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ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Date: May 27, 2025 FFROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC 700 G Street 333 W.7th Ave., Suite 100 Anchorage AK 99501 Anchorage, Alaska DATA TRANSMITTAL Kuparuk River Unit/Field Well API #PTD #Comments 1H-112 50029237870100 2240320 3B-16A 50029212890100 2231250 2B-03B 50029211510200 2230800 2M-39 50103207950000 2181710 3S-612 50103207770000 2181110 3S-611 50103207740000 2181030 1H-108B 50029236080200 2180820 1H-110 50029236010000 2180310 1H-116 50029235940000 2180120 2S-06 50103207470000 2160850 2M-37 50103207450000 2160820 1D-39 50029229970000 2002160 1D-40A 50029229690100 2001900 2N-302 50103203800000 2011150 1R-03A 50029214060100 2000210 3H-37 50103208220000 2191940 2S-09A 50103207490100 2161280 T40450 T40451 T40452 T40453 T40454 T40455 T40456 T40457 T40458 T40459 T40460 T40461 T40462 T40463 T40464 T40465 T40466 By Gavin Gluyas at 1:15 pm, May 28, 2025 2S-09A 50103207490100 2161280 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Colville River Unit/Field Well API # PTD # Comments CD5-31 50103208280000 2210020 CD5-96 50103208110000 2191620 CD4-499 50103208100000 2191610 CD5-26 50103208060000 2191070 CD5-98 50103208030000 2190590 CD5-24 50103207990000 2190060 CD5-23 50103207610000 2171550 CD5-19 50103207600000 2171210 CD5-22 50103207590000 2170890 CD5-316 50103207560000 2170400 CD3-111A 50103205260100 2170040 CD3-198 50103206370000 2110240 CD4-24 50103206020000 2090970 CD4-26 50103206000000 2090490 CD2-15 50103203860000 2011590 CD2-12 50103204550000 2030730 CD4-214 50103205370000 2061450 CD4-17 50103205340000 2061180 CD2-73 50103205900000 2081960 T40467 T40468 T40469 T40470 T40471 T40472 T40473 T40474 T40475 T40476 T40477 T40478 T40479 T40480 T40481 T40482 T40483 T40484 T40487 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Greater Mooses Tooth Unit/Field Well API # PTD # Comments MT7-99 50103208450000 2221020 T40485 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com z_ z..5 ConocoPhillips Alaska NECE1VED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 SEP 2 6 2017 AOGCC 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. 7ZSin rely, � Roger Winter ConocoPhillips Well Integrity Field Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 9/25/2017 2S pad Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor! Well Name API# PTD# _ cement pumped cement date inhibitor sealant date ft bbls ft gal 2S-05 501032073900 216-039-0 22" 0.05 11" 6/7/2017 1.7 9/10/2017 2S-06 501032074700 216-085-0 4' 0.25 15" 6/10/2017 3.4 9/10/2017 2S-07 501032071300 215-079-0 22" 0.16 11" 6/7/2017 3.4 9/10/2017 2S-08 501032072200 215-174-0 17" 0.10 13" 6/7/2017 3.4 9/10/2017 }2S-09A 501032074901 216-128-0 39" 0.30 12" 6/10/2017 4.25 9/20/2017 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 0 0 o o r (0 co .N (0 co � N O �. J) co 1) co co Cl. 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I d 10 C.) 0 d' c. o O d d co V O LL O o' dcp u) Q a 2 3 Z 0 a 0 1 0 oaIv 0 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2_ ‘o-t 1.Operations Abandon E Plug Perforations E Fracture Stimulate F Pull Tubing r Operations Shutdown Performed: Suspend n Perforate fl Other Stimulate r Alter Casing rChange Approved Program E Plug for Redrill 1- Perforate New Pool 1 Repair Well r Re-enter Susp Well E r- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 1 Exploratory E -2-te"0980 21(e-i2$-C 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-103-20749-04 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25603,ADL 25589,ADL 25590 KRU 2S-09A 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 14172 feet Plugs(measured) None true vertical 6301 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 0 true vertical 0 feet (true vertical) 0 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 119 119 SURFACE 2783 10 3/4 2822 2596 INTERMEDIATE 4285 8.87 7247 6264 Perforation depth: Measured depth: N/A RECEIVED True Vertical Depth: N/A DEC 15 2015 Tubing(size,grade,MD,and TVD) 3.5, L-80, 7985,6318 AOG CC Packers&SSSV(type,MD,and ND) PACKER=BAKER PREMIER PRODUCTION PACKER @ 7880 MD and 6303 ND SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): 8388- 14051 Treatment descriptions including volumes used and final pressure: Total Well - 11 stages, 1,074, 400 lbs placed... See attached schematic for full FRAC details 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 542 670 Subsequent to operation 2453 833 1575 3360 268 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F ? Exploratory r— Development F Service E Stratigraphic E Copies of Logs and Surveys Run r 01\\ ' 16.Well Status after work: Oil F Gas E WDSPL Printed and Electronic Fracture Stimulation Data F GSTOR r WINJ E WAG E GINJ f SUSP SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-561 Contact Adam Klem @ 263-4529 Email Adam.Klem a(�,conocophillips.com Printed Name Adam Klem Title Completions Engineer Signature g7// rv„ A,1,,— kis— Phone:263-4529 Date /211SI20/b Form 10-404 Revised 5/2015 �� 5�� Submit igi al Only (4)" 3/21/20/7 RBDMS LU-DEC 1 5 ?nig "0,(- 1/-7 • S 2S-09 DTTMSTF JOBTYP SUMMARYOPS 11/9/16 FRACTURING Completed rig up of frac spread. Pressure tested treating equipment/line. Sheared Alpha sleeve @ 6591 psi treating press, 8936 psi BHP. Will return in A.M to frac. 11/10/16 FRACTURING PUMPED MINI FRAC AND STAGES 1-5. CUT STAGE#4 SHORT DUE TO SAND CASTLE ISSUES. SECURED WELL FOR NIGHT. 11/14/16 FRACTURING PUMPED STAGES 6-11. ALL STAGES PUMPED AS DESIGNED. SECURED WELL FOR NIGHT. BEGIN RDMO OF FRAC EQUIPMENT. 11/16/16 FRACTURING BRUSHED & FLUSHED TBG/DRIFTED 2.78"TO D-NIPPLE @ 7905' RKB. SET 2.75" CA-2 PLUG @ SAME. ATTEMPTED TBG DDT(FAIL). IN PROGRESS. 11/17/16 FRACTURING PULLED 2.75" CA-2 PLUG @ 7905' RKB. MADE CORRELATION RUN TO GLM @ 3903' RKB. SET 3.5" EVO-TRIEVE PLUG MID ELEMENT @ 3936' RKB WITH HES DPU. DDT&3000 PSI MITT PASSED. DEPLOYED CATCHER& PULLED DV @ 3903' RKB. READY FOR DHD. 11/17/16 FRACTURING (SEC) : POT-T(PASSED). PPPOT-T (PASSED). Intermediate POT-T(PASSED). Intermediate PPPOT-T (PASSED). POT-IC (PASSED). PPPOT-IC (PASSED). TESTED TWC TO 1025 PSI (PASSED). T& IA DDT TO 0 PSI (PASSED). 11/18/16 FRACTURING TREE SWAP (COMPLETE) 11/20/16 FRACTURING SET GLV(3/16" PORT/1981 TRO) @ 3903' RKB; PULLED CATCHER & EVO-TRIEVE @ 3936' RKB; DEPLOY CATCHER; PULLED DMY VLV @ 7142' RKB &SET OV(5/16" PORT); PULLED DMY VLV @ 6862' RKB & REPLACED IN KIND; PULLED CATCHER @ 7832' RKB; MEASURED BHP @ 8046' RKB: 3879 PSI. (UNABLE TO GET ANY DEEPER). JOB COMPLETE. • Hydraulic Fracturing Fluid Product Component Information Disclosure } Job Start Date: 11/9/2016 Job End Date: 11/14/2016 State: Alaska County: Harrison Bay API Number: 50-103-20749-0-00 "` Operator Name: ConocoPhillips Company/BurlingtonFrac Focus Resources Well Name and Number. 2S-09P. Chemical Disclosure Registry �,s Latitude: 70.21987700 Longitude: -150.15268100 Datum: NAD27 C7ROUNDViATER Federal Well: NO �.,aiir�» Oil a Gas Indian Well: NO t, t .• ON,, CO.uhc L. r''''''''''—true Vertical Depth: 6,302 }Total Base Water Volume(gal): 726,215 k: . ; :ase Non Water Volume: 0 Hydraulic Fracturing Fluid Composition: Chemical Maximum Maximum Abstract Ingredient Ingredient Trade Name Supplier Purpose Ingredients Service Concentration Concentration Comments Number in Additive in HF Fluid (CAS#) (%by mass)" (%by mass)** Sea Water Operator Base Fluid Water 7732-18-5 96.00000 80.20772 Density=8.500 Ingredients Listed Above Listed Above Water 7732-18-5 100.00000 0.10206 • • SP BREAKER Halliburton Breaker Listed Below SAND-COMMON Halliburton Proppant WHITE-100 MESH,SSA-2, 2500 LB SACK Listed Below Optiflo-II Halliburton Breaker Listed Below 20/40 Wanli Xinmi Wanli Additive Industry Development Co.,Ltd Listed Below MO-67 Halliburton pH Control Additive Listed Below Silica Flour Halliburton Additive Listed Below OPTIFLO-III Halliburton Breaker DELAYED RELEASE BREAKER Listed Below LOSURF-300D Halliburton Non-ionic Surfactant • . Listed Below LVT-200 penreco Additive Listed Below CarboLite 16/20 CarboCeramics Additive Listed Below CL-31 Halliburton Crosslinker CROSSLINKER Listed Below CL-22 UC Halliburton Crosslinker Listed Below WG-36 GELLING Halliburton Gelling Agent AGENT Listed Below BE-6 Halliburton Biocide MICROBIOCIDE Listed Below Items above are Trade Names with the exception of Base Water.Items below are the individual ingredients. Corundum 1302-74-5 55.00000 6.44998 Mullite 1302-93-8 45.00000 5.27726 Sodium chloride 7647-14-5 4.00000 3.34360 Ceramic materials and 66402-68-4 100.00000 2.72868 wares,chemicals Crystalline silica,quartz 14808-60-7 100.00000 1.06720 Hydrotreated Distillate, 64742-47-8 100.00000 0.32716 Light..C9-16 Guar gum 9000-30-0 100.00000 0.30987 Potassium formate 590-29-4 60.00000 0.06804 Borate salts Proprietary 60.00000 0.06804 Ethanol 64-17-5 60.00000 0.04611 Oxylated phenolic resin Proprietary 30.00000 0.03074 Heavy aromatic 64742-94-5 30.00000 0.02305 petroleum naphtha Ammonium persulfate 7727-54-0 100.00000 0.02241 Potassium metaborate 13709-94-9 60.00000 0.02047 Sodium hydroxide 1310-73-2 30.00000 0.01427 Cured acrylic resin Proprietary 30.00000 0.00601 Poly(oxy-1,2-ethanediyl), 127087-87-0 5.00000 0.00384 alpha-(4-nonylphenyl)- omega-hydroxy-, branched Naphthalene 91-20-3 5.00000 0.00384 2-Bromo-2-nitro-1,3- 52-51-7 100.00000 0.00185 propanediol Potassium hydroxide 1310-58-3 5.00000 0.00171 Acrylate polymer Proprietary 1.00000 0.00113 Denise Tuck, Halliburton,3000 N. Sam Houston Pkwy E., Houston,TX 77032, 281-871-6226 Sodium glycollate 2836-32-0 1.00000 0.00113 Sodium carboxymethyl 9004-32-4 1.00000 0.00113 cellulose 1,2,4 Trimethylbenzene 95-63-6 1.00000 0.00077 Sodium persulfate 7775-27-1 100.00000 0.00007 Sodium sulfate 7757-82-6 0.10000 0.00000 'Total Water Volume sources may include various types of water including fresh water,produced water,and recycled water "Information is based on the maximum potential for concentration and thus the total may be over 100% "'If you are calculating a percentage of total ingredients do not add the water volume below the green line to the water volume above the green line Note:For Field Development Products(products that begin with FDP),MSDS level only information has been provided. Ingredient information for chemicals subject to 29 CFR 1910.12000)and Appendix D are obtained from suppliers Material Safety Data Sheets(MSDS) KUP 41)D 0 2S-09A oriptig nocoPhillips Well Attributes Max Angle&MD TD lkle35kci,Inc. . -' Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) igil. 501032074901 KUPARUK RIVER UNIT PROD 95.58 11,414.56 14,172.0 .°. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 25-09A,12/14/201610:14:24 AM SSSV:NONE Last W0: 39.10 10/28/2016 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;35.3..E _ Last Tag. 11/17/2016 Rev Reason:NEW WELL,GLV C/O,PULLED pproven 12/7/2016 NIB 8 ROD,FRAC Casing Strings • asing Description OD(in) ID(in) TopftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(L..Grade Top ThCONDUCTOR 16 15.250 391 119.1 119.1 62.50 -40 Welded �'. .:illC Casing Description ODin) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WWt/LenF/Len(I...Grade Top Thread SURFACE 103/4 9.950 38.7 2,822.0 2,5961 45.50 L-80 HYD 563 CONDUCTOR,39.1-119.1 Casing Description OD(In) ID(in) Top(ftKB) 'Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade TopThread Y INTERMEDIATE 2 75/8 6.875 37.2 8,129.9 6,333.1 29.70 L-80 Hyd563 # Casing Description OD lin) 'ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...i Wt/Len(I...Grade Top Thread SURFACE;38.7-2,822.0 LINER 41/2 3.958 7,958.5 14,163.2 6,300.7 12.60 L-80 TenarisXP • • BTC-m GAS LIFT;3,903.3 Inn Liner Details Nominal ID B iii i • Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com lin) 7,978.5 6,317.5 82.38 NIPPLE Baker 5.5""RS"Packoff Seal Nipple 17#Q125 4.250 Hyd 563 box x box GAS LIFT;6,862.3 ; II 7,980.8 6,317.8 82.43 HANGER Baker 5.5"x 7.63""DG"Flex-Lock Liner hanger 4.810 Mt GAS LIFT;7,142.2 0125 Hyd 563 pin x pin ':.SW 7,990.1 6,319.0 82.62 XO Reducing 5.5"Hyd 563 15.5#box x 4.5"12.6#TenarisXP pin 3.920 N1 Crossover Bushing Sliding Sleeve;7,830,8 !�I Gauge/Pump Senor;7,8.65.1 - - 8,202.0 6,338.5 86.29 SWELL Baker-"Swell Packer#12-"L"5.75"OD SN: 3.960 fr PACKER 51333-010-20 PACKER;7,880.4 -- :' 8,387.6 6,341.0 91.74 FRAC Baker 4-1/2"Frac Sleeve#10-(2.688"Ball,Drift ID 2.635 mr NIPPLE;7,904.9 Sleeve/Port 2.625")PN:10437089 8,687.5 6,333.7 90.59 SWELL Baker-"Swell Packer#11-"K"5.75"OD SN: 3.970 Locator;7,954.0PACKER 51333-010-13 Locator;7955.0 8,993.7 6,331.3 90.69 FRAC Baker 4-1/2"Frac Sleeve#9-(2.625"Ball,Drift ID 2.573 Sleeve/Port 2.563")PN:10437088 Mme snoe,7,983.9 I"1 9,252.9 6,328.1 90.78 SWELL Baker-"Swell Packer#10-"J"5.75"OD SN: 3.950 PACKER 51333-010-15 i t 9,559.6 6,325.5 90.01 FRAC Baker 4-1/2"Frac Sleeve#8-2.563"Ball,Drift w/ 2.510 Sleeve/Pon 2.50"PN:10437087 INTERMEDIATE 2;37.2-8,129.9 , 9,859.4 6,326.2 89.47 SWELL Baker-"Swell Packer#9-"I"5.75"OD SN:51333 3.960 PACKER -010-12 10,164.9 6,332.0 89.13 FRAC Baker 4-1/2"Frac Sleeve#7-(2.5"Ball,Drift w/ 2.448 Sleeve/Port 2.438")PN:10437086 IMES 10,464.5 6,330.5 91.13 SWELL Baker-"Swell Packer#8-"H"5.75"OD SN: 3.970 Hyd Frac-Gelledwater;8,388.0 I i■, I PACKER 51333-010-21 MCA 10,769.4 6,330.3 89.24 FRAC Baker 4-1/2"Frac Sleeve#6-(2.438"Ball,Drift w/ 2.385 Sleeve/Pon 2.375")PN:10437085 lililiii- 11,109.6 6,334.0 90.16 SWELL Baker-"Swell Packer#7-"G"5.75"OD SN: 3.940 -awm PACKER 51333-010-16 Hyd Frao-GelledMater;8.994.0 I 11.1 I r 11,209.9 6,331.9 92.59 SWELL Baker-"Swell Packer#6-"F"5.75"OD SN: 3.960 PACKER 51333-010-18 liiililr11,476.1 6,310.5 94.35 FRAC Baker 4-1/2"Frac Sleeve#5-(2.375"Ball,Drift w/ 2.323 fiir. Sleeve/Port 2.313")PN:10437084 Hyd Frac-Gelledwater;0,560.0 1 IIMI I 11,733.3 6,304.5 89.69 SWELL Baker-"Swell Packer#5-"E"5.75"OD SN: 3.950 PACKER 5133-010-23 11,953.6 6,303.5 91.12 FRAC Baker 4-1/2"Frac Sleeve#4-(2.313"Ball,Drift w/ 2.260 Sleeve/Port 2.25")PN:10437083 la=garra Hyd Frac-Gelledwater:14165.0 I NMI I 12,253.9 6,298.9 88.14 SWELL Baker-"Swell Packer#4-"D"5.75"OD SN: 3.950' ram PACKER 51333-010-6 ,..®...- 12,5192 6,302.1 90.41 FRAC Baker 4-1/2"Frac Sleeve#3-(2.25"Ball,Drift w/ 2.198 Sleeve/Port 2.188") PN:10437082 12,778.1 6,297.4 91.97 SWELL Baker-"Swell Packer#3-"C"5.75"OD SN: 3.960 Hyd Frac-Gelledwaten 10.7690 I IMO I PACKER 51333-010-2 13,039.7 6,293.3 89.81 FRAC Baker 4-1/2"Frac Sleeve#2-(2.188"Ball,Drift w/ 2.135 Sleeve/Port 2.125")PN:10437081 lililfir 13,298.5 6,294.4 88.73 SWELL Baker-"Swell Packer#2-"B"5.75"OD SN: 3.960 PACKER 51333-010-25 liliGlir 13,564.8 6,297.8 89.83 FRAC Baker 4-1/2"Frac Sleeve#1-(2.125"Ball,Drift w/ 2.073 _1 Sleeve/Port 2.063")PN:10437070 Hyd Frac-ceoeawater;11,476.0 I 1 13,825.0 6,297.5 90.00 SWELL Baker-"Swell Packer#1-"A"5.75"OD SN: 3.950 PACKER 5133-010-1 14,051.3 6,297.9 88.99 FRAC SLEEVE Baker 4-1/2"Alpha Sleeve PN H810-07-0027 3.010 Hyd Frac-Geliedwater,11,954 0 I ., I 14,064.7 6,298.1 88.69 SLEEVE Baker 4-1/2"Wellbore Isolation Valve(WIV)PN H809 -89-0011 liiiii ' Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ibtft) Grade Top Connection 1 TUBING 3 1/2 2.992 35.3 7,984.9 6,318.3 9.30 L-80 EUE-m Hyd Frac-Gelletlwater;12,519.0 I � f l Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com lin) 35.3 HANGER Cameron 11"x 4-1/2"IBT-m Tubing Hanger 3.900 80.1 80.1 0.11 XO Reducing XO,4-1/2"12.68 L-80 IBTM box x 3-1/2"9.3#L-80 EUE 2.992 Hyd Frac-Geuedwater:130400 I MEM I pin 7,830.6 6,294.9 80.61 Sliding Sleeve Baker 31',"CMU in closed position w/2.812"DS Profile 2.810 liliiiir7,855.1 6,298.9 80.74 Gauge/Pump Schlumberger Gauge Carrier 3%"EUE-m box X EUE 2.897 I...=-=j Sensor 8RD Pin C16GM-0416 Hyd Frac-Geucdwater,13,565.0 I Irl I.1-1 I 7,880.4 6,303.0 80.89 PACKER Baker Premier Production Packer 7.625"x 3.5"(659-287) 2.880 liar 7,904.9 6,306.8 81.02 NIPPLE Camco 2.75 D nipple 4Y"OD (6306'TVD,81°) 2.750 Hyd Frac-Geuedwate,:1a.os1.0 f 7,954.0 6,314.2 81.88 Locator Baker 7.625"x 3.5"Shear pinned Fluted No-Go Sub- 3.010 Large OD 0 p 7,955.1 6,314.3 81.90 Locator Baker 7.625"x 3.5"Shear pinned Fluted No-Go Sub- 3.010 I� I1 small OD 7 1' 7,983.9 6,318.2 82.49 Mule Shoe Mule shoe WLEG,3-1/2"IBT box 3.490 LINER;7,998.5-14,183.2, 111 L KUP 11111D • 2S-09A nocoPhillips0 Alaska.he. COrroca.Mips ••• 2S-09A,12/14/2016 1014.25 AM Vertical schemayc.(actual). HANGER'35.3 --r a• .-- • NI .) �s Stimulations&Treatments • J -Proppant Designed(Ib) rroppant In Formation(Ib) (Date 535,625.01 502,075.0 11/10/2016 � � Stimulations&Treatments 1r Min Top Max Btm Top(TVD) Btm(TVD) Vol Clean Vol Slurry —"V,CONDUCTOR;39.1-119.1 Depth(ftKB) Depth(ftKB) (ftKB) (kKB) Stg B Date Stim/Treat Fluid Pump(bbl) (bbl) t B 11,954.0 14,053.0 6,297.9 6,297.9 1 11/10/2016 Hybor G,Gelled Salt Water - 2262.00 2370.00 SURFACE;38.7-2,822.0 11,954.0 14,053.0 6,297.8 6,297.8 2 11/10/2016 Hybor G,Gelled Salt Water 1502.00 1611.00 11,954.0 14,053.0 6,293.3- 6,293.3 3 11/10/2016 Hybor G,Gelled Salt Water 1497.00 1605.00 GAS LIFT;3,903.3 M'' 11,954.0 14,053.0 6,302.1 6,302.1 4 11/10/2016 Hybor G,Gelled Salt Water ' 1252.00 1321.00 11,954.0 14,053.0 6,303.5 6,303.4 5 11/10/2016 Hybor G,Gelled Salt Water 1647.00 1756.00 • i F Proppant Designed(Ib) Proppant In Formation(Ib) Date 642,750.0 644,330.0 11/14/2016 GAS LIFT;6,862.3 Stimulations&Treatments N Min Top Max Btm Top(TVD) Btm(TVD) Vol Clean Vol Slurry IN GAS LIFT;7,1422 ; Depth(kKB) Depth(kKB) (ftKB) (ftKB) Stg 8 Date Stim/Treat Fluid Pump(bbl) (bbl) MI 8,388.0 11,478.0 6,310.5 6,310.4 6 11/14/2016 Hybor G,Gelled Salt Water 1566.00 1674.00 4s 8,388.0 11,478.0 6,330.3 6,330.4 7 11/14/2016 Hybor G,Gelled Salt Water 1499.00 1606.00 Sliding Sleeve;7,830.8 :NMI AMP Gauge/Pump Sensor;7,855.1 8,388.0 11,478.0 6,332.0 6,332.0 8 11/14/2016 Hybor G,Gelled Salt Water 1499.00 1607.00 slow 8,388.0 11,478.0 6,325.5 6,325.5 9 11/14/2016 Hybor G,Gelled Salt Water 1548.00 1656.00 PACKER,7,880.4 r.■ 8,388.0 11,478.0 6,331.3 6,331.2 10 11/14/2016 Hybor G,Gelled Salt Water 8994.00 8996.00 NIPPLE;7,904.9 - 8,388.0 11,478.0 6,341.0 6,340.9 11 11/14/2016 'Hybor G,Gelled Salt Water 8388.00 8390.00 Mandrel Inserts Loaner;7,954.0 St Loeser;7,955.0 Pi onl F N Top(TVD) Valve Latch Port Size TRO Run Top(kKB) (PoB) Make Model OD(in) Sery Type Type lin) (psi) Run Date Corn Mule Shoe;7,963.9 1 3,903.3 3,502.4 Camco KBMG 1 GAS LIFT DMY BK-5 10/26/2016 2 6,862.3 6,021.1 Camco KBMG 1 GAS LIFT DMY BK-5 10/26/2016 8 ' 8 3 7,142.2 6,147.6 Camco KBMG Notes:General&Safety 1 GAS LIFT DMY BK 11/1/2016 INTERMEDIATE 2;37.2-8,129.9 End Date Annotation 11/17/2016 NOTE. NOTE Hyd Frac-Gelledwater,9,388.0 IMI I ililiir s.MMilt Hyd Frac-Gelledwater.8,994.0 I IUI I E�7 ` iar MAMMill Hyd Frao-Gelledwater;9,560 0 I IUI 1 inist- Hyd Frac-Gelledwater,10165.0 CC Hyd Frac-Gelledwater;10,799.0 I Mil ' I °— iiiiiir Hyd Frac Gelledwater,11,476.0 I :t I I Hyd Frac-Gelledwater,11,954.0 I i., I lillir Hyd Frac-Gelledwater;12,519.0 I`l 711 I I Ii'`aai Hyd Frac-Gelledwater;13,040 0 I li.. I liilliir Hyd Frac-Gelledwater;13,565.0 I 11=111 iliiir Hyd Frac-Gelledwater:14.051.0 1 I ool LINER;7,958.5-14.163.2, 1 l[l • Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Thursday,June 08, 2017 9:53 AM To: Guo, Haibin (Haibin.Guo@conocophillips.com); Haggerty-Sherrod,Ann (Northland Staffing Services) (Ann.Haggerty-Sherrod@contractor.conocophillips.com) Subject: KRU 2S-09A(PTD 216-128) 10-407 Submission Please review and correct the 10-407 form: 1. The intermediate 2 casing, liner and cementing record is incorrect or missing 2. The intermediate 1 casing depths do not appear to be correct 3. Please provide a clear copy of the WBS You may email the corrected form to me. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCa�alaska.Qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 • • Corr cfiC00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a.Well Status: Oil , Gasp SPLUG❑ Other ❑ Abandoned ❑ Suspended ❑ lb.Well Class' 2OMMC 25.105 20AAC 25.110 Development 0 , Exploratory 0 GINJ❑ WINJ❑ WAGE] WDSPL 0 No.of Completions: Service 0 Stratigraphic Test❑ 2.Operator Name: 6.Date Comp.,Susp.,or 14.Permit to Drill Number/ Sundry: ConocoPhillips Alaska,Inc. Aband.: 10/27/2016 216-128/ 3.Address: 7.Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 491teFPe49- I o to it to L'- 50-103-20749-01-00 • 4a.Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 3062'FNL,1496'FEL,Sec 17,TION,ROBE,UM 10/22/2016 KRU 2S-09A , Top of Productive Interval: 9.Ref Elevations: KB:159 17.Field/Pool(s): 3257'FNL,692'FEL,Sec 17,1-10N,ROBE,UM GL:120 BF: Kuparuk River FieldlKuparuk River Oil Pool Total Depth: 10.Plug Back Depth MD/TVD: 18.Property Designation: 2594' FNL,4663'FEL,Sec 9,TION,RO8E,UM 2572/2383 ADL 25603,ADL 25589,ADL 25590 • 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19.Land Use Permit: Surface: x- 481074 y-5929986 Zone-4 14172/6301 • 2675,2676,2677,2678 TPI: x- 481878 y-5929789 Zone-4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 483184 y-5935729 Zone-4 N/A 1399/1370 5.Directional or Inclination Survey: Yes El (attached) No 0 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)1 2822/2596 22.Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 MC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper,resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res/Neutron Den 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH IVO AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM - HOLE SIZE CEMENTING RECORD PULLED 16 62.5 H-40 39 119 39 119 24 Pre-Driven Cement to Surface 10.75 45.5 L-80 39 2822 39 2596 13.5 1080 sx 11 ppg Class G,286 sx 7.625 29.7 L-80 37 8130 37 6333 9.875 Stage 1:778 sx 15.8 ppg Class G Stage 2:229 sx 15.8 Class G 4.5 12.6 L-80 7958 14163 6315 16301 6.75 Liner-NON CEMENTED 24.Open to production or injection? Yes 0 No ❑ 25.TUBING RECORD If Yes,list each interval open(MDTTVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 31/2 7985 N/A FRAC SLEEVEIPORT @8388 MD and 6341 TVD FRAC SLEEVEIPORT @ 8994 MD and 6331 TVD 26.ACID,FRACTURE,CEMENT SQUEEZE,ETC. FRAC SLEEVEIPORT @9560 MD and 6326 TVD Was hydraulic fracturing used during completion? Yes❑ No 0 FRAC SLEEVEIPORT @ 10164 MD and 6332 TVD FRAC SLEEVEIPORT @ 10769 MD and 6330 TVD Per 20 AAC 25.283(i)(2)attach electronic and printed information FRAC SLEEVEIPORT @ 11476 MD and 6311 TVD DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED FRAC SLEEVEIPORT @11954 MD and 6303 TVD FRAC SLEEVEIPORT @i2519 MD and 6302 TVD FRAC SLEEVEIPORT @ 13040 MD and 6293 TVD • FRAC SLEEVE/PORT @ 13565 MD and 6298 TVD 27 __ -' T _. . __-- PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): SHUT-IN Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period ...♦ Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate .. 111- Form ►Form 10-407•'1Revised 11/2015 `/7'L /a/25/! ' CONTINUED ON PAGE 2 Submit ORIGINIAL only 't 4� 1 17_ '1,0 6/7 RBDMS t,t_ L 6 t.015 Cr' RECEIVED III • NOV 2 $ 2015 STATE OF ALASKA _ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AN&PWC la.Well Status: Oil 0 Gasp SPLUG❑ Other ❑ Abandoned El Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ❑ WAGE 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.: 10/27/2016 , 216-128/ 3.Address: 7.Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 1-8i1-6/20-t6 lou IIts L., 50-103-20749-01-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 3062'FNL, 1496'FEL,Sec 17,T10N, RO8E,UM 10/22/2016KRU 2S-09A • Top of Productive Interval: 9. Ref Elevations: KB:159 17.Field/Pool(s): 3257 FNL,692'FEL,Sec 17,T1ON,R08E, UM GL:120 BF: Kuparuk River Field/Kuparuk River Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18.Property Designation: 2594' FNL,4663'FEL,Sec 9,T10N, RO8E, UM 2572/2383 ADL 25603,ADL 25589,ADL 25590 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 489484- Lig l03r-t y ` 9•5'z°l"&B Zone-4 14172/6301 2675,2676,2677,2678 TPI: x- 481878 y- 5929789 Zone-4 12.SSSV Depth MDITVD: 20.Thickness of Permafrost MD/ND: Total Depth: x- 483184 y- 5935729 Zone-4 N/A 1399/1370 5. Directional or Inclination Survey: Yes El (attached) No El 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL)I 2822/2596 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper,resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res/Neutron Den 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 H-40 39 119 39 119 24 Pre-Driven Cement to Surface 10.75 45.5 L-80 39 2892 39 2661 13.5 1080 sx 11 ppg Class G,286 sx 7.625 29.7 L-80 39 2892 39 6369 9.875 Stage 1:484 sx 15.8 ppg Class G Stage 2:247 sx 15.8 Class G 4.5 12.6 L-80 7958 14163 6315 6301 6.75 Liner 24.Open to production or injection? Yes ❑ No ❑ 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3 1/2 7985 N/A FRAC SLEEVEIPORT @ 8994 MD and 6331 TVD FRAC SLEEVE/PORT @9560 MD and 6326 TVD 26.ACID,FRACTURE,CEMENT SQUEEZE, ETC. FRAC SLEEVEIPORT©10164 MD and 6332 TVD Was hydraulic fracturing used during completion? Yes❑ No El FRAC SLEEVEIPORT @ 10769 MD and 6330 TVD FRAC SLEEVEIPORT @ 11476 MD and 6311 TVDPer 20 AAC 25.283(i)(2)attach electronic and printed information Ipl27 ito FRAC SLEEVEIPORT @ 11954 MD and 6303 TVD DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED FRAC SLEEVEIPORT @ 12519 MD and 6302 TVD FRAC SLEEVEIPORT @ 13040 MD and 6293 TVD L,L- FRAC SLEEVEIPORT @ 13565 MD and 6298 TVD FRA(`Si FFVF(n11d1151 Mn and 8907 TVn 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): SHUT-IN Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period - Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate -► Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 RBDMS L DEC - 6 2 mit ORIGINIAL onn • • 28.CORE DATA Conventional Core(s): Yes ❑ No D Sidewall Cores: Yes ❑ No LI If Yes, list formations and intervals cored(MD/TVD, FromlTo),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 1399 1370 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 8080 6329 information, including reports,per 20 AAC 25.071. West Sak D 1956 1853 C-80 3195 2920 C-37 5410 4858 HRZ 6874 6027 Kalubik 7481 6238 Kuparuk C(top C4) 7966 6315 Kuparuk A5 8010 6322 Kuparuk C 12118 6299 TD(A4) 14172 6300 Formation at total depth: Kuparuk A4 31. List of Attachments: Daily Operations Summary, Definitive Survey,Cement Reports,Schematic Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report.Production or well test results.oer 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Haibin Guo @ 265-1487 Email: Haibin.Guo@cop.com aca 6'-„� Printed Name: G.L.Alvord Title: Alaska Drilling Manager 9)0j, &°� F�� At l � Signature: Jt,^e �'�'oj� Phone: 265-6120 Date: t{-z INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation:Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including, but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report, production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only ,,•':1''''''''''''''''''•'1:1:'.'...-"'.:..-Ii.'. , ( -(,)/ v' 0 • z i KUP PROD 2S-09A ConocoPhillips $, wen Attributes Max Angle&MD TD Aldskii.1111:. . Wellbore AP111/191 Held NameWe/bole Status not(.1 MO 11111111 Act Btm(MB) Conotalbilaps 501032014901 KUPARUK RIVER UNIT PROD 95.58 1141406 14,172.0 ... Comment lin ppm) pate Annotalion End Date 1113-4,4(n) Rig Release Data 2S-02A,CIRY21117 14632PM SSSV:NONE ,Last WO: 39_10 10/28/2016 Verbal schorrorc acti Annotation Depth(11013) En Date AMU. Lost Mod By End Date . HANGER.35.3 .........•,Nower Last Tag: 11117/2016 Rev Reason:GIN C/O pprOven 12/14/2016 me Casing Strings ..,,,...,13.11.11.00 MIMI.. 1 .02r-Casing Description OD Iln) 10 In) Top 1105) vol Depth COKED Set Depth(TVD)...Wt/Len(L.Glade Top Thread 16 15250 39.1 119.1 1191 62.50 H-40 Welded Casing DesctiptIon OD pn) ID fin) Top(MD) Set Depth(1(013) Set Depth DVD)...Waco(I...Grade Top Thread w' CONDUCTOR SURFACE 103/4 9.950 30.7 2,822.0 ' 2,596.1 45.50 L-80 IWO 563 DUCT ;30 1-119.1- moo _ CasIng Descilption 013161) ID(In) Top IRKED Set Depth pm) Set Depth(TV0),..WI/Len(L..Grade Top Thread CONOR . ' .INTERMEDIATE 2 7 5/8 6.875 37.2 B129.9 B333.1 29.70 L-80 Hyd563 Casing Destription 001(v) ID(in) lop(MB) Set Depth 101(8) Set Depth MD)...WULen(1...Grade Top Thread SuRGACE:38.7-2,022.0.--ri I. LINER 41/2 3958 7,958.5 14,163.2 6,300.7 12.60 L-80 TenadsXP BTC.m Jim GAS OFT.3,033.3 Liner Details I Top(MB) Top(TVD)(IIKB) Top Moir) 'tent Des corn Ito) 6,317.5 82,38 NIPPLE Baker 5.5"'RS"Packoff Seal Nipple 17#0125 Nominal ID 4.250 GAS tI8T;s0s7 3 LIT Hyd 563 box x box MI Itrla 7,980.8 6317.8 82.43 HANGER Baker 5.5"x 7.63""DG"Flex-Lock Liner hanger 0)25 Hyd 563 pros/DO 4.810 GAS UST;7.142 2 NM 7,990.1 6,3190 82.62 XO Reducing 5.5'Hyd 563 15.5 8 box x 4.5"12.6#TenatisXP pin 3.920' SLIIIIIG SLV,7,8306 I MN Crossover Bushing GAUGE;7,015.1 VT., 8,202.0 6,338.5 86.29 SWELL Baker-"Swed Packer#12-"L"5.75"OD SN: 3.960 mci_ PACKER 51333.010-20 PACKER,7.8.80 4 10 mit- 8,387.6 6,341.0 91.74 FRAC Baker 4-1/2"Frac Sleeve 010-(2.688'Ball,Drift ID 2.635 NIPPLE;7,0140 Sleeve/Pod 2.625")PN:10437069 11•111 8,687.5 6,333.7 90.59 SWELL Baker-"Swell Packer fl 11-OM 5.75"OD SN: 3.970 LO•CATOR;76154.0 PACKER 51333.010.13 LOCATOR;7.9550 I= _ , 8,993.7 6,331.3 90.69 FRAC Baker 4-1/2"Frac Sleeve#9-(2.625"Ball,Drift ID 2.573 Sleeve/Per) 2.563")PN:10437088 MULESHOE;2.983 9 ili,..„1 I 11 9,252.9 6,328.1 90.78 SWELL Baker-"Swell Packer#10-"J'5.75"OD SN: 3.950 , PACKER 51333-010-15 0,559.6 6,325.5 90.01 FRAC Baker 4-112'Frac Sleeve 88-2.563"Ball,Drift to/ 2.510 1 1 Sleeve/Port 2.50'PN:10437087 it7LERM9O10TE 2, L 9,859.4 6,326.2 89.47 SWELL Baker-'Swell Packer 89."15,15"OD 05:51333 3,960 37.2-8.129 9 PACKER -010-12 illiille 10,164.9 6,332.0 89.13 FRAC Baker 4-1/2"Frac Sleeve#7-(2.5"Ball,Dolt w/ 2.448 Sleeve/Port 2.438")PN:10437086 10,464.5 6,330.5 91.13 SWELL Baker-.'Swell Packer#8-"H"5.75'OD SN: 3.970 Hydrailo Fruium,0.388 0 PACKER 51333.010-21 10,769.4 6,3304 89.24 FRAC Baker 4-1/2"Frac Sleeve 00-(2.438"Ball,Drift vol 2.385 Sleeve/Por) 2.375")PN:10437085 liiit• 11,109.6 6,334,0 90.16 SWELL Baker-"Swell Packer 117-'0"5.75*OD SN: 3.940 PACKER 51333-010-16 doiviro Femme,8991 0 I Cry I 11,209.9 6,331.0 92.59 SWELL Baker-"Swell Packer 116-'F"5.75"OD SN: 3.960 PACKER 01333-010-18 -*air 11,476.1 6,310.5 94.35 FRAC Baker 4-1/2"Frac Sleeve 05-(2.375"Ball,Drill vol 2.3231 ( Iee Hydrade Fracture;9,5400 AA:11S,1 I I I I I I 11,733.3 6,304.5 89,59 SWELL Lport 2.313")PN:10431084 Baker-"Swell Packer 85-'E"5.75"OD SN: 3.990 PACKER 5133-010-23 1Viair 11,953.6 6,303.5' 91.12 FRAC; Baker 4-1/2"Frac Sleeve 04-(2.313'13011,Orin ear 2.260 S)eeve/Port 2.25")PN:10437083 Rydraura Fracture,10165.0 1 IL" 31 1 12,253.9 6,298,9 88.14 SWELL PACKER Baker-'Swell Packer 04-"0"5.75'0D SN: 3.950 51333-010-6 12,519.2 6,302.1 90.41 FRAC Baker 4-1/2"Frac Sleeve#3-12.25"Ball,Drift vd 2.198 Sleeve/Pod 2.188')PN:10437082 lirdiai.do Frxtuie.10,769.0 ?..1...? 1 12,778_1 6,207.4 91.97 SWELL Baker-"Swell Packer 83-"C"5.75"OD SN: 3.960 PACKER 51353-010-2 Bill 1.1.E• 13,039.7 6,293.3 89.81 FRAC Baker 4-1/2'Frac Sleeve#2-(2.188"Bad,Drift sal 2,135 Sleeve/Pod 2.125')PN:10437081 13,298.5 6,294.4 813,73 SWELL Baker-"Swell Packer 02-"FM 5.75"OD SN: 3.960 : PACKER 51333-010-25 liGliir . 13,564.8 6,297.8 89.83 FRAC Baker 4-1/2"Frac Sleeve#1-(2.125"Ball,Drift vd - 2.073 • ' Sleeve/Port 2.0631 P14:16437070 .:: now,HEM.,11,1160 , I 13,825,0 6,297.5 90.00 SWELL Baker-"Swell Packer#1-"A"5.75"OD SN: 3.950 PACKER 5133-010-1 11•181- ' 14,051.3 6,297.9 8999 FRAC SLEEVE Baker 4-112'Alpha Sleeve P14 H810-07-0027 3.010 dvaiatec Ffittmo,11.910.0 14,064.7 6,298.1 88.69 SLEEVE Baker 4-1127Wellbom Isolation Valve(WIV)P19 H809 -89-0011 Tubing Strings Tubing Description String Ma...ID En) Top(ItKITI Set Depth(IL.Set Depth 1150)1..WI(IIO) Grade Top Connection TUBING 31)2 2.992 35.3 7,984.9 6,318.3 9.30 L-80 SUE-re lifdrxttcf W..,12.5190 I Completion Details Nominal ID 1118-1r Top(MB) Top 1TVD)(ftKB) Top reel(1) Item Des Com (In) 35.3 HANGER Cameron 11"x 4-112"IBT-m Tubing Hanger 3.900 ilydra,re Fracture;13,0800 I _till I 80.1 80.1 0.11 XO Reducing XO,4-1/2"12.60 L-80)BTM box x 3-1/2'9,31 1-80 EUE pin 2.992 7,830.6 6,294.9 80.61 SLIDING SLV Baker 354"CMU in closed position en/2,812'DS Profile 2.810 lalir 7,855.1 6,298.9 80.74 GAUGE Schlumberger Gauge Carrier 319"SUE-m box X SUE 2.897 8140 Pin C16GM-0416 Thredmfo Frame.:13.561-0 I MINI I 7,880.4 5,303.0 80.89 PACKER Baker Premier Production Packer 7.625"x 3.5'(659-287) 2.880' Ili III 7,904.9. 6,305_8 81.02 NIPPLE Camco 2.75 0 nipple 4/9'OD(6306'TVD,81') 2.750 6,314.2 81.88 LOCATOR Baker 7.625"x 3.5"Shear pinned Fluted No-Go Sub- 7,054.0 3.010 Horatio Fracture;14.051.0 I 1.1 .1 1 Large OD .r.,_.,_. i • . i 7,955.1 6.314.3 81.90 LOCATOR Baker 7.625"x 3.5'Shear pinned Flu/ed No-Go Sub- 3.010 .. seen//OD d 4i: 7,983.9 6,318.2 82.49 MULE SHOE Mule shoe WLEG,3-1/2"IBT box 3.490 LINER;7.958 5-14,163.2.- .1 1 (' 0, v e_Cf-c,. • • t KUP PROD 2S-09A ConocoPhillips ' Q Alaska.Inc. Co/teak lryx. .. 2809A,20039 630.20173.4692 PM Venial schema.heart) • IWIGER;35.3 .-........ a Stimulations&Treatments . 4waurmsresunruuuwuuuusmsaput i< Proppant O.ig ned(Ib) Proppant to Formation 90) Dale III .. 5110,00119 466,500.0 11/10/2016 Stimulations&Treatments Vol Clean Pump - COIIDUCTOR,38.1-143.1 Slg O Top 111681 BIm(1105) Date SlimFTreal Fluid (bbi) Vol Slurry(bbl) 6 ❑ 1 14,051.0 14,053.0 11110/2016 Hybor G,Gelled Sall Water 2262.00 2370.00 SURFACE;38.7'7,0220-4 ► 2 13,565_0 13,567.0 11/10/2016 Hybor G,Gelled Salt Waler 1502.00 1611.00 3 10040.0 13,042.0 11/10/2016 Hybor G,Gelled Sall Water 1497.00 160590 GAS LIFT;3.603.3 • 4 12,5190 12521.0 11/10/2016 Hybor G,Gelled Sall Water 1252.00 1321.00 1MIN 1 5 11554.0 11,956.0 111102016 Hybor G,Gelled Sall Water 1647.00 1756.00 I Proppant Designed(Ib) Proppant In Formation Ob) Date 600,000.0 599,9300 11/14/2010 GAS LIFT;6.8523 � Stimulations&Treatments N_ Vol Clean Pump 300011.;].1422 0�. 5100 Top(8Ke) Blm18KB) Dale 51ImRreal Fluid DAD Vol Slurry(bbl) 11111111 G 11,476.0 11,478.0 11/142016 Hybor G,Gelled Sal/Waler 1566.09 167400 01.10240 UV 7.8308 �, 7 10,769.0 10,771.0 17114201E Hyhor G,Gelled Salt Waler 1499.00 1606.00 GOUGE;7.855.1 p.m, 8 10,165.0 10,167.0 11114/2016 Hybar G,Celled Salt Waler 1499.00 1607.00 &� 9 9,560.0 9,562.0 11714/2916 Hyhor G,Gelled Sall Wale( 1548.00 1656.00 PACKER'1.000'4 TO 8,994.0 8,996.0 11/14/2016 Hybor C,Gelled Sall Water 8994.00 8996.00 PIM NIPPLE;7,004.0 11 8,768.0 8,390.0 11/14/2010 Hybor G,Gelled Salt Waler 8388.00 8390.00 Mandrel Inserts LOCATOR:7,559.0 ! Sr � LOCATOR;7,955.0 iall rillTop(TV()) Valve Latch Port She TRO Rue ' N, Top(DKR) 1600) R1aka Model OD On) Sera Type , Typo On) (pM) Run Dale Com or 75.4.15MULE 540E;r6 „.