,971.47 11,300.00 89.98 194.71 6,305.84 6,146.84 -2,901.49 -4,902.42 0.00 4,071.47 11,400.00 89.98 194.71 6,305.88 6,146.88 -2,998.21 -4,927.82 0.00 4,171.47 11,500.00 89.98 194.71 6,305.91 6,146.91 -3,094.94 -4,953.22 0.00 4,271.46 4/27/2016 2:11:57PM Page 6 COMPASS 5000.1 Build 74 • • SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan:2S-12 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:120+39 @ 159.00usft(Doyon 142) Project: Kuparuk River Unit MD Reference: Plan:120+39 @ 159.00usft(Doyon 142) Site: Kuparuk 2S Pad North Reference: True Well: Plan:2S-12 Survey Calculation Method: Minimum Curvature Wellbore: Plan:2S-12 Design: 2S-12wp09[Bull] Planned Survey .s i.wra�i a Measured Vertical Depth Inclination Azimuth Depth TVDss +N/-S +E/-W DLS Vert Section (usft) (°) (0) (usft) usft (usft) (usft) 6,146.95 11,600.00 89.98 194.71 6,305.95 6,146.95 -3,191.66 -4,978.62 0.00 4,371.46 11,700.00 89.98 194.71 6,305.98 6,146.98 -3,288.38 -5,004.01 0.00 4,471.46 11,800.00 89.98 194.71 6,306.01 6,147.01 -3,385.10 -5,029.41 0.00 4,571.46 11,900.00 89.98 194.71 6,306.05 6,147.05 -3,481.82 -5,054.81 0.00 4,671.46 12,000.00 89.98 194.71 6,306.08 6,147.08 -3,578.54 -5,080.21 0.00 4,771.46 12,100.00 89.98 194.71 6,306.12 6,147.12 -3,675.26 -5,105.61 0.00 4,871.46 12,200.00 89.98 194.71 6,306.15 6,147.15 -3,771.98 -5,131.01 0.00 4,971.46 12,300.00 89.98 194.71 6,306.19 6,147.19 -3,868.70 -5,156.41 0.00 5,071.45 12,400.00 89.98 194.71 6,306.22 6,147.22 -3,965.42 -5,181.81 0.00 5,171.45 12,500.00 89.98 194.71 6,306.25 6,147.25 -4,062.14 -5,207.21 0.00 5,271.45 12,600.00 89.98 194.71 6,306.29 6,147.29 -4,158.86 -5,232.60 0.00 5,371.45 12,700.00 89.98 194.71 6,306.32 6,147.32 -4,255.58 -5,258.00 0.00 5,471.45 12,800.00 89.98 194.71 6,306.36 6,147.36 -4,352.30 -5,283.40 0.00 5,571.45 12,900.00 89.98 194.71 6,306.39 6,147.39 -4,449.03 -5,308.80 0.00 5,671.45 13,000.00 89.98 194.71 6,306.43 6,147.43 -4,545.75 -5,334.20 0.00 5,771.45 13,100.00 89.98 194.71 6,306.46 6,147.46 -4,642.47 -5,359.60 0.00 5,871.44 13,200.00 89.98 194.71 6,306.49 6,147.49 -4,739.19 -5,385.00 0.00 5,971.44 13,300.00 89.98 194.71 6,306.53 6,147.53 -4,835.91 -5,410.40 0.00 6,071.44 13,400.00 89.98 194.71 6,306.56 6,147.56 -4,932.63 -5,435.80 0.00 6,171.44 13,500.00 89.98 194.71 6,306.60 6,147.60 -5,029.35 -5,461.19 0.00 6,271.44 13,600.00 89.98 194.71 6,306.63 6,147.63 -5,126.07 -5,486.59 0.00 6,371.44 13,700.00 89.98 194.71 6,306.67 6,147.67 -5,222.79 -5,511.99 0.00 6,471.44 13,800.00 89.98 194.71 6,306.70 6,147.70 -5,319.51 -5,537.39 0.00 6,571.44 13,900.00 89.98 194.71 6,306.73 6,147.73 -5,416.23 -5,562.79 0.00 6,671.43 14,000.00 89.98 194.71 6,306.77 6,147.77 -5,512.95 -5,588.19 0.00 6,771.43 14,100.00 89.98 194.71 6,306.80 6,147.80 -5,609.67 -5,613.59 0.00 6,871.43 14,200.00 89.98 194.71 6,306.84 6,147.84 -5,706.39 -5,638.99 0.00 6,971.43 14,300.00 89.98 194.71 6,306.87 6,147.87 -5,803.12 -5,664.39 0.00 7,071.43 14,400.00 89.98 194.71 6,306.91 6,147.91 -5,899.84 -5,689.78 0.00 7,171.43 14,500.00 89.98 194.71 6,306.94 6,147.94 -5,996.56 -5,715.18 0.00 7,271.43 14,600.00 89.98 194.71 6,306.97 6,147.97 -6,093.28 -5,740.58 0.00 7,371.43 14,675.54 89.98 194.71 6,307.00 6,148.00 -6,166.34 -5,759.77 0.00 7,446.97 Start 1°1100'DLS,-145.19°TF,for 200.55' 14,700.00 89.78 194.57 6,307.05 6,148.05 -6,190.01 -5,765.95 1.00 7,471.42 14,800.00 88.96 194.00 6,308.15 6,149.15 -6,286.90 -5,790.63 1.00 7,571.41 14,876.09 88.33 193.57 6,309.95 6,150.95 -6,360.78 -5,808.76 1.00 7,647.46 Start 0.01°/100'DLS,18.08°TF,for 1630.8' 14,900.00 88.34 193.57 6,310.65 6,151.65 -6,384.01 -5,814.37 0.01 7,671.35 15,000.00 88.34 193.57 6,313.55 6,154.55 -6,481.18 -5,837.82 0.01 7,771.28 15,100.00 88.35 193.57 6,316.43 6,157.43 -6,578.35 -5,861.28 0.01 7,871.21 15,200.00 88.35 193.57 6,319.31 6,160.31 -6,675.52 -5,884.74 0.01 7,971.13 15,300.00 88.36 193.58 6,322.18 6,163.18 -6,772.68 -5,908.20 0.01 8,071.06 15,400.00 88.36 193.58 6,325.04 6,166.04 -6,869.85 -5,931.67 0.01 8,170.99 15,500.00 88.37 193.58 6,327.89 6,168.89 -6,967.01 -5,955.14 0.01 8,270.92 15,600.00 88.38 193.58 6,330.73 6,171.73 -7,064.18 -5,978.61 0.01 8,370.85 4/27/2016 2:11.57PM Page 7 COMPASS 5000.1 Build 74 • • SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan:2S-12 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:120+39 @ 159.00usft(Doyon 142) Project: Kuparuk