„II 1 3,903.3 3,502,4 Cameo K6MG 1 GAS LIFT GLV 'BK-5 0.188 1,981.0 11/20/2016 2 6.862.3 6,021.1 Cameo KDMG 1 GAS LIFT OV '130-5 0.313 0.0 11202016 1 L. 3 7,142.2 6,147.6 Cameo KBMG 1 GAS LIFT OMY 'BK 0.000 0.0 11/202016 IIITER6ICDIATE 2 37.24,123 6 Notes:General&Safety End Dale Annota ion 11/1712016 NOTE. Hydreteg Fraoson;8,348.0 I CI I NOTE: iilillr w1 Hydav'c Frustum;8,834.0 I 0 I I I ai liydnu`c Frxeue;9,560.0 $L I.._L J I Hpkau'o frxAro:10,1650 I { I I t^`al I iX OI 1 Hpira,c Frs-ave;10.769 0 `giali 0/4,93.0 i Facture,11,9760 I rC1T1 I £ -'. FF(( �y11 I Hydrnfc Frac10 11,929 0 !pi I 7' iiiiiilir i _ i d HI'dlo fC Fracture,12519.0 1 I 1 �I 1 t 4 i liar I i Hyriasto FraMvre,130400 I 02}I 1 S Iiiiiir € 1 lu-) ,Sdnw FracMa;19,50 1 14 t i I pp 1 -.1 f -wiaite• f ✓p 1 Hyclra✓'.c 1ra'Nre:19.051.0 I y r' 0 n n n 1111E R;7,0`0 5.14,163.2-, ,1 1 KUP PROD 2S-09A ConocoPhillips - Well Attributes ID Max Angle&MD TD Alaska,Inc. 1 Wetlbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Bhn(B)(S) Cbnocopt9etpx 501032074901 KUPARUK RIVER UNIT PROD 95.58 11,414.56 14,172.0 .". " Comment HES(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2S-09A,12/1412016 34821 PM SSSV:NONE Last WO: 39.10 10/28/2016 Vertical schematic(actual) Annotation Depth(ftKB) End data Annotation Last Mod By End Date Last Tag: 11/17/2016 Rev Reason:GLV C/0 pproven 12/14/2016 a O a Casing Strings "� Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ----- - - - •-- ' CONDUCTOR 16 15.250 39.1 119.1 119.1 62.50 H-40 Welded ..I Caning Description OD(in) ID(in) Top(ftKB) Set Depth(MEN Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 10 3/4 9.950 38.7 2,822.0 2,596.1 45.50 L-80 HYD 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread �cowoucroR:39.1-119.1 MINTERMEDIATE 2 7 5/8 6.875 37.2 8,129.9 6,333.1 29.70 L-80 Hyd563 Casco Description 00 '1D in Top(ftKB Set Casing (in) ( ) ) Depth(ftKB) Set Depth(ND)...WULen(I...Grade Top Thread SURFACE;38.7-2.822.0 LINER 41/2 3.958 7,958.5 14,163.2 6,300.7 12.60 L-80 TenarisXP BTC-m GAS LIFT;3,903.3 allLiner Details Nominal ID 4 ) Top(ftKB) Top(TVD)(ftKB) Top Ind(°) Item Des Com (in) 7,978.5 6,317.5' 82.38 NIPPLE Baker 5,5"RS"Packoff Seal Nipple 17#0125 4.250 H GAS LIFT;6,862.3 yd 563 box x box 1t 7,980.8 6,317.8 82.43 HANGER Baker 5.5"x 7.63""DG"Flex-Lock Liner hanger 4.810 GAS LIFT:7,1422 0125 Hyd 563 pin x pin 7,990.1 6,319.0 82.62 XO Reducing 5.5"Hyd 563 15.5#box x 4.5"12.6#TenarisXP pin 3.920' swing sleeve;7,830.6 Crossover Bushing Gauge/Punt sensor:7,855_1 1111.111'I 8,202.0 6,338.5 86.29 SWELL Baker-"Swell Packer#12-"L"5.75"OD SN: 3.960 PACKER 51333-010-20 PACKER;7,880.4 IN 8,387.6 6,341.0 91.74 FRAC Baker 4-1/2"Frac Sleeve#10-(2.688"Ball,Drift ID 2.635 II ev NIPPLE;7,904.9 8,687.5 6,333.7 90.59 SWELL 2.625")PN:10437089 Baker-"Swell Packer#11-"K'5.75"OD SN: 3.970 Locator;7,954.0, PACKER 51333-010-13 Locator 7,9550 8,993.7 6,331.3 90.69 FRAC Baker 4-1/2"Frac Sleeve#9-(2.625"Ball,Drift ID 2.573 Sleeve/Port 2.563")PN:10437088 Mule 5twe;7,983.9 I. 9,252.9 I 9,252.9 6,328.1 90.78 SWELL Baker-'Swell Packer#10-"J"5.75"OD SN: 3.950 lI PACKER 51333-010-15 9,559.6 6,325.5 90.01 FRAC Baker4-172"Frac Sleeve#8-2-563"Ball,Drift w/ 2.510 Sleeve/Port 2.50"PN:10437087 l 9,859.4 6,326.2 89.47 SWELL Baker-"Swell Packer#9-"I'5.75"OD SN:51333 3.960 INTERMEDIATE 2;372 8,129.9 PACKER -010-12 10,164.9 6,332.0 89.13 FRAC Baker 4-1/2'Frac Sleeve#7-(2.5"Ball,Drift w/ 2.448 Sleeve/Port 2.438")PN:10437086 m 10,464.5 6,330.5 91.13 SWELL Baker-"Swell Packer#8-"H"5.75"OD SN 3.970 Hyd Frac-Geledwater;8,3880 I N■, PACKER 51333-010-21 EICII 10,7694' 6,330.3 89.24 FRAC Baker 4-1/2'Frac Sleeve#6-(2.438"Ball,Drift wl 2.385 Sleeve7Port 2.375")PN:10437085 Vial' 11,109.6 6,334.0 90.16 SWELL Baker-"Swell Packer#7-"G"5.75"OD SN 3.940 PACKER 51333-010-16 Hyd Frac-Geletlweter;8,994.0 A till d 11,209.9 6,331.9 92.59 SWELL Baker-"Swell Packer#6-"F"5.75"OD SN: 3.960 PACKER 51333-010-18 liilir 11,476.1 6,310.5 94,35 FRAC Baker 4-1/2"Frac Sleeve#5-(2.375"Ball,Drift w/ 2.323 Sleeve/Port 2.313")PN:10437084 Hyd Frac-Geledwater;9,8600 1 Y 11,733.3 6,304.5 89.69 SWELL 'Baker-"Swell Packer#5-"E"5.75"Ob SI: 3.950 T�� PACKER 5133-010-23 „ 11,953.6' 6liGlift. ,303.5 91.12 FRAC Baker 4-1/2"Frac Sleeve#4-(2.313"Ball,Drift w/ - 2.260 Sleeve/Port 2.25")PN:10437083 Hyd Frac-GeleOvmter;10,165.0 ® 12,253.9 6,298.9 88.14 SWELL Baker-"Swell Packer#4-"D"5.75"OD SKI 3.950 1111 9 PACKER 51333-010-6 12,5192 6,302.1 90.41 FRAC Baker4-1/2"Frac Sleeve#3-(2.25"Ball,Drift w/ 2.198 Sleeve/Port 2.188")PN:10437082 1 12,778.1 6,297.4 91.97 SWELL Baker-"Swell Packer#3-"C"5.75°OD SN: 3.960 :x o;. I PACKER 51333-010-2 Hyd Frae-Geledweter,10,7690 13,039.7 6,293.3 89.81 FRAC Baker 4-1/2"Frac Sleeve#2-(2.188"Ball,Drift w/ 2.135 Sleeve/Port 2.125")PN:10437081 13,298.5 6,294.4 88.73 SWELL Baker-"Swell Packer#2-"9"5.75"OD SN 3.960 PACKER 51333-010-25 " 13,564.8 6,297.8 89.83 FRAC Baker 4-1/2'Frac Sleeve#1-(2.125"BaH,Drift WI 2.073 ��1 Sleeve/Port 2.063")PN:10437070 Hyd Frac-Ge46tlweter,11,476.0 I r'�TI I 13,825.0 6,297.5 90.00 SWELL Baker-"Swell Packer#1-"A"5.75"OD SN: 3.950 ?--"f PACKER 5133-010-1 "roir 14,051.3 6,297.9 88.99 FRAC SLEEVE Baker4-1/2"Alpha Sleeve PN H810-07-0027 3.010 Hyd Frac-Gepedweter;11,954_0 f I r - m 14,064.7 6,298.1 88.69 SLEEVE Baker 4-1/2"Wellborn Isolation Valve(WTV)PN H809 -89-0011 Tubing Strings `tiGiiir Tubing Description Sting Me...ID(in) Top(ftKB) Set Depth(ft..Sat Depth(TVD)(...Wt(Ib/It) Grade Top Connection TUBING 31/2 2.992 35.3 7,984.9 6,318.3 9.30 L-80 EUE-m Hyd Frac-GeflOMater,12,519.0 I . Completion Details 1® Nominal ID Top(ftKB) Top(ND)(ftKB) Tap Inel(°) Item Des Com (in) 35.3 HANGER Cameron 11"x 4-1/2"IBT-m Tubing Hanger 3.900 80.1 80.1 0.11 X0 Reducing X0,4-1/2"12.6#L-80 IBTM box x 3-1/2"9.3#L-80 EUE 2.992 Hyd Frec-celedwamr;13,040.0 I pin 7,830.6 6,294.9 80.61 Sliding Sleeve Baker 3W CMU in closed position w/2.812"OS Profile 2.810 Iiiilir 7,855.1 6,298.9 80.74 Gauge/Pump Schlumberger Gauge Carrier 314"EUE-m box X EUE 2.897 Sensor 8RD Pin C16GM-0416 Hyd Frac-Geladwater,13,5660 15.-7'I I I 1 7,880.4 6,303.0 80.89 PACKER 'Baker Premier Production Packer 7.625"x3.5"(659-287) 2.880 _iiiiiiir 7,904.9 6,306.8 81.02 NIPPLE Cameo 2.75 D nipple 4W OD(6306'ND,81°) 2.750 7,954.0 6,314.2 81.86 Locator Baker 7.625'x 3.5"Shear pinned Fluted No-Go Sub- 3.010 ®i Large OD Hyd Frac-Galwabr; etl14,051.0 I 7,955.1 6,314.3 81.90 Locator Baker 7.625°x 3.5°Shear pinned Fluted No-Go Sub- 3.010 small OD 7,983.9 6,3182- 82.49 Mule Shoe Mule shoe WLEG,3-1/2"IBT box 3.490 LINER;7,958.5-14,1632 i iii- KUP PROD 2S-09A ConocoPhillips a • Alaska,Inc. cogmPMM1s 20-09A,12/142016 348:23 PM Vertical schematic(acwaq HANGER;36,3 •=r. G7 . Stimulations&Treatments n Proppant Designed(Ib) Proppant In Fomlalion(Ib) Date -- ----'-- ------ _ --- - 5 .0 502,075.0 11/10/2016 Stimulations&Treatmentments op in Vol Clmn Slurry �/A-1 CONDUCTOR;39.1-119.1 ' DePN(BKB) DepN(BKe)TEL Min Top Mm Btm T(ftKB U) B((fIRS)) Stg 11 Date StirtVTreat Fluid Pump(bbl) Vo(bat) 4 j 11,954.0 14,053.0 6,297.9 6,297.9 1 11/10/2016 Hybor G,Gelled Salt Water 2262.00 2370.00 SURFACE;38.7-2,822.0 11,954.0 14,053.0 6,297.8 6,297.8 2 11/10/2016 Hybor G,Gelled Salt Water 1502.00 1611.00 11,954.0 14,053.0 6,293.3 6,293.3 3 11/10/2016 Hybor G,Gelled Salt Water 1497.00 1605.00 GAB LIFT;3,903.3ft 11,954.0 14,053.0 6,302.1 6,302.1 4 11/10/2016 Hybor G,Gelled Salt Water 1252.00 1321.00 11,954.0 14,053.0 6,303.5 6,303.4 5 11/10/2016 Hybor G,Gelled Salt Water 1647.00 1756.00 <I ',} Proppant Designed(lb) ProPpant In Formation(Ib) Date 642,750_0 644,330.0 11/14/2016 GAS LIFT;8.882,3 Stimulations&Treatments Min Top Max Ban Top(TVD) abn(TVD) Vol Clean Vol Stony GAS LIFT;7,142.2 Depth(MB) Depth OMB) (itKB) MB) 545 R Date StiMTreat Fluid Pump(bbl) (bbl) 8,388.0 11,478.0 6,310.5 6,310.4 6 11/14/2016 Hybor G,Gelled Salt Water 1566.00 1674.00 lets 8,388.0 11,478.0 6,330.3 6,330.4 7 11/14/2016 Hybor G,Gelled Salt Water 1499.00 1606.00 Sliding Sleeve;7,830s ,NM 8,388.0 11,478.0 6,332.0 6,332.0 8 11/14/2016 Hybor G,Gelled Salt Water 1499.00 1607.00 Goose/Pony,Sonoor,7,855.1 8,388.0 11,478.0 6,325.5 6,325.5 9 11/14/2016 Hybor G,Gelled Salt Water 1548.00 1656.00 PACKER;7,880.4 8,366.0 11,478.0 6,331.3 6,331.2 10-11/14/2016 Hybor G,Gelled Salt Water 8994.00 8996.00 1 8,388.0 11,478.0 6,341.0' 6,340.9 11 11/14/2016 Hybor G,Gelled Salt Water 8388.00 8390.00 NIPPLE;7,904.9 ° . ___ Mandrel Inserts Lotor;7,9540 - .may Sl ca ali Locator;7,955.0 t �y on Top(TVD) Valve Latch Pat Size TRO Run N Top M te) . ke 00(in) Sw Type Type (m) (pai) Ron Date Coon Mule Shoe;7,9819 IIIrI=c. 1 3,903.3(BKB) 3,502.4. CamcoMa �KBMGModel1 GAS LIFT GLV BK-5 0.188 1,981.0 11/20/2016 2' 6,862.3 6,021.1 Camco KBMG 1 GAS LIFT OV BK-5 0.313 0.0 11/20/2016 1 3 0 u 3- 7,142.2 6,147.6 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/20/2016 INTERMEDIATE2;37.2-8,129.9 - Notes:General&Safety End Date Annotation NOTE: I "`'... NOTE: Hyd Frac-Gefletlweter,8,388.0 illIir Hyd Frec-Gebdeeter;8994.0 1 ,■, I cCa Hyd Frac-Geledxeter;9,560.0 I fpl 1® Hyd Frac-C.a./ate,10,185.0 I ■in I X IHyd Frac-Geledaalter;10,769.0 Hyd Frac-Geledvsmr;11,4780 I I `7iiir Hyd Frac-G.Aetlxater;11954.6 I I I I FF liiiir Hyd Frac-Geledwaler;12,519.01 ' Km l ` lliar I>`J Hytl Frac-Geledweler;130400 '1 II I -11111- Hyd lamHyd Frac-G...0er;13,565.0 1 1rI 1 11 I ` liltilr Hyd Frac-GaleMmbr;14,051.0 I Il7j)tJ I LINER;7,958.5-14,1632,_--,I • • 2S-09 ConocoPhillips Proposed P&A Schematic 10/05/2016 CAMERON 07 16"Conductor to-120' • 13.5" Surface Hole TOC: 2572'MD r iia ' 'i „ West Sak Sand:T 1,960'MD/I,853'ND • B 2,748'MD/2,596'TVD ..........-0,0,",47,,.;,, Surface Casing i'% (ayytcfiC0 • • 2S-09A ConocoPhillips Proposed SideTrack Schematic 10/07/2016 ,CAMERON 16"Conductor to—120' • • 13.5" -;urfac West Sak Sand:T 1,960'MD/1,853'TVD B 2,748'MD/2,596'ND ii\ Surface Casing 10-3/4"45.5#L-80 Hydril 563 2822'MD 1 2,596` TVD (31 iNC) — 9-7/8" x 11" Intermediate ;widge Hole ['lug 297'2.' (''Ai i ‘ , 21 Stage TOC: 4918'MD,500'MD ' above C-37 Stage Collas 5,518'MD !„ wt },}I $ 15 t4't til'I is 'ti t��? t�?>� l ?,�,�;z?y,k ? ,�„ , , i ? 1 # \\\\\\\ I i'#}l� # i t „ 'E � I! c +N i !k tt�r '7 i. E,? � ' �iy�?� �j�,! I I ��}�, 1. — — \ I , ?c i'.G37ll rlv.}T'Y tpl,T fld i„? 1,R \ 14)s tlirr' Growler(Iceberg):5 SiY11p:14,9d!(•TW ? 1'? . — 1t ntop ``� air+t 6 ii4 tNDlssk T ' ti'. % --- >> , ,\„‘\.,:,::::.:.:::...''.. . '::. . Beuda .8,437 MD l5,653'TW',. . 1 —. HRZ:6,875'MD/6,G25''ND Kalubik:7,187'MD 16,159'ND i Kuuaruk C:'r 981'MD!6.318'TVD KuparukA4:7504'MD/6,331'NO • illtfRillfidiate Cautnc( 7-5/8"29.70 L-80 Hyd563 Cas1trg • 7,247'MD/6,264'TVD (71° INC intermediate Casing 7-518" 29.7#L-80 Hyd563 Casing TD:14,1n'MD/6,339'TVD 8,155'MD/6,339'TVDOt/4NCai•Otauction Hole • • 2S-09A ConocoPhillips Proposed SideTrack Schematic 1 0/07/2016 CAMERON A16"Conductor to-120' 13.5" Surface Hole West Sak Sand:T 1,960'MD/1,853'TVD B 2,748'MD/2,596'TVD Surface Casing _ Al\ 10-3/4"45.5# L-80 Hydril 563 2,822' MD/2,596' TVD (31' INC) 9-7/8" x 11" Intermediate ridge Hole Plug 2972' MD i` 2nd Stage TOC 4918'MD,500'MD above C-37 \\\\\\\\ C-37: TOC 7007' Growler(Iceberg): Cairn: x74'MD/5,554'TVD Bermuda:6,427'MD 15,653'TVD • HRZ: MD/6,025'ND Kalubik:7,187'MD/6,159'ND � Kuparuk C:7.981'MD 16.318'TVD Kuparuk A4:7,504'MD/6,331'TVD Jntermediate Casing • 7-5/8" 29.7# L-80 Hyd563 Lasitig- 7,247' MD/6,264' TVD 71° ntermediate Casing ( INC)) 7-5/8" 29.7# L-80 Hyd563 Casing TD:14,171'MD/6,339'TVD 8,155' MD/6,339' TVDegiNC reduction Hole n ,,s'-,_ • • 2S-09A ConocoPhillips Proposed SideTrack Schematic 10/07/2016 ' CAMERON .fir 2 16"Conductor to-120' SUPERS -0 ED • 13.5" Surface Hole i; . West Sak Sand:T 1,960'MD/1,853'ND 6 i B 2,748'MD/2,596'ND Surface Casing r. 10-3/4" 45.5# L-80 Hydril 563 2,822' MD/2,596' TVD (31° INC) i', f "r ' " 9-7/8" x 11" Intermediate II :ridge Hole Plug 2972' MD 2nd Stage TOO 4918'MD,500'MD above 0-37 o Stage Collar:5,518'MD ,, ' //� , s r�`41= ,mo gra y, �, 3 7007' r/i %i i� t r/ Growler(Iceberg) 5/6,,,2`MD/12,986'TVD-,,,/ r D ---— =' a op -- ...: VP�„ �� TV-1:, Cairn '6'-'-.` ,n ctnerit retali v, 7tC Bermuda::,.427'-MD/$; 3'1 ; yr \, HRZ:6,875 MD 16,025'ND Kalubik:7,187'MD/6,159'ND Kuparuk C:7,981'MD/6.318'TVD r F Kuparuk A4:7,504'MDI 6,331'ND erre is e Casing e 7 /8” 29,7# L-80Hyd563 Ca1"�Y` Intermediate Casing 7,247' MD/6,264' TVD (71° INC) 7-5/8" 29.7# L-80 Hyd563 Casing TD:14,171'MD/6,339'TVD 8,155' MD/6,339' TVDtaT/4N( )roductlon Hole i; s • ,.. Operations Summary (with Timelog Depths) az _ 2S-09 ConocoPhillips Rig: DOYON 142 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)', 9/12/2016 9/13/2016 6.00 MIRU MOVE MOB P Pull modules off well 2S-06.Back sub 0.0 0.0 18:00 00:00 base of well.Move rig mats,prep well 2S-09 with grader and spot rig mats. Remove hand rails on wellhouse 2S- 10 and 2S-08. Move sub base over well 2S-09. 9/13/2016 9/13/2016 2.00 MIRU MOVE MOB P PJSM-spot rig mats around 2S-09& 0.0 0.0 00:00 02:00 rig foot print. 9/13/2016 9/13/2016 1.50 MIRU MOVE MOB P PJSM-remove hand rails from well 0.0 0.0 02:00 03:30 houses adjacent to 2S-09&line up sub base to spot over well. 9/13/2016 9/13/2016 1.50 MIRU MOVE MOB P PJSM-spot sub base over 2S-09,set 0.0 0.0 03:30 05:00 stomper supports,skid rig floor over well center,&remove tongue from sub base. 9/13/2016 9/13/2016 2.50 MIRU MOVE MOB P PJSM-spot pits,pumps,motor,&rock 0.0 0.0 05:00 07:30 washer modules.SIMOPS hook up steam,air,water,mud,&electrical interconnects. 9/13/2016 9/13/2016 1.50 MIRU MOVE MOB P PJSM-spot pipe shed module. 0.0 0.0 07:30 09:00 SIMOPS secure all walkways& landings. Pull&connect electrical. Continue berming around the rig. 9/13/2016 9/13/2016 3.00 MIRU 'MOVE RURD P PJSM-continue hooking up 0.0 0.0 09:00 12:00 interconnects,install ramp on skate,& complete pre-spud checklist. Rig accepted at 12:00 hrs. 9/13/2016 9/13/2016 1.50 MIRU MOVE NUND P PJSM-install riser on surface riser& 0.0 0.0 12:00 13:30 torque bolts on diverter system. SIMOPS bring on spud mud to the pits. Rig swapped to shore power at 13:30 hrs. 9/13/2016 9/13/2016 0.50 MIRU MOVE RURD P PJSM-install mouse hole in the rotary 0.0 0.0 13:30 14:00 table. 9/13/2016 9/13/2016 1.00 MIRU MOVE SFTY P Conduct pre-spud meeting with rig 0.0 0.0 14:00 15:00 team. 9/13/2016 9/13/2016 4.00 MIRU MOVE PULD P PJSM-pick up&rack back 30 stands 0.0 0.0 15:00 19:00 of 5"DP in the derrick,using the mouse hole. 9/13/2016 9/13/2016 3.50 MIRU MOVE PULD P PJSM-pick up&rack back 5 stands of 0.0 0.0 19:00 22:30 5"HWDP&1 stand of 7"NMFC in the derrick,using the mouse hole. 9/13/2016 9/13/2016 0.50 MIRU MOVE BOPE P PJSM-perform diverter test with 5" 0.0 0.0 22:30 23:00 DP,annular closure time 21 sec,knife valve opening time 6 sec.Initial system pressure 2950 psi,pressure after closure 1950 psi,200 psi recharge time 6 sec,full recharge time 45 sec.Average pressure of 6 nitrogen bottle 2500 psi.Pit&gas alarms tested.Witness of test waived by AOGCC Rep. Brian Bixby. 9/13/2016 9/14/2016 1.00 MIRU MOVE BHAH P PJSM-pick up surface BHA#1 to 87' 0.0 87.0 23:00 00:00 MD as per SLB DD. 9/14/2016 9/14/2016 1.25 MIRU MOVE BHAH P PJSM-continue making up BHA 1 per 87.0 118.0 00:00 01:15 SLB DD f/87'-118'MD. 9/14/2016 9/14/2016 0.25 MIRU MOVE SEQP P PJSM-test high pressure mud lines to 118.0 118.0 01:15 01:30 3500 psi,good. Page 1/58 Report Printed: 10/31/2016 9 l • Operations Summary (with Timelo • the *rte' 2S-09 ConocoPhiiiips '' Rig: DOYON 142 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) 9/14/2016 9/14/2016 5.00 SURFAC DRILL DDRL P PJSM-directional drill 13-1/2"surface 118.0 559.0 01:30 06:30 hole section f/119'-559'MD,559' TVD,550 gpm, 1050 psi,50 rpm,Tq on 4K,off 3K,WOB 10K,FO 20%,PU 76K,SO 83K,ROT 83K,MW 9.0 ppg, Max gas 0,ADT 2.67,AST.89,Bit 2.67,Jars 47.56,Total Footage 440' MD. 9/14/2016 9/14/2016 1.50 SURFAC DRILL CIRC P PJSM-circulate while rigging up to run 559.0 559.0 06:30 08:00 gyro,390 gpm,400 psi. 9/14/2016 9/14/2016 4.00 SURFAC DRILL DDRL P PJSM-directional drill 13-1/2"surface 559.0 933.0 08:00 12:00 hole section f/559'-933'MD,926' TVD,550 gpm, 1200 psi,50 rpm,Tq on 5K,off 2K,WOB 23K,FO 21%,PU 85K,SO 91K, ROT 91K, MW 9.1 ppg, Max gas 0,ADT 1.68,AST.49,Bit 4.84,Jars 49.67,Total Footage 374' MD.Run gyro shots on connections f/ 559'to 835'MD. 9/14/2016 9/14/2016 6.00 SURFAC DRILL DDRL P PJSM-directional drill 13-1/2"surface 933.0 1,512.0 12:00 18:00 hole section f/933'-1512'MD, 1473' TVD,550 gpm, 1428 psi,50 rpm,Tq on 5K,off 2K,WOB 28K,FO 20%,PU 95K,SO 93K,ROT 93K,MW 9.6 ppg, ADT 4.42,AST 2.7,Bit 9.26,Jars 54.18,Total Footage 579'MD. 9/14/2016 9/15/2016 6.00 SURFAC DRILL DDRL P PJSM-directional drill 13-1/2"surface 1,512.0 1,997.0 18:00 00:00 hole section f/1512'-1997'MD, 1888' TVD,750 gpm,2170 psi,60 rpm,Tq on 3K,off 2K,WOB 5-28K, FO 25%, PU 108K,SO 103K,ROT 107K,MW 10.0 ppg,ADT 3.34,AST.84,Bit 12.6, Jars 57.52,Total Footage 485'MD. 9/15/2016 9/15/2016 1.50 SURFAC DRILL DDRL P PJSM-directional drill 13-1/2"surface 1,997.0 2,166.0 00:00 01:30 hole section f/1997'-2166'MD,2034' TVD,700 gpm,2150 psi, 100 rpm,Tq on 6-7K,off 2-3K,WOB 20K,FO 25%, PU 108K,SO 103K,ROT 107K,MW 10.0 ppg,ADT 1.07,AST 0,Bit 13.67, Jars 58.59,Total Footage 169'MD. 9/15/2016 9/15/2016 1.00 SURFAC DRILL CIRC T Real time communication lost with 2,166.0 1,979.0 01:30 02:30 LWD,decision made to trip for BHA change.CBU 2 times @ 770 gpm, 2250 psi, 100 rpm,Tq 2-3K,f/2166'- 1979'MD. 9/15/2016 9/15/2016 0.50 SURFAC DRILL OWFF T Monitorwell,static. 1,979.0 1,979.0 02:30 03:00 Fire Drill CRT 72 sec @ 03:00 hrs. 9/15/2016 9/15/2016 3.25 SURFAC DRILL TRIP T PJSM-TOH f/1979'-747'MD. 1,979.0 747.0 03:00 06:15 9/15/2016 9/15/2016 0.25 SURFAC DRILL OWFF T Monitor well,static. 747.0 747.0 06:15 06:30 9/15/2016 9/15/2016 1.50 SURFAC DRILL BHAH T PJSM-rack back HWDP,Jars,& 747.0 0.0 06:30 08:00 NMFC.Lay down UBHO,MWD,LWD, &NM Stab. 9/15/2016 9/15/2016 1.50 SURFAC DRILL BHAH T PJSM-make up new NM Stab, LWD, 0.0 746.0 08:00 09:30 &MWD to motor&bit.Run in hole with NMFC,Jars,&HWDP to 746' MD. Page 2/58 Report Printed: 10/31/2016 s Itj Operations Summary (with Timelog Depths) Col 0 2S-09 Phiifib Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dar(hr)', ;Phase Op Code Activity Code Time P-T-x Operation (ftKB) End Depth(ftKB) 9/15/2016 9/15/2016 1.50 SURFAC DRILL TRIP T PJSM-TIH f/746'-1660'MD,work 746.0 1,660.0 09:30 11:00 through tight spots at 1117', 1504',& 1623'MD. 9/15/2016 9/15/2016 2.00 SURFAC DRILL REAM T Ream f/1660'-2070'MD,450 gpm, 1,660.0 2,070.0 11:00 13:00 500 psi,FO 12%,50 rpm,Tq 2-3K, PU 114K,SO 103K,ROT 107K. 9/15/2016 9/15/2016 1.00 SURFAC DRILL CIRC T Circulate&condition mud system 2,070.0 2,169.0 13:00 14:00 2070'-2169'MD.Observed thick mud w/clay returns blinding off shakers. Stage up pumps to 750 gpm,ICP 500 psi,FCP 2053 psi,FO 24%,50 rpm, Tq 2.5K,PU 115K,SO 103K,ROT 107K. 9/15/2016 9/15/2016 6.50 SURFAC DRILL DDRL P PJSM-directional drill 13-1/2"surface 2,169.0 2,833.0 14:00 20:30 hole section f/2166'-2833'MD,2605' TVD,780 gpm,2557 psi, 100 rpm,Tq on 6-7K,off 4K,WOB 26K,FO 25%, PU 126K,SO 114K,ROT 118K, MW 10.0 ppg,ADT 4.14,AST.94,Bit 17.81,Jars 62.73,Total Footage 664' MD. 9/15/2016 9/15/2016 1.00 SURFAC CASING CIRC P Circulate&condition mud system 2,833.0 2,733.0 20:30 21:30 2833'-2733'MD,780 gpm,2493 psi, FO 24%, 100 rpm,Tq 4.5K,PU 126K, SO 114K,ROT 118K,7793 strokes pumped. 9/15/2016 9/15/2016 1.00 SURFAC CASING CIRC T Observe flow line pack off with thick 2,733.0 2,733.0 21:30 22:30 mud.Clear flow line&experience shakers blind off.Clear shakers to resume circulating out thick mud w/ clay.Stage pumps back up to 170-750 gpm,340-2325 psi, 10-100 rpm. 9/15/2016 9/15/2016 1.00 SURFAC CASING CIRC P CBU f/2733'-2626'MD @ 750 gpm, 2,733.0 2,626.0 22:30 23:30 2325 psi, 100 rpm,Tq 4K, PU 126K, SO 114K,ROT 118K. 9/15/2016 9/16/2016 0.50 SURFAC CASING OWFF P Monitor well,observe slight drop in 2,626.0 2,626.0 23:30 00:00 fluid level. 9/16/2016 9/16/2016 3.50 SURFAC CASING TRIP P PJSM-blow down TD,TOH from 2,626.0 388.0 00:00 03:30 2626'-388'MD,PU 130K,SO 90K. Spill Drill CRT 79 sec @ 03:30 hrs. 9/16/2016 9/16/2016 3.50 SURFAC CASING BHAH P PJSM rack back HWDP,Jars& 388.0 0.0 03:30 07:00 NMFC.Lay down BHA#2.Clean up rig floor. 9/16/2016 9/16/2016 0.50 SURFAC CASING RURD P R/U Casing equipment on the rig floor, 0.0 0.0 07:00 07:30 Volant CRT,bail extensions and elevators. 9/16/2016 9/16/2016 6.25 SURFAC CASING PUTB P PJSM-P/U 10 3/4 shoe track,floats, 0.0 1,437.0 07:30 13:45 baker loc threads,check floats,good. Run 10 3/4",45.5#,Hydril 563, dopeless casing,to 1468'MD. M/U torque 19,400#, fill every 10 joints. Rejected joints 5&6-bad pin/box. 9/16/2016 9/16/2016 0.75 SURFAC CASING CIRC P Circulate&condition mud staging up 1,437.0 1,437.0 13:45 14:30 pumps,due to extremely thick mud,to 2.5 bpm,235 gpm, 128 psi,PU 105K, SO 87K, 2031 strokes pumps. 9/16/2016 9/16/2016 1.00 SURFAC CASING PUTB P Run 10 3/4",45.5#,Hydril 563, 1,437.0 1,717.0 14:30 15:30 dopeless casing,f/1437'-1717'MD. M/U torque 19,400#, fill every 10 joints. Page 3/58 Report Printed: 10/31/2016 Operations Summary (with Timelog Depths) t 2S-09 C«��oPhithp Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time: End Time Dur(hr) Phase Op Code Activity Code Time P-T-X OperationMKS) End',Depth(ftKB) 9/16/2016 9/16/2016 1.25 SURFAC CASING CIRC P Circulate&condition mud staging up 1,717.0 1,758.0 15:30 16:45 pumps,due to loss of down weight f/ 1717'-1758'MD.Stage up pump due to extremely thick mud, 1-4 bpm,400- 170 psi, FO 9%,PU 106K,SO 95K, 1168 strokes pumps. 9/16/2016 9/16/2016 1.25 SURFAC CASING PUTB P Run 10 3/4",45.5#,Hydril 563, 1,758.0 2,249.0 16:45 18:00 dopeless casing,f/1758'-2249'MD. M/U torque 19,400#, fill every 10 joints. 9/16/2016 9/16/2016 1.25 SURFAC CASING CIRC P Circulate&condition mud staging up 2,249.0 2,291.0 18:00 19:15 pumps,due to loss of down weight f/ 2249'-2291'MD.Stage up pump due to extremely thick mud, 1-3 bpm,375- 130 psi,FO 8%,PU 130K,SO 115K, 1944 strokes pumps. 9/16/2016 9/16/2016 1.25 SURFAC CASING PUTB P Run 10 3/4",45.5#,Hydril 563, 2,291.0 2,780.0 19:15 20:30 dopeless casing,f/2291'-2780'MD. M/U torque 19,400#, fill every 10 joints.Ran a total of 68 joints,2 stop rings&68 bow spring centralizers. Rejected 2 joints&no remakes. 9/16/2016 9/16/2016 0.50 SURFAC CASING HOSO P Make up CIW 10.75"hanger&landing 2,780.0 2,823.0 20:30 21:00 joint,run in landing hanger at 2823' MD. PU 155K,SO 94K. 9/16/2016 9/16/2016 0.25 SURFAC CEMENT RURD P PJSM- blow down top drive,rig up 2,823.0 2,823.0 21:00 21:15 cement hose to CRT. 9/16/2016 9/17/2016 2.75 SURFAC CEMENT CIRC P Circulate&condition mud for cement 2,823.0 2,823.0 21:15 00:00 job,staging up pumps,2-7 bpm,ICP 410,FCP 330 psi,FO 4-11%,PU 151K,SO 130K, 9055 strokes pumps. SIMOPS hold PJSM with oncoming crew for cementing. 9/17/2016 9/17/2016 1.50 SURFAC CEMENT CIRC P Circulate&condition mud for 2,823.0 2,823.0 00:00 01:30 cementing,298 gpm,311 psi,PU 152K,SO 130K. 9/17/2016 9/17/2016 2.75 SURFAC CEMENT CMNT P Cement as per SLB detail.Flood lines 2,823.0 2,823.0 01:30 04:15 w/5 bbls of H2O. P/T lines to 800/ 3500 psi,good.Pump 50.2 bbls of CW -100 at 5.5 bpm,205 psi.Pump 68.6 bbls of 10.5 ppg Mud Push II at 4.5 bpm, 190 psi. Drop bottom plug.Pump 360.7 bbls of 11.0 ppg lead cement at 6.5 bpm,225-360 psi. 9/17/2016 9/17/2016 0.25 SURFAC CEMENT CMNT T While pumping lead cement the 2,823.0 2,823.0 04:15 04:30 cementers lost prime on their pump with 291 bbls away.Pumping was resumed to finish lead cement. Between pumping the lead&tail cement SLB troubleshot the cement unit. Page 4/58 Report Printed: 10/31/2016 • Operations Summary (with Timelog!epths) gaikt 2S-09 Conoco nocot7tlit��li5 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB)l End Depth(ftKS)' 9/17/2016 9/17/2016 1.50 SURFAC CEMENT CMNT P Pump 59.1 bbls of 15.8 ppg tail 2,822.0 0.0 04:30 06:00 cement at 4.5 bpm,450 psi. Drop top plug.Pump 10 bbls of fresh H2O at 3 bpm,230 psi.Pump 253 bbls of 10.0 ppg mud at 3-5 bpm,340-665 psi. Plug bumped at 2508 strokes. Pressure up to 1100 psi&hold for 5 minutes.Bleed off pressure to check floats,good. 173 bbls of cement returns to surface.CIP @ 05:54 hrs. After swapping to the rig to displace cement the casing string was picked up to begin reciprocation.The string was picked up 2-3 feet with PU 180K, previous PU was 160K.Slacked off to verify ability to land back on hanger. Unable to slack off to land hanger. Continue attempts to land on hanger with no success.Pick up w/190K,to 18"from fully landed mark,to be able to set emergency slips.Displacement of cement was continuous. 9/17/2016 9/17/2016 0.50 SURFAC CEMENT OWFF P Monitor well at landing joint& 0.0 0.0 06:00 06:30 conductor outlet,static.SIMOPS begin rigging down cementing equipment. 9/17/2016 9/17/2016 5.00 SURFAC CEMENT WOC T Wait on cement.SIMOPS disconnect 0.0 0.0 06:30 11:30 diverter line from knife valve& remove.Lay down Volant CRT&put on 150 ton elevators.Remove mouse hole.Clear&clean rig floor.Clean mud pits.Load&strap 5"DP in the pipe shed. 9/17/2016 9/17/2016 1.25 SURFAC CEMENT NUND T PJSM-rig up bridge cranes to annular 0.0 0.0 11:30 12:45 &pick up with diverter tee.Clean cement debris from hanger&starting. 9/17/2016 9/17/2016 0.25 SURFAC CEMENT NUND T PJSM-attempt to stretch casing,with 0.0 0.0 12:45 13:00 pick up weight to 250K,to install emergency slips. 9/17/2016 9/17/2016 2.50 SURFAC CEMENT NUND P PJSM-lay down landing joint& 0.0 0.0 13:00 15:30 surface riser. Nipple down annular, diverter tee&starting head. 9/17/2016 9/17/2016 1.50 SURFAC CEMENT NUND T PJSM-install landing joint to hanger. 0.0 0.0 15:30 17:00 Pick up to 250K&install emergency slips as per CIW Rep.Remove&lay down landing joint. 9/17/2016 9/17/2016 1.00 SURFAC WHDBOP NUND P PJSM-install 50'sling to top drive& 0.0 0.0 17:00 18:00 install MBS wellhead as per CIW Rep. Test seals on hanger to 5000 psi for 10 min,witnessed. 9/17/2016 9/17/2016 4.50 SURFAC WHDBOP NUND P PJSM-nipple up riser,BOPE,& 0.0 0.0 18:00 22:30 choke/kill lines.SIMOPS clean pits. 9/17/2016 9/18/2016 1.50 SURFAC WHDBOP MPDA P PJSM-nipple up RCD&position 0.0 0.0 22:30 00:00 choke skid.SIMOPS clean pits& grease choke.Pickup 4 stands of 5" DP racking back in derric. 9/18/2016 9/18/2016 3.75 SURFAC WHDBOP MPDA P PJSM-NU MPD equipment on stack 0.0 0.0 00:00 03:45 and run lines. SIMOPS-P/U 5"DP&stand back 30 stands. Page 5/58 Report Printed: 10/31/2016 y , tperations Summary (with Timelog epths) 0 l 2S-09 ii€ ps Rig: DOYON 142 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) 9/18/2016 9/18/2016 0.50 SURFAC WHDBOP RURD P PJSM-pull mouse hole from from 0.0 0.0 03:45 04:15 roatary table, P/U test joint and set test plug. 9/18/2016 9/18/2016 2.00 SURFAC WHDBOP MPDA P PJSM-fill BOPE stack,Install RCD 0.0 0.0 04:15 06:15 and test plug.Test RCD and air valve, 250 psi/mins 1500 psi/5 min's.Pull test plug. 9/18/2016 9/18/2016 1.25 SURFAC WHDBOP RURD P PJSM-install 5"TJ,R/U to test BOPE. 0.0 0.0 06:15 07:30 9/18/2016 9/18/2016 2.00 SURFAC WHDBOP BOPE T Leak on choke line-troubleshoot. 0.0 0.0 07:30 09:30 Noticed damaged sealing face and small gouge on inner Grey lock face. 9/18/2016 9/18/2016 1.00 SURFAC WHDBOP WAIT T Discuss plan forward on replacement 0.0 0.0 09:30 10:30 of choke hard line and adjusting grey locks. Service Top Drive, Iron roughneck& draw works. 9/18/2016 9/18/2016 1.00 SURFAC WHDBOP BOPE T PJSM-C/O piping on choke line, 0.0 0.0 10:30 11:30 install new tested piping in choke line. 9/18/2016 9/18/2016 0.50 SURFAC WHDBOP BOPE P Fill stack and shell test 250/3500. 0.0 0.0 11:30 12:00 9/18/2016 9/18/2016 0.50 SURFAC WHDBOP BOPE T PJSM-Kill line has small leak on grey 0.0 0.0 12:00 12:30 lock connection.Bleed off pressure an tighten. Page 6/58 Report Printed: 10/31/2016 Operations Summary (with Timelog Depths) 4 $„ r4,3323' 2S-09 citlips Rig: DOYON 142 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) 9/18/2016 9/18/2016 5.00 SURFAC WHDBOP BOPE P Test witness waived by AOGCC Rep. 0.0 0.0 12:30 17:30 Guy Cook.All tests with 5"TJ. 250/3500 psi,charted for 5 minutes each. 1)Annular;CV#1, 12, 13, 14,4"Kill line Demco on mud manifold,&4-1/2" IF Dart valve. 2)Upper 3-1/2"X 6"VBR's,CV#9,11, Mezzanine Kill line Demco,&4-1/2"IF FOSV. 3)CV#8, 10,&HCR Kill 4)CV#6&7. 5)Super choke&manual choke tested to 2000 psi. 6)CV#2,5&Manual Kill 7)HCR Choke 8)Manual Choke&upper Top Drive IBOP 9)Lower 3-1/2"X 6"VBR's&lower Top Drive IBOP. 10)Blind rams,CV#3,4,&6 Accumulator draw down performed w/ 2ea.Air pumps&electric triplex pumps, initial system pressure 3000 psi,after closure 1850 psi,200 psi attained in 10 sec,full pressure attained in 45 sec, 6 nitrogen bottles with an average pressure of 2516 psi. Test pit level&flow out alarms. All H2S and Combustible gas alarms tested.Primary&remote BOP controls were functioned. Initial shell test failed at gray lock connection on choke line,changed out spool because of fluid cut.Re-test shell,failed at gray lock connection on kill line,re-tightened.Re-tested shell passed. 9/18/2016 9/18/2016 0.50 SURFAC WHDBOP BOPE T PJSM-test Newly installed Choke line 0.0 0.0 17:30 18:00 to 250/5000 psi,5 minutes each.Blow &rig down test equipment. 9/18/2016 9/18/2016 1.25 SURFAC WHDBOP RURD P PJSM-remove test plug&install wear 0.0 0.0 18:00 19:15 bushing w/10"ID.RILDS.Change out rotary bushings for split bushings. SIMOPS modify trip nipple length. 9/18/2016 9/18/2016 0.25 SURFAC CEMENT PULD P PJSM-pick up 1 stand of 5"DP&rack 0.0 0.0 19:15 19:30 back in the derrick.SIMOPS modify trip nipple for higher elevation. 9/18/2016 9/18/2016 0.25 SURFAC CEMENT RURD P PJSM-install trip nipple&blow down 0.0 0.0 19:30 19:45 kill/choke lines. 9/18/2016 9/18/2016 2.75 SURFAC CEMENT BHAH P PJSM-Make up 9-7/8"X11" 0.0 783.0 19:45 22:30 intermediate BHA 3 as per SLB DD to 783'MD,PU 87K,SO 92K 9/18/2016 9/19/2016 1.50 SURFAC CEMENT PULD P PJSM-pick up 5"DP&single in the 783.0 1,826.0 22:30 00:00 hole with BHA 3 f/783'-1826MD. 9/19/2016 9/19/2016 1.25 SURFAC CEMENT PULD P PJSM-TIH f/1826'-2580'MD,picking 1,826.0 2,580.0 00:00 01:15 up 5"DP from the pipe shed,PU 134K,SO 106K. Page 7/58 Report Printed: 10/31/2016 0 Operations Summary (with Timelog Depths) of p 2S-09 ONt coPhiliips Rig: DOYON 142 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) 9/19/2016 9/19/2016 1.00 SURFAC CEMENT CIRC P Circulate&condition mud for casing 2,580.0 2,580.0 01:15 02:15 pressure test at 550 gpm, 1500 psi,40 rpm,Tq 4-6K,MW 10.0 ppg. 9/19/2016 9/19/2016 0.25 SURFAC CEMENT RURD P PJSM-rig up to test casing. 2,580.0 2,580.0 02:15 02:30 9/19/2016 9/19/2016 1.00 SURFAC CEMENT PRTS T Attempt to test casing. Pressure up to 2,580.0 2,580.0 02:30 03:30 1150 psi&observe pressure drop off. Trouble shoot surface equipment& replace pressure sensator on OA. Pressure up to 1929 psi&observe pressure drop off on test equipment. Trouble shoot&replace test hose. Test surface test equipment to 3500 psi,good. 9/19/2016 9/19/2016 0.75 SURFAC CEMENT PRTS P PJSM-test 10-3/4"surface casing to 2,580.0 2,580.0 03:30 04:15 3500 psi for 30 minutes,charted. Pressure up to 3550 psi with 35 strokes at 5 spm.Shut in&observed pressure for 30 minutes.Initial shut in pressure was 3550 psi.Final shut in pressure was 3530 psi. Rig down test equipment. 9/19/2016 9/19/2016 1.75 SURFAC CEMENT SLPC P PJSM-cut&slip 102'of drill line. 2,580.0 2,580.0 04:15 06:00 9/19/2016 9/19/2016 0.75 SURFAC CEMENT COCF P Wash down to TOC f/2580'-2713' 2,580.0 2,713.0 06:00 06:45 MD,at 84 gpm, 130 psi. 9/19/2016 9/19/2016 2.50 SURFAC CEMENT DRLG P PJSM-Drill out cement,plugs,shoe 2,713.0 2,833.0 06:45 09:15 track&rat hole f/2713'-2833'MD at 300-510 gpm,550-1420 psi,50-90 rpm,Tq 4-10K,WOB 10-20K,PU 144K,SO 110K,ROT 122K,MW 10.0 ppg.Drill out shoe with 4K WOB. SCR @ 2770'MD,2562'TVD,MW 10.0,08:24 hrs #1 @ 30= 130 psi,©40=190 psi #2@30=130 psi,@40= 190 psi 9/19/2016 9/19/2016 0.25 SURFAC CEMENT DDRL P PJSM-Ddrill f/2833'-2853'MD,2622' 2,833.0 2,853.0 09:15 09:30 TVD,600 gpm, 1775 psi,60 rpm,Tq on 7.5K,off 5K,WOB 10K,PU 144K, SO 110K,ROT 122K,MW 10.0 ppg, ADT.17,Bit.17,Jars 42.29,total footage 20'MD. 9/19/2016 9/19/2016 0.50 SURFAC CEMENT CIRC P C&C mud system for FIT/LOT f/2853'- 2,853.0 2,769.0 09:30 10:00 2769'MD,650 gpm, 1990 psi,60 rpm, Tq 4-7K,MW 10.0 ppg,pumped 3773 strokes. 9/19/2016 9/19/2016 0.25 SURFAC CEMENT OWFF P Monitor well,static. 2,769.0 2,769.0 10:00 10:15 9/19/2016 9/19/2016 1.25 SURFAC CEMENT LOT P PJSM-rig up test equipment.Perform 2,769.0 2,769.0 10:15 11:30 LOT to an EMW of 15.7 ppg.Pressure up w/10.0 ppg mud to 810 psi in 11 strokes.Observe pressure decrease to 400 psi.Shut in&observe pressure for 10 minutes.Initial shut in pressure 400 psi.Final shut in pressure 320 psi. Confer with town on test.Blow down& rig down test equipment. Page 8/58 Report Printed: 10/31/2016 Y Sh4S Operations Summary (with Timelog Depths) 2S-09 Coetarcoxitlips Rig: DOYON 142 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) 9/19/2016 9/19/2016 0.50 INTRM1 DRILL DISP P PJSM-displace well to 9.2 ppg LSND 2,769.0 2,853.0 11:30 12:00 f/2769'-2853'MD at 500 gpm, 1050 psi,40 rpm,Tq 4-7K,2502 strokes. 9/19/2016 9/19/2016 7.00 INTRM1 DRILL DDRL P PJSM-directional drill 9-7/8"X11" 2,853.0 2,962.0 12:00 19:00 intermediate hole section f/2853'- 2962'MD,2727'TVD,700 gpm, 1593 psi, 100 rpm,Tq on 5-6K,off 4-7K, WOB 10-30K,FO 23%,PU 144K,SO 110K, ROT 125K,MW 9.2 ppg,ADT 4.1,Bit 4.27,Jars 46.39,Total Footage 109'MD. SCR @ 2944'MD,2708'TVD,MW 9.2+, 18:15 hrs #1 @ 30=120 psi,@ 40=160 psi #2©30=120 psi,@ 40=160 psi 9/19/2016 9/19/2016 1.25 INTRM1 DRILL CIRC T Experience problems with directional 2,962.0 2,962.0 19:00 20:15 steering,circulate at 706 gpm, 1641 psi,60 rpm,Tq 5K,FO 23%,pumped 12867 strokes.Could not determine cause of steering issue(tools,junk in hole,or geology). 9/19/2016 9/19/2016 0.50 INTRMI DRILL DDRL P PJSM-directional drill 9-7/8"X11" 2,962.0 3,006.0 20:15 20:45 intermediate hole section f/2962'- 3006'MD,2750'TVD,700 gpm, 1611 psi, 100 rpm,Tq on 5-6K,off 4-7K, WOB 2K,FO 23%,PU 144K,SO 110K, ROT 125K,MW 9.2 ppg,Max gas 5, ADT.25,Bit 4.52,Jars 46.64, Total Footage 44'MD. 9/19/2016 9/19/2016 0.25 INTRMI DRILL TRIP P PJSM-TOH f/3006'-2924'MD,PU 3,006.0 2,924.0 20:45 21:00 144K,SO 110K. 9/19/2016 9/19/2016 0.25 INTRM1 DRILL CIRC P Open under reamer,drop RFID chips 2,924.0 2,924.0 21:00 21:15 &pump down at 700 gpm, 1603 psi, FO 23%,for 300 strokes.Reduce rate to 200 gpm,235 psi,FO 10%, 150 strokes. Increase rate to 700 gpm. Observed pressure decrease to 1348 psi&MWD turbine speed reduce to 2382 from 2929 previously.Pull test into shoe w/5K overpull to verify reamer open. 9/19/2016 9/19/2016 1.00 INTRM1 DRILL UREM P Under ream hole f/2924'-3006'MD,to 2,924.0 3,006.0 21:15 22:15 open hole f/9-7/8"to 11"at 800 gpm, 1692 psi,FO 23%,100 rpm,Tq 4-6K, WOB 1-2K,ECD 9.74, PU 144K,SO 110K,ROT 125K,MW 9.3 ppg. SCR @ 2960'MD,2720'TVD,MW 9.3,21:45 hrs #1 @ 30=120 psi,@ 40= 160 psi #2@30=120 psi,@40=160 psi 9/19/2016 9/20/2016 1.75 INTRM1 DRILL DDRL P PJSM-directional drill 9-7/8"X11" 3,006.0 3,146.0 22:15 00:00 intermediate hole section f/3006'- 3146'MD,2866'TVD,807 gpm, 1735 psi, 100 rpm,Tq on 6-8K,off 5.5K, WOB 6-12K,FO 23%,PU 136K,SO 115K, ROT 123K,MW 9.3 ppg,Max gas 38, ADT.75,Bit 5.27,Jars 47.39, Total Footage 140'MD. Page 9/58 Report Printed: 10/31/2016 operations Summary (with Timelog4t)epths) 2S-09 0Conoc.oPhillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(Er) Phase Op Code Activity Code. Time P-T-X Operation (11KB) End Depth MKS)9/20/2016 9/20/2016 6.00 INTRM1 DRILL DDRL P PJSM-directional drill 9-7/8"X11" 3,146.0 3,798.0 00:00 06:00 intermediate hole section f/3146'- 3798'MD,3436'TVD,800 gpm, 1885 psi,FO 25%, 140 rpm,Tq on 7-9K, WOB 6-12K,ECD 10.03,Off Bottom 1875 psi, PU 158K,SO 127K,ROT 140K,off 6K,MW 9.2 ppg,Max gas 30, ADT 4.66, Bit 9.93,Jars 52.05, Total Footage 652'MD. SCR @ 3530'MD,3201'TVD,MW 9.2,03:46 hrs #1 @ 30= 140 psi,@ 40=180 psi #2@30= 140 psi,@40=180 psi 9/20/2016 9/20/2016 6.00 INTRM1 DRILL DDRL P PJSM-directional drill 9-7/8"X11" 3,798.0 4,384.0 06:00 12:00 intermediate hole section f/3798'- 4384'MD,3967'TVD,800 gpm,2100 psi,FO 29%, 140 rpm,Tq on 8-12K, WOB 7-15K,ECD 10.19,Off Bottom 2090 psi,PU 180K,SO 130K,ROT 148K,off 8K,MW 9.25 ppg,Max gas 22, ADT 4.56,Bit 14.49,Jars 56.61, Total Footage 586'MD. Kick w/Drilling CRT 180 sec @ 10:40 hrs. SCR @ 4006'MD,3616'TVD, MW 9.25,08:10 hrs #1 @ 30=150 psi,@ 40=200 psi #2@30= 160 psi,@40=200 psi 9/20/2016 9/20/2016 6.50 INTRM1 DRILL DDRL P PJSM-directional drill 9-7/8"X11" 4,384.0 4,951.0 12:00 18:30 intermediate hole section f/4384'- 4951'MD,4527'TVD,800 gpm,2254 psi,FO 30%, 140 rpm,Tq on 8-13K, WOB 11K,ECD 10.34,Off Bottom 2225 psi,PU 200K,SO 144K, ROT 167K,off 10K,MW 9.5 ppg,Max gas 21, ADT 4.67,Bit 19.17,Jars 61.29, Total Footage 567'MD. Kick w/Drilling CRT 160 sec @ 16:00 hrs. SCR @ 4473'MD,4045'TVD, MW 9.3+, 13:00 hrs #1 @ 30=175 psi,@ 40=210 psi #2@30=175 psi,@40=210 psi 9/20/2016 9/20/2016 0.50 INTRM1 DRILL BKRM T PJSM-loose a swab on#2 mud 4,951.0 4,887.0 18:30 19:00 pump.BROOH f/4951'-4887'MD at 211 gpm,306 psi, FO 14%,20 rpm, Tq 10K. 9/20/2016 9/20/2016 1.00 INTRM1 DRILL MPDA P PJSM-remove trip nipple,install MPD 4,887.0 4,951.0 19:00 20:00 bearing&drain nipple.Line up MPD choke skid.Calibrate chokes at drilling parameters f/4887'-4951'MD. SIMOPS change out swab on#2 mud pump. Page 10/58 Report Printed: 10/31/2016 iterations Summary (with Timelog!epths) 2S-09 Caix30312hinips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation {MKS) End Depth(ftKS)', 9/20/2016 9/21/2016 4.00 INTRM1 DRILL DDRL P PJSM-directional drill 9-7/8"X11" 4,951.0 5,375.0 20:00 00:00 intermediate hole section f/4951'- 5375'MD,4945'TVD,800 gpm,2850 psi,FO 35%, 140 rpm,Tq on 7-16K, WOB 15K,ECD 10.84,Off Bottom 2550 psi,PU 212K,SO 143K, ROT 168K,Tq off 10-12K,MW 9.6 ppg, Max gas 136, ADT 3.20, Bit 22.37, Jars 64.49,Total Footage 424'MD. SCR @ 4950'MD,4528'TVD,MW 9.5,20:00 hrs #1 @ 30=200 psi,@ 40=240 psi #2 @ 30=200 psi,@ 40=240 psi 9/21/2016 9/21/2016 6.00 INTRM1 DRILL DDRL P PJSM-directional drill 9-7/8"X11" 5,375.0 5,897.0 00:00 06:00 intermediate hole section f/5375'- 5897'MD,5419'TVD,790 gpm,2740 psi,FO 36%, 140 rpm,Tq on 12-19K, WOB 22-24K,ECD 10.79,Off Bottom 2681 psi,PU 235K,SO 150K, ROT 177K,Tq off 13-14K, MW 9.7 ppg, Max gas 88, ADT 4.78, Bit 27.15, Jars 69.27,Total Footage 522'MD. SCR @ 5516'MD,5079'TVD,MW 9.7,01:28 hrs #1 @ 30=220 psi,@ 40=280 psi #2 @ 30=220 psi,@ 40=280 psi 9/21/2016 9/21/2016 2.00 INTRM1 DRILL DDRL P PJSM-directional drill 9-7/8"X11" 5,897.0 6,087.0 06:00 08:00 intermediate hole section f/5897'- 6087'MD,5578'TVD,790 gpm,2794 psi, FO 36%, 140 rpm,Tq on 12-19K, WOB 25K,ECD 10.91,Off Bottom 2753 psi,PU 236K,SO 154K, ROT 183K,Tq off 13-14K,MW 9.7 ppg, Max gas 52, ADT 1.57,Bit 28.72, Jars 70.84,Total Footage 190'MD. SCR @ 6087'MD,5578'TVD,MW 9.7,08:00 hrs #1 @ 30=190 psi,@ 40=260 psi #2 @ 30=190 psi,@ 40=260 psi 9/21/2016 9/21/2016 0.50 INTRM1 DRILL LOT P Perform dynamic open hole LOT @ 6,087.0 6,087.0 08:00 08:30 6087'MD,5578'TVD,MW 9.7 ppg. Top of Cairn at 5554'TVD.Close in choke while pumping at 790 gpm, 2765 psi, 10 rpm,Tq 12K.Close in choke to observe pressure build up of 230 psi or an EMW of 11.46 ppg. Page 11/58 Report Printed: 10/31/2016 operations Summary (with Timelog epths) 0 2S-09 ' . .,tips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time Pi-T-X Operation MKS) End Depth(ftKB). 9/21/2016 9/21/2016 7.75 INTRM1 DRILL DDRL P PJSM-directional drill 9-7/8"X11" 6,087.0 6,845.0 08:30 16:15 intermediate hole section f/6087'- 6845'MD,6091'TVD,750 gpm,2656 psi,FO 36%, 120 rpm,Tq on 8-20K, WOB 25K,ECD 11.1,Off Bottom 2650 psi, PU 232K,SO 160K,ROT 187K,Tq off 13K,MW 10.0 ppg,Max gas 300, ADT 7.88,Bit 35.03,Jars 77.15,Total Footage 758'MD. Fire Drill CRT 110 sec @ 15:00 hrs. SCR @ 6653'MD,5988'TVD,MW 10.0, 14:30 hrs #1 @ 30=250 psi,@ 40=300 psi #2 @ 30=250 psi,@ 40=300 psi 9/21/2016 9/21/2016 0.75 INTRM1 DRILL CIRC P CBU @ 6845'MD,685 gpm,2260 psi, 6,845.0 6,845.0 16:15 17:00 FO 36%, 140 rpm,Tq 9-15K,7000 strokes. 9/21/2016 9/21/2016 1.00 INTRM1 DRILL LOT P Perform dynamic open hole LOT @ 6,845.0 6,845.0 17:00 18:00 6845'MD,6091'TVD,MW 10.0 ppg. Top of Cairn at 5554'TVD.Close in choke while pumping at 200 gpm,200 psi, 10 rpm,Tq 13K.Close in choke to observe pressure build up of 265 psi or an EMW of 10.92 ppg. 9/21/2016 9/21/2016 5.00 INTRM1 DRILL DDRL P PJSM-directional drill 9-7/8"X11" 6,845.0 7,190.0 18:00 23:00 intermediate hole section f/6845'- 7190'MD,6248'TVD,790 gpm,3100 psi,FO 35%, 130 rpm,Tq on 11-19K, WOB 21K,ECD 11.22,Off Bottom 3080 psi,PU 234K,SO 160K,ROT 186K,Tq off 13-15K,MW 10.0+ppg, Max gas 202, ADT 3.68, Bit 38.71, Jars 80.83,Total Footage 345'MD. 9/21/2016 9/21/2016 0.50 INTRM1 DRILL CIRC P CBU f/7190'-7130'MD,790 gpm, 7,190.0 7,130.0 23:00 23:30 3055 psi,FO 25%,60 rpm,Tq 13- 17K,racking stand back in the derrick. 9/21/2016 9/22/2016 0.50 INTRM1 DRILL LOT P Perform static open hole LOT @ 7130' 7,130.0 7,130.0 23:30 00:00 MD,6222'TVD,MW 10.0+ppg.Top of Cairn at 5554'TVD.Start test at the shut in pressure of 160 psi. Pressure up to 205 psi,in 7 strokes&observe 205 psi to 10 strokes.Shut in& observe for 10 minutes.Initial shut in pressure 205 psi,final shut in pressure 165 psi.205 psi is an EMW of 10.7 ppg. 9/22/2016 9/22/2016 3.00 INTRM1 DRILL DDRL P PJSM-directional drill 9-7/8"X11" 7,190.0 7,257.0 00:00 03:00 intermediate hole section f/7190'- 7257'MD,6267'TVD,790 gpm,2906 psi,FO 26%, 140 rpm,Tq on 10-19K, WOB 12K, ECD 10.92,Off Bottom 2887 psi,PU 265K,SO 147K,ROT 184K,Tq off 15-17K,MW 10.0 ppg, Max gas 64, ADT 1.91,Bit 40.62, Jars 82.74,Total Footage 67'MD. Page 12/58 Report Printed: 10/31/2016 • t;°00Operations Summary (with Timelo9%e the ) 2S-09 Cor'ocoPhiilips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time. End Time- Dur{hr}', ''Phase Op Code Activity Code Time P-T-X Operation {ftK6} End'Depth{ftKS)' 9/22/2016 9/22/2016 1.75 INTRM1 CASING CRC P CBU 3X at 650 gpm,2915 psi,FO 7,257.0 7,257.0 03:00 04:45 26%, 100 rpm,Tq 12-18K, 19288 strokes.Obtain final surveys&SCR's. SCR @ 7257 MD,6267'TVD,MW 10.0,03:00 hrs #1 @ 30=235 psi,@ 40=295 psi #2 @ 30=235 psi,@ 40=295 psi 9/22/2016 9/22/2016 0.75 INTRM1 CASING OWFF P Perform MPD no-flow test,open& 7,257.0 7,257.0 04:45 05:30 shut chokes observing shut in pressure each time.Trend showed signs of breathing. 9/22/2016 9/22/2016 1.75 INTRM1 CASING CIRC P PJSM-close under reamer as per 7,257.0 7,228.0 05:30 07:15 WFT Rep.f/7257'-7228'MD,drop RFID tags&pump down at 650 gpm, 2134 psi, FO 28%,for 1000 strokes. Reduce rate to 200 gpm,425 psi,FO 11%,400 strokes. Increase rate to 650 gpm with no indication of closure. Repeat process 2 more times. 9/22/2016 9/22/2016 0.75 INTRM1 CASING CIRC P Continue to weight up mud system f/ 7,228.0 7,228.0 07:15 08:00 10.0 to 10.2 ppg at 675 gpm,2328 psi, 100 rpm,Tq 13-17K,PU 265K,SO 147K,ROT 187K. Spill Drill 180 sec @ 07:33 hrs. 9/22/2016 9/22/2016 1.50 INTRM1 CASING BKRM P PJSM-BROOH f/7228'-7080'MD, 7,228.0 7,080.0 08:00 09:30 650 gpm,2173 psi,60 rpm,Tq 14- 17K.Continue weighting up mud system to 10.2 ppg. 9/22/2016 9/22/2016 1.75 INTRM1 CASING PMPO P Pump out of hole f/7080'-6653'MD, 7,080.0 6,653.0 09:30 11:15 650 gpm,2173 psi,PU 257K,SO 140K,ROT 183K,MW 10.2 ppg. 9/22/2016 9/22/2016 1.75 INTRM1 CASING CIRC P Circulate&condition hole clean at 650 6,653.0 6,653.0 11:15 13:00 gpm,2187 psi, 100 rpm,Tq 11-17K, PU 250K,SO 140K,ROT 190K, 12150 strokes pumped. 9/22/2016 9/22/2016 1.00 INTRM1 CASING OWFF P Monitor well, 10 rpm,Tq 15K.Observe 6,653.0 6,653.0 13:00 14:00 well bore breathing,to static.Observe static for 30 min. 9/22/2016 9/22/2016 0.25 INTRM1 CASING MPDA P PJSM-line up MPD system to trip out 6,653.0 6,653.0 14:00 14:15 of hole,blow down TD. 9/22/2016 9/22/2016 3.75 INTRM1 CASING SMPD P PJSM- TOH holding 35-40 psi with 6,653.0 2,772.0 14:15 18:00 MPD,f/6653'-2772'MD,PU 138K, SO 108K. 9/22/2016 9/22/2016 1.00 INTRM1 CASING CIRC P CBU 2X at 500 gpm, 1200 psi,40 2,772.0 2,772.0 18:00 19:00 rpm,Tq 7K,PU 138K,SO 108K, ROT 122K,5329 strokes. 9/22/2016 9/22/2016 1.00 INTRM1 CASING OWFF P Monitor well, 10 rpm,Tq 15K.Observe 2,772.0 2,772.0 19:00 20:00 well bore breathing,to static.Observe static for 30 min. 9/22/2016 9/22/2016 1.00 INTRM1 CASING MPDA P PJSM-remove drain nipple&RCD 2,772.0 2,772.0 20:00 21:00 bearing.Install trip nipple&line up returns system. 9/22/2016 9/22/2016 1.75 INTRM1 CASING TRIP P PJSM-TOH f/2772'-783'MD. 2,772.0 783.0 21:00 22:45 9/22/2016 9/23/2016 1.25 INTRM1 CASING 'BHAH P PJSM-lay down 18 joints of 5"HWDP 783.0 193.0 22:45 00:00 &Jars 783'-193'MD. Total losses for 24 hrs 7 bbls. Page 13/58 Report Printed: 10/31/2016 . R • Operations Summary (with TimelogDepths) 2S-09 itr Rig: DOYON 142 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) 9/23/2016 9/23/2016 2.75 INTRM1 CASING BHAH P PJSM-lay down BHA 3 f/193'-0'MD, 193.0 0.0 00:00 02:45 as per SLB DD. 9/23/2016 9/23/2016 0.75 INTRM1 CASING WWWH P PJSM-make up stack wash tool& 0.0 0.0 02:45 03:30 flush stack at 400 gpm,40 rpm.Lay down stack washing tool.SIMOPS clear&clean rig floor of BHA. 9/23/2016 9/23/2016 1.50 INTRM1 CASING BOPE P PJSM-change out upper VBR's to 7- 0.0 0.0 03:30 05:00 5/8"solid body rams.SIMOPS mobilize casing equipment to rig floor. 9/23/2016 9/23/2016 1.50 INTRM1 CASING BOPE P PJSM-remove wear ring&install test 0.0 0.0 05:00 06:30 plug.Test upper rams to 250/3500 psi for 5 minutes each.Test annular to 250/2500 psi for 5 min each.All tests charted.Pull test joint&plug.Blow down&rig down test equipment. 9/23/2016 9/23/2016 1.00 INTRM1 CASING RURD P PJSM-rig up to run casing.Change 0.0 0.0 06:30 07:30 out bails f/121"to 131",install 4'bail extensions,side door elevators,& casing power tongs. 9/23/2016 9/23/2016 6.50 INTRM1 CASING PUTB P PJSM-pick up 7.625",29.7#,L-80, 0.0 2,747.0 07:30 14:00 Hyd 563,dopeless casing.Baker-lok shoe track&check floats.TIH to 2747' MD filling on the fly&topping off every 10 joints. Install 88 Hydroform centralizers to joint#61,with 3 centralizers per 2 joints configuration. PU 110K,SO 103K. 9/23/2016 9/23/2016 1.25 INTRM1 CASING CIRC P Circulate&condition f/2747'-2787' 2,747.0 2,787.0 14:00 15:15 MD,staging up pumps to 8 bpm,225 psi,FO 15%,MW 10.0 ppg in&out, 4304 strokes pumped. 9/23/2016 9/23/2016 2.00 INTRM1 CASING PUTB P Continue running 7.625",29.7#,L-80, 2,787.0 3,690.0 15:15 17:15 Hyd 563,dopeless casing f/2787'- 3690'MD.Fill each joint on the fly& top off every 10 joints.SO 103K 9/23/2016 9/23/2016 1.75 INTRM1 CASING CIRC P Circulate and condition mud while 3,690.0 3,690.0 17:15 19:00 reciprocating.Staged up pump to 6 bpm,290 psi, 10%FO, 10 ppg MW in/out. 9/23/2016 9/23/2016 2.25 INTRM1 CASING PUTB P Continue running 7.625",29.7#,L-80, 3,690.0 4,913.0 19:00 21:15 Hyd 563,dopeless casing f/3690'- 4913'MD.Fill each joint on the fly& top off every 10 joints.PU 186K,SO 133K 9/23/2016 9/24/2016 2.75 INTRM1 CASING CIRC T Break circulation to fill pipe for 4,913.0 4,913.0 21:15 00:00 displacement strap w/1 bpm,365 psi, FO 4%.Stage up to 2 bpm,350 psi, FO 4%.Shut down to strap displacement&record half of calculated displacement.Attempt to circulate at 2 bpm showing losses. Reduce rate to.5 bpm 270 psi,slight visual of flow out observed.Adjust rates to 2 bpm on the up stroke&.5 bpm on the down stroke with no improvement.Estimated losses 75% of bbls pumped. Calculated trip gain 22.05 bbls. Actual trip gain 16.95 bbls. Circulation losses 80 bbls. Total formation losses 84 bbls. Page 14/58 Report Printed: 10/31/2016 IPperations Summary (with Timelog!epths) 0 2S-09 Corx:PcoPhillips Rig: DOYON 142 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(WKB). 9/24/2016 9/24/2016 1.75 INTRM1 CASING CIRC T Circulate&condition at 2 bpm,285 4,913.0 4,913.0 00:00 01:45 psi, FO minimal,PU 180K,SO 135K, strokes 3637,loss rate—1.9 bpm. 9/24/2016 9/24/2016 1.25 INTRM1 CASING PMPO T PJSM-pump 7-5/8"casing out of hole 4,913.0 4,716.0 01:45 03:00 f/4913'-4716'MD,2 bpm,285 psi,FO minimal,PU 170K. 9/24/2016 9/24/2016 0.50 INTRM1 CASING CIRC T Circulate&condition at 2 bpm,280 4,716.0 4,716.0 03:00 03:30 psi,FO minimal,PU 170K,SO 130K. No success establishing good circulation.Decision made to wash in the hole to 6599'to try circulating again. 9/24/2016 9/24/2016 1.00 INTRM1 CASING PUTB T PJSM-wash in the hole w/7-5/8" 4,716.0 4,913.0 03:30 04:30 casing f/4716'-4913'MD,2 bpm,360 psi,FO minimal. 9/24/2016 9/24/2016 1.50 INTRM1 CASING PUTB P PJSM-wash in the hole w/7-5/8" 4,913.0 5,450.0 04:30 06:00 casing f/4913'-5450'MD,2 bpm,360 psi,FO minimal,PU 200K,SO 143K. 9/24/2016 9/24/2016 6.00 INTRM1 CASING PUTB P Continue running 7.625",29.7#,L-80, 5,450.0 6,599.0 06:00 12:00 Hyd 563,dopeless casing f/5450'- 6599'MD.Wash each joint down at 2 bpm,328 psi,FO 4%(full returns @ 5969'MD),strokes 8714 PU 245K,SO 157K.Total losses for tour 540 bbls. 9/24/2016 9/24/2016 2.75 INTRM1 CASING CIRC P Circulate&condition staging pump up 6,599.0 6,599.0 12:00 14:45 to 6 bpm,265 psi,FO 10%,PU 250K, SO 160K,6250 strokes. 9/24/2016 9/24/2016 1.75 INTRM1 CASING PUTB P Continue running 7.625",29.7#,L-80, 6,599.0 7,205.0 14:45 16:30 Hyd 563,dopeless casing f/6599'- 7205'MD.Wash at 2 bpm,242 psi, FO 3%(wash down to 6715'MD) 9/24/2016 9/24/2016 0.50 INTRM1 CASING HOSO P PJSM-make up hanger&landing 7,205.0 7,247.0 16:30 17:00 joint.Wash down at 2 bpm,242 psi, FO 3%,PU 267K,SO 160K.Land casing on hanger at 7247'MD. 9/24/2016 9/24/2016 0.25 INTRM1 CEMENT CIRC P Circulate&condition 2 bpm,250 psi, 7,247.0 7,247.0 17:00 17:15 FO 4%.SIMOPS PJSM to rig up cement line to pump in sub on CRT. 9/24/2016 9/24/2016 0.25 INTRM1 CEMENT RURD P Blow down top drive,isolate top drive 7,247.0 7,247.0 17:15 17:30 &rig up cement line. 9/24/2016 9/24/2016 3.75 INTRM1 CEMENT CIRC P Circulate&condition for cement job 7,247.0 7,247.0 17:30 21:15 staging up the pump to 6 bpm,330 psi,FO 11%,PU 269K,SO 161K, 15053 strokes. 9/24/2016 9/24/2016 0.25 INTRM1 CEMENT SFTY P PJSM for cementing 7-5/8"casing. 7,247.0 7,247.0 21:15 21:30 Continue circulating at 6 bpm,330 psi, FO 11%. 9/24/2016 9/24/2016 0.75 INTRM1 CEMENT CIRC P Circulate&condition for cement job at 7,247.0 7,247.0 21:30 22:15 6 bpm,330 psi, FO 11%,PU 269K, SO 161K.SIMOPS batch up mud push&cement. Page 15/58 Report Printed: 10/31/2016 • Operations Summary (with Timeloggepths) 2S-09 ConocoPhiilips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code; Activity Code Time P-T-X Operation (EKB) End Depth(ftKB).. 9/24/2016 9/25/2016 1.75 INTRM1 CEMENT CMNT P Line up to cement unit&pump 5 bbls 7,247.0 7,247.0 22:15 00:00 of MPII to flood lines at 3 bpm,200 psi.Test lines to 518/4000 psi.Reset high trip to 2000 psi(for stage tool). Continue to pump 12.5 ppg MPII at 5 bpm,265 psi for a total of 42.6 bbls. Drop bottom plug.Pump 15.8 ppg Shark Tooth slurry as follows; 10 bbls w/no cemnet,50 bbls w/1 ppb cemnet,and 40 bbls w/no cemnet at 5.2 bpm,215 psi,FO 11%.Drop closing plug. Pump 10 bbls of H2O at 6.1 bpm, 103 psi.Swap to rig and pump 10.0 ppg LSND mud at 6 bpm, 125 psi,FO 10%.Observe losses start —1625 strokes.Pumped 2000 strokes of displacement at 24:00 hrs. Gained 68 bbls for tour,due to well bore breathing. Total losses 472 for last 24 hrs. 9/25/2016 9/25/2016 1.00 INTRM1 CEMENT CMNT P Continue displacement with 10 ppg 7,247.0 7,247.0 00:00 01:00 LSND at 6 bpm, 127 psi,FO 8%,Slow rate(losses @ 1625 strokes)to 2 bpm,70 psi,FCP 571 psi @ 2 bpm. Bump plug at 3100 strokes.Check floats,good.CIP @ 00:58 hrs.Total Losses for first stage 6 bbls from cement around the shoe to CIP. 9/25/2016 9/25/2016 0.25 INTRM1 CEMENT OWFF P Monitor well,static. 7,247.0 7,247.0 01:00 01:15 9/25/2016 9/25/2016 3.75 INTRM1 CEMENT CIRC P PJSM-pressure up at 2 bpm& 7,247.0 7,247.0 01:15 05:00 observe stage tool open at 2937 psi. Circulate thru stage tool staging up pump to 6 bpm,275 psi,FO 10%, pumped 3200 strokes at 6 bpm. SIMOPS load,strap,&tally 4"DP in pipe shed.PJSM for 2nd stage cement. 9/25/2016 9/25/2016 2.25 INTRM1 CEMENT CMNT P Pump second stage cement as per 7,247.0 0.0 05:00 07:15 SLB cementing program. Pump 40.6 bbls of 12.5 ppg MPII at 5.4 bpm,227 psi. Pump 50 bbls of 15.8 ppg Sharks Tooth slurry at 4 bpm, 160 psi.Drop closing plug.Pump 10 bbls of H2O at 6.1 bpm,95 psi.Swap to rig& displace with 10 ppg LSND at 6 bpm, 483 psi,FO 7%.Slow pump rate as losses were observed to 2 bpm,516 psi. Losses started at—1800 strokes (cement at stage tool at 1882 stk). Bump plug at 2349 strokes,pressuring up to 1700 psi to shift stage collar closed.Observed closing at 1300 psi. Hold for 5 minutes,bleed off,&check for flow.Tool closed.CIP @ 06:51 hrs. Total Losses for second stage 14 bbls from cement at tool to CIP. 9/25/2016 9/25/2016 0.25 INTRM1 CEMENT OWFF P Monitor well,static. 0.0 0.0 07:15 07:30 Page 16/58 Report Printed: 10/31/2016 '' Operations Summary (with TimelogDepths) 0 0 2S-09 ifip Rig: DOYON 142 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(MB) 9/25/2016 9/25/2016 2.75 INTRM1 CEMENT WWSP P PJSM-back out landing joint,drain& 0.0 0.0 07:30 10:15 flush stack. Make up packoff running tool to landing joint.Set packoff& RILDS,per CIW Rep.Test seals to 5000 psi for 10 minutes,witnessed. Lay down running tool&landing joint. SIMOPS lay down casing equipment &prep floor to lay down 5"DP from derrick. 9/25/2016 9/25/2016 4.25 INTRM1 CEMENT PULD P PJSM- lay down 37 stands of 5"DP 0.0 0.0 10:15 14:30 from derrick.SIMOPS rig up to flush& freeze OA. 9/25/2016 9/25/2016 3.00 INTRM1 CEMENT FRZP P PJSM-pressure test lines to 2000 psi. 0.0 0.0 14:30 17:30 Flush OA w/123 bbls of fresh H2O,3 bpm, ICP 520 psi,FCP 630 psi.Rig up LRS.Pump 90 bbls of Isotherm at 1 bpm, ICP 500 psi,FCP 1020 psi. Shut in pressure 900 psi.SIMOPS Lay down 26 stands of 5"DP from derrick. Clean pits. 9/25/2016 9/25/2016 2.75 INTRM1 CEMENT PULD P PJSM- lay down 23 stands of 5"DP 0.0 0.0 17:30 20:15 from derrick. 9/25/2016 9/25/2016 2.75 INTRM1 CEMENT RURD P PJSM-change out upper rams to 3- 0.0 0.0 20:15 23:00 1/2"X6"VBR's,C/O saver sub to 4" XT39,dress roughneck for 4"DP,& C/O to 4"elevators w/4-5/16"ID. 9/25/2016 9/26/2016 1.00 INTRM1 CEMENT PULD P PJSM-pick up 5 stands of 4"DP, 0.0 0.0 23:00 00:00 racking back in the derrick. OA 460 psi at 24:00 hrs. 9/26/2016 9/26/2016 3.00 INTRM1 CEMENT PULD P PJSM-pick up&rack back 25 stands 0.0 0.0 00:00 03:00 of 4"HWDP. 9/26/2016 9/26/2016 8.50 INTRM1 CEMENT PULD P PJSM-pick up&rack back 69 stands 0.0 0.0 03:00 11:30 of 4"DP. 9/26/2016 9/26/2016 1.50 INTRM1 WHDBOP RURD P PJSM-set test plug,rig up to test& 0.0 0.0 11:30 13:00 perform shell test. Page 17/58 Report Printed: 10/31/2016 tz 0 Iterations Summary (with Timelog!epths) 2S-09 c€�nocoMibps Rig: DOYON 142 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) 9/26/2016 9/26/2016 5.00 INTRM1 WHDBOP BOPE P Test witness waived by AOGCC Rep. 0.0 0.0 13:00 18:00 Chuck Scheve.Tested with 3-1/2"&4- 1/2"test joints.250/3500 psi,charted for 5 minutes each. Test#1 with 3 1/2"test joint,testing Annular,CV#1,#12,#13,#14 and 4" kill line valve on mud manifold,XT-39 Dart valve. Test#2-Top Pipe rams,CV#9,#11, mezzanine kill valve,and XT-39 FOSV Test#3-CV#5,#8,#10, HCR Kill, and upper IBOP. Test#4-CV#4,#6,#7,and lower IBOP. Test#5-CV#2 Test#6-Lower Pipe rams Test#7-Blind rams,CV#3 Installed 4 1/2"test joint. Test#8-Annular,HCR Choke. Test#9-Super Choke to 1500 PSI. Test#10-Manual operated choke to 1500 PSI. Test#11 -Top Pipe rams,Manual choke Test#12-Lower Pipe rams Perform Koomey draw down test. Observed initial system pressure at ACC-3050 PSI,MAN-1500 PSI,and annular-1000 PSI.After Closure observed ACC-1775 PSI,200 PSI increase in 9 seconds,and full pressures at 52 seconds. Observed 6 nitrogen bottles with an average PSI of 2433 PSI. Performed CPAI drawdown test. Tested pit level sensors&flow out alarms.Gas detection alarms tested w/low&high level. 9/26/2016 9/26/2016 1.00 INTRM1 WHDBOP RURD P PJSM-blow down&rig down test 0.0 0.0 18:00 19:00 equipment.Set wear bushing w/10" ID&RILDS.SIMOPS confirm 4"DP count in the shed. 9/26/2016 9/26/2016 3.00 INTRM1 CEMENT BHAH P PJSM-make up production 6-3/4"X7- 0.0 419.0 19:00 22:00 1/2"BHA 4 f/0-419'MD as per SLB DD. 9/26/2016 9/27/2016 2.00 INTRM1 CEMENT PULD P PJSM-single in the hole w/BHA 4 f/ 419.0 2,310.0 22:00 00:00 416'-2310'MD,PU 70K,SO 74K. Kick w/Tripping CRT 148 sec @ 23:00 hrs. OA 450 psi at 24:00 hrs. 9/27/2016 9/27/2016 0.50 INTRMI CEMENT DHEQ P Shallow hole test MWD at 214 gpm, 2,310.0 2,310.0 00:00 00:30 1100 psi,FO 11%.B/D topdrive. 9/27/2016 9/27/2016 1.75 INTRM1 CEMENT PULD P Continue to single in the hole on 4"DP 2,310.0 4,175.0 00:30 02:15 f/2310'-4175'MD,monitoring displacement on pit 1, 9/27/2016 9/27/2016 0.50 INTRMI CEMENT CIRC P Fill pipe and cycle on sonicscope, 4,175.0 4,175.0 02:15 02:45 PUW 126k,SOW 97k.B/D topdrive. Page 18/58 Report Printed: 10/31/2016 • • 4 , Operations Summary (with Timelog Depths) — ," 2S-09 i ConocoPhi111!ps Rig: DOYON 142 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). 9/27/2016 9/27/2016 0.25 INTRM1 CEMENT PULD P Continue to single in the hole on 4"DP 4,175.0 4,585.0 02:45 03:00 f/4175'-4585'MD,monitoring displacement on pit 1. Note:Logged section f/4210'-4305' MD with sonicscope at 800 ft/hr. 9/27/2016 9/27/2016 1.25 INTRM1 CEMENT QEVL P Run in hole on 4"DP stands from 4,585.0 5,342.0 03:00 04:15 derrick f/4585'-5342'MD'at 800 ft/hr for logging cement.PUW 145k,SOW 105k. 9/27/2016 9/27/2016 0.50 INTRM1 CEMENT COCF P Wash and ream down f/5342'and tag 5,342.0 5,389.0 04:15 04:45 hard cement at 5389'MD w/200 gpm, 1325 psi, 10%F/O,40rpm,ROT 121k w/6k TQ. 9/27/2016 9/27/2016 2.25 INTRM1 CEMENT DRLG P Drill stage collar f/5389'-5404'MD, 5,389.0 5,404.0 04:45 07:00 201 gpm, 1460 psi,40-60 rpm,Tq 6K, WOB 2-12K. Ream section 4X to ensure clear. 9/27/2016 9/27/2016 2.50 INTRM1 CEMENT QEVL P Run in hole on 4"DP stands from 5,404.0 7,053.0 07:00 09:30 derrick f/5404'-7053'MD'at 800 ft/hr for logging cement.PUW 187k,SOW 109k. 9/27/2016 9/27/2016 1.50 INTRM1 CEMENT CIRC P Circulate&condition LSND mud at 7,053.0 7,053.0 09:30 11:00 250 gpm,2000 psi,FO 10%,80 rpm, Tq 8K.Observe 10.0ppg MW in/out after 3810 strokes. 9/27/2016 9/27/2016 0.25 INTRM1 CEMENT RURD P Rig up to pressure test intermediate 7,053.0 7,053.0 11:00 11:15 casing. 9/27/2016 9/27/2016 1.25 INTRM1 CEMENT PRTS P Pressure test 7-5/8",29.7#, 7,053.0 7,053.0 11:15 12:30 intermediate casing to 3500 psi for 30 minutes,charted.Pumped 4.0 bbls and bled back 4.0 bbls. 9/27/2016 9/27/2016 0.50 INTRM1 CEMENT SVRG P Service top drive and adjust energy 7,053.0 7,053.0 12:30 13:00 track cable. 9/27/2016 9/27/2016 0.75 INTRM1 CEMENT COCF P Wash and ream down f/7053'-7091 w/ 7,053.0 7,091.0 13:00 13:45 250 gpm,2055 psi,9%F/O,60rpm, 9.5k TQ,ROT 134k. 9/27/2016 9/27/2016 0.25 INTRM1 CEMENT COCF P Drill cement f/7091'-7120'MD w/250 7,091.0 7,120.0 13:45 14:00 gpm, 1950 psi,9%F/O,40-80 rpm,9- 12k TQ. 9/27/2016 9/27/2016 1.25 INTRM1 CEMENT DRLG P Drill plug and baffle collar f/7120'- 7,120.0 7,125.0 14:00 15:15 7125'MD w/250 gpm,2080 psi,9% F/O,40-80 rpm, 10k TQ,5-10k WOB. 9/27/2016 9/27/2016 1.50 INTRM1 CEMENT DRLG P Drill cement f/7091'-7120'MD w/250 7,125.0 7,159.0 15:15 16:45 gpm,2080 psi,9%F/O 40-80 rpm, 10k TQ,5-10k WOB. 9/27/2016 9/27/2016 3.25 INTRM1 CEMENT DRLG P Drill plug and float collar f/7159'-7165' 7,159.0 7,165.0 16:45 20:00 MD w/205 gpm, 1390 psi,7%F/O,60 -80 rpm,9-10k TQ,5-18k WOB. 9/27/2016 9/27/2016 0.75 INTRM1 CEMENT DRLG P Drill cement f/7165'-7243'MD w/205 7,165.0 7,243.0 20:00 20:45 gpm, 1390 psi,7%F/O 60-80 rpm,9- 10k TQ,5-18k WOB.Tag top of shoe @ 7243'MD. Page 19/58 Report Printed: 10/31/2016 ;,...,..., ,,,,:,.. .,.-',' i T,.., • 0 8 Operations Summary (with Timelog Depths) 2S-09 ConocoPhitlaps Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftK6) End Depth(ftKS). 9/27/2016 9/27/2016 0.75 INTRM1 CEMENT DRLG P Drill float shoe and rathole f/7243'- 7,243.0 7,257.0 20:45 21:30 7257'MD w/203 gpm, 1425 psi,9% F/0,80 rpm,8-10k TQ, 1-5k WOB, PUW 187k,SOW 104k, ROT 133k w/ 8k TQ.Ream shoe 3 x times to ensure clear. SPR's at 7243'MD,6254'TVD,MW 10.0 ppg,20:55 hrs. #1 @ 20=420,@ 30=650 psi #2@20=410,@ 30=620 psi 9/27/2016 9/27/2016 2.25 INTRM1 CEMENT DDRL P Drill 20'of new formation f/7257'- 7,257.0 7,277.0 21:30 23:45 7277'MD,6280'TVD,w/238 gpm, 1940 psi,8%F/O,80 rpm,8.5k TQ, 16-18k WOB,ECD 10.62ppg,Off bottom SPP 1930 psi,PUW 190k, SOW 105k,ROT 135k w/9k TQ,MW 10.0ppg,Gas 38 units,ADT 1.24, Bit 1.24,Jar 65.66. Note-Observed well pack off at 7260' MD.Necessary WOB to drill ahead thereafter increased from 11 k to 18k and pump pressure increased 120 psi. 9/27/2016 9/28/2016 0.25 INTRM1 CEMENT CIRC P Obtain survey and commence 7,277.0 7,207.0 23:45 00:00 circulating to obtain even mud weight for FIT w/240 gpm, 1980 psi,9%F/O, 80 rpm,9k TQ. OA pressure=680 psi 9/28/2016 9/28/2016 0.50 INTRM1 CEMENT CIRC P Continue circulating to obtain even 7,207.0 7,207.0 00:00 00:30 mud weight for FIT w/243 gpm, 1940 psi,9%F/O,80 rpm,9k TQ for total of 2579 strokes,9.95ppg MW in/out. 9/28/2016 9/28/2016 0.50 INTRM1 CEMENT RURD P Rack back stand, Blow down top 7,207.0 7,207.0 00:30 01:00 drive,and rig up test equipment for FIT test. Monitor well-static. 9/28/2016 9/28/2016 0.25 INTRM1 CEMENT FIT P Perform FIT to an EMW of 13.0ppg at 7,207.0 7,207.0 01:00 01:15 7277'MD,6274'TVD,with a 9.95ppg MW.Pressured up to 993psi w/1.1 bbls,shut in&observe pressure decrease 920 psi over 10 minutes. Bled back 1.0 bbls. 9/28/2016 9/28/2016 0.50 PROD1 DRILL SVRG P Service top drive. 7,207.0 7,207.0 01:15 01:45 9/28/2016 9/28/2016 1.25 PROD1 DRILL DISP P Displace well from LSND to FloPro 7,277.0 7,207.0 01:45 03:00 mud system.Pump 30 bbls Hi-Vis pill followed by 318 bbls of 10.0 ppg FloPro @ 214 gpm, 1470 psi,FO 8%, reciprocating and rotating pipe at 60 rpm,Tq 7.5K. SPR's at 7277'MD,6274'TVD,MW 10.0 ppg,02:53 hrs. #1 @ 20=350,@ 30=570 psi #2 @ 20=350,@ 30=570 psi Note: Initial concentration of Encapso lubricant at 1.75% 9/28/2016 9/28/2016 0.25 PROD1 DRILL OWFF P Blow down topdrive and monitor well 7,207.0 7,207.0 03:00 03:15 for flow-static. Page 20/58 Report Printed: 10/31/2016 i Operations Summary (with Timelog!epths) 2S-09 cane itlips �1sska Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-Xi (ftKB) End Depth(AKE) 9/28/2016 9/28/2016 0.75 PROD1 DRILL MPDA P Pull MPD trip nipple and install MPD 7,207.0 7,207.0 03:15 04:00 bearing/drain nipple. 9/28/2016 9/28/2016 0.50 PROD1 DRILL MPDA P Establish circulation,calibrate MPD 7,207.0 7,277.0 04:00 04:30 system,and wash down to bottom w/ 209 gpm, 1440 psi, 11%F/O,50 rpm, 7k TQ. 9/28/2016 9/28/2016 1.50 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 7,277.0 7,307.0 04:30 06:00 7277'-7307'MD,6289'TVD,w/259 gpm, 1985 psi, 11%F/O,70 rpm,Tq on 7.5K,off 7K,4-18K WOB,ECD 10.70ppg,Off Btm SPP 1975 psi, PUW 171K,SOW 116K,ROT 137K, MW 10.0 ppg,Gas 22 units,ADT 1.31,Bit 2.55,Jar 66.97.Footage 30' MD.Hold 312 psi MPD backpressure on connections. 9/28/2016 9/28/2016 3.00 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 7,307.0 7,410.0 06:00 09:00 7307'-7410'MD,6318'TVD,w/259 gpm, 1985 psi, 10%F/O, 100 rpm,Tq on 7.5K,off 7K,21K WOB,ECD 10.75 ppg,Off Btm SPP 1975 psi,PUW 171K,SOW 116K,ROT 137K,MW 10.0 ppg,Gas 1546 units,ADT 2.31, Bit 4.86,Jar 69.28.Footage 103'MD. Hold 312 psi MPD backpressure on connections. 9/28/2016 9/28/2016 1.00 PROD1 DRILL CIRC P Pump down 6 x RFID chips for 7,410.0 7,410.0 09:00 10:00 opening underreamer as per WFT w/ 258 gpm, 1958 psi,20 rpm,6k Tq. Pull to 7392'MD bit depth to test if reamer blocks open at casing shoe but see no over pull.Pump down additional 6 x RFID chips w/258 gpm, 1958 psi,20 rpm,6K Tq. Pull to 7390' MD bit depth and observe 7K overpull into shoe,confirming reamer blocks are open. Note: Underreamer nozzles are blanked off and flow tube mandrel removed from tool as lesson learned from 2S-12 washout 9/28/2016 9/28/2016 2.00 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 7,410.0 7,501.0 10:00 12:00 7410'-7501'MD,6335'TVD,w/260 gpm,2030 psi, 10%F/O, 110 rpm,Tq on 7.5-10K,off 7K,22K WOB,ECD 10.83 ppg,Off Btm SPP 2010 psi, PUW 161K,SOW 114K,ROT 127K, MW 10.0 ppg,Gas 250 units,ADT 1.48,Bit 6.34,Jar 70.76. Footage 91' MD.Hold 312 psi MPD backpressure on connections. Page 21/58 Report Printed: 10/31/2016 • Operations Summary (with Timelo !e the 9 p ) 2S-09 ConocoPhillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Our(hr) PhaseStart Depth Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(itK13) 9/28/2016 9/28/2016 4.25 PROD1 DRILL DDRL P DDriII 6-3/4"production section f/ 7,501.0 7,644.0 12:00 16:15 7501'-7644'MD,6348'TVD,w/262 gpm,2040 psi, 10%F/O, 110 rpm,Tq on 8.5-10K,off 8K, 14K WOB, ECD 10.89 ppg,Off Btm SPP 2010 psi, PUW 175K,SOW 106K, ROT 128K, MW 10.0 ppg,Gas 550 units,ADT 3.55, Bit 9.89,Jar 74.31.Footage 143' MD.Hold 312 psi MPD backpressure on connections. Note:7-1/2"hole TD at 7495.5'MD (reamer blocks 148.5'behind bit) Top of Kuparuk C observed at 7443' Top of A5 observed at 7468' Top of A4 observed at 7504',—50' TVD higher than expected Note:At 7613',start increasing Encapso lubricant concentration from 1.75%to 2.25%to help mitigate high stick-slip. 9/28/2016 9/28/2016 0.75 PROD1 DRILL CIRC P Pump down 6 x RFID chips to close 7,644.0 7,591.0 16:15 17:00 underreamer as per WFT.Obtain SPR's and CBU w/250 gpm, 1820 psi, 10%F/O, 110 rpm,7-9k TQ,Pumped 2400 total strokes,MW in/out 10.0 ppg. SPR's at 7616'MD,6348'TVD,MW 10.0 ppg, 16:30 hrs. #1 @ 20=400,©30=625 psi #2 @ 20=400,@ 30=620 psi 9/28/2016 9/28/2016 0.75 PROD1 DRILL SMPD P Strip out of hole f/7591'-7230', 7,591.0 7,230.0 17:00 17:45 holding 420 psi MPD backpressure out of slips and 312 psi in slips, PUW 170k,SOW 107k. 9/28/2016 9/28/2016 0.25 PROD1 DRILL CIRC P Establish circulation and perform slack 7,230.0 7,230.0 17:45 18:00 off test w/230 gpm, 1640 psi, 10% F/O, PUW 168K,SOW 109K-confirm reamer blocks are closed. 9/28/2016 9/28/2016 1.00 PROD1 DRILL SMPD P Strip in hole f/7230'-7644'w/290 psi 7,230.0 7,644.0 18:00 19:00 MPD back pressure,PUW 172K, SOW 101K. 9/28/2016 9/29/2016 5.00 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 7,644.0 8,090.0 19:00 00:00 7644'-8090'MD,6346'TVD,w/262 gpm,2160 psi, 11%F/O, 180 rpm,Tq on 9-11K,off 8K,21K WOB, ECD 11.25 ppg,Off Btm SPP 2140 psi, PUW 172K,SOW 98K,ROT 126K, MW 10.0 ppg,Gas 69 units,ADT 3.83,Bit 13.72,Jar 78.14. Footage 446'MD. Hold 312 psi MPD backpressure on connections. OA pressure=725 psi Page 22/58 Report Printed: 10/31/2016 rt0 Operations Summary (with Timelo ! the ) 2S-09 Cona iiiiips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time'. End Time Our(hr)', Phase Op Code Activity Code Time P-T-X Operation (EKB) End Depth(ftKB)', 9/29/2016 9/29/2016 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 8,090.0 8,740.0 00:00 06:00 8090'-8740'MD,6325'TVD,w/264 gpm,2176 psi, 11%F/O, 180 rpm,Tq on 10-13K,off 9K,20K WOB,ECD 11.23 ppg,Off Btm SPP 2170 psi, PUW 165K,SOW 95K,ROT 125K, MW 10.0 ppg,Gas 528 units,ADT 3.97, Bit 17.69,Jar 82.11.Footage i 650'MD.Hold 312 psi MPD backpressure on connections. SPR's at 8184'MD,6345'TVD,MW 10.15 ppg,00:40 hrs. #1 @20=510,@30=720psi #2 @ 20=510,@ 30=740 psi 9/29/2016 9/29/2016 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 8,740.0 9,300.0 06:00 12:00 8740'-9300'MD,6333'TVD,w/264 gpm,2260 psi, 11%F/O, 160-180 rpm,Tq on 10-12K,off 9K,20K WOB, ECD 11.18 ppg,Off Btm SPP 2250 psi,PUW 169K,SOW 96K,ROT 128K,MW 10.0 ppg,Gas 534 units, ADT 3.59, Bit 21.28,Jar 85.70. Footage 560'MD. Hold 312 psi MPD backpressure on connections. SPR's at 8754'MD,6325'TVD,MW 10.0 ppg,06:12 hrs. #1 @ 20=520,@ 30=720 psi #2 @ 20=520,@ 30=720 psi 9/29/2016 9/29/2016 1.25 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 9,300.0 9,417.0 12:00 13:15 9300'-9417'MD,6337'TVD,w/264 gpm,2265 psi, 10%F/O, 180 rpm,Tq on 13K,off 9.5K,21K WOB,ECD 11.12 ppg,Off Btm SPP 2245 psi, PUW 176K,SOW 95K,ROT 127K, MW 10.0 ppg,Gas 155 units,ADT 0.99,Bit 22.27,Jar 86.69. Footage 117'MD.Hold 312 psi MPD backpressure on connections. 9/29/2016 9/29/2016 2.00 PROD1 DRILL MPDA T Troubleshoot MPD choke#2, 9,417.0 9,417.0 13:15 15:15 circulating/reciprocating pipe w/279 gpm,2440 psi, 11%F/O, 140 rpm,9- 10k TQ,ECD 10.96 ppg.Replace shear pin and change out gate on choke#2 and put back into service. 9/29/2016 9/29/2016 2.75 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 9,417.0 9,694.0 15:15 18:00 9417'-9694'MD,6327'TVD,w/262 gpm,2290 psi, 10%F/O, 180 rpm,Tq on 12-13K,off 9.5K,20K WOB,ECD 11.30 ppg,Off Btm SPP 2280 psi, PUW 173K,SOW 93K, ROT 126K, MW 10.0 ppg,Gas 464 units,ADT 1.83, Bit 24.10,Jar 88.52.Footage 277'MD. Hold 312 psi MPD backpressure on connections. SPR's at 9510'MD,6324'TVD,MW 10.0 ppg, 16:10 hrs. #1 @ 20=560,@ 30=800 psi #2 @ 20=570,@ 30=790 psi Page 23/58 Report Printed: 10/31/2016 !perations Summary (with Timelo !epths 2S-09 C hifiips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr). Phase Op Code Activity Code Time P-T-X Operation (ftKS) End Depth(ftKS) 9/29/2016 9/30/2016 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 9,694.0 10,330.0 18:00 00:00 9694'-10330'MD,6333'TVD,w/264 gpm,2370 psi, 12%F/O, 180 rpm,Tq on 13.5K,off 10.5K, 18K WOB,ECD 11.37 ppg,Off Btm SPP 2375 psi, PUW 185K,SOW 90K,ROT 131K, MW 10.0 ppg,Gas 211 units,ADT 4.10, Bit 28.20,Jar 92.62.Footage 636'MD.Hold 312 psi MPD backpressure on connections. SPR's at 10175'MD,6336'TVD,MW 10.0 ppg,22:30 hrs. #1 @ 20=545,@ 30=790 psi #2 @ 20=540,@ 30=805 psi OA pressure=680 psi 9/30/2016 9/30/2016 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 10,330.0 10,934.0 00:00 06:00 10330'-10934'MD,6317'TVD,w/ 262 gpm,2370 psi, 12%F/O, 160 rpm,Tq on 14K,off 11K, 18K WOB, ECD 11.28 ppg,Off Btm SPP 2360 psi,PUW 193K,SOW 87K,ROT 126K,MW 10.0 ppg,Gas 33 units, ADT 4.05, Bit 32.25,Jar 89.75. Footage 604'MD.Hold 312 psi MPD backpressure on connections. SPR's at 10744'MD,6326'TVD, MW 10.0 ppg,03:30 hrs. #1 @ 20=520,@ 30=760 psi #2 @ 20=520,@ 30=760 psi 9/30/2016 9/30/2016 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 10,934.0 11,410.0 06:00 12:00 10934'-11410'MD,6302'TVD,w/ 260 gpm,2420 psi, 10%F/O, 140 rpm,Tq on 14K,off 11K, 15K WOB, ECD 11.16 ppg,Off Btm SPP 2420 psi, PUW 193K,SOW 88K,ROT 126K,MW 10.0 ppg,Gas 420 units, ADT 3.90,Bit 36.15,Jar 100.57. Footage 476'MD.Hold 312 psi MPD backpressure on connections. SPR's at 11399'MD,6302'TVD,MW 10.0 ppg, 11:40 hrs. #1 @ 20=480,@ 30=730 psi #2 @ 20=480,@ 30=830 psi 9/30/2016 9/30/2016 2.00 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 11,410.0 11,584.0 12:00 14:00 11410-11584'MD,6302'TVD,w/ 262 gpm,2550 psi, 11%F/O, 135 rpm,Tq on 14K,off 11K, 17K WOB, ECD 11.24 ppg,Off Btm SPP 2540 psi,PUW 195K,SOW 96K,ROT 128K,MW 10.0 ppg,Gas 166 units, ADT 1.36,Bit 37.51,Jar 101.93. Footage 174'MD. Hold 312 psi MPD backpressure on connections. Note:Observe failure on Periscope LWD @ 11,357'-continue to drill and discuss path forward with town. Page 24/58 Report Printed: 10/31/2016 ki Operations Summary (with TimelogDepths) p the ) 00 2S-09 Conocillips Rig: DOYON 142 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)' 9/30/2016 9/30/2016 0.25 PROD1 DRILL CIRC T Decision made to pull out of hole and 11,584.0 11,584.0 14:00 14:15 change out BHA due to failed Periscope LWD.Obtain slow pump rates,downlink to turn off tools,and pump up survey. SPRs at 11486'MD,6302'TVD,MW 10.0 ppg, 14:10 hrs. #1 @20=510,@30=775psi #2 @20=510,@30=765 psi 9/30/2016 9/30/2016 0.75 PROD1 DRILL OWFF T Perform MPD drawdown to determine 11,584.0 11,584.0 14:15 15:00 pore pressure of formation.Trap 308 psi,line up to trip tank,and reduce backpressure in steps until pressure was completely bled off.Observed well static at 10.0 ppg MW with no backpressure @ 6302'TVD,total of 0.5 bbls bled back. 9/30/2016 10/1/2016 9.00 PROD1 DRILL BKRM T Backream OOH f/11584'-8094'MD, 11,584.0 8,094.0 15:00 00:00 264 gpm,2135 psi, 140 rpm,Tq 8- 10K,ROT 128k,ECD 10.98 ppg. Target pulling speed 1000 ft/hr.Hold 312 psi MPD backpressure on connections. OA pressure=100 psi 10/1/2016 10/1/2016 2.00 PROD1 DRILL BKRM T Backream OOH f/8094'-7716'MD, 8,094.0 7,716.0 00:00 02:00 260 gpm,2060 psi, 140 rpm,Tq 8- 10K, ROT 127k,PUW 172k,SOW 105k,ECD 10.95 ppg.Target pulling speed 1000 ft/hr.Hold 312 psi MPD backpressure on connections.Slow pulling speed to 150 ft/hr for last stand to circulate 1 x bottoms up prior to pulling through shales. 10/1/2016 10/1/2016 1.00 PROD1 DRILL SMPD T Strip BHA through Kalubik shales into 7,716.0 7,247.0 02:00 03:00 cased hole f/7716'-7247',holding MPD backpressure at 420 psi out of slips and 312 psi in slips.Observed one tight spot at 7288'w/36k overpull but otherwise pulled very smoothly. PUW 172k,SOW 103k. 10/1/2016 10/1/2016 1.50 PROD1 DRILL CIRC T Circulate 1.5 x bottoms up w/214 7,247.0 7,247.0 03:00 04:30 gpm, 1506 psi, 12%F/O,60 rpm,8K Tq, 10.85 ppg ECD,while preparing pits for displacement to brine. Dilute 11.8 ppg NaBr from upright tanks w/ freshwater and NaCI to obtain 11.0 ppg. 10/1/2016 10/1/2016 1.00 PROD1 DRILL SMPD T Pump OOH f/7247'-6747'MD laying 7,247.0 6,747.0 04:30 05:30 in 55 bbls hi-vis 11.0 ppg NaBr spacer for 5 x stands w/2 bpm,420 psi, holding 312 psi MPD backpressure on connections and 200 psi when spotting spacer.Chase spacer to bit w/11.0 ppg NaBr brine. Page 25/58 Report Printed: 10/31/2016 ,,,,, , , ,.., • • Operations Summary (with Timelog Depths) 2S-09 CcsnocxyPhilliips. Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(EKE) 10/1/2016 10/1/2016 1.25 PROD1 DRILL DISP T Displace cased hole from 10.0 ppg 6,747.0 6,747.0 05:30 06:45 FloPro to 11.0 ppg NaBr brine w/213 gpm, 1300 psi,60 rpm,7.5k TQ,ECD 11.4 ppg,decreasing MPD backpressure as per stepdown schedule from rig engineer. 10/1/2016 10/1/2016 0.25 PROD1 DRILL OWFF T Monitor well-static. 6,747.0 6,747.0 06:45 07:00 10/1/2016 10/1/2016 4.00 PROD1 DRILL SMPD T Strip OOH to top of HWDP f/6747'- 6,747.0 420.0 07:00 11:00 420',holding 150 psi MPD backpressure. 10/1/2016 10/1/2016 0.25 PROD1 DRILL OWFF T Monitor well at top of BHA-static 420.0 420.0 11:00 11:15 10/1/2016 10/1/2016 1.25 PROD1 DRILL MPDA T Pull MPD bearing and drain nipple and 420.0 420.0 11:15 12:30 install trip nipple. 10/1/2016 10/1/2016 2.50 PROD1 DRILL BHAH T Pull OOH f/420' to surface,racking 420.0 0.0 12:30 15:00 back 4"HWDP and jar and laying out BHA.Both plunger and flapper floats looked ok with small amount of debris around springs,but were both still functional. Underreamer grade: 1-1- CT-D-X-0-RR-DTF.Bit grade:4-4-BT- A-X-0-CT-DTF.Observed 1 small chipped tooth on the second cutter block of underreamer and a few metal shavings lodged between the body and cutter block.Observed 8 x broken teeth on the bit. Calculated displacement for trip=63 bbls Actual hole fill= 141 bbls 10/1/2016 10/1/2016 1.25 PROD1 DRILL CLEN T Clean and clear rig floor. 0.0 0.0 15:00 16:15 10/1/2016 10/1/2016 2.75 PROD1 DRILL BHAH T Pick up BHA#5 as per SLB and RIH 0.0 367.0 16:15 19:00 to 367'. 10/1/2016 10/1/2016 3.75 PROD1 DRILL TRIP T Run in hole on elevators w/4"DP 367.0 5,100.0 19:00 22:45 stands from derrick f/367'-5100', monitoring displacement on pit 1. 10/1/2016 10/1/2016 0.50 PROD1 DRILL SVRG T Adjust top drive rail and torque tube. 5,100.0 5,100.0 22:45 23:15 10/1/2016 10/2/2016 0.75 PROD1 DRILL SVRG T Blow down top drive and change out 5,100.0 5,100.0 23:15 00:00 washpipe. 10/2/2016 10/2/2016 1.00 PROD1 DRILL SVRG T Observe new washpipe leaking under 5,100.0 5,100.0 00:00 01:00 hydrostatic pressure. Re-tighten and test to 3500 psi-good test. 10/2/2016 10/2/2016 1.50 PROD1 DRILL TRIP T Run in hole on elevators w/4"DP 5,100.0 7,182.0 01:00 02:30 stands from derrick f/5100'-7182', monitoring displacement on pit 1. 10/2/2016 10/2/2016 1.00 PROD1 DRILL MPDA T Pull trip nipple and install new MPD 7,182.0 7,182.0 02:30 03:30 bearing and drain nipple. 