River Unit MD Reference: Plan:120+39 @ 159.00usft(Doyon 142) Site: Kuparuk 2S Pad North Reference: True Well: Plan:2S-12 Survey Calculation Method: Minimum Curvature Wellbore: Plan:2S-12 Design: 2S-12wp09[Bull] Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/-S +E/-W DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) 6,174.56 15,700.00 88.38 193.58 6,333.56 6,174.56 -7,161.34 -6,002.09 0.01 8,470.78 15,800.00 88.39 193.59 6,336.38 6,177.38 -7,258.50 -6,025.57 0.01 8,570.71 15,900.00 88.39 193.59 6,339.18 6,180.18 -7,355.67 -6,049.05 0.01 8,670.64 16,000.00 88.40 193.59 6,341.98 6,182.98 -7,452.83 -6,072.54 0.01 8,770.57 16,100.00 88.41 193.59 6,344.77 6,185.77 -7,549.99 -6,096.03 0.01 8,870.50 16,200.00 88.41 193.59 6,347.54 6,188.54 -7,647.15 -6,119.52 0.01 8,970.43 16,300.00 88.42 193.60 6,350.31 6,191.31 -7,744.31 -6,143.02 0.01 9,070.36 16,400.00 88.42 193.60 6,353.07 6,194.07 -7,841.47 -6,166.52 0.01 9,170.29 16,500.00 88.43 193.60 6,355.81 6,196.81 -7,938.63 -6,190.02 0.01 9,270.23 16,506.90 88.43 193.60 6,356.00 6,197.00 -7,945.33 -6,191.64 0.01 9,277.12 TD:16506.9'MD,6356'TVD Targets Target Name -<hit/miss target Dip Angle` Dip Dir. TVD +N/-S +EI-W -Shape (°) (°); (usft) (usft), (usft) 411=1/ .....11116111../mMi IMO alMM 2S-Bull 3.Toe 021815 PB 0.00 0.00 6,356.00 -7,945.33 -6,191.64 -plan hits target center -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 119.00 119.00 16"x 42" 16 42 2,877.89 2,581.00 10-3/4"x 13-1/2" 10-3/4 13-1/2 16,506.90 6,356.00 4-1/2"x 6-3/4" 4-1/2 6-3/4 8,283.22 6,189.00 7-5/8"X 9-7/8"by 11" 7-5/8 11 4/27/2016 2.11:57PM Page 8 COMPASS 5000.1 Build 74 • • SLB Standard Proposal Report k Database: EDM Production Local Co-ordinate Reference: Well Plan:2S-12 i Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:120+39 @ 159.00usft(Doyon 142) Project: Kuparuk River Unit MD Reference: Plan:120+39 @ 159.00usft(Doyon 142) I.- .,-.. Site: Kuparuk 2S Pad North Reference: True r Well: Plan:2S-12 Survey Calculation Method: Minimum Curvature i,! Wellbore: Plan:2S-12 Design: 2S-12wp09[Bull] Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (1 (°) 369.00 369.00 K-15 Marker 7,702.71 5,979.00 Top HRZ 6,827.52 5,499.00 Top Cairn 1,440.39 1,419.00 Base permafrost(?) 289.00 289.00 top T-3 Sand 6,061.81 4,967.00 Growler-AA 8,276.00 6,187.00 Lower Kalubik(K-1 mkr) 2,811.10 2,531.00 Base W Sak 6,961.33 5,583.00 Top Bermuda 7,107.79 5,671.00 Base Bermuda 7,162.94 5,703.00 C-35 5,782.72 4,759.00 C-37 8,842.25 6,294.00 A4 1,916.08 1,847.00 Top W Sak(W Sak D) 5,406.65 4,475.00 C-40 8,057.55 6,119.00 Upper Kalubik(base HRZ) 3,313.30 2,907.00 C-80 5,022.90 4,187.00 C-50 8,753.22 6,284.00 Kuparuk C(Top C4) Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W ,° (usft) (usft) (usft) (usft) Comment "I" t0IIIId 0 ° 500.00 500.00 0.00 0.00 KOP:Start 1.5°/100'DLS,345°TF,for 100.01' 600.01 600.00 1.26 -0.34 Start 2.57100'DLS,-10°TF,for 301.48' 901.49 900.00 26.81 -10.74 Adjust TF to-30°,for 485.54' 1,387.03 1,369.00 126.23 -81.58 Hold for 106.72' 1,493.75 1,469.00 154.42 -105.98 Start 3.5°/100'DLS,-45.12°TF,for 704.62' 2,198.37 2,072.24 340.24 -406.72 Hold for 3017.17' 5,215.54 4,331.23 1,110.02 -2,252.71 Start 2.5°/100'DLS,-99.25°TF,for 3659.16' 8,874.70 6,297.00 -555.99 -4,286.50 Hold for 30' 8,904.70 6,299.61 -584.89 -4,294.08 Start 4°/100'DLS,0.04°TF,for 124.51' 9,029.21 6,305.07 -705.17 -4,325.66 Hold for 5646.33' 14,675.54 6,307.00 -6,166.34 -5,759.77 Start 1°/100'DLS,-145.19°TF,for 200.55' 14,876.09 6,309.95 -6,360.78 -5,808.76 Start 0.01°/100'DLS,18.08°TF,for 1630.8' 16,506.90 6,356.00 -7,945.33 -6,191.64 TD:16506.9'MD,6356'TVD 4/27/2016 2.11:57PM Page 9 COMPASS 5000.1 Build 74 • • N O. 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O O. 7 V' V' V 1` n CO W O 0 ,- CO CO M M M M N N N N N N N E O O O O O o O o r r 7 7 C C C C C C C 0 c7) re tr y o J () U Y N m N m m m m m m m m m m Nm m m (nN Nm (Nn 0- 0 aN a0 a0 a a0 a0 ., U C C Qt ' U U H (r N N s N '_' G E v) a x a aca /1 o c, Y Y Y G N N N a' 2 2 cc cy ct N O O O d Q 2 2 2 N CO N N N Q N N CM (9 N N Q 0_ 0_ O o to a mE `o a, `o O CO E m c m U z'= U 0 U U o o Em d m C 0 0 7 co E' co H N N N 0 0 0 CD m < <00 2 Y Y Y N- O CO 3 0) < Q Q U N- N r d' d' R N• ii 0' 00 0 0 00 U } o o O a o o O CM O o (a N aig V V V U) d 0 7 pE V N 03 N- C a) s- CO d la co N N ,j, E W Q W0-‘, y LoO a) O O a C o o M i Q) O oi a a1 o t a) o nm m O Q.