10/2/2016 10/2/2016 2.00 PROD1 DRILL DISP T Displace well from 11.0 ppg NaBr 7,182.0 7,182.0 03:30 05:30 brine to 10.0 ppg FloPro WBM.Pump 26 bbls hi-vis brine spacer and chase with 321 bbls 10.0 ppg FloPro w/216 gpm, 1430 psi, 10%F/O, 11.0 ppg ECD,50 rpm,7.5K Tq, Page 26/58 Report Printed: 10/31/2016 ,..:i.:% • • KA Operations Summary (with Timelog Depths) 2S-09 Con Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKS)', 10/2/2016 10/2/2016 0.25 PROD1 DRILL SMPD T Strip in hole f/7182'-7345',holding 7,182.0 7,345.0 05:30 05:45 MPD backpressure of 105 psi out of slips and 312 psi in slips.PUW 172K, SOW 106K. 10/2/2016 10/2/2016 1.50 PROD1 DRILL SMPD T Work tight hole at 7345',holding 312 7,345.0 7,187.0 05:45 07:15 psi MPD backpressure.Stage up pumps to 2 bpm,640 psi and attempt to wash down through tight hole. Stage up rotary to 20 rpm,8-10 K Tq. Observe hole pack off.Work pipe free and pull up inside casing to 7187'. 10/2/2016 10/2/2016 0.75 PROD1 DRILL CIRC T Circulate bottoms up inside cased 7,187.0 7,247.0 07:15 08:00 hole w/218 gpm, 1445 psi, 12%F/O, 10/2/2016 10/2/2016 3.00 PROD1 DRILL REAM T Ream down w/4 bpm,903 psi, 10% 7,247.0 7,247.0 08:00 11:00 F/O,20 rpm,6-7K Tq, 116 psi MPD backpressure f/7247'-7277'and observe hole pack off.Work pipe free and pull up into casing shoe.Stage up pumps to 3 bpm,690 psi,20 rpm,7k TQ, 140psi MPD backpressure.Ream down to 7257'and observe hole pack off.Jar pipe free and pull up into casing shoe. 10/2/2016 10/2/2016 0.50 PROD1 DRILL CIRC T Stage up pumps to 260 gpm, 1860 7,247.0 7,247.0 11:00 11:30 psi, 12%F/O,20 rpm,7.5k Tq and confirm good circulation. 10/2/2016 10/2/2016 4.75 PROD1 DRILL REAM T Ream section f/7247'-7343'w/2-3 7,247.0 7,247.0 11:30 16:15 bpm,600-760 psi,20 rpm,7.5k Tq, adjusting MPD back pressure as per ramp schedule.Observe erratic torque and pack off tendencies between 7340'-7343'.Observe hole pack off at 7343'and work pipe free.Pull up and observe hole pack off again at 7282'. Work pipe free and pull up into casing shoe. ' 10/2/2016 10/2/2016 1.00PROD1 DRILL CIRC T Circulate 1.5 bottoms up w/241 gpm, 7,247.0 7,247.0 16:15 17:15 2290 psi, 10%F/O,40-60 rpm,9K Tq, observing abrupt pressure drop to 1890 psi after pumping 3000 strokes. PUW 174k,SOW 106k. 10/2/2016 10/2/2016 3.25 PROD1 DRILL REAM T Ream section f/7247'-7344'w/2 7,247.0 7,247.0 17:15 20:30 bpm,750 psi, 12%F/O,20 rpm,7.5k Tq,210 psi MPD backpressure, varying WOB from 10-22k.Work pipe back up inside casing 10/2/2016 10/2/2016 1.50 PROD1 DRILL CIRC T Circulate 1.5 bottoms up w/220-250 7,247.0 7,247.0 20:30 22:00 gpm, 1945-2425 psi, 12%F/O,80 rpm,7.5k Tq. 10/2/2016 10/2/2016 0.25 PROD1 DRILL SMPD T Strip in hole f/7247'-7343'w/MPD 7,247.0 7,343.0 22:00 22:15 backpressure of 150 psi out of slips and 312 psi in slips.Slack off to block weight at 7343'with no success. 10/2/2016 10/2/2016 1.25 PROD1 DRILL REAM T Ream down f/7343'-7347'w/2-3 7,343.0' 7,347.0 22:15 23:30 bpm,640-838 psi, 11%F/O,20-40 rpm,7-8k Tq, 10-24k WOB.Observe hole pack off at 7347'. Page 27/58 Report Printed: 10/31/2016 t°,1:14, Operations Summary (with Timelog!epths) ;' ; ,'' 2S-09 c nocoPhitlips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftK€S) End Depth(ftKE)I 10/2/2016 10/3/2016 0.50 PROD1 DRILL REAM T Work pipe free w/50-80k overpull and 7,347.0 7,247.0 23:30 00:00 pull back up into casing shoe.PUW 172k,SOW 106k. OA pressure=260 psi 10/3/2016 10/3/2016 1.25 PROD1 DRILL REAM T Stage up pumps and circulate bottoms 7,247.0 7,247.0 00:00 01:15 up inside casing w/212 gpm/1800 psi,80 rpm,7K Tq,ROT 127K,PUW 175K,SOW 105K. 10/3/2016 10/3/2016 1.00 PROD1 DRILL REAM T Ream down f/7247'-7288'w/2.5 7,247.0 7,247.0 01:15 02:15 bpm,740 psi,20 rpm,8K Tq, 180 ft/hr target speed.Observe hole pack off at 7288'.Work pipe free and pull up into casing shoe. 10/3/2016 10/3/2016 2.00 PROD1 DRILL REAM T Stage up pumps to 2.5 bpm,740 psi, 7,247.0 7,312.0 02:15 04:15 20 rpm,8K Tq and ream down f/7247' -7342'.Observe hole pack off at 7342'.Work pipe free and pull up to 7312'. 10/3/2016 10/3/2016 5.00 PROD1 DRILL REAM T Ream down w/2 bpm,680 psi,20 7,312.0 7,372.0 04:15 09:15 rpm,8K Tq,5-15K WOB f/7312'- 7352'.Stage up pumps to 200 gpm, 1400 psi and pump up survey- confirmed that we are still in original hole w/73.9° INC at 7352'.Continue reamingdown f /7352'-7372'w/same parameters.At 7372',attempt to stage up high enough to pump up another survey and packed off at 140 gpm. 10/3/2016 10/3/2016 0.75 PROD1 DRILL REAM T Work pipe free up to 7334'and 7,372.0 7,334.0 09:15 10:00 attempt to stage p g up pumps.Observe another pack off at 7334'.Work pipe free and stage up to 2 bpm. 10/3/2016 10/3/2016 4.50 PROD1 DRILL REAM T Ream down w/2bpm,680 psi,20 rpm, 7,334.0 7,657.0 10:00 14:30 8.5K Tq,2-7K WOB f/7334'-7657'. 10/3/2016 10/3/2016 1.75 PROD1 DRILL SMPD T Strip in hole f/7657'-9550'holding 7,657.0 9,550.0 14:30 16:15 MPD backpressure of 105 psi out of slips and 312 psi in slips. 10/3/2016 10/3/2016 3.00 PROD1 DRILL CIRC T Stage up pumps to 2.5 bpm, observe 9,550.0 9,550.0 16:15 19:15 hole pack off at 9550'.Work pipe free. Stage up pumps and rotary to 262 gpm/2227 psi,30 rpm,and 10K Tq, 11.29ppg ECD,and observe hole pack off.Work pipe free. 10/3/2016 10/3/2016 1.75 PROD1 DRILL CIRC T Stage up pumps and rotary to 212 9,550.0 9,550.0 19:15 21:00 gpm, 1595 psi,90 rpm, 10K Tq, 11.35ppg ECD and observe hole pack off.Work pipe free. 10/3/2016 10/3/2016 1.00 PROD1 DRILL CIRC T Stage up pumps and rotary to 261 9,550.0 9,550.0 21:00 22:00 gpm,2142 psi, 100 rpm, 10K Tq, 11.35ppg ECD and observe hole pack off.Work pipe free. 10/3/2016 10/4/2016 2.00 PROD1 DRILL CIRC T Stage up pumps and rotary to 261 9,550.0 9,550.0 22:00 00:00 gpm,2117 psi, 140 rpm,9K Tq, 11.35ppg ECD.Sustain drilling rate for 2 minutes and then observe hole pack off.Work pipe free.PUW 195k,SOW 90k. OA pressure=580 psi Page 28/58 Report Printed: 10/31/2016 Operations Summary (with TimelogDepths) 2S-09 conoccett imps - Rig: DOYON 142 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) 10/4/2016 10/4/2016 2.50 PROD1 DRILL REAM T Run in hole one stand deeper to 9645' 9,550.0 9,645.0 00:00 02:30 and wipe section.Stage up pumps and rotary to 2 bpm,763 psi, 10 rpm, and observe hole packoff.Work pipe free.Stage up pumps to 3.3 bpm,974 psi and observe hole pack off.Work pipe free and wipe section. 10/4/2016 10/4/2016 1.25 PROD1 DRILL SMPD T Strip in hole f/9645'-10500'w/MPD 9,645.0 10,500.0 02:30 03:45 backpressure of 160 psi out of slips and 312 psi in slips. 10/4/2016 10/4/2016 4.75 PROD1 DRILL REAM T Wipe section f/10500'-10590'and 10,500.0 10,590.0 03:45 08:30 stage up pumps to 2 bpm,816 psi. Observe hole packoff.Work pipe free and stage up to 2 bpm,800 psi, 18 rpm, 10K Tq.Observe hole packoff. Work pipe free 10/4/2016 10/4/2016 2.25 PROD1 DRILL REAM T Stage up pumps to 2.4 bpm,868 psi, 10,590.0 10,590.0 08:30 10:45 20 rpm, 11 k Tq and observe hole pack off.Work pipe free and stage up to 3.3 bpm, 1025 psi,26 rpm,9.5K Tq and observe hole packoff.Work pipe free. 10/4/2016 10/4/2016 7.00 PROD1 DRILL REAM T Stage up pumps to 2 bpm,750 psi,20 10,590.0 11,436.0 10:45 17:45 rpm,9.8K Tq and ream in hole slowly f/10590'-11436'w/MPD backpressure of 202 psi at rate and 312 psi in slips. Note:Start adding Asphasol to mud system at 14:00 hrs to help stabilize shales,6 Ib/bbl concentration. 10/4/2016 10/4/2016 3.25 PROD1 DRILL REAM T Reciprocate stand f/11436'-11530' 11,436.0 11,530.0 17:45 21:00 and stage up pumps and rotary to 3.5 bpm, 1128 psi,30 rpm, 11.5K Tq and observe hole pack off.Work pipe free and stage up to 4.5 bpm, 1550 psi,35 rpm, 11.5K Tq and observe hole pack off.Work pipe free. Note-observed large amount of shale coming out over shakers once we reached 3.5 bpm/35 rpm and up. 10/4/2016 10/4/2016 2.25 PROD1 DRILL REAM T Stage up to 1.5 bpm,831 psi,20 rpm, 11,530.0 11,530.0 21:00 23:15 11.5K Tq,and observe hole pack off. Work pipe free.Stage up to 3.5 bpm, 1145 psi,30 rpm, 10.5K Tq and observe hole pack off.Work pipe free. Note:Able to work through and regain circulation/rotation after pack off events much quicker with less overpull than previously. Page 29/58 Report Printed: 10/31/2016 • `'0 Operations Summary (with Timelo .e the p9 p ) 2S-09 ConocoPhillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P'-T-X Operation (MKB) End Depth(FKB). 10/4/2016 10/5/2016 0.75 PROD1 DRILL REAM T Stage up to 2.5 bpm,924 psi,25 rpm, 11,530.0 11,530.0 23:15 00:00 10K Tq and observe hole start to pack off-maintain rotation and work free. Stage up to 2 bpm,857 psi,25 rpm, 10,3K Tq. Note:Observed that the majority of pack off events occur when increasing parameters while moving pipe on the upstroke. 10/5/2016 10/5/2016 1.25 PROD1 DRILL REAM T Stage up to 4.1 bpm, 1300 psi,30 11,530.0 11,530.0 00:00 01:15 rpm, 10.3K Tq and observe start to pack off @ 11477'-maintain rotation and work free. 10/5/2016 10/5/2016 2.25 PROD1 DRILL REAM T Stage up to 5.0 bpm, 1730 psi,60 11,530.0 11,530.0 01:15 03:30 rpm, 11.0K Tq, 11.31ppg ECD, observe hole pack off at 11516'.Work pipe free maintaining rotation.Attempt to stage back up and observe hole continue to try to pack off-pick up and wipe section. 10/5/2016 10/5/2016 1.25 PROD1 DRILL REAM T Stage up to 5.0 bpm, 1696 psi,60 11,530.0 11,530.0 03:30 04:45 rpm, 11K Tq, 11.28ppg ECD,observe hole pack off @ 11517'.Work pipe free . 10/5/2016 10/5/2016 2.75 PROD1 DRILL REAM T Stage up to 4.0 bpm, 1190 psi,45 11,530.0 11,530.0 04:45 07:30 rpm, 10.5K Tq,and slowly work through lower part of stand between 11510'-11520'.Continue staging up to 5.5 bpm, 1940 psi,50 rpm, 10.8K Tq and observe hole pack off at 11518'.Work pipe free.Attempt to stage back up between and observe hole continue to try and pack off. 10/5/2016 10/5/2016 3.00 PROD1 DRILL REAM T Stage up to 2.0 bpm,800 psi,20 rpm, 11,530.0 11,530.0 07:30 10:30 9.8K Tq and slowly work through 11510'-11520'.Continue staging up to 3.0 bpm, 1027 psi,20 rpm,9.6K Tq and observe hole start to pack off @ 11510'. Maintain 20 rpm and wipe section,attempting to stage up pumps. 10/5/2016 10/5/2016 1.00 PROD1 DRILL REAM T Stage up to 3.0 bpm, 1031 psi,60 11,530.0 11,530.0 10:30 11:30 rpm, 10.8K Tq and observe hole start to pack off @ 11497'.Decrease rotary to 20 rpm and work to regain circulation. 10/5/2016 10/5/2016 4.50 PROD1 DRILL REAM T Stage up to 4.0 bpm, 1308 psi,45 11,530.0 11,530.0 11:30 16:00 rpm, 10.7K Tq and ream stand down. Pump 19 bbls of 10.5ppg sweep(150 funnel viscosity)and circulate around w/3 bpm, 1025 psi,45 rpm, 10K Tq. Did not observe much of an increase in cuttings when sweep came around. 10/5/2016 10/5/2016 1.00 PROD1 DRILL CIRC T Stage up without rotary to 4.5 bpm, 11,530.0 11,439.0 16:00 17:00 1540 psi,and observe hole pack off at 11464'.Work pipe free and rack stand back. Page 30/58 Report Printed: 10/31/2016 • Operations Summary (with Timeloggg!epths) t 2S-09 CoriocoPhillips Rig: DOYON 142 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)', 10/5/2016 10/5/2016 4.50 PROD1 DRILL SMPD T Strip out of hole f/11439'-7600'at 11,439.0 7,600.0 17:00 21:30 1500 fUhr pull speed w/MPD backpressure of 420 psi out of slips and 312 psi in slips.Observe 40k overpull at 9100',but otherwise pulled out ok.PUW 188k.SOW 95k. Note:Decision made to abandon the lateral and re-drill intermediate and production sections due to instability of the Kalubik shale zone. 10/5/2016 10/5/2016 1.75 PROD1 DRILL SMPD T Strip BHA through the Kalubik up into 7,600.0 7,247.0 21:30 23:15 casing f/7600'-7220'at 300 ft/hr pull speed and MPD backpressure of 420 psi out of slips and 312 psi in slips. Observe 30-40k overpulls at 7597', 7466',7455',7382',and 7346'-7335'. Also observed 20k overpull inside casing @ 7215'. 10/5/2016 10/6/2016 0.75 PROD1 DRILL CIRC T Circulate 2 x bottoms up inside casing 7,247.0 7,185.0 23:15 00:00 w/220 gpm, 1500 psi,60 rpm,7.3K Tq. Note:Did not see any signs of fresh Kalubik shale coming over the shakers throughout circulation,only the same coffee-ground size particles of shale. No increase in cuttings seen at bottoms up. 10/6/2016 10/6/2016 1.00 PROD1 DRILL CIRC T Continue circulating total of 2 x 7,185.0 7,185.0 00:00 01:00 bottoms up inside casing w/220 gpm, 1500 psi,60 rpm,7.3K Tq. Note:Did not see any signs of fresh Kalubik shale coming over the shakers throughout circulation,only the same coffee-ground size particles of shale. No increase in cuttings seen at bottoms up. 10/6/2016 10/6/2016 0.50 PROD1 DRILL OWFF T Monitor well for 30 minutes-static. 7,185.0 7,185.0 01:00 01:30 10/6/2016 10/6/2016 0.25 PROD1 DRILL SVRG T Service top drive,grease crown and 7,185.0 7,185.0 01:30 01:45 wash pipe. Line up MPD system for stripping out of hole. 10/6/2016 10/6/2016 4.25 PROD1 DRILL SMPD T Strip out of hole racking back 4"DP f/ 7,185.0 460.0 01:45 06:00 7185'-460'holding MPD backpressure at 420 psi out of slips and 312 psi in slips,pulling at 5000 ft/hr pull speed. 10/6/2016 10/6/2016 0.25 PROD1 DRILL OWFF T Monitor well for 10 minutes-well 460.0 460.0 06:00 06:15 static. 10/6/2016 10/6/2016 1.75 PROD1 DRILL MPDA T Pull MPD bearing assembly and drain 460.0 460.0 06:15 08:00 nipple. Install trip nipple.Clear rig floor of MPD equipment. Page 31/58 Report Printed: 10/31/2016 0,1, • • Operations Summary (with Timelog Depths) 2S-09 GarxxoMaps Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-x ; Operation (W8) End Depth(MKS)'., 10/6/2016 10/6/2016 3.00 PROD1 DRILL BHAH T Pull out of hole and lay down BHA. 460.0 0.0 08:00 11:00 The bit had 3 x chipped teeth and was graded 0-1-CT-G-X-0-NO-HP. Observed dull spiral markings across the BHA tools,especially noticeable on the Impulse tool. It is presumed that the BHA was spinning on a sharp ledge while going in the hole,possibly at the shoe. 10/6/2016 10/6/2016 0.50 PROD1 DRILL RURD T Clean/clear rig floor. 0.0 0.0 11:00 11:30 10/6/2016 10/6/2016 0.50 PROD1 DRILL SFTY T Perform post-jarring derrick inspection 0.0 0.0 11:30 12:00 and mobilize cement retainer to rig floor. 10/6/2016 10/6/2016 4.50 PROD1 PLUG TRIP T Make up cement retainer as per Baker 0.0 7,082.0 12:00 16:30 and run in hole on 4"DP stands to 7082'. PUW 164k,SOW 108k. Observe string take 5-10k weight at 7082'. 10/6/2016 10/6/2016 0.75 PROD1 PLUG CIRC T Circulate at 7082',staging up from 1 7,082.0 7,052.0 16:30 17:15 bpm,281 psi,3%F/O to 3.5 bpm,495 psi,8%F/O,picking up to 7052'. 10/6/2016 10/6/2016 0.25 PROD1 PLUG PACK T Set cementer retainer at 7052'as per 7,052.0 7,052.0 17:15 17:30 Baker rep. 10/6/2016 10/6/2016 0.25 PROD1 PLUG RURD T Lay down 2 x joints 4"DP and rig up 7,052.0 7,052.0 17:30 17:45 to pressure test retainer. 10/6/2016 10/6/2016 0.50 PROD1 PLUG PRTS T Pressure test cement retainer to 3000 7,052.0 7,052.0 17:45 18:15 psi for 10 minutes,charted-good test. 4.9 bbls pumped/returned 10/6/2016 10/6/2016 0.75 PROD1 PLUG LOT T Sting into cement retainer to perform 7,052.0 7,052.0 18:15 19:00 injectivity test.Pump at 1/4 bpm for 2.6 bbls and observe pressure increase to 2639.Kill pump and observe pressure bleed down to1640 psi.Resume pumping at 1/4 bpm and pump 1.6 bbls,observe pressure slowly increasing to 2246 psi and then observe returns from annulus.Shut down pumps and bleed off pressure. 10/6/2016 10/6/2016 0.25 PROD1 PLUG CIRC T Sting out from retainer,circulate at 3 7,052.0 7,052.0 19:00 19:15 bpm,514 psi and clean off top of retainer. 10/6/2016 10/6/2016 1.00 PROD1 PLUG LOT T Sting back into cement retainer to 7,052.0 7,052.0 19:15 20:15 perform injectivity test.Stage up pump in increments to 3 bpm and observe pressure stabilize at 1952psi, 162 strokes.Pump 5 more bbls and observe pressure start to increase above 2200 psi.Reduced rate to 1.5 bpm,2195 psi,and continued pumping,total of 362 strokes pumped. Kill pump and observe pressure bleed down to 1690 psi. 10/6/2016 10/6/2016 0.25 PROD1 PLUG SFTY T Hold PJSM for pumping cement 7,052.0 7,052.0 20:15 20:30 squeeze. 10/6/2016 10/6/2016 1.00 PROD1 PLUG RURD T Line up and flush choke line/gas 7,052.0 7,052.0 20:30 21:30 buster for taking returns through choke manifold.Rig up cementers and blow down lines. Page 32/58 Report Printed: 10/31/2016 • Operations Summary (with TimeloggDepths) 0 2S-09 Coritfips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur(hr) PhaseStart Depth Op Code Activity Code: Time P-7-x Operation (ftK6) End Depth(ftK6) 10/6/2016 10/6/2016 1.00 PROD1 PLUG CMNT T Cementers pump 10 bbls water and 7,052.0 7,052.0 21:30 22:30 pressure test lines to 550/3500 psi- good test. Pump 58.8 bbls 15.8ppg Class G cement at 4.5 bpm, 1576 psi, holding 800 psi backpressure through rig choke to minimize u-tubing.Shut chokes to hold pressure while swapping from cement to water. Cementers pump 5 bbls of water at 3bpm,240 psi and sting into cement retainer.Bleed off backside pressure, open bag,and line up to rig pump. 10/6/2016 10/6/2016 1.00 PROD1 PLUG SQEZ T Pump 62 bbls 10.0ppg FloPro w/rig 7,052.0 7,052.0 22:30 23:30 pump.Staged up to 1.5 bpm, 1578 psi for 14.5 bbls and then observed pressure start to increase up to 2860 psi with no breakover.Decreased rate to 1 bpm and observed pressure breakover at 3039 psi.Continued pumping at 1 bpm,observing pressure climb to 3286 psi after 36.5 bbls pumped and then continue to fluctuate between 3000-3200 psi.Shut down after 62 bbls pumped and observe pressure fall to 2400 psi. Note:Squeezed 52 bbls of 15.8ppg Class G cement below cement retainer. 10/6/2016 10/7/2016 0.50 PROD1 PLUG TRIP T Sting out of cement retainer and pull 7,052.0 6,644.0 23:30 00:00 out of hole 4 x stands slowly to 6644'. Cement in place @ 00:06 hrs. Estimated top of cement inside 7-5/8" casing @ 6903'MD. 10/7/2016 10/7/2016 1.00 PROD1 PLUG CIRC T Confirm circulation,install wiper ball, 6,644.0 6,644.0 00:00 01:00 and circulate drill string clean with 417 gpm, 1332 psi for full surface-to- surface volume. 10/7/2016 10/7/2016 2.75 PROD1 PLUG TRIP T Pull OOH racking back 50 x stands 4" 6,644.0 1,910.0 01:00 03:45 DP f/6644'-1910',monitoring displacement on trip tank. 10/7/2016 10/7/2016 2.50 PROD1 PLUG PULD T Pull OOH sideways laying down 20 x 1,910.0 0.0 03:45 06:15 stands 4"DP and Baker tool f/1910' to surface,monitoring displacement on the trip tank. 10/7/2016 10/7/2016 0.50 PROD1 PLUG RURD T Clean/clear rig floor 0.0 0.0 06:15 06:45 10/7/2016 10/7/2016 4.25 PROD1 PLUG TRIP T Run in hole with muleshoe on 4" 0.0 6,750.0 06:45 11:00 HWDP and 4"DP stands from derrick to 6750',monitoring displacement on trip tank. 10/7/2016 10/7/2016 1.00 PROD1 PLUG WASH T Wash in hole on 4"DP f/6750'-7007' 6,750.0 7,007.0 11:00 12:00 w/84 gpm,345 psi,PUW 192k,SOW 128k.Tag top of cement at 7007'w/ 8k weight. 10/7/2016 10/7/2016 2.25 PROD1 PLUG TRIP T Trip OOH w/4"DP standing back in 7,007.0 2,770.0 12:00 14:15 derrick,monitoring displacement on trip tank. Page 33/58 Report Printed: 10/31/2016 !perations Summary (with Timelogillepths) 0:1'''%:. 2S-09 hit11ps Rig: DOYON 142 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). 10/7/2016 10/7/2016 3.25 PROD1 PLUG PULD T Pull OOH sideways laying down 30 x 2,770.0 0.0 14:15 17:30 stands 4"HWDP,monitoring displacement on trip tank. 10/7/2016 10/7/2016 0.25 PROD1 PLUG RURD T Clean/clear rig floor 0.0 0.0 17:30 17:45 10/7/2016 10/7/2016 0.25 PROD1 PLUG SFTY T Hold PJSM for slip/cut drill line. 0.0 0.0 17:45 18:00 10/7/2016 10/7/2016 2.50 PROD1 PLUG SLPC T Slip and cut 140'of drill line,perform 0.0 0.0 18:00 20:30 drawworks inspection,and calibrate top drive on amphion system. 10/7/2016 10/7/2016 0.50 PROD1 PLUG PULD T Hold PJSM and make up CIBP as per 0.0 0.0 20:30 21:00 Baker. 10/7/2016 10/7/2016 1.75 PROD1 PLUG TRIP T Run in hole on 4"DP stands from 0.0 2,972.0 21:00 22:45 derrick to 2972. PUW 84k,SOW 79k. 10/7/2016 10/7/2016 0.25 PROD1 PLUG MPSP T Drop 1.45"ball and pump down on 2,972.0 2,972.0 22:45 23:00 seat and set as per Baker,pressuring up to 1300 psi,bleeding down to 200 psi,and P/U to shear at 110k. Note:Top of CIBP @ 2972' 10/7/2016 10/8/2016 1.00 PROD1 PLUG MPSP T Rig up and pressure test CIBP to 3000 2,972.0 2,945.0 23:00 00:00 psi for 10 minutes,charted-good test. 1.9 bbls pumped/returned.Blow down kill line,rack back stand,and prepare for displacement to 140°F seawater. OA pressure=750 psi 10/8/2016 10/8/2016 0.25 PROD1 PLUG SFTY T Hold PJSM for displacing well to 2,945.0 2,945.0 00:00 00:15 seawater. 10/8/2016 10/8/2016 1.75 PROD1 PLUG DISP T Displace cased hole to 140°F 2,945.0 2,945.0 00:15 02:00 seawater.Pump 30 bbl hi-vis spacer followed by 290 bbls seawater from insulated vac truck at 166 gpm, ICP 412 psi,FCP 73 psi. 10/8/2016 10/8/2016 1.50 PROD1 PLUG TRIP T Trip out of hole f/2945'to surface, 2,945.0 0.0 02:00 03:30 racking back 4"DP stands and laying out Baker CIBP running tool. Monitor displacement on trip tank. 10/8/2016 10/8/2016 3.00 PROD1 PLUG TRIP T Make up Baker MSC cutter and trip in 0.0 2,972.0 03:30 06:30 hole on 4"DP stands to 2972'at 1.5 min/stand running speed as per Baker.Tag CIBP at 2972'w/5K. SIMOPS:Pressure test hardline to open top tank to 1500 psi and bleed off OA pressure.780 psi initial pressure bled down to 0 psi.Observed 1.5 bbl bled back. 10/8/2016 10/8/2016 1.50 PROD1 PLUG CPBO T Pick up and spot cutter at 2962'. 2,972.0 2,962.0 06:30 08:00 Perform casing cut w/226 gpm,830 psi,80 rpm,2.7k Tq,observing pressure drop to 180 psi.Close annular and confirm cut by pumping down drill string taking returns up OA to open top tank w/42 gpm,470 psi. Pick up 10'and confirm circulation again w/42 gpm,415 psi. Page 34/58 Report Printed: 10/31/2016 01;14' �q / !perations Summary (with Timelog!epths) 2S-09 Citlips Rig: DOYON 142 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) 10/8/2016 10/8/2016 1.00 PROD1 PLUG RURD T Rack back 1 x stand,rig up Little Red 2,962.0 2,945.0 08:00 09:00 to pump down drill string,pressure test lines to 2000 psi,and hold PJSM for displacement. 10/8/2016 10/8/2016 0.75 PROD1 PLUG DISP T Displace isotherm out of OA.LRS 2,945.0 2,945.0 09:00 09:45 pump 30 bbl 90°F diesel down drill string to cutter at 4 bpm,518 psi, taking seawater returns to the rig. Close annular and open OA.LRS pump 60 bbls 90°F diesel staging up to 2.5 bpm,830 psi,observing pressure drop to 400 psi rapidly after 40 bbls pumped.Volume in open top tank at 82 bbls. 10/8/2016 10/8/2016 2.25 PROD1 PLUG DISP T Line up rig to pump down drill string w/ 2,945.0 2,945.0 09:45 12:00 annular closed,taking returns to OA. Pump 25 bbl soap pill at 4 bpm,440 psi,followed by 10 bbls Hi-vis pill at 3 bpm,300 psi,followed by 35 bbls 9.2ppg WBM at 4.5 bpm,790 psi.Line up to kill line and pump 25 bbl soap pill at 4.5 bpm,330 psi,followed by 40 bbl Hi-vis pill at 4.5 bpm,325 psi, followed by 78 bbl 9.2ppg WBM at 5.0 bpm,216 psi.Shut down and suck down fluid level in open top tank. Continue pumping 103 bbl 9.2ppg WBM at 5.5 bpm,350 psi. 10/8/2016 10/8/2016 1.00 PROD1 PLUG OWFF T Monitor gauge on OA.Observe 2,945.0 2,945.0 12:00 13:00 pressure increase from 10 psi to 30 psi.Bleed off and open OA to the cellar to monitor for flow.Observe thick gelled fluid flowing back. 10/8/2016 10/8/2016 0.25 PROD1 PLUG CIRC T Line up to pump down IA w/annular 2,945.0 2,945.0 13:00 13:15 closed taking returns to open top tank. Pump 35 bbls 9.2ppg WBM at 4.0 bpm,235 psi. 10/8/2016 10/8/2016 2.25 PROD1 PLUG OWFF T Monitor well for flow out of OA into the 2,945.0 2,945.0 13:15 15:30 cellar as well as the drill pipe and IA. Observe fluid flowing back.Check volume with vis cup every 5 minutes, initial flowback rate of 1.2 bbl/hr decreased to 0.35 bbl/hr. 10/8/2016 10/8/2016 2.00 PROD1 PLUG TRIP T Pull out of hole f/2945'to surface, 2,945.0 0.0 15:30 17:30 PUW 87k,SOW 82k,monitoring displacement on trip tank.L/D Baker MSC cutter assembly. Note:Monitored OA for flowback to cellar during trip,observe initial flowback taper off to static. 10/8/2016 10/8/2016 0.50 PROD1 PLUG RURD T Clean/clear rig floor. 0.0 0.0 17:30 18:00 10/8/2016 10/8/2016 1.50 PROD1 PLUG BOPE T Change out top 3-1/2"x 6"VBR rams 0.0 0.0 18:00 19:30 for 7-5/8"solid body casing rams. Simops:mobilize casing tools to rig floor Page 35/58 Report Printed: 10/31/2016 El° •Operations Summary (with Timelo9 epths)the 9,11 Pi:','"'' ConocoPhillips . Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr)': Phase Op Code Activity Code Time P-T-X Operation (EKES) End Depth(ftKB)' 10/8/2016 10/8/2016 1.50 PROD1 PLUG BOPE T Remove wear ring&install test plug. 0.0 0.0 19:30 21:00 Test upper rams and annular to 250/3500 psi for 5 minutes each, charted.Pull test joint&plug.Blow down&rig down test equipment. 10/8/2016 10/8/2016 2.00 PROD1 PLUG PULL T Run in with pack off pulling tool on 4" 0.0 0.0 21:00 23:00 DP and make up to pack off.Bleed off pressure and run out lock down screws.Pull pack off to floor and lay out same. Simops:Reassemble double-stack casing tongs on rig floor-will not fit through beaver slide in one piece. 10/8/2016 10/9/2016 1.00 PROD1 PLUG PULL T Run in with landing joint and make up 2,962.0 2,923.0 23:00 00:00 to hanger,bumping 1 turn to the right and then 8 turns to the left.Pull hanger to the floor,PUW 118k,SOW 111k.Lay down landing joint and hanger and make up XO with circulating swedge to casing. 10/9/2016 10/9/2016 0.75 PROD1 PLUG CIRC T Circulate 2 x bottoms up w/11 bpm, 2,923.0 2,923.0 00:00 00:45 237 psi, 17%F/O until shakers clean up. 10/9/2016 10/9/2016 4.75 PROD1 PLUG PULL T POOH and lay out 7-5/8"casing f/ 2,923.0 0.0 00:45 05:30 2923'to surface,70 full joints plus 19.48'of cut joint#71,monitoring displacement on trip tank. 10/9/2016 10/9/2016 0.50 PROD1 PLUG RURD T Rig down casing tongs and clean/ 0.0 0.0 05:30 06:00 clear rig floor 10/9/2016 10/9/2016 2.50 PROD1 PLUG BOPE T Change out upper 7-5/8"casing rams 0.0 0.0 06:00 08:30 for 3-1/2"x 6"VBRs.Simops change out saver sub from XT39 to 4-1/2"IF 10/9/2016 10/9/2016 1.00 PROD1 WHDBOP RURD T Set test plug,rig up to test&perform 0.0 0.0 08:30 09:30 shell test. Page 36/58 Report Printed: 10/31/2016 • • Operations Summary (with Timelog Depths) _ 2S-09 Comaco� Rig: DOYON 142 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) 10/9/2016 10/9/2016 4.50 PROD1 WHDBOP BOPE T Test witnessed by AOGCC Rep.Guy 0.0 0.0 09:30 14:00 Cook.Tested with 5"test joints. 250/3500 psi,charted for 5 minutes each. Test#1 with 5"test joint,testing Annular,CV#1,#12,#13,#14,4"kill line valve on mud manifold,and 4-1/2" IF Dart valve. Test#2-Top Pipe rams,CV#9,#11, mezzanine kill valve,and 4-1/2"IF FOSV Test#3-CV#8,#10,and HCR Kill. Test#4-CV#6,#7. Test#5-Super choke and manual choke to 1500 psi Test#6-CV#2,#5,and manual kill Test#7-HCR choke. Test#8-Manual choke Test#9-Lower pipe rams,upper IBOP Test#10- Lower IBOP Test#11 -Blind rams,CV#3,#4,and #6. Perform Koomey draw down test. Observed initial system pressure at ACC-3050 PSI, MAN-1500 PSI,and annular-1000 PSI.After Closure observed ACC-1800 PSI,200 PSI increase in 10 seconds,and full pressures at 55 seconds. Observed 6 nitrogen bottles with an average PSI of 2392 PSI. Tested pit level sensors&flow out alarms.Gas detection alarms tested w/low&high level. 10/9/2016 10/9/2016 1.00 PROD1 WHDBOP RURD T Blow down&rig down test equipment. 0.0 0.0 14:00 15:00 Pull test plug,set wear bushing w/10" ID&RILDS. 10/9/2016 10/9/2016 0.50 PROD1 PLUG RURD T R/U casing equipment for running 3- 0.0 0.0 15:00 15:30 1/2"EUE cement stinger. 10/9/2016 10/9/2016 2.00 PROD1 PLUG PULD T Run in hole w/30 xjoints 3-1/2"EUE 0.0 937.0 15:30 17:30 cement stinger from surface to 937', monitoring displacement on trip tank. 10/9/2016 10/9/2016 2.75 PROD1 PLUG PULD T RIH on 5"DP singles from pipe shed f/ 937.0 2,960.0 17:30 20:15 937'-2960',monitoring displacement on trip tank. 10/9/2016 10/9/2016 1.00 PROD1 PLUG PULD T Make up 15'pup and attempt to run in 2,960.0 2,964.0 20:15 21:15 and tag top of bridge plug.Observe string tagging up on 7-5/8"casing cut at 2964'w/5k weight,PUW 92k,SOW 89k.Work section trying to get stinger inside casing.Rotate at 10-20 rpm, 1.5k tq,pump at 2-6 bpm, 100-144 psi,and watch for sign of increase in pump pressure on tag w/4-7k weight- no increase observed.Discuss with engineer. 10/9/2016 10/9/2016 0.50 PROD1 PLUG CIRC T Continue circulating 1 x bottoms up at 2,964.0 2,964.0 21:15 21:45 10 bpm,214 psi, 17%F/O,observe 9.2ppg MW in/out,total of 305 bbls pumped. Page 37/58 Report Printed: 10/31/2016 • • 0;. ,,,,or.:4,,,,, ,, Operations Summary (with Timelog Depths) 2S-09 corxmOgiitlips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(he) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftK8)i 10/9/2016 10/9/2016 0.75 PROD1 PLUG RURD T Layout 15'pup and M/U 5'pup for 2,964.0 2,964.0 21:45 22:30 spaceout.Blowdown topdrive and rig up cement line.Establish circulation at 4bpm, 117 psi,7%F/O and hold PJSM for cement job. 10/9/2016 10/9/2016 1.25 PROD1 PLUG CMNT T Line up to cement unit&start batch 2,964.0 2,964.0 22:30 23:45 mixing 17ppg cement.Pump 5 bbls of water to flood lines at 4 bpm, 137 psi. Test lines to 600/4000 psi.Reset high trip to 2500 psi.Batch mix 12.5ppg mudpush and pump at 5.5 bpm, 127 psi for a total of 35.5 bbls. Pump 17ppg Class G cement at 6 bpm, 150 psi for total of 60.1 bbls. Pump 12.5ppg mudpush at 4 bpm,30 psi for total of 4 bbls.Flush lines to rig floor w/1.5 bbls mudpush.Swap to rig and pump 9.2ppg WBM at 6 bpm,76- 350 psi for total of 28.6 bbls. Observed pressure rapidly increase to 350 psi after 24.5 bbls pumped as fluid caught falling cement. 10/9/2016 10/10/2016 0.25 PROD1 PLUG RURD T Rig down cement line and lay out pup 2,964.0 2,929.0 23:45 00:00 joint and top single f/2964'-2929'. 10/10/2016 10/10/2016 1.25 PROD1 PLUG TRIP T Pull OOH at 1000 ft/hr f/2929'-2075', 2,929.0 2,075.0 00:00 01:15 racking back 5"DP.Observe first single pull slightly wet and then remaining stands pull wet. CIP @ 01:15 10/10/2016 10/10/2016 0.75 PROD1 PLUG CIRC T Drop wiper ball,kick out with 15 bbls 2,075.0 2,075.0 01:15 02:00 fresh water,and circulate drill string clean w/250 bbls 9.2ppg WBM at 10 bpm, 154 psi, 16%F/O. 10/10/2016 10/10/2016 1.50 PROD1 PLUG TRIP T Pull OOH racking back 5"DP f/2075'- 2,075.0 937.0 02:00 03:30 937',monitoring displacement on trip tank. 10/10/2016 10/10/2016 1.50 PROD1 PLUG PULD T Rig up tongs and Pull OOH layind 937.0 0.0 03:30 05:00 down 3-1/2"cement stinger f/937'to surface,monitoring displacement on trip tank. 10/10/2016 10/10/2016 1.50 PROD1 PLUG RURD T Rig down casing running equipment, 0.0 0.0 05:00 06:30 clean and clear rig floor from cement job,clear shed and prepare for picking up 5"DP. 10/10/2016 10/10/2016 6.00 PROD1 PLUG PULD T Pick up and rack back 46 x stands 5" 0.0 0.0 06:30 12:30 DP out of the mousehole. 10/10/2016 10/10/2016 1.00 PROD1 PLUG RURD T Clean and clear rig floor and mobilize 0.0 0.0 12:30 13:30 BHA to floor. 10/10/2016 10/10/2016 3.25 PROD1 PLUG BHAH T Pick up BHA#6 as per SLB and 0.0 781.0 13:30 16:45 single in with 5"HWDP and jars to 781'. 10/10/2016 10/10/2016 1.50 PROD1 PLUG PULD T Run in hole on 5"DP singles f/781'- 781.0 2,017.0 16:45 18:15 2017',filling pipe every 1000'and monitoring displacement on trip tank. PUW 117k,SOW 104k. 10/10/2016 10/10/2016 0.25 PROD1 PLUG TRIP T Continue running in hole on 5"DP 2,017.0 2,204.0 18:15 18:30 stands f/2017'-2204',monitoring displacement on trip tank. Page 38/58 Report Printed: 10/31/2016 Operations Summary (with Timelog Depths) 2S-09 ConocoPniti®ps Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time'. End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKE) 10/10/2016 10/10/2016 0.75 PROD1 PLUG WASH T Wash in hole f/2204'-2374'at 2 bpm, 2,204.0 2,400.0 18:30 19:15 147 psi,6%F/O.Tag up at 2374'w/ 8k weight.Ream down from 2374'- 2400'w/12 bpm,50 rpm, 1-3k WOB and observe hard cement at 2400'. TOC @ 2400'. 10/10/2016 10/11/2016 4.75 PROD1 PLUG DRLG T Drill out cement f/2400'-2772',2554' 2,400.0 2,772.0 19:15 00:00 TVD w/350-500 gpm,750-1150 psi, 14-19%F/O,50-70 rpm,6-12k Tq on, 4-7k Tq off,5-12k WOB, PUW 130k, SOW 110k,ROT 123k,9.2ppg MW. Note:Shakers blinding off @ 2775' due to cement contamination,adjust flow rates,lower screen sizes,and treat mud to minimize fluid loss over shakers. 10/11/2016 10/11/2016 0.50 PROD1 PLUG DRLG T Drill out cement f/2772'-2795',w/ 2,772.0 2,795.0 00:00 00:30 350-500 gpm,750-1150 psi, 14-19% F/O,50-70 rpm,6-12k Tq on,4-7k Tq off,5-12k WOB,PU 130k,SO 110k, ROT 123k,9.2ppg MW. Note:Shakers blinding off due to cement contamination,adjust flow rates,lower screen sizes,and treat mud to minimize fluid loss over shakers. 10/11/2016 10/11/2016 0.50 PROD1 PLUG CIRC T PJSM-circulate at a reduced rate to 2,795.0 2,795.0 00:30 01:00 change shaker screens 116 gpm, 100 psi,70 rpm,Tq 5K. 10/11/2016 10/11/2016 1.50 PROD1 PLUG DRLG T Drill out cement f/2795'-2854',w/ 2,795.0 2,854.0 01:00 02:30 650 gpm, 1651 psi,FO 20%,60 rpm, Tq on 6k,Tq off 4K,WOB 5-8K, PU 135K,SO 110K,ROT 123K,MW 9.2 PPg. 10/11/2016 10/11/2016 2.50 INTRM2 DRILL DDRL T PJSM-directional drill 9-7/8"X11" 2,854.0 2,958.0 02:30 05:00 intermediate hole section f/2854'- 2958'MD,2712'TVD,650 gpm, 1650 psi,FO 20%,60 rpm,Tq on 6K,WOB 5-8K,ECD,Off Bottom 1600 psi,PU 135K,SO 110K,ROT 123K,Tq off K, MW 9.2 ppg,Max gas 136, ADT 1.32, Bit 2.91,Jars 85.65,Total Footage 104'MD. Kick w/Drilling CRT 150 sec @ 04:00 hrs. 10/11/2016 10/11/2016 1.50 INTRM2 DRILL DISP T PJSM-displace well to 9.2 ppg LSND 2,958.0 2,958.0 05:00 06:30 at 615 gpm, 1226 psi,60 rpm. 10/11/2016 10/11/2016 0.50 INTRM2 DRILL CIRC T Drop RFID opening chips&pump 2,958.0 2,958.0 06:30 07:00 down at 640 gpm,1350 psi.Observe no change in MWD turbine speed or pump pressure.Pull test to 15K over. Page 39/58 Report Printed: 10/31/2016 „S ' ^ Operations Summary (with Timelo De the 9 p ) 2S-09 ConocciPhitiips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depth Start Time End Time Dor(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 10/11/2016 10/11/2016 1.00 INTRM2 DRILL DDRL T PJSM-directional drill 9-7/8"X11" 2,958.0 3,024.0 07:00 08:00 intermediate hole section f/2958'- 3024'MD,2712'TVD,803 gpm, 1965 psi,FO 25%,80-100 rpm,Tq on 7K, WOB 3-5K,ECD,Off Bottom 1900 psi,PU 135K,SO 110K,ROT 123K, Tq off 6K, MW 9.2 ppg, Max gas, ADT.74,Bit 3.65,Jars 86.39,Total Footage 66'MD. 10/11/2016 10/11/2016 1.50 INTRM2 DRILL CIRC T PJSM-TOH f/3024'-2822'MD, 3,024.0 2,822.0 08:00 09:30 observe no over pull as reamer enters the shoe.Drop below shoe&drop RFID chips to close as per WFT. Attempt to confirm opening&closing of reamer.Decision made to trip to surface&change out under reamer. 10/11/2016 10/11/2016 0.25 INTRM2 DRILL OWFF T Monitor well,static.SIMOPS blow 2,822.0 2,822.0 09:30 09:45 down TD. 10/11/2016 10/11/2016 2.25 INTRM2 DRILL TRIP T PJSM-TOH f/2822'-96'MD, 2,822.0 96.0 09:45 12:00 10/11/2016 10/11/2016 1.00 INTRM2 DRILL BHAH T PJSM-lay down reamer,pick up to 96.0 96.0 12:00 13:00 power drive inspecting pads,&make up back up reamer. 10/11/2016 10/11/2016 0.50 INTRM2 DRILL BHAH T PJSM-shallow test reamer at surface 96.0 96.0 13:00 13:30 at 502 gpm,615 psi.Reamer opened &closed as intended.Blow down top drive. 10/11/2016 10/11/2016 2.50 INTRM2 DRILL TRIP T PJSM-TIH f/96-2944'MD,fill pipe 96.0 2,944.0 13:30 16:00 every 1000',PU 122K,SO 110K. 10/11/2016 10/11/2016 0.50 INTRM2 DRILL CIRC T Circulate to open reamer at 650 gpm, 2,944.0 2,944.0 16:00 16:30 1415 psi, FO 20%,20 rpm,Tq 5K, PU 122K,SO 120K,MWD turbine 2425 rpm.Drop RFID tags&pump down at 650 gpm. Reduce flow at 350 strokes to 200 gpm,pressure dropped f/1421 psi to 1185 psi.Torque increased 2K. With pumps at 650 gpm,MWD turbine at 2031 rpm.Reamer indicated open. 10/11/2016 10/11/2016 0.50 INTRM2 DRILL UREM T Ream f/2944'-3024',750 gpm, 1744 2,944.0 3,024.0 16:30 17:00 psi,FO 22%, 100 rpm,Tq 5-7K,WOB 1K, 130 fph, PU 135K,SO 112K,ROT 125K. 10/11/2016 10/12/2016 7.00 INTRM2 DRILL DDRL T PJSM-directional drill 9-7/8"X11" 3,024.0 3,620.0 17:00 00:00 intermediate hole section f/3024'- 3620'MD,3287'TVD,815 gpm, 1950 psi,FO 22-24%, 120 rpm,Tq on 6- 14K,WOB 8-14K, ECD 9.8-10.1,Off Bottom 1935 psi,PU 155K,SO 117K, ROT 134K,Tq off 4-8K,MW 9.2 ppg, Max gas 46, ADT 5.07,Bit 8.72,Jars 91.46,Total Footage 596'MD. SCR @ 3525'MD,3205'TVD,MW 9.2 ppg,23:10 hrs. #1 @ 30= 140;@ 40=180 #2@30=140;@40= 180 Page 40/58 Report Printed: 10/31/2016 • Operations Summary (with Timelog Depths) 2S-09 ConocoPhifhps P,lts=I:.ib Rig: DOYON 142 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) 10/12/2016 10/12/2016 6.00 INTRM2 DRILL DDRL T PJSM-directional drill 9-7/8"X11" 3,620.0 4,190.0 00:00 06:00 intermediate hole section f/3620'- 4190'MD,3723'TVD,815 gpm,2100 psi, FO 22%, 120 rpm,Tq on 12K, WOB 15K,ECD 10.03,Off Bottom 1930 psi,PU 168K,SO 120K,ROT 136K,Tq off 11K,MW 9.2 ppg,Max gas 8, ADT 4.32,Bit 13.04,Jars 95.74,Total Footage 570'MD. 10/12/2016 10/12/2016 6.00 INTRM2 DRILL DDRL T PJSM-directional drill 9-7/8"X11" 4,190.0 4,757.0 06:00 12:00 intermediate hole section f/4190'- 4757'MD,4222'TVD,815 gpm,2314 psi, FO 23%, 140 rpm,Tq on 14K, WOB 15K,ECD 10.18,Off Bottom 2280 psi,PU 181K,SO 141K,ROT 145K,Tq off 12K,MW 9.2 ppg,Max gas 8, ADT 4.57,Bit 17.61,Jars 100.35,Total Footage 567'MD. SCR @ 4287'MD,3807'TVD,MW 9.2 ppg,07:00 hrs. #1 @30=180;@40=220 #2@30= 180;@40=220 SCR @ 4757'MD,4222'TVD,MW 9.2 ppg, 11:45 hrs. #1 @30=180;@40=220 #2@30=180;@40=220 10/12/2016 10/12/2016 3.50 INTRM2 DRILL DDRL T PJSM-directional drill 9-7/8"X11" 4,757.0 5,139.0 12:00 15:30 intermediate hole section f/4757'- 5139'MD,4609'TVD,815 gpm,2560 psi,FO 22%, 140 rpm,Tq on 15K, WOB 13-18K, ECD 10.56,Off Bottom 2484 psi,PU 180K,SO 147K,ROT 163K,Tq off 7-10K,MW 9.2-9.6 ppg, Max gas 40, ADT 3.04, Bit 20.65, Jars 103.39,Total Footage 382'MD. Man Down Drill CRT 67 sec at 14:40 hrs. 10/12/2016 10/12/2016 0.50 INTRM2 DRILL CIRC T CBU at 815 gpm,2560 psi,FO 22%, 5,139.0 5,139.0 15:30 16:00 140 rpm,Tq 7-10K,PU 180K,SO 147K,ROT 163K,MW 9.6 ppg. 10/12/2016 10/12/2016 0.25 INTRM2 DRILL OWFF T Monitor well,static.SIMOPS blow 5,139.0 5,139.0 16:00 16:15 down TD. 10/12/2016 10/12/2016 1.25 INTRM2 DRILL MPDA T PJSM-remove trip nipple,install MPD 5,139.0 5,139.0 16:15 17:30 bearing,&drain nipple. Break in bearing at 30&60 rpm for 5 minutes each. Page 41/58 Report Printed: 10/31/2016 4110 • Operations Summary (with Timelog Depths) 2S-09 hiErps Rig: DOYON 142 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)', 10/12/2016 10/13/2016 6.50 INTRM2 DRILL DDRL T PJSM-directional drill 9-7/8"X11" 5,139.0 5,705.0 17:30 00:00 intermediate hole section f/5139- 5705'MD,5139'TVD,815 gpm,2750 psi,FO 22%, 140 rpm,Tq on 13-18K, WOB 15-25K, ECD 10.75,Off Bottom 2725 psi,PU 198K,SO 157K, ROT 169K,Tq off 7-10K,MW 9.7 ppg,Max gas 59, ADT 4.34,Bit 24.99,Jars 107.73,Total Footage 566'MD. SCR @ 5705'MD,3190'TVD,MW 9.7 ppg,23:30 hrs. #1 @ 30=220;@ 40=270 #2 30=220;@40=260 10/13/2016 10/13/2016 6.00 INTRM2 DRILL DDRL T PJSM-directional drill 9-7/8"X11" 5,705.0 6,368.0 00:00 06:00 intermediate hole section f/5705- 6368'MD,5711'TVD,815 gpm,2850 psi,FO 22-30%, 140 rpm,Tq on 13- 18K,WOB 15-25K,ECD 10.7-11.0, Off Bottom 2825 psi,PU 210K,SO 158K,ROT 171K,Tq off 20K,MW 9.8 ppg,Max gas 50, ADT 4.95,Bit 29.94,Jars 112.68,Total Footage 663' MD. SCR @ 6272'MD,5634'TVD, MW 9.9 ppg,05:30 hrs. #1 @ 30=220;@ 40=280 #2 @ 30=220;@ 40=280 10/13/2016 10/13/2016 6.00 INTRM2 DRILL DDRL T PJSM-directional drill 9-7/8"X11" 6,368.0 6,842.0 06:00 12:00 intermediate hole section f/6368'- 6842'MD,6015'TVD,800 gpm,2950 psi,FO 22-30%, 140 rpm,Tq on 18- 22K,WOB 15-25K,ECD 10.7-11.0, Off Bottom 2900 psi,PU 230K,SO 149K,ROT 177K,Tq off 20K, MW 9.9 ppg,Max gas 50, ADT 3.93,Bit 33.87,Jars 116.61,Total Footage 474' MD. Spill Drill CRT 120 sec @ 07:00 hrs. 10/13/2016 10/13/2016 6.00 INTRM2 DRILL DDRL T PJSM-directional drill 9-7/8"X11" 6,842.0 7,235.0 12:00 18:00 intermediate hole section f/6842'- 7235'MD,6179'TVD,800 gpm,3200 psi,FO 25-30%, 140 rpm,Tq on 16- 22K,WOB 15-25K,ECD 11.2-11.45, Off Bottom 3190 psi, PU 244K,SO 144K,ROT 179K,Tq off 18K,MW 10.1 ppg,Max gas 50, ADT 4.23,Bit 38.10,Jars 120.84,Total Footage 393' MD. Fire Drill CRT 69 sec©13:30 hrs. SCR @ 6935'MD,6060'TVD,MW 10.1 ppg, 13:00 hrs. #1 @ 30=250;@ 40=340 #2 @ 30=250;@ 40=340 Page 42/58 Report Printed: 10/31/2016 Operations Summary (with Timelog D pths) 2S-09 ConocoPhilltps Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log , Start Depth Stan Time End Time Dur(hr)' Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth MKS)10/13/2016 10/14/2016 6.00 INTRM2 DRILL DDRL T PJSM-directional drill 9-7/8"X11" 7,235.0 7,600.0 18:00 00:00 intermediate hole section f/7235'- 7600'MD,6257'TVD,800 gpm,3265 psi,FO 22-30%, 140 rpm,Tq on 14- 22K,WOB 15-25K,ECD 11.15-11.4, Off Bottom 3220 psi, PU 254K,SO 134K,ROT 175K,Tq off 17-20K,MW 10.1 ppg,Max gas 335, ADT 4.0,Bit 42.10,Jars 124.84,Total Footage 365' MD. Started having losses at 7599'MD,45 bbls initial loss during connection ramp schedule. SCR @ 7310'MD,6209'TVD,MW 10.0 ppg, 19:00 hrs. #1 @ 30=270;@ 40=330 #2 @ 30=270;@ 40=330 10/14/2016 10/14/2016 6.00 INTRM2 DRILL DDRL T PJSM-directional drill 9-7/8"X11" 7,600.0 8,025.0 00:00 06:00 intermediate hole section f/7600'- 8025'MD,6325'TVD,800 gpm,3240 psi,FO 27%, 140 rpm,Tq on 22K, WOB 25K, ECD 11.27,Off Bottom 3100 psi,PU 254K,SO 131K,ROT 174K,Tq off 20K,MW 10.2 ppg,Max gas 101, ADT 5.62,Bit 47.72,Jars 130.46,Total Footage 365'MD. Kick w/Drilling CRT 180 sec @ 05:00 hrs. Observed losses while drilling ahead f/ 7600'-7884'MD,starting at 25 bph reducing to none. 10/14/2016 10/14/2016 3.00 INTRM2 DRILL DDRL T PJSM-directional drill 9-7/8"X11" 8,025.0 8,138.0 06:00 09:00 intermediate hole section f/8025'- 8138'MD,6334'TVD,800 gpm,3170 psi,FO 27%, 150 rpm,Tq on 25K, WOB 12K,ECD 11.27,Off Bottom 3000 psi,PU 280K,SO 115K,ROT 172K,Tq off 20K,MW 10.2 ppg,Max gas 101, ADT 2.44,Bit 50.16,Jars 132.9,Total Footage 113'MD. Drill ahead at 50 fph for hole cleaning, hold 150 psi on connections. 10/14/2016 10/14/2016 2.00 INTRM2 CASING CIRC T CBU f/8135'-8074'MD at 800 gpm, 8,138.0 8,074.0 09:00 11:00 3125 psi, 100 rpm,Tq 15-20K,PU 280K,SO 115K,ROT 171. 10/14/2016 10/14/2016 1.00 INTRM2 CASING OWFF T Perform MPD no flow test,6 test 8,074.0 8,074.0 11:00 12:00 cycles,record pressure every 5 minutes. ISIP 101 psi,FSIP 57 psi. 10/14/2016 10/14/2016 0.50 INTRM2 CASING CIRC T PJSM-close under reamer as per 8,074.0 8,074.0 12:00 12:30 WFT Rep.650 gpm,2293 psi, 10 rpm, Tq 19K,FO 27%,MWD turbine 2148 rpm.Drop RFID chips&circulate 1000 strokes at 650 gpm,decreasing to 200 gpm for 550 strokes.Pumps off for 10 minutes.Circulate at 650 gpm,2630 psi, 10 rpm,Tq 19K,FO 27%,MWD turbine 2539 rpm. Page 43/58 Report Printed: 10/31/2016 PmgeOperations Summary (with Timelog Depths) ' 2S-09 ConocoPhitifFis Rig: DOYON 142 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(EKE)', 10/14/2016 10/14/2016 2.00 INTRM2 CASING PMPO T Load 66 bbls of LCM pill in DP&spot 8,074.0 7,507.0 12:30 14:30 f/8074'-7507'MD,3 bpm,360 psi, 1500 fph, PU 285K,SO 115K. 10/14/2016 10/14/2016 2.50 INTRM2 CASING PMPO T PJSM-pump out of hole with MPD f/ 7,507.0 6,844.0 14:30 17:00 7507'-6844'MD at 650 gpm,2577 psi, FO 30%,PU 270K,SO 115K. 10/14/2016 10/14/2016 1.75 INTRM2 CASING CIRC T CBU 2x till shakers clean f/6844'- 6,844.0 6,747.0 17:00 18:45 6747'MD at 700 gpm,2740 psi,FO 30%,80 rpm,Tq 18K, PU 273K,SO 147K,ROT 188K. 10/14/2016 10/14/2016 3.25 INTRM2 CASING OWFF T Monitor well,perform well bore 6,747.0 6,747.0 18:45 22:00 breathing test&observe well go static, 10 rpm,Tq 19K. 10/14/2016 10/15/2016 2.00 INTRM2 CASING PMPO T Load 171 bbls of LCM pill in DP&spot 6,747.0 6,100.0 22:00 00:00 f/6747'-6100'MD,3 bpm,340 psi, 1500 fph, PU 250K,SO 110K. 10/15/2016 10/15/2016 1.50 INTRM2 CASING PMPO T PJSM-continue spotting LCM pill f/ 6,100.0 5,328.0 00:00 01:30 6100'-5328'MD,3 bpm,300 psi, 1500 fph, PU 221K,SO 131K. 10/15/2016 10/15/2016 1.75 INTRM2 CASING SMPD T PJSM-strip out of the hole from 5328'- 5,328.0 4,280.0 01:30 03:15 4280'MD, 140 psi BP out of slips,40 psi BP in slips. 10/15/2016 10/15/2016 0.25 INTRM2 CASING OWFF T Monitor well because of improper hole 4,280.0 4,280.0 03:15 03:30 fill,by shutting in the MPD chokes.No pressure build up,well static. 10/15/2016 10/15/2016 1.75 INTRM2 CASING SMPD T PJSM-strip out of the hole from 4280'- 4,280.0 3,052.0 03:30 05:15 3052'MD, 125 psi BP out of slips,40 psi BP in slips. 10/15/2016 10/15/2016 0.25 INTRM2 CASING SRVY T Check shot survey @ 3052'MD. 3,052.0 3,052.0 05:15 05:30 10/15/2016 10/15/2016 0.50 INTRM2 CASING SMPD T Strip out of the hole from 3502'-2812' 3,052.0 2,812.0 05:30 06:00 MD, 125 psi BP out of slips,40 psi BP in slips, PU 135K,SO 107K. 10/15/2016 10/15/2016 1.00 INTRM2 CASING CIRC T CBU at 595 gpm, 1609 psi,FO 27%, 2,812.0 2,812.0 06:00 07:00 60 rpm,Tq 6-7K,ROT 119K. 10/15/2016 10/15/2016 1.25 INTRM2 CASING OWFF T Monitor well till static,bled back 1 bbl. 2,812.0 2,812.0 07:00 08:15 10/15/2016 10/15/2016 1.25 INTRM2 CASING MPDA T PJSM-remove MPD bearing,install 2,812.0 2,812.0 08:15 09:30 trip nipple,blow down MPD choke& lines. 10/15/2016 10/15/2016 3.75 INTRM2 CASING TRIP T PJSM-TOH f/2812'-192'MD,PU 2,812.0 192.0 09:30 13:15 65K,SO 65K. 10/15/2016 10/15/2016 1.75 INTRM2 CASING BHAH T PJSM-lay down BHA 7 as per SLB 192.0 0.0 13:15 15:00 DD. 10/15/2016 10/15/2016 1.00 INTRM2 CASING WWWH T PJSM-make up stack washer&clean 0.0 0.0 15:00 16:00 stack w/850 gpm, 145 psi,FO 25%. Lay down stack washer. 10/15/2016 10/15/2016 1.00 INTRM2 CASING BHAH T PJSM-clear&clean floor of BHA. 0.0 0.0 16:00 17:00 SIMOPS-empty stack&bring casing running equipment to the rig floor. 10/15/2016 10/15/2016 1.00 INTRM2 CASING BOPE T PJSM-change out upper rams to 7- 0.0 0.0 17:00 18:00 5/8"solid body rams.SIMOPS-rig up to run casing. 10/15/2016 10/15/2016 1.00 INTRM2 CASING RURD T PJSM-remove wear ring&install test 0.0 0.0 18:00 19:00 plug. Page 44/58 Report Printed: 10/31/2016 • Operations Summary (with TimelogDepths) 3 2S-09 ConocoPhillips Rig: DOYON 142 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(EKE) 10/15/2016 10/15/2016 1.00 INTRM2 CASING BOPE T PJSM-test annular to 250/2500 psi, 0.0 0.0 19:00 20:00 charted for 5 minutes each.Test upper rams to 250/3500 psi,charted for 5 minutes each. Remove test plug &blow down lines. 10/15/2016 10/16/2016 4.00 INTRM2 CASING PUTB T PJSM-run 7-5/8",Hyd 563 DL,29.7#, 0.0 1,768.0 20:00 00:00 L80 casing as per detail to 1768'MD. Make up shoe track&Baker Lok all connections to the landing collar. Pump through&test floats. Hydroform centralizers installed w/3 centralizers per 2 joints.All connections torqued to 18,000 ft/lbs. 10/16/2016 10/16/2016 2.25 INTRM2 CASING PUTB T PJSM-run 7-5/8", Hyd 563 DL,29.7#, 1,768.0 2,814.0 00:00 02:15 L80 casing as per detail f/1768'-2814' MD,PU 117K,SO 103K. Install stage collar between joints 64&65. Hydroform centralizers installed w/3 centralizers per 2 joints.A total of 117 centralizers installed.All connections torque to 18,000 ft/lbs. 10/16/2016 10/16/2016 1.25 INTRM2 CASING CIRC T Circulate&condition staging up to 5 2,814.0 2,814.0 02:15 03:30 bpm, 182 psi,pumped 1582 strokes. 10/16/2016 10/16/2016 2.50 INTRM2 CASING PUTB T PJSM-run 7-5/8",Hyd 563 DL,29.7#, 2,814.0 4,002.0 03:30 06:00 L80 casing as per detail f/2814'-4002' MD,PU 142K,SO 117K.All connections torque to 18,000 ft/lbs. 10/16/2016 10/16/2016 1.50 INTRM2 CASING CIRC T Circulate&condition staging up to 4 4,002.0 4,002.0 06:00 07:30 bpm, 178 psi,pumped 2604 strokes. Losses 8 bbls. 10/16/2016 10/16/2016 1.25 INTRM2 CASING PUTB T PJSM-run 7-5/8",Hyd 563 DL,29.7#, 4,002.0 4,539.0 07:30 08:45 L80 casing as per detail f/4002'-4539' MD,PU 167K,SO 130K.All connections torque to 18,000 ft/lbs. 10/16/2016 10/16/2016 0.75 INTRM2 CASING CIRC T Circulate&condition staging up to 3 4,539.0 4,539.0 08:45 09:30 bpm,240 psi,pumped 786 strokes. Losses 6 bbls. 10/16/2016 10/16/2016 1.25 INTRM2 CASING PUTB T PJSM-run 7-5/8", Hyd 563 DL,29.7#, 4,539.0 5,030.0 09:30 10:45 L80 casing as per detail f/4539'-5030' MD,PU 180K,SO 131K.All connections torque to 18,000 ft/lbs. 10/16/2016 10/16/2016 2.25 INTRM2 CASING CIRC T Circulate&condition staging up to 4 5,030.0 5,030.0 10:45 13:00 bpm, 152 psi,FO 7%,PU 195K,SO 135K,pumped 3500 strokes. 10/16/2016 10/16/2016 1.00 INTRM2 CASING PUTB T PJSM-run 7-5/8",Hyd 563 DL,29.7#, 5,030.0 5,523.0 13:00 14:00 L80 casing as per detail f/5030'-5523' MD, PU 207K,SO 143K.All connections torque to 18,000 ft/lbs. 10/16/2016 10/16/2016 0.75 INTRM2 CASING CIRC T Circulate&condition staging up to 3 5,523.0 5,523.0 14:00 14:45 bpm, 133 psi, FO 5%,PU 206K,SO 143K,pumped 762 strokes. 10/16/2016 10/16/2016 2.00 INTRM2 CASING PUTB T PJSM-run 7-5/8",Hyd 563 DL,29.7#, 5,523.0 6,386.0 14:45 16:45 L80 casing as per detail f/5523'-6386' MD,PU 245K,SO 147K.All connections torque to 18,000 ft/lbs. 10/16/2016 10/16/2016 2.50 INTRM2 CASING CIRC T Circulate&condition staging up to 3 6,386.0 6,386.0 16:45 19:15 bpm, 109 psi,FO 5%,PU 245K,SO 143K,pumped 3100 strokes. Page 45/58 Report.Printed: 10/31/2016 :� :' Operations Summary (with Timelog Depths) ) ter ,, 2S-09 Conoc:oPhi Clips Rig: DOYON 142 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(ftK8)', 10/16/2016 10/16/2016 1.00 INTRM2 CASING PUTB T PJSM-run 7-5/8",Hyd 563 DL,29.7#, 6,386.0 6,869.0 19:15 20:15 L80 casing as per detail f/6386-6869' MD, PU 257K,SO 157K.All connections torque to 18,000 ft/lbs. Spill Drill CRT 70 sec @ 20:00 hrs. 10/16/2016 10/16/2016 1.75 INTRM2 CASING CIRC T Circulate&condition staging up to 5 6,869.0 6,869.0 20:15 22:00 bpm,90 psi, FO 9%,PU 257K,SO 157K,pumped 3600 strokes. 10/16/2016 10/17/2016 2.00 INTRM2 CASING PUTB T PJSM-run 7-5/8",Hyd 563 DL,29.7#, 6,869.0 7,763.0 22:00 00:00 L80 casing as per detail f/6869'-7763' MD, PU 293K,SO 153K.All connections torque to 18,000 ft/lbs. Losses for tour 37 bbls. 10/17/2016 10/17/2016 1.00 INTRM2 CASING PUTB T PJSM-run 7-5/8", Hyd 563 DL,29.7#, 7,763.0 8,089.0 00:00 01:00 L80 casing as per detail f/7763'-8089' MD.All connections torque to 18,000 ft/lbs. 10/17/2016 10/17/2016 0.50 INTRM2 CASING HOSO T PJSM-make up hanger&landing joint 8,089.0 8,129.0 01:00 01:30 as per CIW Rep.Wash down at 1 bpm,201 psi,PU 312K,SO 138K. Land hanger at 8129'MD. 10/17/2016 10/17/2016 3.25 INTRM2 CEMENT CIRC T Circulate&condition mud for cement 8,129.0 8,129.0 01:30 04:45 job staging up pump rate to 4.5 bpm, 201 psi, FO 7%,no losses. 10/17/2016 10/17/2016 0.25 INTRM2 CEMENT RURD T PJSM-blow down top drive,make up 8,129.0 8,129.0 04:45 05:00 cement line onto CRT. 10/17/2016 10/17/2016 2.25 INTRM2 CEMENT CIRC T Circulate&condition mud for cement 8,129.0 8,129.0 05:00 07:15 job staging up pump rate to 6 bpm, 315 psi, FO 10%, PU 300K,SO 149K, no losses.SIMOPS-PJSM for cementing. 10/17/2016 10/17/2016 3.00 INTRM2 CEMENT CMNT T Cement 1st stage as per SLB 8,129.0 8,129.0 07:15 10:15 schedule. Pump 5 bbls of H2O& pressure test lines to 600/4000 psi. Pump 40 bbls of 12.5 ppg mud push at 3.7 bpm, 150 psi.Drop bottom plug. Pump 15.2 bbls of 15.8 ppg neat cement at 5 bpm,265 psi.Pump 99.5 bbls of 15.8 ppg cement w/2 ppb of CemNet at 5.1 bpm, 175 psi.Pump 46 bbls of 15.8 ppg neat cement at 5.1 bpm, 180 psi. Drop top plug&pump 10 bbls of H2O at 6 bpm,207 psi. Swap to rig&displace w/353.7 bbls of 10.0 ppg LSND mud at 7 bpm, 120 psi.Slow rate to 3 bpm,830 psi& bump plug at 3502 strokes.Pressure up to 1340 psi&hold for 5 minutes. Bleed off&check floats,good.CIP 10:10 hrs. 10/17/2016 10/17/2016 0.25 INTRM2 CEMENT CIRC T Pressure up to 2935 psi to observe 8,129.0 8,129.0 10:15 10:30 stage tool shear open. Establish circulation through stage tool. 10/17/2016 10/17/2016 2.75 INTRM2 CEMENT CIRC T Stage up pump rate to 5 bpm, ICP 230 8,129.0 8,129.0 10:30 13:15 psi,FCP 197 psi,FO 8%,pumped 6414 strokes. 10/17/2016 10/17/2016 2.75 INTRM2 CEMENT CIRC T Circulate through stage collar at 3 8,129.0 8,129.0 13:15 16:00 bpm, 103 psi, FO 6%,pumped 5125 strokes.SIMOPS PJSM for 2nd stage cement job. Page 46/58 Report Printed: 10/31/2016 i i 0 Operations Summary (with Timelog Depths) 0 2S-09 Gonoccitlips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Tune'. End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/17/2016 10/17/2016 2.00 INTRM2 CEMENT CMNT T Cement 2nd stage as per SLB 8,129.0 0.0 16:00 18:00 schedule.Pump 5 bbls of H2O.Pump 41.9 bbls of 12.5 ppg mud push at 4.1 bpm, 108 psi.Pump 10.2 bbls of 15.8 ppg neat cement at 5.5 bpm,252 psi. Pump 33.1 bbls of 15.8 ppg cement w/ 2 ppb of CemNet at 5.5 bpm,222 psi. Pump 4.2 bbls of 15.8 ppg neat cement at 4 bpm, 180 psi.Drop closing plug&pump 10 bbls of H2O at 5 bpm,7 psi.Swap to rig&displace w/243 bbls of 10.0 ppg LSND mud at 7 bpm,300 psi.Slow rate to 3 bpm, i 600 psi&bump plug at 2404 strokes. CIP 18:05 hrs. 10/17/2016 10/17/2016 0.50 INTRM2 CEMENT CIRC T Pressure up to 2000 psi,observing 0.0 0.0 18:00 18:30 stage tool close at 1420 psi.Hold for 5 minutes. Bleed off pressure&fluid to trip tank,with 2.7 bbls.Check to ensure no flow back,good. 10/17/2016 10/17/2016 0.50 INTRM2 CEMENT OWFF T Monitor well,static.SIMOPS rig down 0.0 0.0 18:30 19:00 &blow down cement lines.Rig down Volant CRT. 10/17/2016 10/17/2016 2.00 INTRM2 CEMENT WWSP T PJSM-pull landing joint&empty0.0 0.0 19:00 21:00 stack.Make up running tool on landing joint w/pack off. Install pack off as per CIW Rep.RILDS.Test pack off to 5000 psi for 10 minutes,witnessed by CPAI.Lay down landing joint. SIMOPS clean manifold valves of cement. 10/17/2016 10/17/2016 0.50 INTRM2 CEMENT RURD T PJSM-clean&clear casing running 0.0 0.0 21:00 21:30 equipment from rig floor. 10/17/2016 10/17/2016 1.00 INTRM2 'CEMENT PULD T PJSM-lay down 6 stands of 5"HWDP 0.0 0.0 21:30 22:30 from the derrick,using the mouse hole. Fire Drill CRT 120 sec @ 22:00 hrs. 10/17/2016 10/18/2016 1.50 INTRM2 CEMENT PULD T PJSM-lay down 16 stands of 5"DP 0.0 0.0 22:30 00:00 from the derrick,using the mouse hole. 10/18/2016 10/18/2016 9.50 INTRM2 CEMENT PULD T PJSM-lay down 64 stands of 5"DP 0.0 0.0 00:00 09:30 from derrick.SIMOPS change out upper rams to 3-1/2"X 6"VBR's& clean pits. 10/18/2016 10/18/2016 3.00 INTRM2 CEMENT RURD T PJSM-C/O saver sub to 4"XT39,C/O 0.0 0.0 09:30 12:30 handling equipment to 4",C/O Iron Roughneck die blocks for 4",&adjust stop plate.SIMOPS-load&process 90 joints of 4"HWDP in the pipe shed. 10/18/2016 10/18/2016 2.75 INTRM2 CEMENT PULD T PJSM-pick up&rack back 30 stands 0.0 0.0 12:30 15:15 of 4"HWDP in the derrick. 10/18/2016 10/18/2016 1.75 INTRM2 CEMENT FRZP T PJSM-rig up LRS&PT lines.Pump 0.0 0.0 15:15 17:00 123 bbls of H2O at 3.5 bpm, ICP 750 psi,FCP 625 psi.Line up&pump 91.5 bbls of Isotherm at 3.5-1 bpm, ICP 900 psi,FCP 650 psi.OA shut in pressure 550 psi.SIMOPS service top drive&crown.Rig up test equipment &set test plug. Page 47/58 Report Printed: 10/31/2016 • 0 Operations Summary (with Timelog Depths) 2S-09 Comm'r hitIips Rig: DOYON 142 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(EKE) 10/18/2016 10/18/2016 0.50 INTRM2 WHDBOP RURD T PJSM-make up XT39 FOSV&dart 0.0 0.0 17:00 17:30 valve.Fill all lines with H2O.Perform shell test,good. 10/18/2016 10/18/2016 4.00 INTRM2 WHDBOP BOPE T Test witness waived by AOGCC Rep. 0.0 0.0 17:30 21:30 Chuck Scheve.Tested with 3-1/2"&4- 1/2"test joints.250/3500 psi,charted for 5 minutes each. Test#1 with 3 1/2"test joint,testing Annular,CV#1,#12,#13,#14 and 4" kill line valve on mud manifold. Test#2-Top Pipe rams,CV#9,#11, mezzanine kill valve,and XT-39 Dart valve. Test#3- CV#8,#10,HCR Kill,and XT-39 FOSV. Test#4-CV#6,#7. Test#5- Super Choke & Manual operated choke to 2000 PSI. Test#6-CV#2,#5&Manual Kill Test#7-Lower Pipe rams Test#8-Blind rams,CV#3,#4,#6 Installed 4 1/2"test joint. Test#9-Annular, HCR Choke,upper IBOP. Test#10-Top Pipe rams,Manual choke,and lower IBOP Test#11 -Lower Pipe rams Perform Koomey draw down test. Observed initial system pressure at 3100 psi,after closure 1800 psi,200 psi increase in 6 seconds,and full pressures at 51 seconds. Observed 6 nitrogen bottles with an average PSI of 2608 PSI.Tested pit level sensors&flow out alarms.Gas detection alarms tested w/low&high level. 10/18/2016 10/18/2016 1.25 INTRM2 WHDBOP RURD T PJSM-blow down/rig down test 0.0 0.0 21:30 22:45 equipment&lines.Remove test plug. Install 10"ID wear bushing,RILDS X2. 10/18/2016 10/19/2016 1.25 INTRM2 CEMENT BHAH T PJSM-make up 6-3/4"production 0.0 137.0 22:45 00:00 BHA 8 as per SLB DD to 137'MD. OA pressure 500 psi @ 24:00 hrs. 10/19/2016 10/19/2016 1.50 INTRM2 CEMENT BHAH T PJSM-continue making up 6 3/4" 137.0 392.0 00:00 01:30 production BHA 8 as per SLB DD,f/ 137'-392'MD,PU 52K,SO 58K. 10/19/2016 10/19/2016 3.25 INTRM2 CEMENT PULD T PJSM-single in the hole f/392'-2666' 392.0 2,666.0 01:30 04:45 MD,72 joints. 10/19/2016 10/19/2016 1.00 INTRM2 CEMENT DHEQ T Shallow hole test MWD&LWD tools. 2,666.0 2,666.0 04:45 05:45 Down link to turn on sonic logging. 10/19/2016 10/19/2016 0.75 INTRM2 CEMENT PULD T PJSM-single in the hole f/2666'-3140' 2,666.0 3,140.0 05:45 06:30 MD, 15 joints,PU 97K,SO 83K. 10/19/2016 10/19/2016 0.50 INTRM2 CEMENT TRIP T PJSM-TIH f/3140'-4372'MD with 4" 3,140.0 4,372.0 06:30 07:00 DP from the derrick. 10/19/2016 10/19/2016 2.00 INTRM2 CEMENT QEVL T TIH f/4372'-5482'MD,sonic logging 4,372.0 5,482.0 07:00 09:00 cement stage 2 at 800 fph,PU 157K, SO 99K. Page 48/58 Report Printed: 10/31/2016 C; Operations Summary (with Timeloggepths) 0 2S-09 `tgps Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time PTX Operation (MKS) End Depth(ftKB) 10/19/2016 10/19/2016 2.50 INTRM2 CEMENT DRLG T PJSM-drill out cement,plug,&stage 5,482.0 5,518.0 09:00 11:30 collar f/5482'-5518'MD at 248 gpm, 1650 psi,FO 6%,40-60 rpm,Tq 7- 10K,PU 161K,SO 100K,ROT 120K. Work through stage collar 6 times. 10/19/2016 10/19/2016 4.00 INTRM2 CEMENT QEVL T TIH f/5518'-7875'MD,sonic logging 5,518.0 7,875.0 11:30 15:30 cement stage 1 at 800 fph,PU 220K, SO 100K,fill pipe every 2000'MD. OA pressure 600 psi @ 12:00 hrs. Kick w/Tripping CRT 153 sec @ 15:00 hrs. 10/19/2016 10/19/2016 1.50 INTRM2 CEMENT CIRC T Circulate&condition for casing test at 7,875.0 7,875.0 15:30 17:00 230 gpm, 1642 psi,FO 7%,40 rpm, Tq 12K,PU 220K,SO 100K,ROT 137K. 10/19/2016 10/19/2016 1.00 INTRM2 CEMENT PRTS T PJSM-rig up to test casing.Test 7- 7,875.0 7,875.0 17:00 18:00 5/8"casing to 3500 psi,for 30 minutes charted.Pressure up with 43 strokes. Shut in&observe pressure decrease from 3590 psi to 3490 psi in 30 minutes.Pumped 4.4 bbls&bled back 4.3 bbls.Rig down&blow down test equipment. 10/19/2016 10/19/2016 0.50 INTRM2 CEMENT COCF T PJSM-wash&ream to TOC f/7875'- 7,875.0 7,963.0 18:00 18:30 7963'MD,220 gpm, 1500 psi,FO 9%, 50 rpm,Tq 11-12K. 10/19/2016 10/19/2016 4.25 INTRM2 CEMENT DRLG T Drill out shoe track&rat hole cement 7,963.0 8,138.0 18:30 22:45 f/7963'-8138'MD,230 gpm, 1680 psi,FO 9%,50-60 rpm,Tq 11-12K, WOB 3-7K,BTM of shoe at 8129'MD. 10/19/2016 10/19/2016 0.25 INTRM2 CEMENT DDRL T DDrill 6-3/4"production section f/ 8,138.0 8,158.0 22:45 23:00 8138'-8158'MD,6335'TVD,230 gpm, 1680 psi,FO 11%,60 rpm,Tq 11- 12K,WOB 7-15K, PU 220K,SO 100K, ROT 132K,ADT.25,Bit.25,Jars.25, total footage 20'MD. 10/19/2016 10/20/2016 1.00 INTRM2 CEMENT CIRC T Circulate&condition at 230 gpm, 8,158.0 8,158.0 23:00 00:00 1660 psi,FO 9%,60 rpm,Tq 12K,PU 220K,SO 100K,ROT 132K,2583 strokes.Lay down single&blow down TD. OA pressure 580 psi @ 24:00 hrs. SCR @ 8156'MD,6335'TVD,MW 10.0 ppg,23:45 hrs. #1 @ 30=580;@ 40=850 #2 @ 30=580;@ 40=850 10/20/2016 10/20/2016 1.00 INTRM2 CEMENT FIT T PJSM- lay down a single&rig up for 8,158.0 8,125.0 00:00 01:00 FIT. Perform FIT to an EMW of 13.0 ppg with a 10.0 ppg MW,at 8129'MD, 6333'TVD.Pressure up to 990 psi with 1.2 bbls in 12 strokes.Observe shut in pressure decrease to 900 psi in 10 minutes.Bled back 1.1 bbls.Rig down&blow down all lines. 10/20/2016 10/20/2016 1.25 PROD2 DRILL MPDA T PJSM-remove trip nipple,install RCD 8,125.0 8,158.0 01:00 02:15 bearing,&drain nipple. Break in bearing at 30&60 rpm.SIMOP's PJSM for displacement.Pick up single that is in string. Page 49/58 Report Printed: 10/31/2016 Ill!perations Summary (with Timelogtpths) 2S-09 RFS,. Con occi hii[liipts , Rig: DOYON 142 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(RKS). 10/20/2016 10/20/2016 3.75 PROD2 DRILL DDRL T PJSM-directional drill 6-3/4" 8,158.0 8,429.0 02:15 06:00 production hole section f/8158'-8429' MD,6343'TVD,260 gpm, 1886 psi, FO 10%, 120-140 rpm,Tq on 9-12K, WOB 8-15K,ECD 10.9,Off Bottom 1874 psi,PU 193K,SO 102K,ROT 132K,Tq off 9K, MW 10.0 ppg,Max gas 368, ADT 3.12,Bit 3.37,Jars 3.37,Total Footage 271'MD. SCR @ 8253'MD,6344'TVD,MW 10.0 ppg,03:45 hrs. #1 @ 20=440;@ 30=650 #2 @ 20=420;@ 30=620 10/20/2016 10/20/2016 6.00 PROD2 DRILL DDRL T PJSM-directional drill 6-3/4" 8,429.0 9,106.0 06:00 12:00 production hole section f/8429'-9106' MD,6330'TVD,260 gpm, 1994 psi, FO 10%, 150 rpm,Tq on 11-13K, WOB 15K, ECD 11.13,Off Bottom 1990 psi,PU 193K,SO 100K,ROT 129K,Tq off 11K,MW 10.05 ppg,Max gas 218, ADT 3.95,Bit 7.32,Jars 7.32,Total Footage 667'MD. SCR @ 8821'MD,6332'TVD, MW 10.0 ppg,09:50 hrs. #1 @ 20=460;@ 30=650 #2 @ 20=480;@ 30=660 10/20/2016 10/20/2016 6.00 PROD2 DRILL DDRL T PJSM-directional drill 6-3/4" 9,106.0 9,959.0 12:00 18:00 production hole section f/9106'-9959' MD,6326'TVD,270 gpm,2205 psi, FO 11%, 150160 rpm,Tq on 14K, WOB 15K, ECD 11.23,Off Bottom 2210 psi,PU 191K,SO 99K,ROT 123K,Tq off 11-12K,MW 10.0 ppg, Max gas 357, ADT 3.42,Bit 11.16, Jars 11.16,Total Footage 853'MD. Kick w/Drilling CRT 43 sec @ 20:00 hrs. SCR @ 9484'MD,6323'TVD,MW 10.0+ppg, 14:30 hrs. #1 @20=510;@30=710 #2@20=510;@30=710 10/20/2016 10/21/2016 6.00 PROD2 DRILL DDRL T PJSM-directional drill 6-3/4" 9,959.0 10,812.0 18:00 00:00 production hole section f/9959'- 10812'MD,6329'TVD,271 gpm, 2295 psi,FO 13%, 150 rpm,Tq on 13K,WOB 15K, ECD 11.24,Off Bottom 2290 psi,PU 200K,SO 94K, ROT 126K,Tq off 12K,MW 10.0 ppg, Max gas 396, ADT 3.76,Bit 14.92, Jars 14.92,Total Footage 853'MD. OA pressure 760 psi at 24:00 hrs. SCR @ 10428'MD,6333'TVD, MW 10.0+ppg,21:30 hrs. #1 @ 20=520;@ 30=730 #2 @ 20=540;@ 30=740 Page 50/58 Report Printed: 10/31/2016 • Operations Summary (with Timelog Depths) . .. 2S-09 Rig: DOYON 142 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) 10/21/2016 10/21/2016 6.00 PROD2 DRILL DDRL T PJSM-directional drill 6-3/4" 10,812.0 11,571.0 00:00 06:00 production hole section f/10812'- 11571'MD,6301'TVD,271 gpm, 2385 psi, FO 10%,150 rpm,Tq on 14K,WOB 15K,ECD 11.37,Off Bottom 2380 psi,PU 208K,SO 90K, ROT 127K,Tq off 12.5K,MW 10.0+ ppg,Max gas 1974, ADT 3.97,Bit 18.89,Jars 18.89,Total Footage 759' MD. SCR©11000'MD,6333'TVD, MW 10.0+ppg,01:05 hrs. #1 @ 20=560;@ 30=800 #2 @ 20=560;@ 30=790 SCR @ 11570'MD,6300'TVD,MW 10.0+ppg,05:52 hrs. #1 @ 20=540;@ 30=760 #2 @ 20=540;@ 30=760 10/21/2016 10/21/2016 6.00 PROD2 DRILL DDRL P PJSM-directional drill 6-3/4" 11,571.0 12,259.0 06:00 12:00 production hole section f/11571'- 12259'MD,6296'TVD,271 gpm, 2470 psi,FO 10%, 150 rpm,Tq on 14K,WOB 2-15K, ECD 11.4,Off Bottom 2465 psi,PU 228K,SO 80K, ROT 130K,Tq off 13K, MW 10.0 ppg, Max gas 690, ADT 3.62,Bit 22.51, Jars 22.51,Total Footage 688'MD. OA pressure 700 psi at 12:00 hrs Kick w/Drilling CRT 120 sec @ 11:25 hrs. Trouble time ended at 06:02 hrs at 11584'MD. SCR @ 12130'MD,6299'TVD,MW 10.1 ppg,09:35 hrs. #1 @20=600;@30=810 #2 @ 20=580;@ 30=800 10/21/2016 10/21/2016 6.00 PROD2 DRILL DDRL P PJSM-directional drill 6-3/4" 12,259.0 12,930.0 12:00 18:00 production hole section f/12259'- 12930'MD,6290'TVD,270 gpm, 2650 psi,FO 9%, 160 rpm,Tq on 15K, WOB 15K,ECD 11.55,Off Bottom 2645 psi, PU 234K,SO 92K,ROT 138K,Tq off 13K, MW 10.0 ppg, Max gas 190, ADT 3.98, Bit 26.49,Jars 26.49,Total Footage 671'MD. Page 51/58 Report Printed: 10/31/2016 Aerations Summary (with Timeloggepths) Y ; kms` 2S-09 Conoco tiiitips at:acke ,,. Rig: DOYON 142 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) 10/21/2016 10/22/2016 6.00 PROD2 DRILL DDRL P PJSM-directional drill 6-3/4" 12,930.0 13,533.0 18:00 00:00 production hole section f/12930'- 13533'MD,6298'TVD,270 gpm, 2780 psi, FO 10%, 150 rpm,Tq on 15K,WOB 12K, ECD 11.65,Off Bottom 2760 psi,PU 235K,SO 94K, ROT 141K,Tq off 13.5K,MW 10.0 ppg,Max gas 240, ADT 4.22,Bit 30.71,Jars 30.71,Total Footage 603' MD. OA pressure 920 psi at 24:00 hrs. SCR @ 13421'MD,6295'TVD,MW 10.0 ppg,23:00 hrs. #1 @ 20=660;@ 30=900 #2 @ 20=660;@ 30=900 10/22/2016 10/22/2016 5.00 PROD2 DRILL DDRL P PJSM-directional drill 6-3/4" 13,533.0 14,172.0 00:00 05:00 production hole section f/13533'- 14172'MD,6300'TVD,272 gpm, 2974 psi,FO 10%, 150 rpm,Tq on 16.5K,WOB 15K,ECD 11.61,Off Bottom 2915 psi, PU 254K,SO 95K, ROT 144K,Tq off 14K, MW 10.0 ppg, Max gas 505, ADT 3.32,Bit 34.03, Jars 34.03,Total Footage 639'MD. SCR @ 13976'MD,6296'TVD,MW 10.0+ppg,02:50 hrs. #1 @ 20=700;@ 30=940 #2 @ 20=700;@ 30=930 10/22/2016 10/22/2016 1.00 PROD2 CASING CIRC P CBU at 270 gpm,2870 psi, 130 rpm, 14,172.0 14,172.0 05:00 06:00 Tq 15K,FO 10%,4521 strokes. SCR @ 14172'MD,6299'TVD,MW 10.0+ppg,06:15 hrs. #1 @ 20=620;@ 30=900 #2 @ 20=620;@ 30=900 10/22/2016 10/22/2016 0.25 PROD2 CASING OWFF P Monitor pressure on shut in MPD 14,172.0 14,161.0 06:00 06:15 chokes,no pressure build.SIMOPS lay down working single&drop 2.375" rabbit w/105'of wire. 10/22/2016 10/22/2016 5.50 PROD2 CASING BKRM P PJSM-BROOH f/14161'-12317'MD, 14,161.0 12,363.0 06:15 11:45 272 gpm,2540 psi,FO 10%, 150 rpm, Tq 14K,PU 212K,SO 97K,ROT 127K, 10/22/2016 10/22/2016 1.00 PROD2 CASING BKRM T Take surveys&ream twice to lessen 12,363.0 12,268.0 11:45 12:45 DLS from 12363'-12268'MD at 274 gpm,2580 psi,FO 10%, 150 rpm,Tq 9-12K. OA pressure 880 psi at 12:00 hrs. 10/22/2016 10/22/2016 5.25 PROD2 CASING BKRM P PJSM-BROOH f/12268'-10625'MD, 12,268.0 10,625.0 12:45 18:00 270 gpm,2360 psi,FO 10%, 140 rpm, Tq 13K,ROT 127K,close chokes every 5 stands&monitor for pressure. Work minor tight spots @ 11140', 11020'-10920'MD. 10/22/2016 10/22/2016 5.75 PROD2 CASING BKRM P PJSM-BROOH f/10625'-8162'MD, 10,625.0 8,162.0 18:00 23:45 270 gpm,2110 psi,FO 8%, 140 rpm, Tq 11K,ROT 131K,ECD 10.91,close chokes every 5 stands&monitor for pressure. Page 52/58 Report Printed: 10/31/2016 ,.: ,A.,,,,, , ,,,, e • Operations Summary (with Timelog Depths) 1 5, 2S-09 ConocoPhillips Rig: DOYON 142 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(ftK6) 10/22/2016 10/23/2016 0.25 PROD2 CASING BKRM P BROOH into the intermediate shoe f/ 8,162.0 8,027.0 23:45 00:00 8162'-8067'MD,220 gpm, 1520 psi, FO 6%,80 rpm,Tq 10K.6 bbls losses for entire back ream to the shoe. OA pressure 820 psi at 24:00 hrs. 10/23/2016 10/23/2016 2.00 PROD2 CASING CIRC P Circulate 2 BU at 8027'MD 8,027.0 8,027.0 00:00 02:00 intermediate shoe,220 gpm, 1500 psi, FO 9%,80 rpm,PU 179K,SO 112K, ROT 136K,4950 strokes. 10/23/2016 10/23/2016 0.75 PROD2 CASING OWFF P Monitor well to static with slight drop. 8,027.0 8,027.0 02:00 02:45 SIMOPs blow down top drive. 10/23/2016 10/23/2016 7.00 PROD2 CASING SMPD P PJSM-strip out of the hole w/MPD f/ 8,027.0 392.0 02:45 09:45 8027'-392'MD, PU 52K,SO 54K, Calculated fill 44 bbls,actual 66 bbls. Retrieve rabbit from top of jars. Spill Drill CRT 120 sec @ 05:52 hrs. 10/23/2016 10/23/2016 0.25 PROD2 CASING OWFF P Monitor well,static.SIMOPs PJSM to 392.0 392.0 09:45 10:00 remove RCD. 10/23/2016 10/23/2016 1.25 PROD2 CASING MPDA P Remove drain nipple&RCD. Install 392.0 392.0 10:00 11:15 trip nipple&line up.Clear&clean rig floor. 10/23/2016 10/23/2016 3.75 PROD2 CASING BHAH P PJSM-lay down BHA8 f/392'to 392.0 0.0 11:15 15:00 surface, as per SLB DD.Clear& clean rig floor. Bit grade 1,2,BT,A,X, 1,CT,TD. OA pressure 0 psi at 12:00 hrs. 10/23/2016 10/23/2016 1.50 COMPZN CASING RURD P PJSM-rig up casing equipment to run 0.0 0.0 15:00 16:30 4-1/2"liner. 10/23/2016 10/24/2016 7.50 COMPZN CASING PUTB P PJSM-RIH with 4-1/2", 12.6#,L-80, 0.0 4,350.0 16:30 00:00 TenarisXP BTC-M,liner per detail to 4350'MD.Ran 97 joints,shoe joint, float collar joint,an WIV,an Alpha sleeve,Frac sleeves 1-7,9 swell packers, 108 Hydroform centralizers& 13 stop rings. OA pressure 0 psi at 24:00 hrs. 10/24/2016 10/24/2016 3.00 COMPZN CASING PUTB P PJSM-RIH with 4-1/2", 12.6#,L-80, 4,350.0 6,170.0 00:00 03:00 TenarisXP BTC-M,liner per detail f/ 4350'-6170'MD. Ran a total of 139 joints, 10 Frac sleeves, 12 swell packers, 153 Hydroform centralizers& 16 stop rings.PU 121K,SO 91K.No remakes or rejected 4-1/2"liner. 10/24/2016 10/24/2016 0.25 COMPZN CASING RURD P PJSM-change out handling 6,170.0 6,170.0 03:00 03:15 equipment to pick up liner hanger/packer. 10/24/2016 10/24/2016 0.50 COMPZN CASING OTHR P PJSM-make up HRD-E ZXP liner top 6,170.0 6,213.0 03:15 03:45 hanger/packer&XO to 1 stand of 4" DP as per Baker Rep. 10/24/2016 10/24/2016 1.00 COMPZN CASING CIRC P Circulate liner volume at 129 gpm,367 6,213.0 6,213.6- 03:45 04:45 psi,FO 6%.SIMOPS mix&fill liner top with Pal-Mix.Clear rig floor of casing handling equipment. 10/24/2016 10/24/2016 1.25 COMPZN CASING RUNL P PJSM-TIH with liner on drill pipe f/ 6,213.0 8,103.0 04:45 06:00 6213'-8103'MD,PU 148K,SO 101K. 10/24/2016 10/24/2016 2.00 COMPZN CASING CIRC P Circulate surface to surface at 129 8,103.0 8,103.0 06:00 08:00 gpm,448 psi, FO 6%.SIMOPS PJSM to install RCD bearing. 10/24/2016 10/24/2016 0.25 COMPZN CASING OWFF P Monitor well,static.Blow down top 8,103.0 8,103.0 08:00 08:15 drive. Page 53/58 Report Printed: 10/31/2016 • Operations Summary (with TimelogDepths) 0,14 44 2S-09 ConocoPhiiiips afxxl::e , Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth {ftK6} End Depth(ftKB)'. 10/24/2016 10/24/2016 0.75 COMPZN CASING MPDA P Remove trip nipple&install RCD 8,103.0 8,103.0 08:15 09:00 bearing with drain nipple. 10/24/2016 10/24/2016 7.00 COMPZN CASING RUNL P PJSM-obtain parameters at the shoe 8,103.0 14,163.0 09:00 16:00 PU 153K,SO 96K,ROT w/SO 110K, 30 rpm,Tq 6.5K.TIH w/4-1/2"liner on DP f/8103'-14163'MD,PU 230K,SO 111K. OA pressure 0 psi at 12:00 hrs. 10/24/2016 10/24/2016 0.75 COMPZN CASING CIRC P PJSM-establish circulation at 1 bpm, 14,163.0 14,163.0 16:00 16:45 540 psi.Tag bottom at 14172'MD w/ 5K,pick 7 set on depth at 14163'MD. Continue circulating liner volume at 3 bpm,848 psi,FO 7%. 10/24/2016 10/24/2016 0.75 COMPZN CASING CIRC P PJSM-pump down 1.5"ball at 3 bpm, 14,163.0 14,163.0 16:45 17:30 856 psi FO 6%. Ball on seat with 1373 strokes.Pressure up to 1500 psi to shut the WIV. 10/24/2016 10/24/2016 0.75 COMPZN CASING PACK P PJSM-pressure up to 2100 psi to set 14,163.0 7,999.0 17:30 18:15 liner hanger.Slack off to 50K to verify hanger set.Pressure up to 3500 psi to release from liner top.Not released. Pressure up to 3700 psi&bleed off, PU to 230K&SO to 50K(not released).Apply 2 wraps to the left& work string.Release torque&pick up to observe PU at 205K,released. Rotate at 20 rpm,ROT 158K,slack off to 40K w/rotary,set liner top packer. Pick up&lay down single.Liner top at 7955'MD. 10/24/2016 10/24/2016 0.75 COMPZN CASING PRTS P PJSM-rig up&test liner top packer 7,999.0 7,999.0 18:15 19:00 down the IA to 3000 psi for 10 minutes,charted.Rig down test equipment. 10/24/2016 10/24/2016 1.75 COMPZN WELLPR DISP P PJSM-displace well to 8.34 ppg sea 7,999.0 7,999.0 19:00 20:45 water at 6 bpm,968 psi,FO 8%. 10/24/2016 10/24/2016 1.50 COMPZN WELLPR CIRC P CBU 2X at 9 bpm, 1840 psi,FO 13%, 7,999.0 7,936.0 20:45 22:15 lay down 2 singles to 7936'MD. 10/24/2016 10/24/2016 0.50 COMPZN WELLPR OWFF P Close chokes to observe no pressure 7,936.0 7,936.0 22:15 22:45 increase.Flow check,static.Monitor well,static.SIMOP's pull drain nipple &rig up to remove RCD. 10/24/2016 10/25/2016 1.25 COMPZN WELLPR MPDA P PJSM-remove RCD,install trip nipple, 7,936.0 7,936.0 22:45 00:00 blow down&disconnect lines.Clean &lay down bearing,drain nipple,& stand.Blow down TD. OA pressure 300 psi at 24:00 hrs. 10/25/2016 10/25/2016 2.50 COMPZN WELLPR SLPC P Slip/cut 117'drill line,service top 7,936.0 7,936.0 00:00 02:30 drive,blocks,crown,and drawworks. 10/25/2016 10/25/2016 0.50 COMPZN WELLPR OWFF P Observe well out of balance-monitor 7,936.0 7,936.0 02:30 03:00 well. 10/25/2016 10/25/2016 1.00'COMPZN WELLPR CIRC P Circulate drill pipe volume at 422 gpm, 7,936.0 7,936.0 03:00 04:00 2218 psi, 14%F/O-observe well out of balance.Circulate 1 x bottoms up @ 422 gpm,2138 psi, 14%F/O. Observe well static. 10/25/2016 10/25/2016 4.50 COMPZN WELLPR PULD P Pull OOH sideways f/7936'-2138' 7,936.0 2,138.0 04:00 08:30 laying out 4"HWDP,PUW 131k,SOW 98k.Monitor displacement on trip tank. Page 54/58 Report Printed: 10/31/2016 110 Operations Summary (with Timelog epths) 1uthps 2S-09 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKE)' 10/25/2016 10/25/2016 2.50 COMPZN WELLPR PULD P Pull OOH sideways f/2138'-54' 2,138.0 54.0 08:30 11:00 laying out 4"DP.Monitor displacement on trip tank. 10/25/2016 10/25/2016 0.75 COMPZN WELLPR PULD P Pull OOH f/54'to surface and lay 54.0 0.0 11:00 11:45 down liner running tool-observed good shear indication on dog sub. 10/25/2016 10/25/2016 4.25 COMPZN WELLPR PULD P Lay down 34 x stands 4"DP using 0.0 0.0 11:45 16:00 mouse hole. Note-leave total of 65 x stands 4"DP racked back in derrick for rig move to 2S-13. 10/25/2016 10/25/2016 1.25 COMPZN RPCOMP WWWH P M/U stack washer and wash wellhead. 0.0 0.0 16:00 17:15 Pull wear ring. 10/25/2016 10/25/2016 0.50 COMPZN RPCOMP OTHR P Pick up D-Nipple w/RHC plug body, 0.0 0.0 17:15 17:45 install ball&rod,and fill with fresh water to test for leaks-no leaks observed.Remove ball and rod and lay down D-nipple. 10/25/2016 10/25/2016 2.25 COMPZN RPCOMP RURD P Rig up to run 3-1/2"upper completion. 0.0 0.0 17:45 20:00 Change out handling equipment to 3- 1/2",Mobilize cannon clamps and SLB tools to rig floor, Hang I-wire sheave in derrick,rig up spooler,and test I-wire. 10/25/2016 10/25/2016 0.25 COMPZN RPCOMP SFTY P Hold PJSM for running 3-1/2"upper 0.0 0.0 20:00 20:15 completion. 