= co V V' d m m w m O - w o 6 w Eto Ca N. ro C co N a) 1 .1 E N O O O tl) 7 U E. co M C'') a E R (A a N CC O C - RE 0 V 2 (0 0 0 ° Qa COmmCOmmCO m . = a a m o o d N CO 2. d L a) O V) 0 0 0 0 0 0 0 _Q ss); o r - U ._ 3 y Cl Cl Cl Q Cl Q Q a) W N w an d 3 3 3 3 3 3 3 T N C x w 0 `a N N N N N N N C y O E to u) u) co u) u) u) a N N N N N N N N 2 p E t' N d i] d d ' O ' N N 5. N ? • o o m m N N m N 3 N (D • «� N C O O t` n M C7 c0 O O m 0 ) co N y O a O O N CO_ N CO O Q N N y m . c ~ CV Co CZ CO o � 8 E ` n• t o rn a) .0 . 2 N N 4 7 N o N C CU V) N D U 0 L o a N 0 2 C ' >> O N C r • j St a CV CV N A M Q Q E O O O a) a) N N N N a N 0 L a C 0 u_ CM 0 3 3 co 0 0 0 co CO N N � `C N C — C1 U F A C) z o Lo L W O O f. i` C7 M (M C — O �O G M 2 U y ''- E M 0 0 N- N- CO CO N N C O 2 c M M O O W r n Cu CO N N N N N L C- }) C a • C _a U) U) L LI- .�.. N N CO CO- O O m L co co = U) N N U .2 N N N N CN- ri. N O u) y U 3 a a n O a (a C C Q O v N 01 V co co 2 N C c .L.. m U NO E " �, d (n (n m m N o N a Ce 'x CM N j CM U) N N d ` O N N C 2 a (o m Z N C c $ ° -° a) m 3 o p_ 3 h C (O N U N C N co O tY ° a a n E a to `m m o N 'N o cri o m . 'n 'n o .� m c u z O N N N ':-I- M M - Q „L.,, C) i a i\ �_ N N d '' y N ▪ U) C) (N N m o N O C 7 a N N N `O C IO U C) - 0 C a Z E C C C N O C _ O U T C R R y (6 (0 N N Q) C O �� U i �' �' CO U d Q. 0_ C N 6 C CS R 0_`'' U Q coIL, co N N Q R — — F Ce m to W 0 0) 6 0 Q 1 • 14:12. April 27 2011 Ladder View 2S-12w„09 Bull r [Bull] The Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. 2 I � NE �vt3x� Y4S 4 NW MI N N , i 1 111 i I 300 I 0 O II 1 1'El Ili ��l 111 1 d ”' nm61B1n��l� t I 1 I a) II I i ' Illullalillillllllll i, I - 150 allll 1,1 N OK/ 1 II U I o ,1j1101 11 c ...940014,aIN.01,,II II N 1 ..._. 4II�I •ap:I]I O Equrvelant Magnetic Distance I 1 1 1 1 I 1 1 1 1 I I I I I I I I I I I I 0 2500 5000 7500 10000 12500 15000 Displayed interval could be less than entire well:Measured Depth 39.00 To 16506.90 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.00 700.00 2S-12wp09 [Bull] (Plan: 2S-12) GYD-GC-SS 119.00 119.00 16"x 42" 700.00 1700.00 2S-12wp09 [Bull] (Plan: 2S-12) MWD 2581.00 2877.89 10-3/4" x 13-1/2" 700.00 2877.89 25-12wp09 [Bull] (Plan: 2S-12) MWD+IFR-AK-CAZ-SC 6189.00 8283.22 7-5/8"X 9-7/8" by 11" 2877.89 4377.89 25-12wp09 [Bull] (Plan: 2S-12) MWD 6356.00 16506.90 4-1/2"x 6-3/4" 2877.89 8283.22 2S-12wp09 [Bull] (Plan: 2S-12) MWD+IFR-AK-CAZ-SC 8283.22 9783.22 2S-12wp09 [Bull] (Plan: 2S-12) MWD 8283.22 16506.90 2S-12wp09 [Bull] (Plan: 2S-12) MWD+IFR-AK-CAZ-SC -17 g. M p n 3 vi v CO U) N N N 1 . 11 r ii a - U N - f C 0) - U I ' o ,I I I I I I l I I l I l l 1 I I I I I 1 I I I I I 1 l I f 1 0 500 1000 1500 2000 2500 3000 3500 Equivelant Magnetic Distance Partial Measured Depth sy bUU 2S-12wp09 [Bull] 111 MD Inc Azi TVD Dleg TFace Tall, 500 " ' 690 39.00 0.00 0.00 39.00 0.00 0.00 39.00 TO 16506.90 500.00 0.00 0.00 500.00 0.00 0.00 690 870 600.01 1.50 345.00 600.00 1.50 345.00 901.49 9.02 336.64 900.00 2.50 -10.00 870 1060 14:13,April 27 2016 1387.03 20.44 319.13 1369.00 2.50 -30.00 1060 1240 1493.75 20.44 319.13 1469.00 0.00 0.00 CASING DETAILS 2198.37 41.52 292.64 2072.24 3.50 -45.12 1240 ------ 1430 5215.54 41.52 292.64 4331.23 0.00 0.00 TVD MD Name 8874.70 85.00 194.71 6297.00 2.50 -99.25 2S-Bull 01.Heel 042716 PB 1430 1610 119.00 119.00 16" x 42" 8904.70 85.00 194.71 6299.61 0.00 0.00 2581.00 2877.89 10-3/4" x 13-1/2" 9029.21 89.98 194.71 6305.07 4.00 0.04 1610 1800 6189.00 8283.72-Z/8" X 9-7/8" by 11" 14675.54 89.98 194.71 6307.00 0.00 0.00 2S-Bull 2.Toe 6356.00 16506.90 4-1/2" x 6-3/4" 14876.09 88.33 193.57 6309.95 1.00 -145.19 1800 2410 16506.90 88.43 193.60 6356.00 0.01 18.08 2S-Bull 3.Toe 021815 PB SURVEY PROGRAM 2410 3030 ep1M 9.8 De 00 88 Suw2,90 ap ,•pa, 3030 3640 39.00 ]00.00 25-12,.6 [Bull] (Plan:25-12) Glm-GG-55 706.08 1807.89 25-121497 [Bull] (Plan:25-12) WO ]07.80 2877.89 25-12x498 [Bull] (Plan:25-12) MIA*IFR-AK-CA.-SC 2877.89 8277.89 25-121498 [Bull] (Plan:25-12) MIA 3640 4250 2273.22 9783.22 2S-121490 [Bull] (Plan:25-12) x0.0 -AK-GAZ-SG 9283.22 9783.22 25-1220 [8011] (Plan:25-12) MW " - 8283.22 16508.90 25-12,..y0 (Plan 2S-12) MM9a R-A 4250 - " " 4860 4860 5470 5470 6090 6090 """ """ 6700 6700 7930 0/360 7930 9150 225 9150 ®" 10380 -30/330 210 30 10380 11600 19� 11600 12830 �1®`� 12830 14060 180 1�®� 165 )�\ye 14060 15280 150 4t�®��`� 15280 16507 -60/300 12 1 A���•��� 60 90 4% tri 75 lk f'�� "*AA [Salmon] ----:"1-0-6 k Ay - .'kzk'sf..,v,T:WI -,,,,,,7---.7>,,A ,7,-Mfry,,J:i,.V.I7CAVV.5::4 r '7 90/270w ,4r A 4 , `1 �1 4,51 `x4 4 � 1 „..,,,-..0.46.