10/25/2016 10/25/2016 0.75 COMPZN RPCOMP PUTB P Run 3.5",9.3#,L-80,EUE 8RD Mod, 0.0 130.0 20:15 21:00 R2 completion tubing as per detail f/0- 130'MD.Pick up WLEG w/No-Go Sub, 1 x joint tubing,D nipple w/RHC, Premier packer,and Gauge carrier. M/U torque 2240 ft-lbs. 10/25/2016 10/25/2016 1.00 COMPZN RPCOMP PRTS P Install gauge and I-wire cable. 130.0 130.0 21:00 22:00 Pressure test gauge carrier to 5000 psi for 5 minutes.Test electrical function as per Cameo rep-good test. 10/25/2016 10/26/2016 2.00 COMPZN RPCOMP PUTB P Run 3.5",9.3#,L-80,EUE 8RD Mod, 130.0 1,042.0 22:00 00:00 R2 completion tubing as per detail f/ 130'-1042'MD,allowing pipe to self fill and monitoring displacement on trip tank.Make up CMU in closed position and GLM w/SOV for 2500psi casing- tubing shear.Install 1 x cannon clamp on every collar and mid-joint protectors below and above GLM's. OA pressure=0 psi 10/26/2016 10/26/2016 6.00 COMPZN RPCOMP PUTB P Run 3.5",9.3#,L-80,EUE 8RD Mod, 1,042.0 4,564.0 00:00 06:00 R2 completion tubing as per detail f/ 1042'-4564'MD,allowing pipe to self fill and monitoring displacement on trip tank. Make up 2 x GLM with dummy valves. Install 1 x cannon clamp on every collar and mid-joint protectors below and above GLM's.PUW 85k, SOW 76k.Test I-wire every 2000'. Page 55/58 Report Printed: 10/31/2016 410 at 0 Operations Summary (with Timelo a the 9 p ) 2S-09 Corso illips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(lir) Phase Op Code Activity Code Time P-T x Operation (ftKE) End Depth(ttKB) 10/26/2016 10/26/2016 6.00 COMPZN RPCOMP PUTB P Run 3.5"9.3#, L-80 EUE 8RD Mod R2 4,564.0 7,988.0 06:00 12:00 completion tubing as per detail f/4564' MD to No-Go @ 7958'MD(muleshoe @ 7988'),allowing pipe to self fill and monitoring displacement on trip tank. Sting into top of liner and set down on shear out sub,observed sub shear @ 14k down.Mark pipe and obtain space out measurements. Install 1 x cannon clamp on every collar.Test I-wire every 2000'.PUW 125k,SOW 84k. 3-1/2"Cross coupling clamps=248 3-1/2"Cross coupling mid clamps=8 3-1/2"x 4-1/2"Cross over clamp= 1 4-1/2"Cross coupling clamp= 1 4-1/2"Cross coupling mid clamp=1 Stainless steel bands=2 on CMU Total for tubing run. 10/26/2016 10/26/2016 1.75 COMPZN RPCOMP HOSO P Space out,L/D 3 joints of 3-1/2"EUE 7,988.0 7,945.0 12:00 13:45 tubing,M/U 3-1/2"EUE pup(2.26'),3- 1/2"EUE X 4-1/2"IBTM XO,and 1 joint of 4-1/2"IBTM tubing. Space out to be 3.51'above fully located. 10/26/2016 10/26/2016 1.00 COMPZN RPCOMP THGR P M/U CIW hanger and landing joint, 7,945.0 7,945.0 13:45 14:45 install bail extensions,XO,head pin, and cement line hose. 10/26/2016 10/26/2016 2.00 COMPZN RPCOMP THGR P Feed I-wire through hanger,terminate 7,945.0 7,979.0 14:45 16:45 as per SLB rep and test wire and down hole gauge-good test. 10/26/2016 10/26/2016 0.75 COMPZN RPCOMP CRIH P Pump 53 bbls of corrosion-inhibited 7,979.0 7,979.0 16:45 17:30 seawater and chase w/68 bbls of neat seawater @ 4bpm,235psi,placing corrosion inhibited brine in annulus from top of liner @ 7958'MD to 6400' MD(above GLM#2). 10/26/2016 10/26/2016 0.75 COMPZN RPCOMP THGR P Land hanger, PUW 128k,SOW 87k. 7,979.0 7,984.9 17:30 18:15 RILDS.Test hanger void to 5000 psi for 15 minutes,CPAI witnessed.Drop ball&rod. 10/26/2016 10/26/2016 2.75 COMPZN RPCOMP PRTS P Pressure up tubing(setting packer at 7,984.9 0.0 18:15 21:00 1600 psi)to 4000 psi with mud pump &test for 30 minutes on chart-good test. Bleed tubing to 2300 psi. Pressure up IA to 4000 psi(tubing pressure increase to 2750 psi)&test for 30 minutes on chart-good test. Bleed off IA and then tubing pressure to 0 psi.Pressure up IA and shear SOV at 2570 psi.Observe communication verifying positive shear at 1 bpm, 125 psi.Observe well for 5 minutes-well static. Note:Rig changed mud pump pop- offs to 4500 psi prior to testing. Page 56/58 Report Printed: 10/31/2016 V Operations Summary (with TimeloRepths) ,..: - 2S-09 hili Rig: DOYON 142 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) 10/26/2016 10/26/2016 0.50 COMPZN RPCOMP RURD P Blow/rig down circulating lines. Lay 0.0 0.0 21:00 21:30 down landing joint&remove bale extensions. I 10/26/2016 10/26/2016 1.25 COMPZN WHDBOP MPSP P Install 4"type HP BPV.Test BPV and 0.0 0.0 21:30 22:45 tubing hanger in the direction of flow to 2500 psi for 30 minutes,charted- good test. 10/26/2016 10/26/2016 0.50 COMPZN WHDBOP OWFF P Monitor well,static.SIMOPS prep for 0.0 0.0 22:45 23:15 nipple down of MPD and BOPE. 10/26/2016 10/27/2016 0.75 COMPZN WHDBOP MPDA P Lay out trip nipple and nipple down 0.0 0.0 23:15 00:00 MPD equipment on stack. 10/27/2016 10/27/2016 2.00 COMPZN WHDBOP MPDA P Nipple down RCD head,Air valve,and 0.0 0.0 00:00 02:00 choke lines.Stage RCD head in mezzanine deck. 10/27/2016 10/27/2016 3.00 COMPZN WHDBOP NUND P Nipple down BOPE and adapter 0.0 0.0 02:00 05:00 spools.Perform between-well- maintenance on annular. Rack back BOPE stack on stump and secure same. 10/27/2016 10/27/2016 6.50 COMPZN WHDBOP THGR P Clean&prep top of hanger. Run I-wire 0.0 0.0 05:00 11:30 through adapter spool,install&test- note control line block had to be swapped out for spare.Set adapter spool&torque studs.Test hanger void to 250/5000 psi for 15 minutes,CPAI witnessed-good test.Test SRL seals to 10,000 psi for 15 minutes,CPAI witnessed-good test.Terminate(- wire as per Camco and test line-good test.SIMOPS perform BWM on BOPE. Note:Rig swap from hi-line to generator power at 08:00 hrs. 10/27/2016 10/27/2016 3.25 COMPZN WHDBOP NUND P Nipple up tree,install wing valves. 0.0 0.0 11:30 14:45 SIMOPS complete BWM and disconnect interconnect lines between modules. 10/27/2016 10/27/2016 1.25 COMPZN WHDBOP PRTS P Fill tree with diesel&test to 250 psi for 0.0 0.0 14:45 16:00 5 min,5000 psi for 15 min.Switch over to Cameron and test to 10,000 psi for 15 min,CPAI witnessed-good tests. 10/27/2016 10/27/2016 2.75 COMPZN WHDBOP MPSP P Remove test dart and attempt to pull 0.0 0.0 16:00 18:45 BPV with dry rod-observed pressure below BPV with annulus on vacuum. Rig up lubricator and pressure test to 2000. Pull BPV.R/D lubricator. 10/27/2016 10/27/2016 1.00 COMPZN WHDBOP RURD P Rig up to freeze protect,taking returns 0.0 0.0 18:45 19:45 directly to cuttings tank. 10/27/2016 10/27/2016 1.25 COMPZN WHDBOP FRZP P Hold PJSM with crews and freeze 0.0 0.0 19:45 21:00 protect well.Pressure test lines to 250/2500 psi.Pump 90 bbls of diesel down the IA,taking returns from the tubing to cuttings tank. Pump at 3 bpm,ICP 900 psi,FCP 1200 psi. 10/27/2016 10/27/2016 1.25 COMPZN WHDBOP FRZP P Allow well to U-tube.SIMOPS clean 0.0 0.0 21:00 22:15 cellar and lay down skate ramp. Page 57/58 Report Printed: 10/31/2016 0 i • .a Operations Summary (with Timelog Depths) 2S-09 Conoco Phillips Rig: DOYON 142 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) 10/27/2016 10/27/2016 1.25 COMPZN WHDBOP MPSP P Rig up lubricator,pressure test to 0.0 0.0 22:15 23:30 2000 psi,and install 4",type H BPV. R/D and lay out lubricator. 10/27/2016 10/28/2016 0.50 DEMOB MOVE MOB P Secure well and install gauges. Final 0.0 0.0 23:30 00:00 pressures are 0 psi on tubing,40 psi on IA,and 200 psi on OA.SIMOPS prep for rig move to 2S-13. Rig release at 24:00 hrs. Page 58/58 Report Printed: 10/31/2016 • • NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-09A Definitive Survey Report 26 October, 2016 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(DoyonVV Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonl2 Well: 2S-09 North Reference: "` True Wellbore: 2S-09A Survey Calculation Method: Minimum Curvature Design: 2S-09A 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-09 Well Position +NI-S 0.00 usft Northing: 5,929,986.08 usft Latitude: 70°13'11.559 N +E/-W 0.00 usft Easting: 481,074.22 usft Longitude: 150°9'9.654 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore 2S-09A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGG M2016 10/1/2016 17.80 80.84 57,533 Design 2S-09A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 2,800.11 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (usft) (usft) (usft) (°) 39.10 0.00 0.00 15.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date , 60.00 835.50 2S-09 Srvy 1-SLB_NSG+MSHOT(2S-0 GYD-GC-MS Gyrodata gyrocompassing m/s 9/14/2016 9:02: 858.68 2,088.06 2S-09 Srvy 2-SLB_MWD+GMAG(2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/14/2016 9:05: 2,184.78 2,758.43 2S-09 Srvy 3-SLB_MWD+GMAG(2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/15/2016 9:05: 2,800.11 2,800.11 2S-09 Srvy 4-SLB_Inc+Filler(2S-09) INC+TREND Inclinometer+known azi trend 9/19/2016 9:33: 2,891.95 8,073.22 2S-09A Srvy 1-SLB_MWD+GMAG(2S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/11/2016 8:10 8,098.11 8,098.11 2S-09A Srvy 2-SLB_Inc+Filler(2S-09A) INC+TREND Inclinometer+known azi trend 10/19/2016 11:41 8,192.63 14,112.54 2S-09A Srvy 3-SLB_MWD+GMAG(2S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/19/2016 11:2, Survey Map Map Vertical MD Inc Azi TVD TVDSS 011-$ +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) 01001 (ft) Survey Tool Name 2,800.11 31.87 180.00 2,577.48 2,418.38 -922.97 17.40 5,929,063.16 481,089.31 0.49 -887.02 INC+TREND(4) 2,822.00 31.73 181.04 2,596.08 2,436.98 -934.51 17.30 5,929,051.62 481,089.17 2.58 -898.19 MWD+IFR-AK-CAZ-SC(5) 10-314"x-13-1/2" 2,891.95 31.33 184.40 2,655.71 2,496.61 -971.03 15.57 5,929,015.11 481,087.36 2.58 -933.92 MWD+IFR-AK-CAZ-SC(5) 2,987.36 28.70 185.70 2,738.32 2,579.22 -1,018.57 11.39 5,928,967.59 481,083.06 2.84 -980.91 MWD+IFR-AK-CAZ-SC(5) 3,082.49 28.79 200.88 2,821.84 2,662.74 -1,062.76 0.95 5,928,923.43 481,072.50 7.66 -1,026.30 MWD+IFR-AK-CAZ-SC(5) 3,177.56 30.27 207.27 2,904.58 2,745.48 -1,105.46 -18.20 5,928,880.78 481,053.25 3.66 -1,072.50 MWD+IFR-AK-CAZ-SC(5) 3,271.74 28.84 202.81 2,986.51 2,827.41 -1,147.51 -37.88 5,928,838.79 481,033.46 2.79 -1,118.21 MWD+IFR-AK-CAZ-SC(5) 3,367.16 29.15 194.65 3,070.00 2,910.90 -1,191.22 -52.69 5,928,795.11 481,018.55 4.16 -1,164.27 MWD+IFR-AK-CAZ-SC(5) 10/26/2016 1:24:06PM Page 2 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonl4 Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyon1d Well: 2S-09 North Reference: True Wellbore: 2S-09A Survey Calculation Method: Minimum Curvature Design: 2S-09A 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) (0/100) (ft) Survey Tool Name 3,462.05 31.36 186.38 3,152 00 2,992 90 -1,238.14 -61.28 5,928,748 22 481,009.84 4.97 -1,211.82 MWD+1FR-AK-CAZ-SC(5) 3,556.27 34.48 179.41 3,231.11 3,072.01 -1,289.21 -63.73 5,928,697.16 481,007.26 5.20 -1,261.78 MWD+IFR-AK-CAZ-SC(5) 3,652.10 37.21 173.55 3,308.81 3,149.71 -1,345.15 -60.20 5,928,641.22 481,010.66 4.57 -1,314.90 MWD+IFR-AK-CAZ-SC(5) 3,745.92 39.54 170.38 3,382.36 3,223.26 -1,402.80 -52.02 5,928,583.56 481,018.69 3.25 -1,368.46 MWD+1FR-AK-CAZ-SC(5) 3,839.60 40.52 170.59 3,454.09 3,294.99 -1,462.22 -42.06 5,928,524.11 481,028.50 1.06 -1,423.29 MWD+IFR-AK-CAZ-SC(5) 3,934.28 40.77 175.14 3,525.95 3,366.85 -1,523.38 -34.41 5,928,462.94 481,035.99 3.14 -1,480.38 MWD+1FR-AK-CAZ-SC(5) 4,029.62 40.79 180.15 3,598.16 3,439.06 -1,585.56 -31.85 5,928,400.76 481,038.39 3.43 -1,539.78 MWD+IFR-AK-CAZ-SC(5) 4,124.84 38.06 179.09 3,671.71 3,512.61 -1,646.02 -31.47 5,928,340.30 481,038.63 2.95 -1,598.08 MWD+IFR-AK-CAZ-SC(5) 4,218.95 35.60 178.15 3,747.03 3,587.93 -1,702.41 -30.12 5,928,283.92 481,039.83 2.68 -1,652.20 MWD+IFR-AK-CAZ-SC(5) 4,313.76 32.76 174.22 3,825.46 3,666.36 -1,755.53 -26.65 5,928,230.79 481,043.17 3.79 -1,702.61 MWD+IFR-AK-CAZ-SC(5) 4,408.96 29.90 171.22 3,906.78 3,747.68 -1,804.62 -20.43 5,928,181.69 481,049.27 3.42 -1,748.42 MWD+IFR-AK-CAZ-SC(5) 4,503.92 27.21 167.19 3,990.19 3,831.09 -1,849.20 -12.00 5,928,137.10 481,057.58 3.48 -1,789.29 MVVD+IFR-AK-CAZ-SC(5) 4,598.33 24.29 163.31 4,075.22 3,916.12 -1,888.86 -1.64 5,928,097.42 481,067.85 3.57 -1,824.92 MWD+IFR-AK-CAZ-SC(5) 4,691.66 21.22 158.20 4,161.28 4,002.18 -1,922.94 10.15 5,928,063.31 481,079.55 3.91 -1,854.79 MWD+IFR-AK-CAZ-SC(5) 4,786.96 17.66 153.42 4,251.14 4,092.04 -1,951.89 23.03 5,928,034.33 481,092.36 4.09 -1,879.42 MWD+IFR-AK-CAZ-SC(5) 4,881.25 15.32 146.03 4,341.56 4,182.46 -1,975.02 36.39 5,928,011.17 481,105.66 3.33 -1,898.30 MWD+IFR-AK-CAZ-SC(5) 4,976.21 13.71 137.57 4,433.49 4,274.39 -1,993.73 51.00 5,927,992.43 481,120.21 2.80 -1,912.60 MWD+IFR-AK-CAZ-SC(5) 5,071.02 12.27 127.18 4,525.89 4,366.79 -2,008.11 66.61 5,927,978.01 481,135.79 2.89 -1,922.45 MWD+IFR-AK-CAZ-SC(5) 5,165.69 10.78 111.53 4,618.67 4,459.57 -2,017.44 82.86 5,927,968.63 481,152.02 3.64 -1,927.26 MWD+1FR-AK-CAZ-SC(5) 5,260.40 10.97 93.81 4,711.71 4,552.61 -2,021.30 100.10 5,927,964.74 481,169.24 3.52 -1,926.51 MWD+IFR-AK-CAZ-SC(5) 5,354.91 12.68 77.54 4,804.23 4,645.13 -2,019.65 119.21 5,927,966.33 481,188.35 3.95 -1,919.98 MWD+IFR-AK-CAZ-SC(5) 5,450.01 14.53 63.39 4,896.68 4,737.58 -2,012.06 140.07 5,927,973.88 481,209.23 3.99 -1,907.24 MWD+IFR-AK-CAZ-SC(5) 5,544.46 17.05 54.08 4,987.58 4,828.48 -1,998.62 161.89 5,927,987.26 481,231.08 3.78 -1,888.62 MWD+IFR-AK-CAZ-SC(5) 5,639.28 20.66 49.48 5,077.30 4,918.20 -1,979.59 185.87 5,928,006.23 481,255.11 4.11 -1,864.03 MWD+IFR-AK-CAZ-SC(5) 5,734.93 23.32 46.57 5,165.99 5,006.89 -1,955.61 212.45 5,928,030.14 481,281.75 3.00 -1,833.99 MWD+IFR-AK-CAZ-SC(5) 5,829.03 25.52 43.04 5,251.67 5,092.57 -1,927.98 239.82 5,928,057.69 481,309.18 2.80 -1,800.22 MWD+IFR-AK-CAZ-SC(5) 5,924.55 27.48 38.22 5,337.16 5,178.06 -1,895.62 267.50 5,928,089.98 481,336.94 3.04 -1,761.80 MWD+IFR-AK-CAZ-SC(5) 6,019.37 28.99 33.43 5,420.70 5,261.60 -1,859.25 293.70 5,928,126.28 481,363.23 2.87 -1,719.89 MWD+IFR-AK-CAZ-SC(5) 6,113.72 32.13 29.21 5,501.95 5,342.85 -1,818.26 318.55 5,928,167.21 481,388.18 4.03 -1,673.86 MWD+IFR-AK-CAZ-SC(5) 6,208.82 35.40 24.54 5,581.01 5,421 91 -1,771.11 342.34 5,928,214.30 481,412.08 4.39 -1,622.15 MWD+IFR-AK-CAZ-SC(5) 6,302.70 39.17 20.21 5,655.70 5,496.60 -1,718.52 363.89 5,928,266.82 481,433.76 4.89 -1,565.78 MWD+IFR-AK-CAZ-SC(5) 6,398.47 42.70 19.69 5,728.04 5,568.94 -1,659.54 385.28 5,928,325.74 481,455.30 3.70 -1,503.28 MWD+IFR-AK-CAZ-SC(5) 6,492.86 44.87 18.59 5,796.18 5,637.08 -1,597.84 406.69 5,928,387.38 481,476.86 2.44 -1,438.14 MWD+IFR-AK-CAZ-SC(5) 6,587.25 49.28 18.66 5,860.45 5,701.35 -1,532.36 428.76 5,928,452.80 481,499.09 4.67 -1,369.18 MWD+IFR-AK-CAZ-SC(5) 6,681.66 52.72 18.66 5,919.86 5,760.76 -1,462.86 452.23 5,928,522.24 481,522.73 3.64 -1,295.97 MWD+IFR-AK-CAZ-SC(5) 6,776.71 56.06 18.73 5,975.19 5,816.09 -1,389.67 476.99 5,928,595.36 481,547.68 3.51 -1,218.86 MWD+IFR-AK-CAZ-SC(5) 6,870.31 59.21 18.66 6,025.29 5,866.19 -1,314.79 502.33 5,928,670.16 481,573.20 3.37 -1,139.98 MWD+IFR-AK-CAZ-SC(5) 6,964.77 61.98 18.23 6,071.66 5,912.56 -1,236.73 528.36 5,928,748.15 481,599.43 2.96 -1,057.84 MWD+IFR-AK-CAZ-SC(5) 7,059.78 64.54 17.80 6,114.41 5,955.31 -1,156.05 554.60 5,928,828.76 481,625.86 2.72 -973.12 MWD+IFR-AK-CAZ-SC(5) 7,154.57 68.43 15.91 6,152.23 5,993.13 -1,072.88 579.77 5,928,911.86 481,651.24 4.49 -886.27 MVVD+IFR-AK-CAZ-SC(5) 10/26/2016 1 24'06PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 25-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyon 1z Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyon 1z Well: 2S-09 North Reference: True Wellbore: 2S-09A Survey Calculation Method: Minimum Curvature Design: 2S-09A Database: OAKEDMP2 Survey • Map Map Vertical MD Inc, Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (1 (1 (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,249.07 72.21 15.79 6,184.04 6,024.94 -987.30 604.07 5,928,997.37 481,675.75 4.00 -797 31 MWD+IFR-AK-CAZ-SC(5) 7,344.90 75.89 15.55 6,210.37 6,051.27 -898.60 628.95 5,929,086.00 481,700.85 3.85 -705.20 MWD+IFR-AK-CAZ-SC(5) 7,439.56 79.46 14.32 6,230.58 6,071.48 -809.26 652.77 5,929,175.27 481,724.90 3.98 -612.73 MWD+IFR-AK-CAZ-SC(5) 7,534.10 80.63 14.40 6,246.92 6,087.82 -719.05 675.87 5,929,265.41 481,748.21 1.24 -519.62 MVVD+IFR-AK-CAZ-SC(5) 7,629.97 80.66 14.19 6,262.50 6,103.40 -627.39 699.22 5,929,357.00 481,771.80 0.22 -425.04 MVVD+IFR-AK-CAZ-SC(5) 7,725.44 80.76 14.09 6,277.92 6,118.82 -536.02 722.24 5,929,448.30 481,795.04 0.15 -330.83 MWD+IFR-AK-CAZ-SC(5) 7,820.23 80.55 13.44 6,293.31 6,134.21 -445.18 744.49 5,929,539.08 481,817.52 0.71 -237.32 MWD+IFR-AK-CAZ-SC(5) 7,914.91 81.08 13.12 6,308.42 6,149.32 -354.21 765.96 5,929,629.98 481,839.22 0.65 -143.90 MWD+IFR-AK-CAZ-SC(5) 8,010.14 83.03 13.57 6,321.58 6,162.48 -262.45 787.73 5,929,721.68 481,861.21 2.10 -49.63 MWD+IFR-AK-CAZ-SC(5) 8,073.22 84.76 14.18 6,328.29 6,169.19 -201.56 802.77 5,929,782.53 481,876.41 2.91 13.08 MWD+IFR-AK-CAZ-SC(5) 8,098.11 84.99 13.81 6,330.52 6,171.42 -177.50 808.77 5,929,806.57 481,882.46 1.75 37.87 INC+TREND(6) 8,129.00 85.31 12.98 6,333.13 6,174.03 -147.56 815.90 5,929,836.49 481,889 66 2.88 68.64 MWD+IFR-AK-CAZ-SC(7) 7-5/8"x 9-7/8 by 11" 8,192.63 85.97 11.26 6,337.97 6,178.87 -85.53 829.22 5,929,898 48 481,903.14 2.88 132.00 MWD+IFR-AK-CAZ-SC(7) 8,287.53 89.18 11.28 6,341.98 6,182.88 7.44 847.74 5,929,991.40 481,921.90 3.38 226.60 MWD+IFR-AK-CAZ-SC(7) 8,382.86 91.73 11.97 6,341.22 6,182.12 100.81 866.95 5,930,084.70 481,941.33 2.77 321.75 MWD+IFR-AK-CAZ-SC(7) 8,477.27 91.89 11.85 6,338.24 6,179.14 193.14 886.42 5,930,176.97 481,961.04 0.21 415.98 MWD+IFR-AK-CAZ-SC(7) 8,572.31 91.30 11.81 6,335.60 6,176.50 286.12 905.90 5,930,269.90 481,980.75 0.62 510.84 MWD+IFR-AK-CAZ-SC(7) 8,666.18 90.65 11.56 6,334.00 6,174.90 378.03 924.91 5,930,361.75 481,999.98 0.74 604.54 MW1J+IFR-AK-CAZ-SC(7) 8,760.98 90.38 11.71 6,333.15 6,174.05 470.88 944.03 5,930,454.55 482,019.33 0.33 699.17 MVVD+IFR-AK-CAZ-SC(7) 8,855.91 90.34 11.48 6,332.55 6,173.45 563.87 963.11 5,930,547.48 482,038.64 0.25 793.93 MWD+IFR-AK-CAZ-SC(7) 8,951.42 90.58 10.51 6,331.78 6,172.68 657.62 981.32 5,930,641.18 482,057.09 1.05 889.20 MWD+IFR-AK-CAZ-SC(7) 9,045.82 90.82 10.63 6,330.63 6,171.53 750.42 998.64 5,930,733.91 482,074.64 0.28 983.31 MWD+IFR-AK-CAZ-SC(7) 9,138.92 90.62 10.17 6,329.46 6,170.36 841.98 1,015.44 5,930,825.43 482,091.67 0.54 1,076.10 MWD+IFR-AK-CAZ-SC(7) 9,234.56 90.69 10.51 6,328.37 6,169.27 936.06 1,032.61 5,930,919.45 482,109.07 0.36 1,171.42 MWD+IFR-AK-CAZ-SC(7) 9,329.61 91.17 9.87 6,326.82 6,167.72 1,029.60 1,049.42 5,931,012.94 482,126.12 0.84 1,266.12 MWD+IFR-AK-CAZ-SC(7) 9,423.86 90.17 9.02 6,325.72 6,166.62 1,122.56 1,064.89 5,931,105.85 482,141.81 1.39 1,359.92 MWD+IFR-AK-CAZ-SC(7) 9,518 83 90.00 9.79 6,325.58 6,166.48 1,216.25 1,080.41 5,931,199.50 482,157.56 0.83 1,454.44 MWD+IFR-AK-CAZ-SC(7) 9,613.21 90.03 10.10 6,325.56 6,166.46 1,309.21 1,096.71 5,931,292.41 482,174.10 0.33 1,548.45 MWD+IFR-AK-CAZ-SC(7) 9,708.21 90.03 10.99 6,325.51 6,166.41 1,402.61 1,114.09 5,931,385.75 482,191.71 0.94 1,643.16 MWD+IFR-AK-CAZ-SC(7) 9,802.63 89.59 11.14 6,325.82 6,166.72 1,495.27 1,132.21 5,931,478.36 482,210.07 0.49 1,737.36 MWD+IFR-AK-CAZ-SC(7) 9,898.19 89.38 11.20 6,326.68 6,167.58 1,589.02 1,150.72 5,931,572.05 482,228.81 0.23 1,832.70 MWD+IFR-AK-CAZ-SC(7) 9,992.55 88.52 12.62 6,328.41 6,169.31 1,681.33 1,170.19 5,931,664.30 482,248.51 1.76 1,926.91 MWD+IFR-AK-CAZ-SC(7) 10,087.44 88.77 14.23 6,330.65 6,171.55 1,773.60 1,192.22 5,931,756.51 482,270.76 1.72 2,021.73 MWD+IFR-AK-CAZ-SC(7) 10,181.95 89.21 16.02 6,332.32 6,173.22 1,864.82 1,216.87 5,931,847.65 482,295.64 1.95 2,116.22 MWD+IFR-AK-CAZ-SC(7) 10,276.00 89.93 16.07 6,333.02 6,173.92 1,955.20 1,242.87 5,931,937.96 482,321.86 0.77 2,210.25 MWD+IFR-AK-CAZ-SC(7) 10,371.25 90.96 14.82 6,332.28 6,173.18 2,047.00 1,268.23 5,932,029.69 482,347.45 1.70 2,305.50 MWD+IFR-AK-CAZ-SC(7) 10,465.96 91.13 14.92 6,330.56 6,171.46 2,138.53 1,292.53 5,932,121.15 482,371.98 0.21 2,400.19 MVVD+IFR-AK-CAZ-SC(7) 10,561.14 90.07 15.34 6,329.56 6,170.46 2,230.40 1,317.37 5,932,212.95 482,397.05 1.20 2,495.36 MWD+IFR-AK-CAZ-SC(7) 10,656.07 89.97 16.63 6,329.53 6,170.43 2,321.66 1,343.51 5,932,304.13 482,423.42 1.36 2,590.28 MVVD+IFR-AK-CAZ-SC(7) 10/26/2016 1:24:06PM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonll Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonl2 Well: 2S-09 North Reference: True Wellbore; 2S-09A Survey Calculation Method: Minimum Curvature Design: 2S-09A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NJ-S +E/-W Northing Easting DLS Section (usft) (°) r) (usft) (usft) (usft) (usft) (ft) (ft) (°/1001 (ft) Survey Tool Name 10,751 75 89.25 17.29 6,330 18 6,171 08 2,413 17 1,371 42 5,932,395.57 482,451.55 1.02 2,685 90 MWD+IFR-AK-CAZ-SC(7) 10,845.73 89.21 17.30 6,331.44 6,172.34 2,502.90 1,399.36 5,932,485.21 482,479.71 0.04 2,779.79 MWD+IFR-AK-CAZ-SC(7) 10,939.95 89.14 16.65 6,332.80 6,173.70 2,593.00 1,426.87 5,932,575.24 482,507.44 0.69 2,873.95 MWD+IFR-AK-CAZ-SC(7) 11,035.25 89.55 15.97 6,333.89 6,174.79 2,684.46 1,453.63 5,932,666.62 482,534.43 0.83 2,969.21 MWD+IFR-AK-CAZ-SC(7) 11,130.69 90.33 15.59 6,333.99 6,174.89 2,776.30 1,479.58 5,932,758.39 482,560.61 0.91 3,064.64 MWD+IFR-AK-CAZ-SC(7) 11,225.14 93.02 14.87 6,331.23 6,172.13 2,867.39 1,504.38 5,932,849.40 482,585.64 2.95 3,159.04 MWD+IFR-AK-CAZ-SC(7) 11,320.11 94.98 14.31 6,324.60 6,165.50 2,959.06 1,528.24 5,932,941.01 482,609.73 2.15 3,253.78 MWD+IFR-AK-CAZ-SC(7) 11,414.56 95.58 13.35 6,315.91 6,156.81 3,050.39 1,550.73 5,933,032.26 482,632.44 1.19 3,347.80 MWD+IFR-AK-CAZ-SC(7) 11,509.80 93.67 13.36 6,308.23 6,149.13 3,142.74 1,572.65 5,933,124.56 482,654.59 2.01 3,442.69 MWD+IFR-AK-CAZ-SC(7) 11,605.20 90.71 11.77 6,304.59 6,145.49 3,235.78 1,593.39 5,933,217.53 482,675.56 3.52 3,537.92 MWD+IFR-AK-CAZ-SC(7) 11,700.10 89.61 11.02 6,304.32 6,145.22 3,328.81 1,612.14, 5,933,310.50 482,694.54 1.40 3,632.63 MWD+IFR-AK-CAZ-SC(7) 11,795.02 89.83 8.94 6,304.78 6,145.68 3,422.28 1,628.58 5,933,403.93 482,711.22 2.20 3,727.18 MWD+IFR-AK-CAZ-SC(7) 11,884.94 90.51 7.36 6,304.52 6,145.42 3,511.29 1,641.33 5,933,492.89 482,724.19 1.91 3,816.45 MWD+IFR-AK-CAZ-SC(7) 11,977.90 91.34 6.45 6,303.02 6,143.92 3,603.56 1,652.51 5,933,585.13 482,735.59 1.32 3,908.47 MWD+IFR-AK-CAZ-SC(7) 12,069.88 92.28 7.64 6,300.11 6,141.01 3,694.80 1,663.78 5,933,676.33 482,747.09 1.65 3,999.52 MWD+IFR-AK-CAZ-SC(7) 12,161.21 90.91 10.52 6,297.57 6,138.47 3,784.94 1,678.19 5,933,766.42 482,761.73 3.49 4,090.32 MWD+IFR-AK-CAZ-SC(7) 12,208.82 88.67 13.34 6,297.74 6,138.64 3,831.51 1,688.03 5,933,812.97 482,771.68 7.56 4,137.85 MWD+IFR-AK-CAZ-SC(7) 12,253.41 88.15 15.65 6,298.98 6,139.88 3,874.66 1,699.18 5,933,856.08 482,782.94 5.31 4,182.42 MWD+IFR-AK-CAZ-SC(7) 12,303.81 87.29 17.15 6,300.99 6,141.89 3,922.97 1,713.40 5,933,904.35 482,797.28 3.43 4,232.76 MWD+IFR-AK-CAZ-SC(7) 12,346.16 88.49 17.95 6,302.55 6,143.45 3,963.32 1,726.16 5,933,944.67 482,810.14 3.40 4,275.04 MWD+IFR-AK-CAZ-SC(7) 12,438.36 90.88 17.07 6,303.05 6,143.95 4,051.24 1,753.90 5,934,032.51 482,838.10 2.76 4,367.14 MWD+IFR-AK-CAZ-SC(7) 12,531.22 90.34 15.74 6,302.06 6,142.96 4,140.31 1,780.12 5,934,121.51 482,864.54 1.55 4,459.97 MWD+IFR-AK-CAZ-SC(7) 12,623.29 90.47 14.59 6,301.41 6,142.31 4,229.17 1,804.21 5,934,210.30 482,888.85 1.26 4,552.03 MWD+IFR-AK-CAZ-SC(7) 12,715.13 91.85 14.11 6,299.55 6,140.45 4,318.13 1,826.97 5,934,299.18 482,911.82 1.59 4,643.85 MWD+IFR-AK-CAZ-SC(7) 12,808.15 92.02 12.76 6,296.41 6,137.31 4,408.55 1,848.56 5,934,389.54 482,933.65 1.46 4,736.78 MWD+IFR-AK-CAZ-SC(7) 12,901.01 91.13 12.21 6,293.86 6,134.76 4,499.18 1,868.63 5,934,480.11 482,953.94 1.13 4,829.51 MWD+IFR-AK-CAZ-SC(7) 12,991.52 89.78 10.78 6,293.14 6,134.04 4,587.87 1,886.67 5,934,568.74 482,972.20 2.17 4,919.84 MWD+IFR-AK-CAZ-SC(7) 13,083.76 89.83 11.07 6,293.46 6,134.36 4,678.43 1,904.15 5,934,659.26 482,989.90 0.32 5,011.85 MWD+IFR-AK-CAZ-SC(7) 13,176.68 90.43 9.96 6,293.24 6,134.14 4,769.79 1,921.11 5,934,750.56 483,007.09 1.36 5,104.48 MWD+IFR-AK-CAZ-SC(7) 13,267.85 88.82 10.24 6,293.84 6,134.74 4,859.54 1,937.09 5,934,840.27 483,023.30 1.79 5,195.31 MVVD+IFR-AK-CAZ-SC(7) 13,360.37 88.55 10.26 6,295.96 6,136.86 4,950.56 1,953.55 5,934,931.24 483,039.98 0.29 5,287.49 MWD+IFR-AK-CAZ-SC(7) 13,452.63 89.76 11.44 6,297.32 6,138.22 5,041.16 1,970.92 5,935,021.78 483,057.57 1.83 5,379.50 MWD+IFR-AK-CAZ-SC(7) 13,544.62 89.69 12.48 6,297.77 6,138.67 5,131.15 1,989.98 5,935,111.71 483,076.86 1.13 5,471.36 MWD+IFR-AK-CAZ-SC(7) 13,638.49 90.34 12.39 6,297.74 6,138.64 5,222.82 2,010.19 5,935,203.32 483,097.30 0.70 5,565.13 MWD+IFR-AK-CAZ-SC(7) 13,731.30 89.97 11.58 6,297.49 6,138.39 5,313.60 2,029.46 5,935,294.05 483,116.80 0.96 5,657.81 MWD+IFR-AK-CAZ-SC(7) 13,822.95 90.00 10.34 6,297.51 6,138.41 5,403.58 2,046.89 5,935,383.97 483,134.45 1.35 5,749.23 MWD+IFR-AK-CAZ-SC(7) 13,915.96 90.00 9.38 6,297.51 6,138.41 5,495.22 2,062.82 5,935,475.56 483,150.60 1.03 5,841.87 MWD+IFR-AK-CAZ-SC(7) 14,006.73 89.98 7.83 6,297.53 6,138.43 5,584.96 2,076.40 5,935,565.26 483,164.41 1.71 5,932.07 MWD+IFR-AK-CAZ-SC(7) 14,099.52 87.91 6.27 6,299.24 6,140.14 5,677.03 2,087.78 5,935,657.29 483,176.02 2.79 6,023.94 MVVD+IFR-AK-CAZ-SC(7) 14,112.54 88.74 6.55 6,299.62 6,140.52 5,689.96 2,089.24 5,935,670.22 483,177.51 6.73 6,036.81 MWD+IFR-AK-CAZ-SC(7) 10/26/2016 1'24'06PM Page 5 COMPASS 5000.1 Build 74 1110 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyon1i Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyon1z Well: 2S-09 North Reference: True Wellbore: 2S-09A Survey Calculation Method: Minimum Curvature Design: 2S-09A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-$ +El-W Northing Easting DLS Section (usft) (*) (*) (usft) (usft) (usft) (usft) (It) (ft) (I1pg') (ft) Survey Tool Name 14,160 00 88.74 6.55 6,300 66 6,141 56 5,737 10 2,094 65 5,935,717.34 483,183 04 0.00 6,083 75 PROJECTED to TD 4 1/2"x 6-314" 14,172 00 88.74 6.55 6,30093 6,141 83 5,749 02 2,096 02 5,935,729 25 483,184 44 0.00 6,095.61 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. Li Yes 0 No I have checked to the best of my ability that the following data is correct: ID Surface Coordinates [j Declination & Convergence GRS Survey Corrections slgned lay'vicerlt 0,ma E Survey Tool Codes Vincent DN Owe, ,therk.e,, SL I3 DE: Osa ra erriai=vosaraslb.corn,c,J5 Dia.:2016'OM -98'00 Client Representative: Date: 26-Oct-2016 10/26/2016 1:24:06PM Page 6 COMPASS 5000.1 Build 74 (o✓ --e c 0 0 "=' Cement Detail Report , f 2S-09 ConocoPhillips ; String: Surface Casing Cement Job: DRILLING ORIGINAL,9/12/2016 18:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 9/17/2016 02:46 9/17/2016 04:32 2S-09 Comment Cement as per SLB detail.Flood lines w!5 bbls of H20.P/T lines to 800/3500 psi,good.Pump 50.2 bbls of CW-100 at 5,5 bpm.205 psi.Pump 68.6 bbls of 10.5 ppg Mud Push II at 4.5 bpm,190 psi.Drop bottom plug.Pump 360.7 bbls of 11.0 ppg lead cement at 6.5 bpm,225-360 psi.While pumping lead cement the cementers lost prime on their pump with 291 bbls away.Pumping was resumed to finish lead cement.Between pumping the lead&tail cement SLB troubleshot the cement unit.Pump 59.1 bbls of 15.8 ppg tail cement at 4.5 bpm,450 psi.Drop top plug.Pump 10 bbls of fresh H2O at 3 bpm,230 psi.Pump 253 bbls of 10.0 ppg mud at 3-5 bpm,340-665 psi.Plug bumped at 2508 strokes.Pressure up to 1100 psi&hold for 5 minutes.Bleed off pressure to check floats,good, 173 bbls of cement returns to surface.CIP @ 05:54 hrs. After swapping to the rig to displace cement the casing string was picked up to begin reciprocation.The string was picked up 2-3 feet with PU 180K,previous PU was 160K.Slacked off to verify ability to land back on hanger.Unable to slack off to land hanger.Continue attempts to land on hanger with no success.Pick up w/190K,to 18"from fully landed mark,to be able to set emergency slips.Displacement of cement was continuous. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement 47.0 2,833.0 Yes 172.0 Yes Yes 0 Pump snit(bbl/m...0 Pump Final(bbl!...0 Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 2 4 6 409.0 560.0 Yes 10.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 47.0 2,333.0 1,080 G 361.7 Yield(ft'/sack) Mix 1120 Ratio(gallsa... Free Water(%) Density(1b/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.88 6.50 11.00 146.0 '3.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 2,333.0 2,833.0 286 G 59.1 Yield(Maack) Mix H2O Ratio(gallsa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa's) Thickening Time(hr) CmprStr 1(psi) 1.16 5.07 15.80 169.2 3.75 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 6/15/2017 0-7-r 0 • Cement Detail Report 2S-09 • evi ` a P E E cocd inarPhitlips String: Surface Casing Cement Job: DRILLING ORIGINAL, 9/12/2016 18:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 9/17/2016 02:46 9/17/2016 04:32 2S-09 Comment Cement as per SLB detail. Flood lines w/5 bbls of H2O. P/T lines to 800/3500 psi,good. Pump 50.2 bbls of CW-100 at 5.5 bpm,205 psi. Pump 68.6 bbls of 10.5 ppg Mud Push II at 4.5 bpm, 190 psi. Drop bottom plug. Pump 360.7 bbls of 11.0 ppg lead cement at 6.5 bpm,225-360 psi.While pumping lead cement the cementers lost prime on their pump with 291 bbls away. Pumping was resumed to finish lead cement. Between pumping the lead&tail cement SLB troubleshot the cement unit. Pump 59.1 bbls of 15.8 ppg tail cement at 4.5 bpm,450 psi. Drop top plug. Pump 10 bbls of fresh H2O at 3 bpm,230 psi. Pump 253 bbls of 10.0 ppg mud at 3-5 bpm,340-665 psi. Plug bumped at 2508 strokes. Pressure up to 1100 psi&hold for 5 minutes.Bleed off pressure to check floats,good. 173 bbls of cement returns to surface.CIP @ 05:54 hrs. After swapping to the rig to displace cement the casing string was picked up to begin reciprocation.The string was picked up 2-3 feet with PU 180K,previous PU was 160K.Slacked off to verify ability to land back on hanger. Unable to slack off to land hanger.Continue attempts to land on hanger with no success. Pick up w/190K,to 18"from fully landed mark,to be able to set emergency slips.Displacement of cement was continuous. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement 47.0 2,833.0 Yes 172.0 Yes Yes 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) 2 4 6 409.0 560.0 Yes 10.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 47.0 2,333.0 1,080 G 361.7 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.88 6.50 11.00 146.0 3.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 2,333.0 2,833.0 286 G 59.1 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 5.07 15.80 169.2 3.75 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 11/4/2016 i • -, Cement Detail Report 0g 11>4 , 0 i• y 'F.tS ,4. a 2S-09 ConocoPhiilips p AIKr.. String: Intermediate Casing Cement Job: DRILLING ORIGINAL,9/12/2016 18:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 9/24/2016 21:35 9/25/2016 06:51 2S-09 Comment Cement 7-5/8"casing as per SLB cementing program.Pump 5 bbls of H2O,test trips&PT lines to 518/4000 psi,good.Pump 42.6 bbls of 12.5 ppg MPII at 5.1 bpm,240 psi.Drop bottom plug.Pump 100.2 bbls of 15.8 ppg Sharks Tooth slurry at 5.2 bpm,215 psi.Drop top plug&pump 10.1 bbis of H2O at 6.1 bpm,100 psi.Swap to rig&displace with 10 ppg LSND at 6 bpm,127 psi,FO 8%,Slow rate(losses @ 1625 strokes)to 2 bpm,70 psi,FCP 571 psi @ 2 bpm.Bump plug at 3100 strokes.Check floats,good.CIP @ 00:58 hrs.Total Losses for first stage 6 bbls. Pump second stage cement as per SLB cementing program. Pump 40.6 bbls of 12.5 ppg MPII at 5.4 bpm,227 psi. Pump 50 bbls of 15.8 ppg Sharks Tooth slurry at 4 bpm,160 psi.Drop closing plug.Pump 10 bbls of H2O at 6.1 bpm,95 psi.Swap to rig&displace with 10 ppg LSND at 6 bpm,483 psi,FO 7%.Slow pump rate as losses were observed to 2 bpm,516 psi.Looses started at—1800 strokes(cement at stage tool at 1882 stk).Bump plug at 2349 strokes, pressuring up1700shiftstage p g io psi to collar closed.Observed closingat 1300psi.Hold for 5 minutes,bleed off,&check for flow.Tool closed.CIP 06:51 @ hrs.Total Losses for second stage 14 bbls. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing Cement from TD of 7247' 6,099.0 7,247.0 No Yes Yes Cement to top of Cairn @ 6057' MD Q Pump!nit(bbllm...Q Pump Final(bbl/...Q Pump Avg(bbll... P Pump Final(psi) P Plug Bump(psi) Reclp? Stroke(ft) Rotated? Pipe RPM(rpm) 5 2 5 571.0 1,027.0 Yes 25.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives . Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mud Push II 5,562.5 6,099.4 42.6 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pats) Thickening Time(hr) CmprStr 1(psi) 12.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Shark Tooth Slurry 6,099.4 7,247.0 484 G 100.2 Yield(ft Jsack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pats) Thickening Time(hr) CmprStr 1(psi) 1.16 5.07 15.80 Additives Additive Type Concentration Conc Unit label Additive Type Concentration Conc Unit label Antifoam D046 0.15 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.6 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.7%BWOC Additive Type Concentration Conc Unit label Retarder D177 0.015 gal/sx Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? CasingCement0 ' Intermediate 5 D above the C 4,948.0 5,402.0 No Yes No Cement -37 at 5402'MD Q Pump!nit(bbllm...Q Pump Final(bbl!...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Reci ? Stroke(ft) . Rotated? Pipe RPM(rpm) ) 3 2 6 516.0 1,700.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mud Push II 4,436.7 40.6 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(iblgal) Plastic Viscosity(Pats) Thickening Time(hr) CmprStr 1(psi) 12.50 Page 1/2 Report Printed: 6/15/2017 ttiiing Cement Detail Report r of Wells 2S-09 ConocoPhillips AA,+4n String: Intermediate Casing Cement Job: DRILLING ORIGINAL,9/12/2016 18:00 Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Shark Tooth Slurry 4,948.3 5,402.0 247 G 50.0 Yield(ft/sack) Mix H2O Ratio(gallsa... Free Water(%) Density(Ib!gal) Plastic Viscosity(Pa's) Thickening Time(hr) CmprStr 1(psi) 1.16 5.06 15.80 Additives Additive Type Concentration Cone Unit label Antifoam D046 0.15%BWOC Additive Type Concentration Cone Unit label Dispersant D085 0.6%BWOC Additive Type Concentration Cone Unit label Fluid Loss Control D167 0.7%BWOC • ti Page 2/2 Report Printed: 6/15/2017 0 t7" Cement Detail Report I a ex SUP- 2S-09 �rdlps kssk., ,.. String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 9112/2016 18:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 9/24/2016 21:35 9/25/2016 06:51 2S-09 Comment Cement 7-5/8"casing as per SLB cementing program. Pump 5 bbls of H2O,test trips&PT lines to 518/4000 psi,good. Pump 42.6 bbls of 12.5 ppg MPII at 5.1 bpm,240 psi. Drop bottom plug. Pump 100.2 bbls of 15.8 ppg Sharks Tooth slurry at 5.2 bpm,215 psi. Drop top plug&pump 10.1 bbls of H2O at 6.1 bpm, 100 psi.Swap to rig&displace with 10 ppg LSND at 6 bpm, 127 psi, FO 8%,Slow rate(losses @ 1625 strokes)to 2 bpm, 70 psi,FCP 571 psi @ 2 bpm. Bump plug at 3100 strokes.Check floats,good.CIP @ 00:58 hrs.Total Losses for first stage 6 bbls. Pump second stage cement as per SLB cementing program. Pump 40.6 bbls of 12.5 ppg MPII at 5.4 bpm,227 psi. Pump 50 bbls of 15.8 ppg Sharks Tooth slurry at 4 bpm, 160 psi. Drop closing plug. Pump 10 bbls of H2O at 6.1 bpm, 95 psi.Swap to rig&displace with 10 ppg LSND at 6 bpm,483 psi, FO 7%.Slow pump rate as losses were observed to 2 bpm,516 psi. Looses started at-1800 strokes(cement at stage tool at 1882 stk). Bump plug at 2349 strokes, pressuring up to 1700 psi to shift stage collar closed.Observed closing at 1300 psi. Hold for 5 minutes,bleed off,&check for flow.Tool closed.CIIP©06:51 hrs.Total Losses for second stage 14 bbls. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing Cement from TD of 7247' 6,099.0 7,247.0 No Yes Yes Cement to top of Cairn @ 6057' MD 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) 5 2 5 571.0 1,027.0 Yes 25.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives> Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mud Push II 5,562.5 6,099.4 42.6 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 12.50 Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) / Class Volume Pumped(bbl) Shark Tooth Slurry 6,099.4 7,247.0 / ,484 G 100.2 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(P!•9hickening Time(hr) CmprStr 1(psi) 1.16 5.07 15.80 Additives Additive Type Concentration Conc Unit label Additive Type Concentration Conc Unit label Antifoam D046 0.15 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.6 %E'WOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.7 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.015 gal,/sx Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing Cement 500'above the C 4,948.0 5,402.0 No Yes No Cement -37 at 5402'MD Q Pump Mit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? [Pipe RPM(rpm) 3 2 6 516.0 1,700.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mud Push Il 4,436.7 40.6 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 12.50 Page 1/2 Report Printed: 11/4/2016 Cement Detail Report 1 W- 2S-09 ConocoPhillips •- "" String: Intermediate Casing Cement Job: DRILLING ORIGINAL,9/12/2016 18:00 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Shark Tooth Slurry 4,948.3 5,402.0 247 G 50.