► . iipiNNr.A7 . ��=//��A-, ; . ��"si 1,�i�r' 1�R�t. *4'0/ -•� .44-:,•••✓�1•'1 T• AV1.9.2[Nurse] i /�� w�'��Zr 61 I-.li 1•I��1 �Ij�f�Are;7ji i ' 1avii-4 0.4iie Cii Ali x i 1 1\v A :1/k. 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N0 M - N LNn c0 00 d' d- q0 0 0 0 0 0 N- 0 0 0 0 0 0 0 0 0 M co 0 o 0 0 M � L(1 � �- 0 � 0 0 O in o O N- O N d-' ".O co d' 0 0N CO d- 0 N- d*\ 0 `p o0 0 N Lf oo .-- , .-- N M M d- d- t_r\ 0 ".O N.. M O . M O\ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M 0 O" n ' d- M 7 0 M d- tr n O 0 M CO O M ".0 00 t11 00 ON d- 00 O ".O N 00 d- O N- a\ M k..000 0 N N M M 'Cl- d- L ,D n 0" 0c- N d- O 01 O �- N a �j r '^ z ¢ LT to , r • T r m 2222 '\\ \, m m m m m m m m f \ \ doo � TI rr.;.r nn m r " � z . r r er � � \.. O 0 0 0°o 4 4 LLPoo O O O p pry.NO O 00 0 O O 00 t F X v A. j/ / Ucoos ,A• O N m \ ..,,, M N gSo M `N / LI*1 0 01 o \ �- M M q) 0 CO 0 LA N 0 o 1.--1 `p N N ON r- O I tri CS 0 .N 0 0 0 c MMd- d- C` 0 'L o 0 OqO 7 7 � � � � � � Lr, 0 a to d1 N N d` d' d` d' M M Q O O rn O d- d1 M 01 d-N p1 LA M M M M N N r . p 0 0 ' o M u1 n d- 0 0 1- d- 0' 0 V1 C) aN 0 00 71- N mCOO 1C" � 0 CYN N C) Mo 0 00o Cr ' N. O N N- N- 0 1f tr .o rn M d- r- N GO rn O ' co I \ _ .- r- N V1 00 CO � d- d` O I • ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-12 Plan: 2S-12 Plan: 2S-12wp09 [Bull] Error Ellipse Survey Report 27 April, 2016 • SLB • Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-12 Project: Kuparuk River Unit TVD Reference: Plan:120+39 @ 159.00usft(Doyon 142) Site: Kuparuk 2S Pad MD Reference: Plan:120+39 @ 159.00usft(Doyon 142) Well: Plan:2S-12 North Reference: True Wellbore: Plan:2S-12 Survey Calculation Method: Minimum Curvature Design: 2S-12wp09[Bull] Output errors are at 1.00 sigma Database: EDM Production Survey Tool Program Date 4/27/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 39.00 700.00 2S-12wp09[Bull](Plan:2S-12) GYD-GC-SS Gyrodata gyro single shots 700.00 1,700.00 2S-12wp09[Bull](Plan:2S-12) MWD MWD-Standard 700.00 2,877.89 2S-12wp09[Bull](Plan:2S-12) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,877.89 4,377.89 2S-12wp09[Bull](Plan:2S-12) MWD MWD-Standard 2,877.89 8,283.22 2S-12wp09[Bull](Plan:2S-12) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,283.22 9,783.22 2S-12wp09[Bull](Plan:2S-12) MWD MWD-Standard 8,283.22 16,506.90 2S-12wp09[Bull](Plan:2S-12) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi-major Semi-minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (") (1 (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) P1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 UNDEFINED 119.00 0.00 0.00 119.00 0.19 0.00 0.19 0.00 1.15 0.00 0.00 0.19 0.19 0.00 GYD-GC-SS(1,1) 289.00 0.00 0.00 289.00 0.33 0.00 0.33 0.00 1.15 0.00 0.00 0.33 0.33 0.00 GYD-GC-SS(1,1) 369.00 0.00 0.00 369.00 0.48 0.00 0.48 0.00 1.15 0.01 0.01 0.48 0.48 0.00 GYD-GC-SS(1,1) 500.00 0.00 0.00 500.00 0.62 0.00 0.62 0.00 1.15 0.02 0.02 0.62 0.62 0.00 GYD-GC-SS(1,1) 600.01 1.50 345.00 600.00 0.77 0.00 0.77 0.00 1.15 0.03 0.03 0.77 0.77 45.00 GYD-GC-SS(1,1) 901.49 9.02 336.64 900.00 0.88 -0.01 0.96 -0.01 1.15 0.09 0.09 0.96 0.91 155.12 MWD(1,2) 1,387.03 20.44 319.13 1,369.00 1.27 -0.02 2.46 -0.16 1.14 0.21 0.27 2.47 1.33 145.56 MWD(1,2) 1,440.39 20.44 319.13 1,419.00 1.40 -0.02 3.00 -0.22 1.15 0.25 0.34 3.01 1.45 144.02 MWD(1,2) 1,493.75 20.44 319.13 1,469.00 1.40 -0.02 3.00 -0.22 1.15 025 0.34 3.01 1.45 144.02 MWD(1,2) 1,916.08 32.53 299.48 1,847.00 1.70 -0.13 2.93 0.04 1.17 0.43 0.46 2.96 1.84 127.86 MWD+IFR-AK-CAZ-SC(2,2) 2,198.37 41.52 292.64 2,072.24 1.87 -0.19 3.69 0.05 1.21 0.50 0.54 3.73 2.04 123.70 MWD+IFR-AK-CAZ-SC(2,2) 2,811.10 41.52 292.64 2,531.00 2.71 -0.19 6.84 -0.08 1.65 0.79 0.91 6.86 2.67 116.93 MWD(2,3) 2,877.89 41.52 292.64 2,581.00 2.71 -0.19 6.84 -0.08 1.65 0.79 0.91 6.86 2.67 116.93 MWD(2,3) 3,313.30 41.52 292.64 2,907.00 3.06 -0.19 10.52 -1.34 1.93 1.04 1.82 10.53 2.89 115.26 MWD(2,3) 5,022.90 41.52 292.64 4,187.00 4.32 -0.19 13.82 0.05 2.87 2.17 2.74 13.82 3.76 112.92 MWD+IFR-AK-CAZ-SC(3,3) 5,215.54 41.52 292.64 4,331.23 4.46 -0.19 14.31 0.05 2.97 227 2.87 14.31 3.85 112.80 MwD+IFR-AK-CAZ-SC(3,3) 5,406.65 40.98 285.43 4,475.00 5.06 -0.19 14.90 0.40 320 2.51 3.18 15.13 4.07 112.44 MWD+IFR-AK-CAZ-SC(3,3) 5,782.72 4124 271.12 4,759.00 6.32 -0.30 14.96 0.79 3.44 2.77 3.53 15.94 4.33 111.46 MWD+IFR-AK-CAZ-SC(3,3) 6,061.81 42.55 260.85 4,967.00 7.74 -0.53 14.60 1.19 3.69 3.05 3.88 16.71 4.64 109.92 MWD+IFR-AK-CAZ-SC(3,3) 6,827.52 50.21 236.46 5,499.00 9.94 -1.59 12.93 2.11 4.45 3.75 4.80 18.53 5.95 103.62 MWD+IFR-AK-CAZ-SC(3,3) 6,961.33 52.03 232.85 5,583.00 9.99 -1.75 12.77 2.21 4.55 3.83 4.91 18.74 6.17 102.66 MWD+IFR-AK-CAZ-SC(3,3) 7,107.79 54.13 229.10 5,671.00 9.96 -2.08 12.52 2.39 4.78 3.99 5.12 19.13 6.68 100.62 MwD+IFR-AK-CAZ-SC(3,3) 7,162.94 54.95 227.74 5,703.00 9.96 -2.08 12.52 2.39 4.78 3.99 5.12 19.13 6.68 100.62 MWD+IFR-AK-CAZ-SC(3,3) 7,702.71 63.66 215.73 5,979.00 9.03 -3.05 12.57 2.89 5.52 4.36 5.67 20.22 8.56 93.57 MWD+IFR-AK-CAZ-SC(3,3) 8,057.55 69.89 208.84 6,119.00 8.32 -3.51 13.08 3.11 5.94 4.50 5.90 20.75 9.68 89.42 MWD+IFR-AK-CAZ-SC(3,3) 8,276.00 73.85 204.88 6,187.00 7.80 -3.79 13.53 3.22 6.09 4.57 6.02 21.32 1023 86.21 MWD(3,4) 8,28322 73.98 204.75 6,189.00 7.80 -3.79 13.53 3.22 6.09 4.57 6.02 21.32 1023 8621 MWD(3,4) 8,75323 82.71 196.72 6,284.00 6.65 -4.39 16.22 3.46 6.38 4.67 6.24 23.54 11.65 72.45 MWD(3,4) 8,84226 84.39 195.25 6,294.00 6.61 -4.46 16.84 3.53 6.47 4.68 6.28 23.97 12.01 70.02 MWD(3,4) 8,874.70 85.00 194.71 6,297.00 6.61 -4.46 16.84 3.53 6.47 4.68 628 23.97 12.01 70.02 MWD(3,4) 8,904.70 85.00 194.71 6,299.61 6.65 -4.46 17.17 3.54 6.50 4.68 6.30 24.15 12.13 69.11 MWD(3,4) 9,029.21 89.98 194.71 6,305.07 6.68 -4.68 18.44 3.59 6.68 4.68 6.37 24.88 12.50 65.67 MWD(3,4) 14,675.54 89.98 194.71 6,307.00 12.98 -4.68 40.39 3.63 12.98 4.68 9.27 41.82 17.68 31.35 MWD+IFR-AK-CAZ-SC(4,4) 14,876.09 88.33 193.57 6,309.95 13.30 -4.48 40.17 3.77 13.30 4.69 9.41 41.86 17.54 31.66 MWD+IFR-AK-CAZ-SC(4,4) 16,506.90 88.43 193.60 6,356.00 15.95 -4.49 48.86 3.77 15.96 4.73 10.60 50.11 18.03 27.38 MWD+IFR-AK-CAZ-SC(4,4) 4/27/2016 2:1837PM Page 2 COMPASS 5000.1 Build 74 Pool Report • 1110 12S-12 (BuII)wp09 Surface Location In CPA:Coordinate Converter ,I T„ • From: ,-To: �_- I Datum: i-NA_D83 ,1 Region: lalaska ... Datum: INAD27 Region: alaska _.:1 i C Latitude/Longitude [Decimal Degrees r Latitude/Longitude 'Decimal Degrees zi $ i C UTM Zone: -_— I- South C UTM Zone: mTrue I- South ri State Plane Zone: 4_ Units: 1us-ft 'i a State Plane Zone: Units: ius-ft C'- Legal Description(NAD27 only) r Legal Description(NAD27 only) Starting Coordinates: — Ending Coordinates: X: 11621019.42 X: 1 480986.096754427 Y 5929717.61 Y: ' 5929968.02452396 Transform Quit I Help 1 2S-12 (BuII)wp09 Surface Location ,, ti CPA:Coo-dinate From: To: . t Datum: INAD83C Region: jalaska j Datum: NAD27 +'°' Region: Ialaska wj C Latitude/Longitude 'Decimal Degrees jj C` Latitude/Longitude Decimal Degrees r UTM Zone: 1-______.. I_- South --- UTM Zone: True i_ South t' State Plane Zone: 1-4.. 1 Units: jusfk C State Plane Zone: _ us 14 Units: -ft + C Legal Description(NAD27 onl v) (%" Legal Description(NAD27 only) ( -Starting Coordinates: Legal Description X: 11621019.42 s Township: Range: 1- 008 ii ...1010 Y: 15929717.61 Meridian: S ection:[17 jFNL-7.1 13080.4556 FEL ••••1 11584.2179 Transform II Quit I Help j I • 12S-12 (Bull)wp09 Intermediate Casing In CPAI Coordinate Converter From: — To: Datum: NAD83 „ Region: Ialaska J Datum: 1NAD27 Region: jalaska +1 Latitude/Longitude !Decimal Degrees + C Latitude/Longitude Decimal Degrees +' C UTM Zone: E South r- UTM Zone: True i South , «" State Plane Zone: 14 + Units: ;us ft + 4State Plane Zone: ,4 us-ft + Units: I C Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: Ending Coordinates: 24 X: 476894.827922788 X: 1616928.24 Y: 5929718.26 T _ L Y: 1 5929968.73301924 Transform Quit j Help l vi- -12 (BuII)wp09 Intermediate Casing a . n CPA:Coordina, ,;„...r From: .. To: — - Datum: NADg3 + Region: alaska Datum: 7 + l __sk , Region: 'last' + C Latitude/Longitude !Decimal Degrees + C Latitude/Longitude 1Decimal Degrees _.'..9 1 C UTM Zone: [--- _ 1 South r UTM Zone: True r South . • State Plane Zone: 4 Units: jus-ft + C State Plane Zone: i4.._. +; Units: 1-u7:6-7A; C Legal Description(NAD27 only) + Legal Description(NAD27 only) Starting Coordinates: Legal Description 1616928.24 Township: 1010N H Range: -_,] ,E . ti': 15929718.26 Meridian: lU + Section:!ie FFNI-E 13091.1495 FEL 1395.91670 Transform Quit I Help c4° ! • [2S-12 (BuII)wp09 Top of Production Horizon (top C4) In CPA:Coo-dinate Converter K'.