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.06 15.80 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.15 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.6 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.7 %BWOC Page 2/2 Report Printed: 11/4/2016 .14:1' Cement Detail Report 0 2S-09 ConocoPhillips na.,ti.s String: 6-314"Lateral Abandonment Plug Job: DRILLING ORIGINAL,9/12/2016 18:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name 6-3/4"Lateral Abandonment Plug 10/6/2016 21:30 10/6/2016 23:30 2S-09 Comment Cementers pump 10 bbls water and pressure test lines to 55013500 psi-good test.Pump 58.8 bbis 15.8ppg Class G cement at 4.5 bpm,1576 psi,holding 800 psi backpressure through rig choke to minimize u-tubing.Shut chokes to hold pressure while swapping from cement to water.Cementers pump 5 bbis of water at 3bpm,240 psi and sting into cement retainer.Bleed off backside pressure,open bag,and line up to rig pump.Pump 62 bbis 10.0ppg FloPro w/rig pump. Staged up to 1.5 bpm,1578 psi for 14.5 bbis and then observed pressure start to increase up to 2860 psi with no breakover.Decreased rate to 1 bpm and observed pressure breakover at 3039 psi.Continued pumping at 1 bpm,observing pressure climb to 3286 psi after 36.5 bbis pumped and then continue to fluctuate between 3000-3200 psi.Shut down after 62 bbls pumped and observe pressure fall to 2400 psi.Sting out of cement retainer and pull out of hole 4 x stands slowly to 6644'. Cement in place @ 00:06 hrs. Squeezed 52 bbls of 15.8ppg Class G cement below cement retainer. Estimated top of cement inside 7-5/8"casing @ 6903'MD. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? 6-3/4"Lateral Squeeze 50 bbis below 7,007.0 8,373.0 No No No Abandonment Plug retainer and 100'above Q Pump Init(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbll... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 1 1 1 3,200.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 7,007.0 Work String Comment Squeezed total of 10 bbis of water and 52 bbis cement below retainer Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Plug Back Cement 6,903.0 8,373.0 G 58.8 Yield(W/sack) Mix H2O Ratio(gal/se... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa's) Thickening Time(hr) CmprStr 1(psi) 15.80 Additives Additive Type Concentration Cone Unit label • Page 1/1 Report Printed: 6/15/2017 (711,-0,--C Cement Detail Report UP RSED " 2S-09 ocoPhitlips _ __ . 0,,.1.:3 String: 6-3/4" Lateral Abandonment Plug Job: DRILLING ORIGINAL, 9/12/2016 18:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name 6-3/4"Lateral Abandonment Plug 10/6/2016 21:30 10/6/2016 23:30 2S-09 Comment Cementers pump 10 bbls water and pressure test lines to 550/3500 psi-good test. Pump 58.8 bbls 15.8ppg Class G cement at 4.5 bpm, 1576 psi,holding 800 psi backpressure through rig choke to minimize u-tubing.Shut chokes to hold pressure while swapping from cement to water.Cementers pump 5 bbls of water at 3bpm,240 psi and sting into cement retainer. Bleed off backside pressure,open bag,and line up to rig pump. Pump 62 bbls 10.0ppg FloPro w/rig pump. Staged up to 1.5 bpm, 1578 psi for 14.5 bbls and then observed pressure start to increase up to 2860 psi with no breakover. Decreased rate to 1 bpm and observed pressure breakover at 3039 psi.Continued pumping at 1 bpm,observing pressure climb to 3286 psi after 36.5 bbls pumped and then continue to fluctuate between 3000-3200 psi.Shut down after 62 bbls pumped and observe pressure fall to 2400 psi.Sting out of cement retainer and pull out of hole 4 x stands slowly to 6644'. Cement in place @ 00:06 hrs. Squeezed 52 bbls of 15.8ppg Class G cement below cement retainer. Estimated top of cement inside 7-5/8"casing @ 6903'MD. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? 6-3/4"Lateral Squeeze 50 bbls below 7,007.0 8,373.0 No No No Abandonment Plug retainer and 100'above 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) 1 1 1 3,200.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 7,007.0 Work String Comment Squeezed total of 10 bbls of water and 52 bbls cement below retainer Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Plug Back Cement 6,903.0 8,373.0 G 58.8 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 15.80 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 11/4/2016 Cement Detail Report r, rill 2S-09 ConocoPhillips String: Intermediate Kickoff Plug Job: DRILLING ORIGINAL,9/12/2016 18:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Kickoff Plug 10/9/2016 22:45 10/9/2016 23:41 2S-09 Comment Line up to cement unit&start batch mixing 17ppg cement.Pump 5 bbls of water to flood lines at 4 bpm,137 psi.Test lines to 600/4000 psi.Reset high trip to 2500 psi.Batch mix 12.5ppg mudpush and pump at 5.5 bpm,127 psi for a total of 35.5 bbls.Pump 17ppg Class G cement at 6 bpm,150 psi for total of 60.1 bbls.Pump 12.5ppg mudpush at 4 bpm,30 psi for total of 4 bbls.Flush lines to rig floor w/1.5 bbls mudpush.Swap to rig and pump 9.2ppg WBM at 6 bpm,76- 350 psi for total of 28.6 bbls.Observed pressure rapidly increase to 350 psi after 24.5 bbls pumped as fluid caught falling cement. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Kickoff Plug From CIBP to 250'above 2,440.0 2,972.0 No No No surface casing shoe 0 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 6 6 350.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Line up to cement unit&start batch mixing 17ppg cement.Pump 5 bbls of water to flood lines at 4 bpm,137 psi.Test lines to 600/4000 psi.Reset high trip to 2500 psi.Batch mix 12.5ppg mudpush and pump at 5.5 bpm,127 psi for a total of 35.5 bbls.Pump 17ppg Class G cement at 6 bpm,160 psi for total of 60.1 bbls.Pump 12.5ppg mudpush at 4 bpm,30 psi for total of 4 bbls.Flush lines to rig floor w/1.5 bbls mudpush.Swap to rig and pump 9.2ppg WBM at 6 bpm,76- 350 psi for total of 28.6 bbls.Observed pressure rapidly increase to 360 psi after 24.5 bbls pumped as fluid caught falling cement. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Plug Back Cement 2,440.0 2,972.0 G 60.1 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.00 3.66 17.00 5.10 Additives Additive Type Concentration Cone Unit label Page 1/1 Report Printed: 6/15/2017 o c- °. Cement Detail Report or IJPERSED : 2S-09 c 3exlim hilliips String: Intermediate Kickoff Plug Job: DRILLING ORIGINAL, 9/12/2016 18:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Kickoff Plug 10/9/2016 22:45 10/9/2016 23:41 2S-09 Comment Line up to cement unit&start batch mixing 17ppg cement. Pump 5 bbls of water to flood lines at 4 bpm, 137 psi.Test lines to 600/4000 psi. Reset high trip to 2500 psi.Batch mix 12.5ppg mudpush and pump at 5.5 bpm, 127 psi for a total of 35.5 bbls. Pump 17ppg Class G cement at 6 bpm, 150 psi fog total of 60.1 bbls. Pump 12.5ppg mudpush at 4 bpm,30 psi for total of 4 bbls. Flush lines to rig floor w/1.5 bbls mudpush.Swap to rig and pump 9.2ppg WBM at 6 bpm,76- 350 psi for total of 28.6 bbls.Observed pressure rapidly increase to 350 psi after 24.5 bbls pumped as fluid caught falling cement. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Kickoff Plug From CIBP to 250'above 2,440.0 2,972.0 No No No surface casing shoe 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) 4 6 6 350.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Line up to cement unit&start batch mixing 17ppg cement. Pump 5 bbls of water to flood lines at 4 bpm, 137 psi.Test lines to 600/4000 psi. Reset high trip to 2500 psi.Batch mix 12.5ppg mudpush and pump at 5.5 bpm, 127 psi for a total of 35.5 bbls. Pump 17ppg Class G cement at 6 bpm, 150 psi for total of 60.1 bbls. Pump 12.5ppg mudpush at 4 bpm,30 psi for total of 4 bbls. Flush lines to rig floor w/1.5 bbls mudpush.Swap to rig and pump 9.2ppg WBM at 6 bpm,76- 350 psi for total of 28.6 bbls.Observed pressure rapidly increase to 350 psi after 24.5 bbls pumped as fluid caught falling cement. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Plug Back Cement 2,440.0 2,972.0 G 60.1 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.00 3.66 17.00 5.10 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 11/4/2016 • • Cement Detail Report 2S-09 ConocoPhiilips M1irnk String: Intermediate 2 Casing Cement Job: DRILLING ORIGINAL,9/12/2016 18:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name intermediate 2 Casing Cement 10/17/2016 08:00 10/17/2016 18:00 2S-09A Comment Cement 1st stage as per SLB schedule.Pump 5 bbls of H2O&pressure test lines to 600/4000 psi.Pump 40 bbis of 12.5 ppg mud push at 3.7 bpm,150 psi. Drop bottom plug.Pump 15.2 bbls of 15.8 ppg neat cement at 5 bpm.265 psi.Pump 99.5 bbis of 15.8 ppg cement W12 ppb of CemNet at 5.1 bpm,175 psi. Pump 46 bbls of 15.8 ppg neat cement at 5.1 bpm,180 psi.Drop top plug&pump 10 bbls of H2O at 6 bpm,207 psi.Swap to rig&displace w/353.7 bbis of 10.0 ppg LSND mud at 7 bpm,120 psi.Slow rate to 3 bpm,830 psi&bump plug at 3502 strokes.Pressure up to 1340 psi&hold for 5 minutes.Bleed off&check floats,good.CIP 10:10 hrs. Cement 2nd stage as per SLB schedule.Pump 5 bbls of H20.Pump 41.9 bbls of 12.5 ppg mud push at 4.1 bpm,108 psi.Pump 10.2 bbls of 15.8 ppg neat cement at 5.5 bpm,252 psi.Pump 33.1 bbis of 15.8 ppg cement w/2 ppb of CemNet at 5.5 bpm,222 psi.Pump 4.2 bbis of 15.8 ppg neat cement at 4 bpm,180 psi.Drop closing plug&pump 10 bbls of H2O at 5 bpm,7 psi.Swap to rig&displace w/243 bbls of 10.0 ppg LSND mud at 7 bpm,300 psi.Slow rate to 3 bpm, 600 psi&bump plug at 2404 strokes.CIP 18:05 hrs. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing Cement from TD of 8138' 6,170.0 8,138.0 No 0.0 Yes Yes Cement to top of Cairn©6170' MD Q Pump Mit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 5 5 823.0 1,346.0 Yes 15.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement 1st stage as per SLB schedule.Pump 5 bbls of H2O&pressure test lines to 600/4000 psi.Pump 40 bbls of 12.5 ppg mud push at 3.7 bpm,150 psi. Drop bottom plug.Pump 15.2 bbls of 15.8 ppg neat cement at 5 bpm,265 psi,Pump 99.5 bbls of 15.8 ppg cement w/2 ppb of CemNet at 5.1 bpm,175 psi. Pump 46 bbls of 15.8 ppg neat cement at 5.1 bpm,180 psi.Drop top plug&pump 10 bbls of H2O at 6 bpm,207 psi.Swap to rig&displace w/353.7 bbls of 10.0 ppg LSND mud at 7 bpm,120 psi.Slow rate to 3 bpm,830 psi&bump plug at 3502 strokes.Pressure up to 1340 psi&hold for 5 minutes.Bleed off&check floats,good.CIP 10:10 hrs. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 6,170.0 8,138.0 778 G 160.7 Yield(ft'/sack) Mix 1120 Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pass) Thickening Time(hr) CmprStr 1(psi) 1.16 5.05 15.80 171.1 5.50 Additives Additive Type Concentration Conc Unit label Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing Cement 500'above the C 4,911.0 5,512.0 No 0.0 Yes No Cement -37 at 5411'MD Q Pump Inst(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 6 6 682.0 1,241.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement 2nd stage as per SLB schedule.Pump 5 bbls of H20.Pump 41.9 bbls of 12,5 ppg mud push at 4.1 bpm,108 psi.Pump 10.2 bbls of 15.8 ppg neat cement at 5.5 bpm,252 psi.Pump 33.1 bbls of 15.8 ppg cement w/2 ppb of CemNet at 5.5 bpm,222 psi.Pump 4.2 bbls of 15.8 ppg neat cement at 4 bpm,180 psi.Drop closing plug&pump 10 bbls of H2O at 5 bpm,7 psi.Swap to rig&displace WI 243 bbls of 10.0 ppg LSND mud at 7 bpm,300 psi.Slow rate to 3 bpm, 600 psi&bump plug at 2404 strokes.CIP 18:05 hrs. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement _ 4,911.0_ 5,512.0 229 G 47.3 Yield(Mack) Mix H2O Ratio(gal/se... Free Water(%) Density(lb/gal) Plastic Viscosity(Pass) Thickening Time(hr) CmprStr 1(pal) 1.16 5.05 15.80 209.1 5.75 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 6/15/2017 • • Cement Detail Report SUPERSEDE' t. 2S-09 CorK3coPhillips String: Intermediate 2 Casing Cement Job: DRILLING ORIGINAL, 9/12/2016 18:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate 2 Casing Cement 10/17/2016 08:00 10/17/2016 18:00 2S-09A Comment Cement 1st stage as per SLB schedule. Pump 5 bbls of H2O&pressure test lines to 600/4000 psi. Pump 40 bbls of 12.5 ppg mud push at 3.7 bpm, 150 psi. Drop bottom plug.Pump 15.2 bbls of 15.8 ppg neat cement at 5 bpm,265 psi.Pump 99.5 bbls of 15.8 ppg cement w/2 ppb of CemNet at 5.1 bpm, 175 psi. Pump 46 bbls of 15.8 ppg neat cement at 5.1 bpm, 180 psi. Drop top plug&pump 10 bbls of H2O at 6 bpm,207 psi.Swap to rig&displace w/353.7 bbls of 10.0 ppg LSND mud at 7 bpm, 120 psi.Slow rate to 3 bpm, 830 psi&bump plug at 3502 strokes. Pressure up to 1340 psi&hold for 5 minutes. Bleed off&check floats,good.CIP 10:10 hrs. Cement 2nd stage as per SLB schedule. Pump 5 bbls of H2O.Pump 41.9 bbls of 12.5 ppg mud push at 4.1 bpm, 108 psi. Pump 10.2 bbls of 15.8 ppg neat cement at 5.5 bpm,252 psi. Pump 33.1 bbls of 15.8 ppg cement w/2 ppb of CemNet at 5.5 bpm,222 psi. Pump 4.2 bbls of 15.8 ppg neat cement at 4 bpm, 180 psi. Drop closing plug&pump 10 bbls of H2O at 5 bpm,7 psi.Swap to rig&displace w/243 bbls of 10.0 ppg LSND mud at 7 bpm,300 psi.Slow rate to 3 bpm, 600 psi&bump plug at 2404 strokes.CIP 18:05 hrs. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing Cement from TD of 8138' 6,170.0 8,138.0 No 0.0 Yes Yes Cement to top of Cairn @ 6170' MD 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) 5 5 5 823.0 1,346.0 Yes 15.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement 1st stage as per SLB schedule. Pump 5 bbls of H2O&pressure test lines to 600/4000 psi.Pump 40 bbls of 12.5 ppg mud push at 3.7 bpm, 150 psi. Drop bottom plug.Pump 15.2 bbls of 15.8 ppg neat cement at 5 bpm,265 psi. Pump 99.5 bbls of 15.8 ppg cement w/2 ppb of CemNet at 5.1 bpm, 175 psi. Pump 46 bbls of 15.8 ppg neat cement at 5.1 bpm, 180 psi. Drop top plug&pump 10 bbls of H2O at 6 bpm,207 psi.Swap to rig&displace w/353.7 bbls of 10.0 ppg LSND mud at 7 bpm, 120 psi.Slow rate to 3 bpm,830 psi&bump plug at 3502 strokes. Pressure up to 1340 psi&hold for 5 minutes.Bleed off&check floats,good.CIP 10:10 hrs. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) r/ CI s Volume Pumped(bbl) Intermediate Cement 6,170.0 8,138.0 778 G 160.7 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) ickening Time(hr) CmprStr 1(psi) 1.16 5.05 15.80 171.1 5.50 Additives Additive Type Concentration Conc Unit label Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing Cement 500'above the C 4,911.0 5,512.0 No 0.0 Yes No Cement -37 at 5411'MD 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 6 6 682.0 1,241.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement 2nd stage as per SLB schedule.Pump 5 bbls of H2O. Pump 41.9 bbls of 12.5 ppg mud push at 4.1 bpm, 108 psi. Pump 10.2 bbls of 15.8 ppg neat cement at 5.5 bpm,252 psi. Pump 33.1 bbls of 15.8 ppg cement w/2 ppb of CemNet at 5.5 bpm,222 psi. Pump 4.2 bbls of 15.8 ppg neat cement at 4 bpm, 180 psi. Drop closing plug&pump 10 bbls of H2O at 5 bpm,7 psi.Swap to rig&displace w/243 bbls of 10.0 ppg LSND mud at 7 bpm,300 psi.Slow rate to 3 bpm, 600 psi&bump plug at 2404 strokes.CIP 18:05 hrs. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 4,911.0 5,512.0 229 G 47.3 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.05 15.80 209.1 5.75 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 11/4/2016 HE es - WED • 2 1 6 1 2 8 NOV 09201i 27704 AOGCC ScbluiubergerDrilling & Measurements Transmittal#: 09N0V16-SPO2 DATA LOGGED MWD/LWD Log Product Delivery tt i14i2o14 M K BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2S-09A Date Dispatched: 9-Nov-16 Job#: 16AKA0109 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Contents on CD N/A VISION*Service 2" MD x x VISION*Service 2"TVD x x VISION*Service 5"MD x x VISION*Service 5"TVD x x LAS Digital Data N/A Contents on CD N/A x 1 Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Tom.Osterkamp(a)conocophillips.com AlaskaPTSPrintCenter(a)slb.com Tom Osterkamp Attn:Stephanie Pacillo 907-263-4795 Received By: () ,,,,,,..#4.,,c-/75 r,,,�e.ie • • 116128 REC'SIV el 7 7 0 4 N0\ 09201' GGCG FINAL NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-09A Definitive Survey Report 26 October, 2016 NAD 27 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonly Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonl Well: 2S-09 North Reference: True Wellbore: 2S-09A Survey Calculation Method: Minimum Curvature Design: 2S-09A 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-09 Well Position +N/-S 0.00 usft Northing: 5,929,986.08 usft Latitude: 70°13'11.559 N +E/-W 0.00 usft Easting: 481,074.22 usft Longitude: 150°9'9.654 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore 2S-09A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2016 10/1/2016 17.80 80.84 57.533 Design 2S-09A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 2,800.11 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.10 0.00 0.00 15.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 60.00 835.50 2S-09 Srvy 1-SLB_NSG+MSHOT(2S-0 GYD-GC-MS Gyrodata gyrocompassing m/s 9/14/2016 9:02: 858.68 2,088.06 2S-09 Srvy 2-SLB_MWD+GMAG(2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/14/2016 9:05: 2,184.78 2,758.43 2S-09 Srvy 3-SLB_MWD+GMAG(2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/15/2016 9:05: 2,800.11 2,800.11 2S-09 Srvy 4-SLB_Inc+Filler(2S-09) INC+TREND Inclinometer+known azi trend 9/19/2016 9:33: 2,891.95 8,073.22 2S-09A Srvy 1-SLB_MWD+GMAG(2S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/11/2016 8:10 8,098.11 8,098.11 2S-09A Srvy 2-SLB_Inc+Filler(2S-09A) INC+TREND Inclinometer+known azi trend 10/19/2016 11:41 8,192.63 14,112.54 2S-09A Srvy 3-SLB_MWD+GMAG(2S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/19/2016 11:2, Survey Ti.[.._ Map Map Vertical S'', 1 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 2,800.11 31.87 180.00 2,577.48 2,418.38 -922.97 17.40 5,929,063.16 481,089.31 0.49 -887.02 INC+TREND(4) Sidetrack 2,822.00 31.73 181.04 2,596.08 2,436.98 -934.51 17.30 5,929,051.62 481,089.17 2.58 -898.19 NOT an Actual Survey 5) confirmed at 2854ft Mo 10-3/4"x 13-1/2" J 2,891.95 31.33 184.40 2,655.71 2,496.61 -971.03 15.57 5,929,015.11 481,087.36 2.58 -933.92 MWD+IFR-AK-CAZ-SC(5) 2,987.36 28.70 185.70 2,738.32 2,579.22 -1,018.57 11.39 5,928,967.59 481,083.06 2.84 -980.91 MWD+IFR-AK-CAZ-SC(5) 3,082.49 28.79 200.88 2,821.84 2,662.74 -1,062.76 0.95 5,928,923.43 481,072.50 7.66 -1,026.30 MWD+1FR-AK-CAZ-SC(5) 3,177.56 30.27 207.27 2,904.58 2,745.48 -1,105.46 -18.20 5,928,880.78 481,053.25 3.66 -1,072.50 MWD+IFR-AK-CAZ-SC(5) 3,271.74 28.84 202.81 2,986.51 2,827.41 -1,147.51 -37.88 5,928,838.79 481,033.46 2.79 -1,118.21 MWD+1FR-AK-CAZ-SC(5) 3,367.16 29.15 194.65 3,070.00 2,910.90 -1,191.22 -52.69 5,928,795.11 481,018.55 4.16 -1,164.27 MWD+1FR-AK-CAZ-SC(5) 10/26/2016 1:24:06PM Page 2 COMPASS 5000.1 Build 74 • S Sc hl urnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(DoyonVV Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonl4 Well: 2S-09 North Reference: True Wellbore: 2S-09A Survey Calculation Method: Minimum Curvature Design: 2S-09A 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 3,462.05 31.36 186.38 3,152.00 2,992.90 -1,238.14 -61.28 5,928,748.22 481,009.84 4.97 -1,211.82 MWD+IFR-AK-CAZ-SC(5) 3,556.27 34.48 179.41 3,231.11 3,072.01 -1,289.21 -63.73 5,928,697.16 481,007.26 5.20 -1,261.78 MWD+IFR-AK-CAZ-SC(5) 3,652.10 37.21 173.55 3,308.81 3,149.71 -1,345.15 -60.20 5,928,641.22 481,010.66 4.57 -1,314.90 MWD+IFR-AK-CAZ-SC(5) 3,745.92 39.54 170.38 3,382.36 3,223.26 -1,402.80 -52.02 5,928,583.56 481,018.69 3.25 -1,368.46 MWD+IFR-AK-CAZ-SC(5) 3,839.60 40.52 170.59 3,454.09 3,294.99 -1,462.22 -42.06 5,928,524.11 481,028.50 1.06 -1,423.29 MWD+IFR-AK-CAZ-SC(5) 3,934.28 40.77 175.14 3,525.95 3,366.85 -1,523.38 -34.41 5,928,462.94 481,035.99 3.14 -1,480.38 MWD+IFR-AK-CAZ-SC(5) 4,029.62 40.79 180.15 3,598.16 3,439.06 -1,585.56 -31.85 5,928,400.76 481,038.39 3.43 -1,539.78 MWD+IFR-AK-CAZ-SC(5) 4,124.84 38.06 179.09 3,671.71 3,512.61 -1,646.02 -31.47 5,928,340.30 481,038.63 2.95 -1,598.08 MWD+IFR-AK-CAZ-SC(5) 4,218.95 35.60 178.15 3,747.03 3,587.93 -1,702.41 -30.12 5,928,283.92 481,039.83 2.68 -1,652.20 MWD+IFR-AK-CAZ-SC(5) 4,313.76 32.76 174.22 3,825.46 3,666.36 -1,755.53 -26.65 5,928,230.79 481,043.17 3.79 -1,702.61 MWD+IFR-AK-CAZ-SC(5) 4,408.96 29.90 171.22 3,906.78 3,747.68 -1,804.62 -20.43 5,928,181.69 481,049.27 3.42 -1,748.42 MWD+IFR-AK-CAZ-SC(5) 4,503.92 27.21 167.19 3,990.19 3,831.09 -1,849.20 -12.00 5,928,137.10 481,057.58 3.48 -1,789.29 MWD+IFR-AK-CAZ-SC(5) 4,598.33 24.29 163.31 4,075.22 3,916.12 -1,888.86 -1.64 5,928,097.42 481,067.85 3.57 -1,824.92 MWD+IFR-AK-CAZ-SC(5) 4,691.66 21.22 158.20 4,161.28 4,002.18 -1,922.94 10.15 5,928,063.31 481,079.55 3.91 -1,854.79 MWD+IFR-AK-CAZ-SC(5) 4,786.96 17.66 153.42 4,251.14 4,092.04 -1,951.89 23.03 5,928,034.33 481,092.36 4.09 -1,879.42 MWD+IFR-AK-CAZ-SC(5) 4,881.25 15.32 146.03 4,341.56 4,182.46 -1,975.02 36.39 5,928,011.17 481,105.66 3.33 -1,898.30 MWD+IFR-AK-CAZ-SC(5) 4,976.21 13.71 137.57 4,433.49 4,274.39 -1,993.73 51.00 5,927,992.43 481,120.21 2.80 -1,912.60 MWD+IFR-AK-CAZ-SC(5) 5,071.02 12.27 127.18 4,525.89 4,366.79 -2,008.11 66.61 5,927,978.01 481,135.79 2.89 -1,922.45 MWD+IFR-AK-CAZ-SC(5) 5,165.69 10.78 111.53 4,618.67 4,459.57 -2,017.44 82.86 5,927,968.63 481,152.02 3.64 -1,927.26 MWD+IFR-AK-CAZ-SC(5) 5,260.40 10.97 93.81 4,711.71 4,552.61 -2,021.30 100.10 5,927,964.74 481,169.24 3.52 -1,926.51 MWD+IFR-AK-CAZ-SC(5) 5,354.91 12.68 77.54 4,804.23 4,645.13 -2,019.65 119.21 5,927,966.33 481,188.35 3.95 -1,919.98 MWD+IFR-AK-CAZ-SC(5) 5,450.01 14.53 63.39 4,896.68 4,737:58 -2,012.06 140.07 5,927,973.88 481,209.23 3.99 -1,907.24 MWD+IFR-AK-CAZ-SC(5) 5,544.46 17.05 54.08 4,987.58 4,828.48 -1,998.62 161.89 5,927,987.26 481,231.08 3.78 -1,888.62 MWD+IFR-AK-CAZ-SC(5) 5,639.28 20.66 49.48 5,077.30 4,918.20 -1,979.59 185.87 5,928,006.23 481,255.11 4.11 -1,864.03 MWD+IFR-AK-CAZ-SC(5) 5,734.93 23.32 46.57 5,165.99 5,006.89 -1,955.61 212.45 5,928,030.14 481,281.75 3.00 -1,833.99 MWD+IFR-AK-CAZ-SC(5) 5,829.03 25.52 43.04 5,251.67 5,092.57 -1,927.98 239.82 5,928,057.69 481,309.18 2.80 -1,800.22 MWD+IFR-AK-CAZ-SC(5) 5,924.55 27.48 38.22 5,337.16 5,178.06 -1,895.62 267.50 5,928,089.98 481,336.94 3.04 -1,761.80 MWD+IFR-AK-CAZ-SC(5) 6,019.37 28.99 33.43 5,420.70 5,261.60 -1,859.25 293.70 5,928,126.28 481,363.23 2.87 -1,719.89 MWD+IFR-AK-CAZ-SC(5) 6,113.72 32.13 29.21 5,501.95 5,342.85 -1,818.26 318.55 5,928,167.21 481,388.18 4.03 -1,673.86 MWD+IFR-AK-CAZ-SC(5) 6,208.82 35.40 24.54 5,581.01 5,421.91 -1,771.11 342.34 5,928,214.30 481,412.08 4.39 -1,622.15 MWD+IFR-AK-CAZ-SC(5) 6,302.70 39.17 20.21 5,655.70 5,496.60 -1,718.52 363.89 5,928,266.82 481,433.76 4.89 -1,565.78 MWD+IFR-AK-CAZ-SC(5) 6,398.47 42.70 19.69 5,728.04 5,568.94 -1,659.54 385.28 5,928,325.74 481,455.30 3.70 -1,503.28 MWD+IFR-AK-CAZ-SC(5) 6,492.86 44.87 18.59 5,796.18 5,637.08 -1,597.84 406.69 5,928,387.38 481,476.86 2.44 -1,438.14 MWD+IFR-AK-CAZ-SC(5) 6,587.25 49.28 18.66 5,860.45 5,701.35 -1,532.36 428.76 5,928,452.80 481,499.09 4.67 -1,369.18 MWD+IFR-AK-CAZ-SC(5) 6,681.66 52.72 18.66 5,919.86 5,760.76 -1,462.86 452.23 5,928,522.24 481,522.73 3.64 -1,295.97 MWD+IFR-AK-CAZ-SC(5) 6,776.71 56.06 18.73 5,975.19 5,816.09 -1,389.67 476.99 5,928,595.36 481,547.68 3.51 -1,218.86 MWD+IFR-AK-CAZ-SC(5) 6,870.31 59.21 18.66 6,025.29 5,866.19 -1,314.79 502.33 5,928,670.16 481,573.20 3.37 -1,139.98 MWD+IFR-AK-CAZ-SC(5) 6,964.77 61.98 18.23 6,071.66 5,912.56 -1,236.73 528.36 5,928,748.15 481,599.43 2.96 -1,057.84 MWD+IFR-AK-CAZ-SC(5) 7,059.78 64.54 17.80 6,114.41 5,955.31 -1,156.05 554.60 5,928,828.76 481,625.86 2.72 -973.12 MWD+IFR-AK-CAZ-SC(5) 7,154.57 68.43 15.91 6,152.23 5,993.13 -1,072.88 579.77 5,928,911.86 481,651.24 4.49 -886.27 MWD+IFR-AK-CAZ-SC(5) 10/26/2016 1:24:06PM Page 3 COMPASS 5000.1 Build 74 S • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyon 1z Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyon 1z Well: 2S-09 North Reference: True Wellbore: 2S-09A Survey Calculation Method: Minimum Curvature Design: 2S-09A Database: OAKE DM P2 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 7,249.07 72.21 15.79 6,184.04 6,024.94 -987.30 604.07 5,928,997.37 481,675.75 4.00 -797.31 MWD+IFR-AK-CAZ-SC(5) 7,344.90 75.89 15.55 6,210.37 6,051.27 -898.60 628.95 5,929,086.00 481,700.85 3.85 -705.20 MWD+IFR-AK-CAZ-SC(5) 7,439.56 79.46 14.32 6,230.58 6,071.48 -809.26 652.77 5,929,175.27 481,724.90 3.98 -612.73 MWD+IFR-AK-CAZ-SC(5) 7,534.10 80.63 14.40 6,246.92 6,087.82 -719.05 675.87 5,929,265.41 481,748.21 1.24 -519.62 MWD+IFR-AK-CAZ-SC(5) 7,629.97 80.66 14.19 6,262.50 6,103.40 -627.39 699.22 5,929,357.00 481,771.80 0.22 -425.04 MWD+IFR-AK-CAZ-SC(5) 7,725.44 80.76 14.09 6,277.92 6,118.82 -536.02 722.24 5,929,448.30 481,795.04 0.15 -330.83 MWD+IFR-AK-CAZ-SC(5) 7,820.23 80.55 13.44 6,293.31 6,134.21 -445.18 744.49 5,929,539.08 481,817.52 0.71 -237.32 MWD+IFR-AK-CAZ-SC(5) 7,914.91 81.08 13.12 6,308.42 6,149.32 -354.21 765.96 5,929,629.98 481,839.22 0.65 -143.90 MWD+IFR-AK-CAZ-SC(5) 8,010.14 83.03 13.57 6,321.58 6,162.48 -262.45 787.73 5,929,721.68 481,861.21 2.10 -49.63 MWD+IFR-AK-CAZ-SC(5) 8,073.22 84.76 14.18 6,328.29 6,169.19 -201.56 802.77 5,929,782.53 481,876.41 2.91 13.08 MWD+IFR-AK-CAZ-SC(5) 8,098.11 84.99 13.81 6,330.52 6,171.42 -177.50 808.77 5,929,806.57 481,882.46 1.75 37.87 INC+TREND(6) I8,129.00 85.31 12.98 6,333.13 6,174.03 -147.56 815.90 5,929,836.49 481,889.66 2.88 68.64 NOT an Actual Survey' 7-5/8"x 9-7/8 by 11" i 8,192.63 85.97 11.26 6,337.97 6,178.87 -85.53 829.22 5,929,898.48 481,903.14 2.88 132.00 MWD+IFR-AK-CAZ-SC(7) 8,287.53 89.18 11.28 6,341.98 6,182.88 7.44 847.74 5,929,991.40 481,921.90 3.38 226.60 MWD+IFR-AK-CAZ-SC(7) 8,382.86 91.73 11.97 6,341.22 6,182.12 100.81 866.95 5,930,084.70 481,941.33 2.77 321.75 MWD+IFR-AK-CAZ-SC(7) 8,477.27 91.89 11.85 6,338.24 6,179.14 193.14 886.42 5,930,176.97 481,961.04 0.21 415.98 MWD+IFR-AK-CAZ-SC(7) 8,572.31 91.30 11.81 6,335.60 6,176.50 286.12 905.90 5,930,269.90 481,980.75 0.62 510.84 MWD+IFR-AK-CAZ-SC(7) 8,666.18 90.65 11.56 6,334.00 6,174.90 378.03 924.91 5,930,361.75 481,999.98 0.74 604.54 MWD+IFR-AK-CAZ-SC(7) 8,760.98 90.38 11.71 6,333.15 6,174.05 470.88 944.03 5,930,454.55 482,019.33 0.33 699.17 MWD+IFR-AK-CAZ-SC(7) 8,855.91 90.34 11.48 6,332.55 6,173.45 563.87 963.11 5,930,547.48 482,038.64 0.25 793.93 MWD+IFR-AK-CAZ-SC(7) 8,951.42 90.58 10.51 6,331.78 6,172.68 657.62 981.32 5,930,641.18 482,057.09 1.05 889.20 MWD+IFR-AK-CAZ-SC(7) 9,045.82 90.82 10.63 6,330.63 6,171.53 750.42 998.64 5,930,733.91 482,074.64 0.28 983.31 MWD+IFR-AK-CAZ-SC(7) 9,138.92 90.62 10.17 6,329.46 6,170.36 841.98 1,015.44 5,930,825.43 482,091.67 0.54 1,076.10 MWD+IFR-AK-CAZ-SC(7) 9,234.56 90.69 10.51 6,328.37 6,169.27 936.06 1,032.61 5,930,919.45 482,109.07 0.36 1,171.42 MWD+IFR-AK-CAZ-SC(7) 9,329.61 91.17 9.87 6,326.82 6,167.72 1,029.60 1,049.42 5,931,012.94 482,126.12 0.84 1,266.12 MWD+IFR-AK-CAZ-SC(7) 9,423.86 90.17 9.02 6,325.72 6,166.62 1,122.56 1,064.89 5,931,105.85 482,141.81 1.39 1,359.92 MWD+IFR-AK-CAZ-SC(7) 9,518.83 90.00 9.79 6,325.58 6,166.48 1,216.25 1,080.41 5,931,199.50 482,157.56 0.83 1,454.44 MWD+IFR-AK-CAZ-SC(7) 9,613.21 90.03 10.10 6,325.56 6,166.46 1,309.21 1,096.71 5,931,292.41 482,174.10 0.33 1,548.45 MWD+IFR-AK-CAZ-SC(7) 9,708.21 90.03 10.99 6,325.51 6,166.41 1,402.61 1,114.09 5,931,385.75 482,191.71 0.94 1,643.16 MWD+IFR-AK-CAZ-SC(7) 9,802.63 89.59 11.14 6,325.82 6,166.72 1,495.27 1,132.21 5,931,478.36 482,210.07 0.49 1,737.36 MWD+IFR-AK-CAZ-SC(7) 9,898.19 89.38 11.20 6,326.68 6,167.58 1,589.02 1,150.72 5,931,572.05 482,228.81 0.23 1,832.70 MWD+IFR-AK-CAZ-SC(7) 9,992.55 88.52 12.62 6,328.41 6,169.31 1,681.33 1,170.19 5,931,664.30 482,248.51 1.76 1,926.91 MWD+IFR-AK-CAZ-SC(7) 10,087.44 88.77 14.23 6,330.65 6,171.55 1,773.60 1,192.22 5,931,756.51 482,270.76 1.72 2,021.73 MWD+IFR-AK-CAZ-SC(7) 10,181.95 89.21 16.02 6,332.32 6,173.22 1,864.82 1,216.87 5,931,847.65 482,295.64 1.95 2,116.22 MWD+IFR-AK-CAZ-SC(7) 10,276.00 89.93 16.07 6,333.02 6,173.92 1,955.20 1,242.87 5,931,937.96 482,321.86 0.77 2,210.25 MWD+IFR-AK-CAZ-SC(7) 10,371.25 90.96 14.82 6,332.28 6,173.18 2,047.00 1,268.23 5,932,029.69 482,347.45 1.70 2,305.50 MWD+IFR-AK-CAZ-SC(7) 10,465.96 91.13 14.92 6,330.56 6,171.46 2,138.53 1,292.53 5,932,121.15 482,371.98 0.21 2,400.19 MWD+IFR-AK-CAZ-SC(7) 10,561.14 90.07 15.34 6,329.56 6,170.46 2,230.40 1,317.37 5,932,212.95 482,397.05 1.20 2,495.36 MWD+IFR-AK-CAZ-SC(7) 10,656.07 89.97 16.63 6,329.53 6,170.43 2,321.66 1,343.51 5,932,304.13 482,423.42 1.36 2,590.28 MWD+IFR-AK-CAZ-SC(7) 10/26/2016 1:24:06PM Page 4 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonl� Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonl� Well: 2S-09 North Reference: True Wellbore: 2S-09A Survey Calculation Method: Minimum Curvature Design: 2S-09A 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) (°1100') (ft) Survey Tool Name 10,751.75 89.25 17.29 6,330.18 6,171.08 2,413.17 1,371.42 5,932,395.57 482,451.55 1.02 2,685.90 MWD+IFR-AK-CAZ-SC(7) 10,845.73 89.21 17.30 6,331.44 6,172.34 2,502.90 1,399.36 5,932,485.21 482,479.71 0.04 2,779.79 MWD+IFR-AK-CAZ-SC(7) 10,939.95 89.14 16.65 6,332.80 6,173.70 2,593.00 1,426.87 5,932,575.24 482,507.44 0.69 2,873.95 MWD+IFR-AK-CAZ-SC(7) 11,035.25 89.55 15.97 6,333.89 6,174.79 2,684.46 1,453.63 5,932,666.62 482,534.43 0.83 2,969.21 MWD+IFR-AK-CAZ-SC(7) 11,130.69 90.33 15.59 6,333.99 6,174.89 2,776.30 1,479.58 5,932,758.39 482,560.61 0.91 3,064.64 MWD+IFR-AK-CAZ-SC(7) 11,225.14 93.02 14.87 6,331.23 6,172.13 2,867.39 1,504.38 5,932,849.40 482,585.64 2.95 3,159.04 MWD+IFR-AK-CAZ-SC(7) 11,320.11 94.98 14.31 6,324.60 6,165.50 2,959.06 1,528.24 5,932,941.01 482,609.73 2.15 3,253.78 MWD+IFR-AK-CAZ-SC(7) 11,414.56 95.58 13.35 6,315.91 6,156.81 3,050.39 1,550.73 5,933,032.26 482,632.44 1.19 3,347.80 MWD+IFR-AK-CAZ-SC(7) 11,509.80 93.67 13.36 6,308.23 6,149.13 3,142.74 1,572.65 5,933,124.56 482,654.59 2.01 3,442.69 MWD+IFR-AK-CAZ-SC(7) 11,605.20 90.71 11.77 6,304.59 6,145.49 3,235.78 1,593.39 5,933,217.53 482,675.56 3.52 3,537.92 MWD+IFR-AK-CAZ-SC(7) 11,700.10 89.61 11.02 6,304.32 6,145.22 3,328.81 1,612.14 5,933,310.50 482,694.54 1.40 3,632.63 MWD+IFR-AK-CAZ-SC(7) 11,795.02 89.83 8.94 6,304.78 6,145.68 3,422.28 1,628.58 5,933,403.93 482,711.22 2.20 3,727.18 MWD+IFR-AK-CAZ-SC(7) 11,884.94 90.51 7.36 6,304.52 6,145.42 3,511.29 1,641.33 5,933,492.89 482,724.19 1.91 3,816.45 MWD+IFR-AK-CAZ-SC(7) 11,977.90 91.34 6.45 6,303.02 6,143.92 3,603.56 1,652.51 5,933,585.13 482,735.59 1.32 3,908.47 MWD+IFR-AK-CAZ-SC(7) 12,069.88 92.28 7.64 6,300.11 6,141.01 3,694.80 1,663.78 5,933,676.33 482,747.09 1.65 3,999.52 MWD+IFR-AK-CAZ-SC(7) 12,161.21 90.91 10.52 6,297.57 6,138.47 3,784.94 1,678.19 5,933,766.42 482,761.73 3.49 4,090.32 MWD+IFR-AK-CAZ-SC(7) 12,208.82 88.67 13.34 6,297.74 6,138.64 3,831.51 1,688.03 5,933,812.97 482,771.68 7.56 4,137.85 MWD+IFR-AK-CAZ-SC(7) 12,253.41 88.15 15.65 6,298.98 6,139.88 3,874.66 1,699.18 5,933,856.08 482,782.94 5.31 4,182.42 MWD+IFR-AK-CAZ-SC(7) 12,303.81 87.29 17.15 6,300.99 6,141.89 3,922.97 1,713.40 5,933,904.35 482,797.28 3.43 4,232.76 MWD+IFR-AK-CAZ-SC(7) 12,346.16 88.49 17.95 6,302.55 6,143.45 3,963.32 1,726.16 5,933,944.67 482,810.14 3.40 4,275.04 MWD+IFR-AK-CAZ-SC(7) 12,438.36 90.88 17.07 6,303.05 6,143.95 4,051.24 1,753.90 5,934,032.51 482,838.10 2.76 4,367.14 MWD+IFR-AK-CAZ-SC(7) 12,531.22 90.34 15.74 6,302.06 6,142.96 4,140.31 1,780.12 5,934,121.51 482,864.54 1.55 4,459.97 MWD+IFR-AK-CAZ-SC(7) 12,623.29 90.47 14.59 6,301.41 6,142.31 4,229.17 1,804.21 5,934,210.30 482,888.85 1.26 4,552.03 MWD+IFR-AK-CAZ-SC(7) 12,715.13 91.85 14.11 6,299.55 6,140.45 4,318.13 1,826.97 5,934,299.18 482,911.82 1.59 4,643.85 MWD+IFR-AK-CAZ-SC(7) 12,808.15 92.02 12.76 6,296.41 6,137.31 4,408.55 1,848.56 5,934,389.54 482,933.65 1.46 4,736.78 MWD+IFR-AK-CAZ-SC(7) 12,901.01 91.13 12.21 6,293.86 6,134.76 4,499.18 1,868.63 5,934,480.11 482,953.94 1.13 4,829.51 MWD+IFR-AK-CAZ-SC(7) 12,991.52 89.78 10.78 6,293.14 6,134.04 4,587.87 1,886.67 5,934,568.74 482,972.20 2.17 4,919.84 MWD+IFR-AK-CAZ-SC(7) 13,083.76 89.83 11.07 6,293.46 6,134.36 4,678.43 1,904.15 5,934,659.26 482,989.90 0.32 5,011.85 MWD+IFR-AK-CAZ-SC(7) 13,176.68 90.43 9.96 6,293.24 6,134.14 4,769.79 1,921.11 5,934,750.56 483,007.09 1.36 5,104.48 MWD+IFR-AK-CAZ-SC(7) 13,267.85 88.82 10.24 6,293.84 6,134.74 4,859.54 1,937.09 5,934,840.27 483,023.30. 1.79 5,195.31 MWD+IFR-AK-CAZ-SC(7) 13,360.37 88.55 10.26 6,295.96 6,136.86 4,950.56 1,953.55 5,934,931.24 483,039.98 0.29 5,287.49 MWD+IFR-AK-CAZ-SC(7) 13,452.63 89.76 11.44 6,297.32 6,138.22 5,041.16 1,970.92 5,935,021.78 483,057.57 1.83 5,379.50 MWD+IFR-AK-CAZ-SC(7) 13,544.62 89.69 12.48 6,297.77 6,138.67 5,131.15 1,989.98 5,935,111.71 483,076.86 1.13 5,471.36 MWD+IFR-AK-CAZ-SC(7) 13,638.49 90.34 12.39 6,297.74 6,138.64 5,222.82 2,010.19 5,935,203.32 483,097.30 0.70 5,565.13 MWD+IFR-AK-CAZ-SC(7) 13,731.30 89.97 11.58 6,297.49 6,138.39 5,313.60 2,029.46 5,935,294.05 483,116.80 0.96 5,657.81 MWD+IFR-AK-CAZ-SC(7) 13,822.95 90.00 10.34 6,297.51 6,138.41 5,403.58 2,046.89 5,935,383.97 483,134.45 1.35 5,749.23 MWD+IFR-AK-CAZ-SC(7) 13,915.96 90.00 9.38 6,297.51 6,138.41 5,495.22 2,062.82 5,935,475.56 483,150.60 1.03 5,841.87 MWD+IFR-AK-CAZ-SC(7) 14,006.73 89.98 7.83 6,297.53 6,138.43 5,584.96 2,076.40 5,935,565.26 483,164.41 1.71 5,932.07 MWD+IFR-AK-CAZ-SC(7) 14,099.52 87.91 6.27 6,299.24 6,140.14 5,677.03 2,087.78 5,935,657.29 483,176.02 2.79 6,023.94 MWD+IFR-AK-CAZ-SC(7) 14,112.54 88.74 6.55 6,299.62 6,140.52 5,689.96 2,089.24 5,935,670.22 483,177.51 6.73 6,036.81 MWD+IFR-AK-CAZ-SC(7) 10/26/2016 1:24:06PM Page 5 COMPASS 5000.1 Build 74 . . Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonl2 Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonli Well: 2S-09 North Reference: True Wellbore: 2S-09A Survey Calculation Method: Minimum Curvature Design: 2S-09A 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 14,160.00 88.74 6.55 6,300.66 6.141.56 5,737.10 2,094.65 5.935,717.34 483,183.04 0.00 6.083.75 NOT an Actual Survey 4 1/2"x 6-3/4" 14,172.00 88.74 6.55 6,300.93 6,141.83 5,749.02 2,096.02 5,935,729.25 483,184.44 0.00 6,095.61 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. E Yes U No I have checked to the best of my ability that the following data is correct: i] Surface Coordinates O Declination & Convergence El GRS Survey Corrections Digitally spned Sy Vircent Osara E Survey Tool Codes Vincent o"= v„remosara. (.Sd'lumberger, oo=Sch'..umoerger. SLB DE: Osara emai'=vosara&Mbcom.c=US Date:2016.10.2614:MS3-08W' Client Representative: ,r `" _= -r - — -��s -4 ._ ),..\) Date: 26-Oct-2016 10/26/2016 1:24:06PM Page 6 COMPASS 5000.1 Build 74 • • 21 61 28 27 70 4 cteolt,:e c7.0'67.0'6Nov 9 FINAL NOCK ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad 2S-09A Definitive Survey Report 25 October, 2016 NAD 83 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(DoyonVV Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(DoyonVV Well: 2S-09 North Reference: True Wellbore: 2S-09A Survey Calculation Method: Minimum Curvature Design: 2S-09A Database: OAKE DM P2 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-09 Well Position +N/-S 0.00 usft Northing: 5,929,735.67 usft Latitude: 70°13'10.439 N +E/-W 0.00 usft Easting: 1,621,107.54 usft Longitude: 150°9'20.804 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore 2S-09A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2016 10/1/2016 17.80 80.84 57,533 Design 2S-09A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 2,800.11 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.10 0.00 0.00 15.00 Survey Program Date 10/25/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 60.00 835.50 2S-09 Srvy 1-SLB_NSG+MSHOT(2S-0 GYD-GC-MS Gyrodata gyrocompassing m/s 9/14/2016 9:02: 858.68 2,088.06 2S-09 Srvy 2-SLB_MWD+GMAG(2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/14/2016 9:05: 2,184.78 2,758.43 2S-09 Srvy 3-SLB_MWD+GMAG(2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/15/2016 9:05: 2,800.11 2,800.11 2S-09 Srvy 4-SLB_Inc+Filler(2S-09) INC+TREND Inclinometer+known azi trend 9/19/2016 9:33: 2,891.95 8,073.22 2S-09A Srvy 1-SLB_MWD+GMAG(2S MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/11/2016 8:1C 8,098.11 8,098.11 2S-09A Srvy 2-SLB_Inc+Filler(2S-09A INC+TREND Inclinometer+known azi trend 10/19/2016 11:4! 