[et4.4.4, "`' From: To: Datum: ' Region: Datum: Region: alaska ,NAD83 9 alaska !.NAD27 €_... Latitude/Longitude Decimal Degrees C Latitude/Longitude !Decimal Degreesl4. UTM Zone: [+ f`- South C UTM Zone: True r South ri State Plane Zone: Units: 1,7;41-71, is State Plane Zone: 4 Units: 1:;:f-17.4:1 C Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: Ending Coordinates: X: 11616764.94 X: 1476731.517384236 Y: 15929288.85 Y: 15929539.33423486 I Transform i Quit I Help 1 12S-12 (BuII)wp09 Top of Production Horizon (top C4) t CPA:Coo-dinate Conve ,„ p From: —To: Datum: ;NAD83 HI Region: alaska Datum: 1NAD27 ''€Region: alaska C LatitudelLongitude Decimal Degrees 4.1 C Latitude/Longitude Decimal Degrees ----.A r- UTM Zone: I South 1-- UTM Zone: True 1- South _ f;- State Plane Zone: 4 Units: us ft C State Plane Zone: 1— �1 Units: rus ft Legal Description(NAD27 only) (. Legal Description(NAD27 only) Starting Coordinates: Legal Description 1616764.94 Township: 010 .1 Range: 1008 E Y 15929288.85 Meridian: U Section: 18 FEL v:1 3521.0844 FEL H 1559.45363 l Transform Quit 1 Help I • -12 (BuII)wp09 TD In CPAI Coordinate Converter : I f-4 From: To: Datum: NAD83 Region: alaska Datum: JNAD27 _I Region: alaska Latitude/Longitude Decimal Degrees .�J C Latitude/Longitude Decimal Degrees h t UTM Zone: 1— fl South ( UTM Zone: True r South State Plane Zone: 14 -j us f Units: pi-7;1 State Plane Zone: 4 us Units: -fk C Legal Description(NAD27 only) r Legal Description(NAD27 only) Starting Coordinates: — Ending Coordinates: X: 11614808.00 X: 1 474774.406415763 Y: [5921789.00 Y: 15922039.66453123 Transform i Quit I Help 12s-12 (Bull)wp09 TD I CPAI Coordinate Con � _ From: -To: i Datum: FNAD83 I Region: Jalaska NAD27 Datum: Region: jalaska C Latitude/Longitude C Latitude/Longitude 9� Decimal Degrees �' 9 Decimal Degrees .} C UTM Zone: 1- South C- UTM Zone: True ra South 4 State Plane Zone: 14 1 Units: ,us-ft -- State Plane Zone: 14 . Units: us-ft C Legal Description(NAD27 only) s Legal Description(NAD27 only) Starting Coordinates: Legal Description X: 11614808.00 Township: 010 R-47,,-1 Range: 1008 1FR Y: 15921789.00 Meridian: lu Section:130 FE---_;:i 1467.76800 FEL 12520.4321 Transform Quit ! Help C - I • - --.._-.._................._. O O R:A9 P I I PS -19 0 co N p 8-OI-I-Z nam I N O O I' l!III OO o03 9,_ EgSal ( MtV^ . N......... ......-...- I 8 I -- ... _. . 4 --. 4„...._ 1 ----- in ..... ..... —OOr i - Ca8888$ N 0 ONM`:g . CO U ( mle W B 1 .°!ec til ! .ic0atit w m dt0a ,N p N Omv O ' %d o��o~ 4 C tm'mm'm'm' 1 A 2. o ZnNNrvN 1 ,. 103 0 oi 1 0%,......mill = Wit O Q I O � fil0 t Ci l + ry r, N . co i .. ali:4 0.35W CD cx oN ■� to M W > , I iG N 60 O CU 1 11 r L-319 N Cel; a) el 3 w N S. 4 O -- i inc.., f., I— T"' N ti N jii M t F �� a ! -> E! r gip"' di" , r, O lit /� tee; 2N Mo 2 N CV O O O O O O O 0. O O O O O O Q O O O O O O M (.0 M Cr) (ui/}/Sn 0000 (±)111oN/(-)gTnoS Mk • • —._.... O j O O 0) O I — — — O O i8.8.8.g.§:' 2, a1a== o U co ea co o-5 03 d UUUUU O H 8888 S! I O 2 �NMMNMOhl" CO b b b a r w U � K �m O m a I'C) r 3 o a!o1V. co r N I ®,d) N o 7,t:4- /cLI, m a_O N I , t y m x�oFxF p(V c'iOM 244(Wf es 4\ '.11111 = 1 46 I A - o p CIM . is. allll : fe cv 3 i 1 el ' 3 to cuI "• :: ui 1 O W N cu cp M ._ O Ca O o 2 0. > L O N _ I O L N I . . N a O p IC) 41) N pi- I. T O O O O O O O c O O O O O O a O O O O O O 05O CO CO CO O N (ui1q4.sn 000£) (+)LIPoN/(-)u1noS • O O 0) I O O Wsooso CO I o yeah daaa m u�uu ' 0 1 o - _ ° 8888oS /1 w ¢ 80 m d aV 3 Awa a n `2rV. � p VN'm 0 5� ecvdor 0 2 O F'F pNeiOM £mmmmm4, 8 ZNN {- NNN i A I N 1037 O it , c p � 0114 M co Co M Nm .-., + rn 0 N O .. 6 1 O W O (D Ir., CD Mor 43) .� WO u O 11, i 0) .MIMI i of i, 0. L 3 N O v.- IR com I Na Io O _ - o LNI H " 0 0 0 0 0 o 0 0 0 0 0 0 0 Q o 0 0 0 0 0 N CD co �) (0 0) N r u!/ � T/sn OOOE) (+)111-1oN/t-)uTnoS As - built REV DATE BY CK APP • DESCRIPTION REV DATE BY .0 APP DESCRIPTION 1 5/28/15 SZ JAH Created Drawing Per K140173ACS 2 11/14/15 SZ MEH Add Well 13 per K150013ACS NOTES• g E 15 14 DMA ce CC a `� jj t __ ,� 25 ii 72 2, ris14 26 i r 1. BASIS OF LOCATION AND ELEVATION IS DS2S f _ v MONUMENTATION PER LOUNSBURY & ASSOC. } usae'` ,C, 33 2`_• 20 27 F 25 25 ., gg c8 27 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ` ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES 7fr.A. "— 1-7ARE NAD 27. "c�P(, , 4 : ' � t3f'/ T11N 3. ELEVATIONS ARE B.P.M.S.L. i q°i' ; REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTiON 1 5/28/15 SZ JAH Created Drawing Per K140173ACS 2 11/14/15 SZ MEH Add Well 13 Per K150013ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 17, T. 10 N., R. 8 E., UMIAT MERIDIAN Well NAD 27 NAD 27 Section Ele',. No. ASP Coordinates Geographic Coordinates Offset. Y X Lat. Long. F.S.L F.E.L. 0.G. PAD 1 5,930,036.15 481,309.02 70' 13' 12.058" 150' 09' 02.839" 2268' 1261' 112.0' 120.0' 2 5,930,029.92 481,279.68 70° 13' 11.996" 150' 09' 03.690" 2262' 1291' 112.4' 120.0' 3 5,930,023.62 481,250.32 70° 13' 11.933" 150° 09' 04.543" 2255 1320' 112.1' 120.0' 4 5,930,017.59 481,221.00 70° 13' 11.873" 150' 09' 05.394" 2249' 1349' 112.0' 120.0' 5 5,930,010.88 481,191.79 70° 13' 11.806" 150' 09' 06.242" 2243' 1378' 111.8' 120.0' 6 5,930,004.80 481,162.27 70° 13' 11.746" 150° 09' 07.098" 2236' 1408' 111.5' 120.0' 7 5,929,998.58 481,133.41 70° 13' 11.684" 150° 09' 07.936" 2230' 1437' 111.4' 120.0' 8 5,929,992.42 481,103.50 70° 13' 11.622" 150' 09' 08.804" 2224' 1467' 111.1' 120.0' 9 5,929,986.08 481,074.22 70' 13' 11.559" 150° 09' 09.654" 2217' 1496' 111.0' 120.0' 10 5,929,979.72 481,044.13 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 5,929,948.70 480,898.09 70° 13' 11.187" 150' 09' 14.767" 2180' 1672' 110.5' 120.0' 14 5,929,955.02 480,927.39 70° 13' 11.250" 150° 09' 13.920" 2186' 1643' 110.5' 120.0' 15 5,929,961.45 480,956.55 70' 13' 11.314" 150° 09' 13.070" 2192' 1614' 110.6' 120.0' * CONDUCTOR AS BUILT THIS SURVEY SEE NOTE 7 SHEET 1 REGARDING CONDUCTOR 15. NAD 27 ,,,loaswat44_ 44:1444 At.•... ....... 04, SURVEYOR'S CERTIFICATE at . V A a44-1, I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND )X4 LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND -;i *\JEREMIAH F. CORNELL./1 Al THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT°' LS-12663 (fr,„ • AS OF NOVEMBER 13, 2015. 84suvirsvc. SURVEYORS ENGINEERS PLANNER, 47 AREA:2S MODULE: XXXX UNIT: 02 ConowPhillips DS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV 1 LK6219d24 5 28/15 CEA-D2SX-6219D24 2 OF 2 2 1,4)1' DATE 13 Y. 0( APP Pt *'IP PON i'A coat 11Y APP 014KRIF 110N 1 5/28/15 SZ JAH Creek: owing Per K140173ACS 2 11/14/15 Si - -...1.1 Add Well 13 Per K150013AC5 CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 17, ., . ., T. 10 N., R. 8 E., LIMIAT MERIDIAN . - - Well NAD 27 MAD 27 Section Hey. No. ASP Coordinates Geographic Coordinates Offset. Y ' X Lot. Long. F.S.L F.E.L. 0.G. PAD 1 5,930,03615 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' i 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 4131,074.22 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' 110.0' 120.0' N.. 1 ii CPAI Coordinate Converter i. '''-' ' - 141 l From - r To: I. r ' Datum . NAD27 ,..id Region aka zi . Datum: INADE13 ...7.1 Region: lalaska jai * C C Latitude/Longitude Decimal Degrees ....r r C Latitude/Longitude 'Decimal Degrees zi C UTM Zone 1 r sth ' r urm ouZone IT rue I South i 1' State Plane Zone 14 ...7:1 Units: us.fr-FE, rirs State Plane Zone r ___.1 z---.„1 Units -us_fi-laj I Legal Description INAD27 only) r Legal Description(NAD27 only) Starring Coordinates- Ending Coordinates: X: 400g86.1X: 1 1621W 42324557 , r f V: 15924388.02 Y: 1 592971761)547598 il fa l" NAD 27 NAD 83 1' 1 , ,I. r ., Transform fl Quit I Help _____________ 7 & .0.c.„---A.,,,s,„.,. ,,,,. ,117,41,174, MINIM, KAN/kM AREA:25 MODULE: XXXX UNIT: D2 ConOCOPhilliPS DS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CAM FILE NO. ORAVANG NO. - PART: REV: lK8219d24 5 28 15 CEA-D2SX--6 219D24 2 OF 2 2 REV DATE BY CK APP • DESCRIPTION REV DATE BY • APP DESCRIPTION PUNCH MARK (TYP.) ON NORTH/SOUTH CONDUCTOR DRILL SITE ORIENTATION LINEN-1 -� N 1-14 I \ . I_.._.-- CELLAR CONDUCTOR & CELLAR PLAN VIEW SCALE: N.T.S. TOP OF CELLAR CUT OFF Lo EL.= 119.38' O 0 in 0 0 © POINTS O o N 7.0 REFERENCE Q POINTS N 13 OO o CONDUCTOR PUNCH MARKS CELLAR PUNCH MARKS ON ORIENTATION LINE ON ORIENTATION LINE SCALE: N.T.S. SCALE: N.T.S. NOTE: 1. REF. DRAWINGS:9776766 WDM—SK-001 2. SURVEY DATED: 11/13/2015LOUNSBURY & ASSOCIATES, INC. 3. ELEVATIONS ARE BPMSL SURVEYORS ENGINEERS PLANNERS AREA: MODULE: XXXX UNIT: ConocoPhillips DS2S CONDUCTOR MARKINGS Alaska, Inc. WELLS 13 CADD ALE NO. DRAWING NO. PART: REV: MI) ORIENTATION WELL 13 11/13/2015 CONDUCTOR WELL 13 1 OF 1 0 • • 2S-12 Drilling Hazards Summary 13-1/2"Hole/10-3/4"Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low If observed-control drill,reduce pump rates,reduce drilling fluid temperatures,Additions of Lecithin. Anti-collision 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"x 11"Hole/7-5/8"Casing Interval Event 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—12.5 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. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is higher than expected. 6-3/4"Hole/4-1/2"Liner Interval Event Risk Level Mitigation Strategy High ECD and swabbing with higher Moderate Condition mud prior to trips. Monitor ECD's with PWD tool while MW's required drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is higher than expected. Lost Circulation Moderate Use PWD and TAD to monitor hole cleaning. Reduced pump rates, adjust mud rheology,add LCM. Use GKA LC decision tree. Use of MPD will allow lower mud weights to reduce ECD while shutting on connections to prevent any potential influx. Stuck pipe Moderate Good hole cleaning,stabilized BHA,proper mud weight to minimize differential stuck,PWD monitor ECD. Hole swabbing on trips Moderate Monitor proper hole fill while tripping,good hole cleaning.Backream out to intermediate shoe,then utilize MPD to strip out and eliminate swab. • • Well: KRU 2S-12 <_=Data Input Name: 1l4TQ <==Data Input Mud Weight (ppg) 10.50 <==Data Input Weak point or LOT-Measured depth(ft) 2,864' <==Data Input Weak point or LOT True vertical depth(ft) 2,569' <==Data Input Weak point or LOT-Hole angle(deg) 41.6° <==Data Input Weak point or LOT-Hole size(in) 9.875" <==Data Input Weak point pressure or LOT-EMW(ppg) 12.50 <==Data Input Zone of interest-Measured depth(ft) 8,274' <==Data Input Zone of interest-True vertical depth (ft) 6,177' <_=Data Input Zone of interest-Hole angle(deg) 74.0° <==Data Input Zone of interest-Hole size(in) 9.875" <==Data Input Zone of interest-Pore pressure EMW(ppg) 10.50 <_=Data Input Gas gradient(psi/ft) 0.10 <==Data Input Bottom hole assembly OD(in) 6.8" <==Data Input Bottom hole assembly length(ft) 200' <==Data Input Drill pipe OD(in) 5.000" <_=Data Input BHA annular vol.@ zone of interest(bbl/ft) 0.0505 DP annular vol.@ zone of interest (bbl/ft) 0.0704 DP annular vol. • weak •oint bbl/ft 0.0704 Additional safety margin(psi) 0.00 <==Data Input Weak point pressure(psi): Plo 1,670 psi Weak point pressure-Safety margin: Pmax 1,670 psi Pmax EMW 12.50 ppg Max anticipated formation pressure(psi): Pf 3,373 psi Weak Pt to Zone of Interest distance(TVD ft): OH {TVD} 3,608' Weak Pt to Zone of Interest distance(MD ft): OH {MD} 5,410' Maximum influx height at the bit (TVD ft): H {TVD} 599' Maximum influx height at the bit (MD ft): H {MD} 2,173' Calc.volume of{H}around BHA: V1bha 10.1 bbl Calc.volume of{H}around drill pipe: Vldp 139.0 bbl Calc.volume that H equals @ initial shut in: V1 149.1 bbl Calc.vol.that H equals @ weak point(MD ft): VWp 56.4 bbl Calc.volume of Vwp @ initial shut in: V2 27.9 bbl Kick Tolerance: V2 27.9 bbl NOTE: Neutral Kick Intensi • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: '<KUL AS— I 1 PTD: -O Development Service _Exploratory _Stratigraphic Test _Non-Conventional FIELD: K GAA u.. RAair- POOL: 141.70641AIK RAJ') J 2i\er O. I Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements /Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion,suspension or abandonment of this well. Revised 2/2015 110 i 171 ToII, , , u) ,. „ 0) O a) a , 0o „ U , , ; o m d c , , c <a , Q o' a L 1 C O O' 0' , III C co W 477 3, O 0, 0, L a), ' o ami; o , m; 3. m; C 0'0' N' , N 'I. Cy =p . Qo wN! ' QCD, ' N , aLpON -,t ' ' c L _ ' ' ' ' ' o. Eocs1 �, F-! , c' ' O' o a , I r a za > $ ' o oN. , , c7' � , - > a, , T' ' o' a o , 6p O , , z,_4),' a, Y I-. v, N, C' a, a co" a), a J' c, Ii1UiUi o a) @ C7 N � � � v, 0 y y �� �'� �� a) Z ' � ' � , ' ' o e ' ' O N Q � CD oa E. 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O E J •E c J o m U W a E a Y 0) a F- 0 a I- Q a s w Q > 0 Q a • # Well History File APPENDIX Infoiwliation 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.