8,192.63 14,112.54 2S-09A Srvy 3-SLB_MWD+GMAG(2S MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/19/2016 11:2• Survey Tie SUI 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 L-i"2,800.11 31.87 180.00 2.577.48 2,418.38 -922.97 17.40 5,928,812.74 1,621,122.58 0.49 -887.02 INC+TREND(4) Sidetrack 2,822.00 31.73 181.04 2,596.08 2,436.98 -934.51 17.30 5,928,801.21 1,621,122.45 2.58 -898.19 ry NOT an Actual Survey confirmed at 2854ft MD 10-3/4"x 13.1/2" 2,891.95 31.33 184.40 2,655.71 2,496.61 -971.03 15.57 5,928,764.69 1,621,120.63 2.58 -933.92 MWD+1FR-AK-CAZ-SC(5) 2,987.36 28.70 185.70 2,738.32 2,579.22 -1,018.57 11.39 5,928,717.17 1,621,116.33 2.84 -980.91 MWD+1FR-AK-CAZ-SC(5) 3,082.49 28.79 200.88 2,821.84 2,662.74 -1,062.76 0.95 5,928,673.01 1,621,105.77 7.66 -1,026.30 MWD+1FR-AK-CAZ-SC(5) 3,177.56 30.27 207.27 2,904.58 2,745.48 -1,105.46 -18.20 5,928,630.37 1,621,086.52 3.66 -1,072.50 MWD+1FR-AK-CAZ-SC(5) 3,271.74 28.84 202.81 2,986.51 2,827.41 -1,147.51 -37.88 5,928,588.38 1,621,066.73 2.79 -1,118.21 MWD+1FR-AK-CAZ-SC(5) 3,367.16 29.15 194.65 3,070.00 2,910.90 -1,191.22 -52.69 5,928,544.70 1,621,051.81 4.16 -1,164.27 MWD+1FR-AK-CAZ-SC(5) 10/25/2016 3:57:10PM Page 2 COMPASS 5000.1 Build 74 • • Schlurnberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120©159.10usft(Doyonl� Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonl� Well: 2S-09 North Reference: True Wellbore: 2S-09A Survey Calculation Method: Minimum Curvature Design: 2S-09A 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 3,462.05 31.36 186.38 3,152.00 2,992.90 -1,238.14 -61.28 5,928,497.81 1,621 043 10 4.97 -1.211.82 MWD+IFR-AK-CAZ-SC(5) 3,556.27 34.48 179.41 3,231.11 3,072.01 -1,289.21 -63.73 5,928,446.75 1,621,040.52 5.20 -1,261.78 MWD+1FR-AK-CAZ-SC(5) 3,652.10 37.21 173.55 3,308.81 3,149.71 -1,345.15 -60.20 5,928,390.81 1,621,043.91 4.57 -1,314.90 MWD+1FR-AK-CAZ-SC(5) 3,745.92 39.54 170.38 3,382.36 3,223.26 -1,402.80 -52.02 5,928,333.15 1,621,051.94 3.25 -1,368.46 MWD+IFR-AK-CAZ-SC(5) 3,839.60 40.52 170.59 3,454.09 3,294.99 -1,462.22 -42.06 5,928,273.70 1,621,061.75 1.06 -1,423.29 MWD+IFR-AK-CAZ-SC(5) 3,934.28 40.77 175.14 3,525.95 3,366.85 -1,523.38 -34.41 5,928,212.53 1,621,069.24 3.14 -1,480.38 MWD+IFR-AK-CAZ-SC(5) 4,029.62 40.79 180.15 3,598.16 3,439.06 -1,585.56 -31.85 5,928,150.35 1,621,071.64 3.43 -1,539.78 MWD+IFR-AK-CAZ-SC(5) 4,124.84 38.06 179.09 3,671.71 3,512.61 -1,646.02 -31.47 5,928,089.89 1,621,071.87 2.95 -1,598.08 MWD+IFR-AK-CAZ-SC(5) 4,218.95 35.60 178.15 3,747.03 3,587.93 -1,702.41 -30.12 5,928,033.50 1,621,073.07 2.68 -1,652.20 MWD+IFR-AK-CAZ-SC(5) 4,313.76 32.76 174.22 3,825.46 3,666.36 -1,755.53 -26.65 5,927,980.38 1,621,076.41 3.79 -1,702.61 MWD+IFR-AK-CAZ-SC(5) 4,408.96 29.90 171.22 3,906.78 3,747.68 -1,804.62 -20.43 5,927,931.28 1,621,082.50 3.42 -1,748.42 MWD+IFR-AK-CAZ-SC(5) 4,503.92 27.21 167.19 3,990.19 3,831.09 -1,849.20 -12.00 5,927,886.69 1,621,090.81 3.48 -1,789.29 MWD+IFR-AK-CAZ-SC(5) 4,598.33 24.29 163.31 4,075.22 3,916.12 -1,888.86 -1.64 5,927,847.01 1,621,101.07 3.57 -1,824.92 MWD+IFR-AK-CAZ-SC(5) 4,691.66 21.22 158.20 4,161.28 4,002.18 -1,922.94 10.15 5,927,812.90 1,621,112.77 3.91 -1,854.79 MWD+1FR-AK-CAZ-SC(5) 4,786.96 17.66 153.42 4,251.14 4,092.04 -1,951.89 23.03 5,927,783.92 1,621,125.58 4.09 -1,879.42 MWD+1FR-AK-CAZ-SC(5) 4,881.25 15.32 146.03 4,341.56 4,182.46 -1,975.02 36.39 5,927,760.76 1,621,138.88 3.33 -1,898.30 MWD+1FR-AK-CAZ-SC(5) 4,976.21 13.71 137.57 4,433.49 4,274.39 -1,993.73 51.00 5,927,742.01 1,621,153.43 2.80 -1,912.60 MWD+IFR-AK-CAZ-SC(5) 5,071.02 12.27 127.18 4,525.89 4,366.79 -2,008.11 66.61 5,927,727.59 1,621,169.01 2.89 -1,922.45 MWD+1FR-AK-CAZ-SC(5) 5,165.69 10.78 111.53 4,618.67 4,459.57 -2,017.44 82.86 5,927,718.22 1,621,185.24 3.64 -1,927.26 MWD+1FR-AK-CAZ-SC(5) 5,260.40 10.97 93.81 4,711.71 4,552.61 -2,021.30 100.10 5,927,714.32 1,621,202.46 3.52 -1,926.51 MWD+IFR-AK-CAZ-SC(5) 5,354.91 12.68 77.54 4,804.23 4,645.13 -2,019.65 119.21 5,927,715.92 1,621,221.57 3.95 -1,919.98 MWD+IFR-AK-CAZ-SC(5) 5,450.01 14.53 63.39 4,896.68 4,737.58 -2,012.06 140.07 5,927,723.46 1,621,242.45 3.99 -1,907.24 MWD+IFR-AK-CAZ-SC(5) 5,544.46 17.05 54.08 4,987.58 4,828.48 -1,998.62 161.89 5,927,736.84 1,621,264.30 3.78 -1,888.62 MWD+IFR-AK-CAZ-SC(5) 5,639.28 20.66 49.48 5,077.30 4,918.20 -1,979.59 185.87 5,927,755.80 1,621,288.33 4.11 -1,864.03 MWD+1FR-AK-CAZ-SC(5) 5,734.93 23.32 46.57 5,165.99 5,006.89 -1,955.61 212.45 5,927,779.72 1,621,314.97 3.00 -1,833.99 MWD+IFR-AK-CAZ-SC(5) 5,829.03 25.52 43.04 5,251.67 5,092.57 -1,927.98 239.82 5,927,807.27 1,621,342.40 2.80 -1,800.22 MWD+1FR-AK-CAZ-SC(5) 5,924.55 27.48 38.22 5,337.16 5,178.06 -1,895.62 267.50 5,927,839.55 1,621,370.16 3.04 -1,761.80 MWD+IFR-AK-CAZ-SC(5) 6,019.37 28.99 33.43 5,420.70 5,261.60 -1,859.25 293.70 5,927,875.85 1,621,396.45 2.87 -1,719.89 MWD+IFR-AK-CAZ-SC(5) 6,113.72 32.13 29.21 5,501.95 5,342.85 -1,818.26 318.55 5,927,916.78 1,621,421.40 4.03 -1,673.86 MWD+IFR-AK-CAZ-SC(5) 6,208.82 35.40 24.54 5,581.01 5,421.91 -1,771.11 342.34 5,927,963.87 1,621,445.32 4.39 -1,622.15 MWD+IFR-AK-CAZ-SC(5) 6,302.70 39.17 20.21 5,655.70 5,496.60 -1,718.52 363.89 5,928,016.39 1,621,466.99 4.89 -1,565.78 MWD+IFR-AK-CAZ-SC(5) 6,398.47 42.70 19.69 5,728.04 5,568.94 -1,659.54 385.28 5,928,075.31 1,621,488.54 3.70 -1,503.28 MWD+IFR-AK-CAZ-SC(5) 6,492.86 44.87 . 18.59 5,796.18 5,637.08 -1,597.84 406.69 5,928,136.95 1,621,510.10 2.44 -1,438.14 MWD+IFR-AK-CAZ-SC(5) 6,587.25 49.28 18.66 5,860.45 5,701.35 -1,532.36 428.76 5,928,202.37 1,621,532.33 4.67 -1,369.18 MWD+1FR-AK-CAZ-SC(5) 6,681.66 52.72 18.66 5,919.86 5,760.76 -1,462.86 452.23 5,928,271.80 1,621,555.98 3.64 -1,295.97 MWD+IFR-AK-CAZ-SC(5) 6,776.71 56.06 18.73 5,975.19 5,816.09 -1,389.67 476.99 5,928,344.92 1,621,580.93 3.51 -1,218.86 MWD+IFR-AK-CAZ-SC(5) 6,870.31 59.21 18.66 6,025.29 5,866.19 -1,314.79 502.33 5,928,419.73 1,621,606.46 3.37 -1,139.98 MWD+IFR-AK-CAZ-SC(5) 6,964.77 61.98 18.23 6,071.66 5,912.56 -1,236.73 528.36 5,928,497.71 1,621,632.68 2.96 -1,057.84 MWD+IFR-AK-CAZ-SC(5) 7,059.78 64.54 17.80 6,114.41 5,955.31 -1,156.05 554.60 5,928,578.32 1,621,659.12 2.72 -973.12 MWD+IFR-AK-CAZ-SC(5) 7,154.57 68.43 15.91 6,152.23 5,993.13 -1,072.88 579.77 5,928,661.41 1,621,684.51 4.49 -886.27 MWD+IFR-AK-CAZ-SC(5) 10/25/2016 3:57:10PM Page 3 COMPASS 5000.1 Build 74 • • Schlurnberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyon 1V Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyon 1. Well: 2S-09 North Reference: True Wellbore: 2S-09A Survey Calculation Method: Minimum Curvature Design: 2S-09A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100) (ft) Survey Tool Name 7,249.07 72.21 15.79 6,184.04 6,024.94 -987.30 604.07 5,928,746.92 1,621,709.02 4.00 -797.31 MWD+IFR-AK-CAZ-SC(5) 7,344.90 75.89 15.55 6,210.37 6,051.27 -898.60 628.95 5,928,835.55 1,621,734.13 3.85 -705.20 MWD+IFR-AK-CAZ-SC(5) 7,439.56 79.46 14.32 6,230.58 6,071.48 -809.26 652.77 5,928,924.82 1,621,758.18 3.98 -612.73 MWD+IFR-AK-CAZ-SC(5) 7,534.10 80.63 14.40 6,246.92 6,087.82 -719.05 675.87 5,929,014.96 1,621,781.50 1.24 -519.62 MWD+IFR-AK-CAZ-SC(5) 7,629.97 80.66 14.19 6,262.50 6,103.40 -627.39 699.22 5,929,106.56 1,621,805.09 0.22 -425.04 MWD+IFR-AK-CAZ-SC(5) 7,725.44 80.76 14.09 6,277.92 6,118.82 -536.02 722.24 5,929,197.85 1,621,828.33 0.15 -330.83 MWD+IFR-AK-CAZ-SC(5) 7,820.23 80.55 13.44 6,293.31 6,134.21 -445.18 744.49 5,929,288.63 1,621,850.82 0.71 -237.32 MWD+IFR-AK-CAZ-SC(5) 7,914.91 81.08 13.12 6,308.42 6,149.32 -354.21 765.96 5,929,379.53 1,621,872.52 0.65 -143.90 MWD+IFR-AK-CAZ-SC(5) 8,010.14 83.03 13.57 6,321.58 6,162.48 -262.45 787.73 5,929,471.23 1,621,894.52 2.10 -49.63 MWD+IFR-AK-CAZ-SC(5) 8,073.22 84.76 14.18 6,328.29 6,169.19 -201.56 802.77 5,929,532.08 1,621,909.72 2.91 13.08 MWD+IFR-AK-CAZ-SC(5) 8,098.11 84.99 13.81 6,330.52 6,171.42 -177.50 808.77 5,929,556.11 1,621,915.77 1.75 37.87 INC+TREND(6) 8,129.00 85.31 12.98 6,333.13 6,174.03 -147.56 815.90 5,929,586.03 1,621,922.98 2.88 68.64 NOT an Actual Survey 7) 7-5/8"x 9-7/8 by 11" 8,192.63 85.97 11.26 6,337.97 6,178.87 -85.53 829.22 5,929,648.02 1,621,936.45 2.88 132.00 MWD+IFR-AK-CAZ-SC(7) 8,287.53 89.18 11.28 6,341.98 6,182.88 7.44 847.74 5,929,740.94 1,621,955.22 3.38 226.60 MWD+IFR-AK-CAZ-SC(7) 8,382.86 91.73 11.97 6,341.22 6,182.12 100.81 866.95 5,929,834.24 1,621,974.66 2.77 321.75 MWD+IFR-AK-CAZ-SC(7) 8,477.27 91.89 11.85 6,338.24 6,179.14 193.14 886.42 5,929,926.52 1,621,994.37 0.21 415.98 MWD+IFR-AK-CAZ-SC(7) 8,572.31 91.30 11.81 6,335.60 6,176.50 286.12 905.90 5,930,019.44 1,622,014.08 0.62 510.84 MWD+IFR-AK-CAZ-SC(7) 8,666.18 90.65 11.56 6,334.00 6,174.90 378.03 924.91 5,930,111.29 1,622,033.32 0.74 604.54 MWD+IFR-AK-CAZ-SC(7) 8,760.98 90.38 11.71 6,333.15 6,174.05 470.88 944.03 5,930,204.08 1,622,052.68 0.33 699.17 MWD+IFR-AK-CAZ-SC(7) 8,855.91 90.34 11.48 6,332.55 6,173.45 563.87 963.11 5,930,297.02 1,622,071.99 0.25 793.93 MWD+IFR-AK-CAZ-SC(7) 8,951.42 90.58 10.51 6,331.78 6,172.68 657.62 981.32 5,930,390.71 1,622,090.45 1.05 889.20 MWD+IFR-AK-CAZ-SC(7) 9,045.82 90.82 10.63 6,330.63 6,171.53 750.42 998.64 5,930,483.45 1,622,108.00 0.28 983.31 MWD+IFR-AK-CAZ-SC(7) 9,138.92 90.62 10.17 6,329.46 6,170.36 841.98 1,015.44 5,930,574.96 1,622,125.03 0.54 1,076.10 MWD+IFR-AK-CAZ-SC(7) 9,234.56 90.69 10.51 6,328.37 6,169.27 936.06 1,032.61 5,930,668.99 1,622,142.44 0.36 1,171.42 MWD+IFR-AK-CAZ-SC(7) 9,329.61 91.17 9.87 6,326.82 6,167.72 1,029.60 1,049.42 5,930,762.47 1,622,159.49 0.84 1,266.12 MWD+IFR-AK-CAZ-SC(7) 9,423.86 90.17 9.02 6,325.72 6,166.62 1,122.56 1,064.89 5,930,855.39 1,622,175.19 1.39 1,359.92 MWD+IFR-AK-CAZ-SC(7) 9,518.83 90.00 9.79 6,325.58 6,166.48 1,216.25 1,080.41 5,930,949.03 1,622,190.95 0.83 1,454.44 MWD+IFR-AK-CAZ-SC(7) 9,613.21 90.03 10.10 6,325.56 6,166.46 1,309.21 1,096.71 5,931,041.94 1,622,207.48 0.33 1,548.45 MWD+IFR-AK-CAZ-SC(7) 9,708.21 90.03 10.99 6,325.51 6,166.41 1,402.61 1,114.09 5,931,135.28 1,622,225.11 0.94 1,643.16 MWD+IFR-AK-CAZ-SC(7) 9,802.63 89.59 11.14 6,325.82 6,166.72 1,495.27 1,132.21 5,931,227.89 1,622,243.46 0.49 1,737.36 MWD+IFR-AK-CAZ-SC(7) 9,898.19 89.38 11.20 6,326.68, 6,167.58 1,589.02 1,150.72 5,931,321.58 1,622,262.21 0.23 1,832.70 MWD+IFR-AK-CAZ-SC(7) 9,992.55 88.52 12.62 6,328.41 6,169.31 1,681.33 1,170.19 5,931,413.83 1,622,281.91 1.76 1,926.91 MWD+IFR-AK-CAZ-SC(7) 10,087.44 88.77 14.23 6,330.65 6,171.55 1,773.60 1,192.22 5,931,506.03 1,622,304.17 1.72 2,021.73 MWD+IFR-AK-CAZ-SC(7) 10,181.95 89.21 16.02 6,332.32 6,173.22 1,864.82 1,216.87 5,931,597.18 1,622,329.06 1.95 2,116.22 MWD+IFR-AK-CAZ-SC(7) 10,276.00 89.93 16.07 6,333.02 6,173.92 1,955.20 1,242.87 5,931,687.48 1,622,355.28 0.77 2,210.25 MWD+IFR-AK-CAZ-SC(7) 10,371.25 90.96 14.82 6,332.28 6,173.18 2,047.00 1,268.23 5,931,779.21 1,622,380.88 1.70 2,305.50 MWD+IFR-AK-CAZ-SC(7) 10,465.96 91.13 14.92 6,330.56 6,171.46 2,138.53 1,292.53 5,931,870.67 1,622,405.41 0.21 2,400.19 MWD+IFR-AK-CAZ-SC(7) 10,561.14 90.07 15.34 6,329.56 6,170.46 2,230.40 1,317.37 5,931,962.47 1,622,430.48 1.20 2,495.36 MWD+IFR-AK-CAZ-SC(7) 10,656.07 89.97 16.63 6,329.53 6,170.43 2,321.66 1,343.51 5,932,053.65 1,622,456.86 1.36 2,590.28 MWD+IFR-AK-CAZ-SC(7) 10/25/2016 3:57:10PM Page 4 COMPASS 5000.1 Build 74 • 0 Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(DoyonlL Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyon1z Well: 2S-09 North Reference: True Wellbore: 2S-09A Survey Calculation Method: Minimum Curvature Design: 2S-09A 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 10,751 75 89.25 17.29 6,330.18 6,171.08 2,413.17 1,371.42 5,932,145.08 1.622,485.00 1.02 2,685.90 MWD+IFR-AK-CAZ-SC(7) 10,845.73 89.21 17.30 6,331.44 6,172.34 2,502.90 1,399.36 5,932,234.73 1,622,513.16 0.04 2,779.79 MWD+IFR-AK-CAZ-SC(7) 10,939.95 89.14 16.65 6,332.80 6,173.70 2,593.00 1,426.87 5,932,324.75 1,622,540.89 0.69 2,873.95 MWD+IFR-AK-CAZ-SC(7) 11,035.25 89.55 15.97 6,333.89 6,174.79 2,684.46 1,453.63 5,932,416.13 1,622,567.89 0.83 2,969.21 MWD+IFR-AK-CAZ-SC(7) 11,130.69 90.33 15.59 6,333.99 6,174.89 2,776.30 1,479.58 5,932,507.90 1,622,594.07 0.91 3,064.64 MWD+IFR-AK-CAZ-SC(7) 11,225.14 93.02 14.87 6,331.23 6,172.13 2,867.39 1,504.38 5,932,598.91 1,622,619.10 2.95 3,159.04 MWD+IFR-AK-CAZ-SC(7) 11,320.11 94.98 14.31 6,324.60 6,165.50 2,959.06 1,528.24 5,932,690.52 1,622,643.20 2.15 3,253.78 MWD+IFR-AK-CAZ-SC(7) 11,414.56 95.58 13.35 6,315.91 6,156.81 3,050.39 1,550.73 5,932,781.77 1,622,665.91 1.19 3,347.80 MWD+IFR-AK-CAZ-SC(7) 11,509.80 93.67 13.36 6,308.23 6,149.13 3,142.74 1,572.65 5,932,874.06 1,622,688.07 2.01 3,442.69 MWD+IFR-AK-CAZ-SC(7) 11,605.20 90.71 11.77 6,304.59 6,145.49 3,235.78 1,593.39 5,932,967.04 1,622,709.04 3.52 3,537.92 MWD+IFR-AK-CAZ-SC(7) 11,700.10 89.61 11.02 6,304.32 6,145.22 3,328.81 1,612.14 5,933,060.01 1,622,728.03 1.40 3,632.63 MWD+IFR-AK-CAZ-SC(7) 11,795.02 89.83 8.94 6,304.78 6,145.68 3,422.28 1,628.58 5,933,153.43 1,622,744.71 2.20 3,727.18 MWD+IFR-AK-CAZ-SC(7) 11,884.94 90.51 7.36 6,304.52 6,145.42 3,511.29 1,641.33 5,933,242.40 1,622,757.69 1.91 3,816.45 MWD+IFR-AK-CAZ-SC(7) 11,977.90 91.34 6.45 6,303.02 6,143.92 3,603.56 1,652.51 5,933,334.63 1,622,769.10 1.32 3,908.47 MWD+IFR-AK-CAZ-SC(7) 12,069.88 92.28 7.64 6,300.11 6,141.01 3,694.80 1,663.78 5,933,425.83 1,622,780.60 1.65 3,999.52 MWD+IFR-AK-CAZ-SC(7) 12,161.21 90.91 10.52 6,297.57 6,138.47 3,784.94 1,678.19 5,933,515.92 1,622,795.24 3.49 4,090.32 MWD+IFR-AK-CAZ-SC(7) 12,208.82 88.67 13.34 6,297.74 6,138.64 3,831.51 1,688.03 5,933,562.47 1,622,805.20 7.56 4,137.85 MWD+IFR-AK-CAZ-SC(7) 12,253.41 88.15 15.65 6,298.98 6,139.88 3,874.66 1,699.18 5,933,605.59 1,622,816.46 5.31 4,182.42 MWD+IFR-AK-CAZ-SC(7) 12,303.81 87.29 17.15 6,300.99 6,141.89 3,922.97 1,713.40 5,933,653.85 1,622,830.80 3.43 4,232.76 MWD+IFR-AK-CAZ-SC(7) 12,346.16 88.49 17.95 6,302.55 6,143.45 3,963.32 1,726.16 5,933,694.17 1,622,843.66 3.40 4,275.04 MWD+IFR-AK-CAZ-SC(7) 12,438.36 90.88 17.07 6,303.05 6,143.95 4,051.24 1,753.90 5,933,782.01 1,622,871.62 2.76 4,367.14 MWD+IFR-AK-CAZ-SC(7) 12,531.22 90.34 15.74 6,302.06 6,142.96 4,140.31 1,780.12 5,933,871.00 1,622,898.07 1.55 4,459.97 MWD+IFR-AK-CAZ-SC(7) 12,623.29 90.47 14.59 6,301.41 6,142.31 4,229.17 1,804.21 5,933,959.79 1,622,922.38 1.26 4,552.03 MWD+IFR-AK-CAZ-SC(7) 12,715.13 91.85 14.11 6,299.55 6,140.45 4,318.13 1,826.97 5,934,048.68 1,622,945.36 1.59 4,643.85 MWD+IFR-AK-CAZ-SC(7) 12,808.15 92.02 12.76 6,296.41 6,137.31 4,408.55 1,848.56 5,934,139.03 1,622,967.19 1.46 4,736.78 MWD+IFR-AK-CAZ-SC(7) 12,901.01 91.13 12.21 6,293.86 6,134.76 4,499.18 1,868.63 5,934,229.60 1,622,987.49 1.13 4,829.51 MWD+IFR-AK-CAZ-SC(7) 12,991.52 89.78 10.78 6,293.14 6,134.04 4,587.87 1,886.67 5,934,318.23 1,623,005.75 2.17 4,919.84 MWD+IFR-AK-CAZ-SC(7) 13,083.76 89.83 11.07 6,293.46 6,134.36 4,678.43 1,904.15 5,934,408.75 1,623,023.46 0.32 5,011.85 MWD+IFR-AK-CAZ-SC(7) 13,176.68 90.43 9.96 6,293.24 6,134.14 4,769.79 1,921.11 5,934,500.05 1,623,040.65 1.36 5,104.48 MWD+IFR-AK-CAZ-SC(7) 13,267.85 88.82 10.24 6,293.84 6,134.74 4,859.54 1,937.09 5,934,589.75 1,623,056.87 1.79 5,195.31 MWD+IFR-AK-CAZ-SC(7) 13,360.37 88.55 10.26 6,295.96 6,136.86 4,950.56 1,953.55 5,934,680.72 1,623,073.56 0.29 5,287.49 MWD+IFR-AK-CAZ-SC(7) 13,452.63 89.76 11.44 6,297.32 - 6,138.22 5,041.16 1,970.92 5,934,771.27 1,623,091.15 1.83 5,379.50 MWD+IFR-AK-CAZ-SC(7) 13,544.62 89.69 12.48 6,297.77 6,138.67 5,131.15 1,989.98 5,934,861.20 1,623,110.44 1.13 5,471.36 MWD+IFR-AK-CAZ-SC(7) 13,638.49 90.34 12.39 6,297.74 6,138.64 5,222.82 2,010.19 5,934,952.81 1,623,130.89 0.70 5,565.13 MWD+IFR-AK-CAZ-SC(7) 13,731.30 89.97 11.58 6,297.49 6,138.39 5,313.60 2,029.46 5,935,043.53 1,623,150.39 0.96 5,657.81 MWD+IFR-AK-CAZ-SC(7) 13,822.95 90.00 10.34 6,297.51 6,138.41 5,403.58 2,046.89 5,935,133.46 1,623,168.04 1.35 5,749.23 MWD+IFR-AK-CAZ-SC(7) 13,915.96 90.00 9.38 6,297.51 6,138.41 5,495.22 2,062.82 5,935,225.04 1,623,184.20 1.03 5,841.87 MWD+IFR-AK-CAZ-SC(7) 14,006.73 89.98 7.83 6,297.53 6,138.43 5,584.96 2,076.40 5,935,314.74 1,623,198.01 1.71 5,932.07 MWD+IFR-AK-CAZ-SC(7) 14,099.52 87.91 6.27 6,299.24 6,140.14 5,677.03 2,087.78 5,935,406.77 1,623,209.63 2.79 6,023.94 MWD+IFR-AK-CAZ-SC(7) 14,112.54 88.74 6.55 6,299.62 6,140.52 5,689.96 2,089.24 5,935,419.70 1,623,211.12 6.73 6,036.81 MWD+IFR-AK-CAZ-SC(7) 10/25/2016 3:57:10PM Page 5 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonll Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyon1z Well: 2S-09 North Reference: True Wellbore: 2S-09A Survey Calculation Method: Minimum Curvature Design: 2S-09A 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 14,160.00 88.74 6.55 6,300.66 6.141.56 5,737.10 2,094.65 5,935,466.82 1,623,216.65 0.00 6,083.75 NOT an Actual Survey 4 1/2"x 6-3/4" 14,172.00 88.74 6.55 6,300.93 6,141.83 5,749.02 2,096.02 5.935,478.73 1,623,218.05 0.00 6,095.61 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. ID Yes L No I have checked to the best of my ability that the following data is correct: O Surface Coordinates J Declination & Convergence E GRS Survey Corrections Ciyitail 'a:,ed.:4'wl-cont Gsara Survey Tool Codes Vincent nt,c„_Vt,,,..r,,,e, n_5.1-I_rrlra-e-, ri-5cli uln-r7g:r. Osal TarAps11,cogs c=JS SLB DE: 1.zau:,rs WOOClient Representative: z7-7r- -/!+ .h_ ) Date: 26-Oct-2016 10/25/2016 3:57:10PM Page 6 COMPASS 5000.1 Build 74 • 4111 , ,OF Tit 41+I//7 • THE STATE Alaska Oil and Gas "ice tl, of ® Conservation Commission �t x �� 333 West Seventh Avenue *,., GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF ALAS MFax: 907.276.7542 www.aogcc.alaska.gov Adam Klem Completions Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2S-09A Permit to Drill Number: 216-128 Sundry Number: 316-561 Dear Mr. Klem: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Dani . Seamount, Jr. Commissioner DATED this day of November, 2016. RBDMS NOV 1 6 2016 • • RECEIVED STATE OF ALASKA NOV Al ���� ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑., ` Repair Well ❑ Operations shutdown❑ i\ '51-4.4).0-- Suspend f44).0-- Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing El Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development 0 . 216-128 ' 3.Address: ❑ 6.API Number: Stratigraphic ❑ Service P.O.Box 100360,Anchorage,Alaska 99510 50-103-20749-01-00 ' 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A • KRU 2S-09A Will planned perforations require a spacing exception? Yes ❑ No ❑., ,/ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 025603, 025589, 025590 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): 14,172' . ' 6300' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 119' 119' Surface 2,783' 10-3/4" 2,822' 2,596' Intermediate 8092' 7-5/8" 8,129' 6,333' Production Liner 6,205' 4-1/2" 14,163' 6,300' 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 7985' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): No SSSV 7880'MD,6,298'TVD 12.Attachments: Proposal Summary U Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program 2 BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑✓ • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 8-Nov-16 OIL Q 1 WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Adam Klem @ 907-263-4529 Email Adam.Klem@conocophillips.com Printed Name Adam?em Title: Completions Engineer - - /r///i/6 Signature Phone 907-263-4529 ate COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 2 ` / _ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location111/ Clearance Other: 4, 5 t S'f .-;J„AL; Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing ceptio;reeqgiired? Yes ❑ No Subsequent Form Required: /,0^` 4101 RBDMS NOV 1 6 2016 11...k,� LL 1110 /. APPROVED BY Approved by: 4 / COMMISSONER THE COMMISSION Date: 1/ /O , Submit Form an d Form 10-403 Re is d 11/2015 OiJRoJei4ic4Avki for 12 months from the date of approval.,' /e40 Attachments in Duplicate 1r. / . 40 I I 7. : 4•1111. .111w. DI . lik mg Strings , Casing CosarlptIcri OD ON C ON Top ittiVal Set Depth ITtkBt Set Depth{TV01.„ Wt/13n 41...GTO. Tap Thread 758 6375 372 8. 293 25.70 L-82 Hyd563 : -- Casing Deecripticn COM} 1)1 int Top(the, Set Depth IttK(11 Set Depth CN _D). 'Wt 1ert 11_Grate 'Tap Tined xcktc. -: ... - : ce,,,e.-t 4-5 :::',..;', IIII .....::::, 4." 41:2 3 953 7,953.5 "4.'932 12 60 L-32 TerartsXF STC-en „,,,,,,,./._,-,.".r'171.:-_1_1- ,....... •••':'::':,,..._ -.., '''..,1'..,---.liner Details 14:1-11,31 C T:p jtKial Tcp:T,T31111K131 Tcp In.-.:1:'1 Itirr Dee SzT :ini ME 4,44.41.M.Z MI Nipple-CRS} Ea.-•.a.' 7222 4 ao;et 1.3...a.'f 5 ..'27 .713•=4x-...05.: -5 ' .4 3': ..... , -.• 7.5--,::-.1 X0 Rec.:'^:: 5 -L.:52.3-f 5.50x x 4 5"1,2 9.re^41,5XP:- 2 2:•25 :2`-55::•:E-L-_:--; '.! '. ••:' 8,2020 Swan Packer Baker- 'Ewe.F55,5 55*Z-n.i:5 75"OD 514 1 '...• .., 51333-210-22 8,387.6 FRAC Baker 4-112"F.,ac Sleeve*10.-.I2 983"Ban.Dt11 ID 2 5E5 EIteee,Port 2 825'1 PN 1'24370% , .. .5.637.5 Swett Packer Baker- E....•a Facka-h•-- '.i" .5 75'OD EN 3 57: :xv.at.0.712.aersv-'EH 1 • _.-_ ., 513-33-1'E.-E xoTmees 7470.7, , ..._ .... ga.e4444•1)7 3.3.0 4- ,.... ... 8,993 7 P RAC .F.a,,a- ''' :':-.3:1"-a-,-:ira.5-:2 92.5'•Es D--`.:ID 2 572 x0"Orrads71,Sill .' . SitevertPort 2 5E1",•='. - • 9252.9 Swell Patter Ea.,.a.--- 2.•.; F a:-,a.-."2- i'57: OD EN: 2 15.: i...c14.4:4 7 Sc4:- ,....: ..............ak:.: 9,559.6 FRAC E a••• ---a. - 2 7-E:'2 3....-4.ye 4•3-2562'Ea' D•e4.w. 2 5': :yew T san: SeevelPort 25:''-'1.'.4,.:-'4.4.• ..: • 9.859,4 Swell Packer 2 5,...3*-.. '2'......: Pa:<a-=9- 1"5 75.03 EN:512.38 2 .: . , !•,-..,c.3.44 -::::: ;4 2 FRAC :-..,„3„.,....,•,2 .,...4.: .:,,,...,,,z,7,:2. "p..„3 ri-r,..41, 2.443 I 54everPort 2 422''. r;',I'2427232 10,454.5 Swell Packer Ea.".a"--'SY/3, Fa:ke-449 •-r: 5.75'0D 514. 3.972 ''.1 ):: •: 7234 FRAC Bake--I.'.: '--4:SeeVe 4,2•:2 42,2'23 D-="v.' 2.385 r"*",..03.4,4'.:3:.:4 y:3 34\ al, gakk• Eoevw Port 2 375,F1J' 427E35 ele..-4414,Mi.4T,4 C.e.Y.,4-.1 I 1.1C9 6 Swell Packer Baiser-"Swel'Fa.:..:a-.7- '3' 5 75•223 1'i 3.940 512-33-212-"E al "1 229 5 Ewell Ricker 2".a.te ,,a 5".;:.....a.-t$2.. CD EN 3.992 Memo =az 479 1 5..5- .'525- 52.-:2 275'1g. D.':....J. 2.323 733.3 5,-,,,en Fae•kerEa.:a"- aw,-; ..-, :•: -..2.- 'E"5 75"CO EN 3.950 ---- ermieei 4..miDa - e.:..,2.,.: :RAC Ea-:;•-•" .= :Sve=r4-:2 32:23 D-,-...v. 2 200 I. SeeveiFort 2 25.511 Swell PI:ker E .4 -- 1%4'; F a:.-..a....4- '3' 57.522 EN 3.950 smate *MIS "7. E1.2.7. F RAC Ea:-.F4-- 2 F'a.-:.•5;-aave.3-225"2 3 .D'1*.w 2.198 saws Seeve)Port = 2,77&l' Swell Packer E a•a•-- 1',...÷. F a:••..a.•03- "C"575'':..' s'.1 3952 ISZEZX '2 2'29.7 FRAC E.E."5•-,.- : ''.55 Z 5,5V,5.5.'Z-::: E?. 4, =En = '1 251 5 . Swei1Packer 2 a'.=-..---'2,4 =a cts•02- •2' 5 75'CD :3'.1 3 333 FRAC Ea..., -----:2' ,---s:S a.eve=•'-:2'25'Ea D.':w. Z:73 valuta Seave'Port 2232' -514': 27: : SM. =SLR '2 225 2* Ewell Packer 2a..a.- - 1,-.•a '5 a.: - Z' 5 75':3 EN 2252 III14051 3 s,?.. *4,094 7 7, Sioeve as,...--..--:-..: .:-.:-5 ET.....4,'e 22-',4 21.25-2•2 -25.2-7 E.,_EEVE Sal:€-4--1 V:i ::-a I":3-.:-'..:4-43,VT.'.'.' ,.:-1E13 1.1 -39-3:" Tubing Strings saw ....vs.... Tuttng fleautptien sting Ma_a1 int Tap ittK131 Set Depth itt. set Depth crmi..wt putt Doane Top connection I 3 .2 2.992 35 3 7 934 5 5.30 L-32 ELIE-'n Completion Details 112 Tin al IC g .... . . , ,, ..., ,K,,,, T:c1TVD1;11K131 Tc;Inv 'n nTali :', i• lac : 35 3 353 323 -i,. r." 237037.7'" Y.4-',...:*127-717_:-;-i a-,-..,..:-. 3.900 7,332.5 1-:'•:,E a.....,a .23,.3."2",:'C.-1J -c c ::-.:•31-:-w Z 1'2'DE F^:."a 2 810 7,855.1 3a4;e.P.m; 1:-_n:.-1-7.,:--'3.: s-1::•EJE-Ti,:cx XE-SiI 2.847 Earsor 1.FD 5"-"2:'11,111-54"51 7,924 9 NipoSe-DB. Ca--::::75 D-::.a4:•-.; cDw,R-ic :'..G bc.:;•:,. S312. 2.750 XN 35.0 .4.,_ _. 7,554.0 _::3tor E a',..;,-7 625"x 3.5'Shea-,a-ea:11 4:e•::14,:y•;..1-:.14:-. 3.010 I ..a Te CO aziees SIMS 7,955 1 4::ator Ea.:a,7.625'x-4,5'5....aa.-:--74T:'-'_:•?:".i:.:::,.:2..:,• 3.010 emmere s>ta F.CO 7.583.9 'I.-a:Shoe Me V4_E:3 3-'.2*'E7::5'. 3.490 • Mandrel Inserts One St.I I I I I I I I I I I I • Section 1 - Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1). i ! Paul K.Wharton Staff Landman ConocoPhillips Alaska, Inc. P.0. Box 100360 ConocoPhillips Anchorage,Alaska 99510-360 Telephone:(907)263-4076 Alaska, Inc, Paul.K.Wharton@conocophilips.com To: Operator and Owners (shown on Exhibit 2) Date: November 1, 2016 Re: Notice pursuant to 20 AAC 25.283 (1) 2S-09A Well Kuparuk River Unit, Alaska ADL 25603 KRU Tract 90, ADL 25604 KRU Tract 89, and ADL 25589, KRU Tract 75 Dear Sirs: ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Kuparuk River Unit ("KRU") working interest owners, provided notice of plans to submit an Application for Sundry Approvals for hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the 2S-09A Well (the "Well"). The Application was filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about November 1, 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: 3062' FNL, 1496' FEL, Section 17, T10N, R08E, UM Target Location: 3207' FNL, 681' FEL, Section 17, T10N, R08E, UM Bottomhole Location: 2594' FNL, 4663' FEL, Section 09, T10N, R08E, 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. Very truly yours, R. 424.1.,74,..., Paul K. Wharton Staff Landman cc: Adam Klem Rebecca Swensen . e ✓ 10/28/2016 i ConocoPhillips / Alaska S2-09A 6 i Lease Plat Feet 0 1,000 2,000 3,000 / I 2S-14 - ADL025590 / ADL025589 2M-35 2S-13L1 2S-13 2S-11 '/ 8 3 / 7 / 2S-04 2S-07 / i 1 2S-05 I / i 2S-09 r \\ 4 I 2S-02 18 II 15 \ I Alli 2S-13PB1 .r, 11 2S-04PB1 , ii ow, diI 111, Vi ADL025603 ( ADL025604 / A 2S-12PB1 Sharktooth-1 19 20 21 2S-12 2S-03PB1 2S-01 2S-08 2S-10 • Frac Points — 2S-09A Open Interval / i / n i — 2S-09ATrajectory 2S 03 28 — —— – 2Z — —— Well Within Trajectory Radius ❑ 1/2 Mi. Frac Point Radius 2S-06 ❑ 1/2 Mi.Trajectory Radius ADNR Protracted Sections ADL025608 ADL025607 ❑CPAI Lease I 0 Kuparuk PA `..—._.._.._.—.—._.—._..�.—.�.--•---.._..—._r • • 2S-09A Hydraulic Fracturing Notice Letter November 1,2016 Page 3 of 4 Exhibit 2 Mineral Owners: Operators: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1220 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Erik Keskula, Manager, NS Development Non-Operators BP Exploration (Alaska) Inc. P.O. Box 196612 900 E. Benson Boulevard (Zip 99508) Anchorage, AK 99519-6612 Attention: Mr. John Dittrich Chevron U.S.A. Inc. 310 K Street, Suite 406 Anchorage, AK 99501 Attention: Mr. David White ExxonMobil Alaska Production Inc. P.O. Box 196601 3301 C Street, Suite 400 (Zip 99503) Anchorage, AK 99519-6601 Attention: Mr. Gilbert Wong Surface Owner: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 Attention: Director • 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-09A 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 November 1,2016,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 1st day of November, 2016. - Paul K.Wharton STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 1st day of November,2016, by Paul K.Wharton. Notary Public, State of Alaska My Commission Expires: , STATE OF ALASKA < .k NOTARY PUBLIC REBECCA SWENSEN -r i.I14 Commission Ex• Au..27,2020. • • Section 2 — Plat 20 AAC 25.283 (a)(2) Plat 1: 2S-09 Landowners 10/28/2016 / ConocoPhillips Alaska S2-09A N 5 Lease Plat 1 f_ 0 1,000 2,000 3,000 Feet i 25-14 ADL025590 ADL025589 2M-35 / 2S-13L1 2S-13 28-11 e, 2S-04 2S-07 28-05 2S-09 I /`)) 2S-02 18 [ 15 1 r 2S-13PB1 A k lll"""2S-04P61 411(t Va/1111y 4 �l */ i di iiiwkilb,,, ADL025603 f ADL025604 2S-12P81 , Sharktoath-1 A 19 70 21 22 26-12 I l f 2S-03PB1 28-01 2S-08 25-10 • Frac Points —2S-09AOpen Interval 2 _. 1' U 3i 1 —2S-09A Trajectory 29 25.03 2- 28 ~-Well Within Trajectory Radius �._..�•�•o• �• �• 01/2 Mi. Frac Point Radius 28-06 01/2 Mi.Trajectory Radius ADNR Protracted Sections ADL025608 ADL025607 DCPAI Lease S • Table 1: Wells within .5 miles API WELL NAME TYPE STATUS 501032073900 2S-05 PROD ACTIVE 501032072970 2S-03PB1 EXPEND PA 501032071700 2S-10 PROD ACTIVE 501032064700 SHARK TOOTH 1 EXPLOR PA 501032074700 2S-06 PROD PROP 501032072700 25-01 PROD ACTIVE 501032072170 2S-04PB1 EXPEND PA 501032072070 25-13PB1 EXPEND PA 501032073200 2S-11 PROD ACTIVE 501032024300 2M-35 INJ ACTIVE 501032074370 2S-12PB1 EXPEND PA 501032074300 2S-12 PROD ACTIVE 501032072000 2S-13 SVC OPSH 501032072060 2S-13L1 SVC OPSH 501032073300 2S-14 PROD ACTIVE 501032072900 2S-03 PROD ACTIVE 501032071000 2S-02 INJ ACTIVE 501032072100 2S-04 INJ ACTIVE 501032074900 2S-09 PROD ACTIVE 501032071300 2S-07 INJ ACTIVE 501032072200 2S-08 INJ ACTIVE SECTION 3 — FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. 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". • • 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./ J • SECTION 5 — DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) All casing is cemented in accordance with 20 AAC 25.52(b) and tested in accordance with 20 AAC 25.030 (g) when completed. See Wellbore schematic for casing details. SECTION 6 — ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(a)(6) Casing & Cement Assessments: The 10-3/4" casing cement pump report on 8/21/2016 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. Took cement returns to surface. The plug bumped at 1,100 psi and the floats were checked and they held. The 7-5/8" casing cement report on 10/17/2016 shows that the job was pumped as designed, indicating competent cementing operations. The first stage was pumped with 15.8 ppg class G cement. Full returns were seen throughout the job. The plug was bumped and the floats were checked and they held. TOC was observed with logging tools at 5535' MD for the firs _ stage cement job 6 � Summary Ve-C1 zt All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated bythe 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. I • • SECTION 7 — PRESSURE TEST INFORMATION AND PLANS TO PRESSURE-TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 9/19/2016 the 10 & 3/4" casing was pressure tested to 3500 psi. On 10/26/2016 the 7 & 5/8" casing was pressure tested to 4000 psi. On 10/26/2016 the 3 12" tubing was pressure tested to 4000 psi. It will be tested to 5,000psi prior to frac. AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 5,000 Annulus pressure during frac 3,600 Annulus PRV setpoint during frac 3,700 (WV V 7 5/8" Annulus pressure test 4,000 3 1/2" Tubing pressure Test 5,000 Nitrogen PRV 7,100 C3-0 I iJ Highest pump trip 6,900 r 6 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 & %" 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 Bleed/Tattle Tale Tank P-1 -' 100110 0 aur / Ak d P. o � t 1 o U ICA 14:11 r , 1 _t rA11 J Ir N N d It ii V, c r►*� a ~ '• Y � I N )orui dwnd Pop Off Tank 2113 Pump Truck Pop-Oft Talk DIN a > c d J kr N Frac Pump NJ -D8C frJ Frac Pump Frac Pump :N !'--r Frac Pump Frac Pump -p --r — --Da [r.I Frac Pump • 41110 10K Frac Tree Note Dimensional information reflected an this drawing t mated measurements oily. 6-5 Ons 11111111 111 1 " RIP ../7, 4"1002 f 4"1002 4-1/16' 10, kt illilW 4-1116' 10,0O01f err, I Et-- CS, 4-1/16' 10,000# Hydraulic 56-94' ai .mIft. 4-1/16' 10,O009 1 4-1/16' 10,000P ! -, ConocoPhillips ,,CAMERON Drill Site 2S-10K Frac Tree 5-E--SEN -3D-is a 1162D=u- -2 0 0 Wellhead with 10K Frac Tree 11111 li 6 5 oT35 , -tote LI Vrwir al LIVOtTratrOP,NiC,CIEsd non ate.drawing arr miralind measurement onhe 4"1002 .,..,, 4"1002 4-1/1ba 10,000V 4-1/16' 10,0001 NI SI 1 , ii ,,_- ,,,0.1 I 1 _ a dirl ,'SI Ililliq CIIIIIIIII a LA A 10- • ' Nu air !I I' 2.1 C°8' .1-1710"I 000Ui 4-1/1 t.3. 1 U,itOta x2- 1507 a Iyaratal• ammummit 'AIMM" 4-1/16" 10,000e OA— i 0 IC 1 41716" 100004 **11111 IP 1173 ' 16.09' r t I I- ,...ouue 60—, ,..I I –--III i • 2-1/10* S,0004 10.10' 15.14 Illr ..... ,11r, 1. . III c *11111111 2,111a . ow 0. °_ 4 INN - i r Imo.am _ r . ' .)-ul . 5,OGOS woo 71.75' - 0111111111 IMMO lit-Ov I i 14.4/5" V LW, fi r os c onductos. Top of1.12' 1 – CanciiiiclOr f tra ti twat rar h.1t.9,1 16 ConocoPhillips , bu- u44,, 7-5f8" 1-112' eCAMERON DTA 1 Sate 2S-Produce, WI 10K It — STEPHEN 12-30-15 .„..... ' 1162040-0 • SECTION 9 — DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The fracturing zone, the Kuparuk A sand interval, is approximately 100' TVT at the heel, with the top of the Kuparuk A at -6,163' TVDSS (8,010' MD) and 100' TVT at the toe of the well, with the top Kuparuk A at -6,133' 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 295' TVT (1,136' MD) and consists of HRZ and Kalubik mudstones. Top HRZ was encountered at -5,868' TVDSS (6,874' 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 -6,265' TVDSS at the heel (the Miluveach interval was not penetrated in the 2S-09 wellbore). • SECTION 10 — LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing & Cement assessments for all wells that transect the confining zone: 2S-04: The 7 & 5/8 casing cement pump report on 10/18/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg cement, followed by 16 ppg tail cement. The plug bumped at 717 psi and the floats were checked and they held. 2S-04 PB1: 2S-04 PB1 was plugged and abandoned per state regulations on 10/12/2015. 2S-07: The 7 & 5/8 casing cement pump report on 8/6/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.3 ppg cement, displaced with 10.6 ppg mud. The plug bumped at 1,251 psi and the floats were checked and they held. 2S-10: The 7 & 5/8 casing cement pump report on 9/2/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg cement, displaced with 10.5 ppg mud. The plug bumped at 1,450 psi and the floats were checked and they held. 2M-35: The 7" casing cement pump report on 6/2/1996 shows that the job was pumped with no returns and the floats did not hold. A CBL was ran from 14,000' to TD, showing good cement at 14,000' MD. • • \ r& eV \\ � 0 0 ! ! � ® � m • 0 q _ Ln 10 \ \[ q- S e \ � ui ) co ui ) 2 ii / ° \ § ® ) © ; ( ; 2 3 ; ; _§_; : j � To to I_ /tci` / / ` WI & - .E.' 3 ± /j §- en / , o \ £ . 13 # a — _ � � ! \ 3 \ \ o ƒ§ ° e E E - - - in - \/ $ [ } ( } & ` � in U §_ - o In - 2 ai 0 / cr, rnrn � » •o. V e e 42 E \! [ 11 o z } -76 12; 3 ikz % 7,4 0. 12 { } all,In / \ / ) 2 £ 2 2 VI • § / .,- 0. §,g ■w (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 4 mapped faults that transect the Kuparuk A interval and enter the confining zone within one half mile radius of the wellbore trajectory for 2S-09. The north-south trending faults around 2S-09 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 sub-seismic faults intersect the 2S-09 wellbore. Sub-seismic faults #1  (see 2S-09 table) terminate within the confining layer. Fault#2 terminates near the C-35. The C-35 in this area consists of shales and siltstone lithologies with an estimated fracture pressure of - 16ppg. Fault#2 also intersected the 2S-07 wellbore. No losses were observed at any of the fault crossings during drilling of the 2S-07 or the 2S-09 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-06 Faults MD(feet) SSTVD(feet) Throw in feet Fault#1(A4/A4) 9,539 -6,167 2(DTS) Fault#2(A4/A4) 11,105 -6,175 20(DTS) Fault#3(A4/C4) 12,118 -6,143 10(DTN) 2S-07 Faults MD(feet) SSTVD(feet) Throw in feet Fault#2(A4/A4) 11,350 -6,167 29(DTS) The effective fracture length is estimated to be 760'. All of the fractures will be longitudinal, running parallel to the 2S-09 wellbore. 2S-09 frac points are all further than 760' longitudinally from mapped faults that do not transect the wellbore. If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults will not interfere with containment. • • Plat 2: Fault Analysis 10/28/2016 ConocoPhillips Alaska S2-09A N Fault Analysis Plat 0 1,000 2,000 3,000 ,N\ Feet ADL025590 ADL025589 i ///44: , 1 i, ,,47, ii . i ne i i i .3 ADL025603 ADL025604 0 N ;AO( • Frac Points n, —2S-09A Open Interval —2S-09A Trajectory Well Within Frac Point Radius —Faults Within Confining Zone O 1/2 Mi.Frac Point Radius F]1/2 Mi.Trajectory Radius ADNR Protracted Sections ADL025608 ADL025607 0CPAI Lease SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) 2S-09 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 20 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 16,951 bbls are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU HES Frac Equipment. 7. PT Surface lines to 9,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 500 bbl breakdown stage (35# linear gel) according to the attached excel HES pump schedule. Bring pumps up to maximum rate of 25 BPM as quick as possible, pressure permitting. Increase annulus pressure to 3,600 psi. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. 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L act to -13 to a v U a U v O Q OF 71 • • ,�� THE STATE Alaska Oil and Gas ofLAS KA Conservation Commission 2_`_ ,- 333 West Seventh Avenue h' '. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 O4'ALAS-1°' 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-09A ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-128 Surface Location: 3062' FNL, 1496' FEL, SEC. 17, T1ON, RO8E, UM Bottomhole Location: 2590' FNL, 4647' FEL, SEC. 9, T1ON, RO8E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition,the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20,Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05,Title 20,Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy . Foerster Chair DATED this al day of October, 2016. STATE OF ALASKA RECEIVED VED ALleA OIL AND GAS CONSERVATION COMM N OCT 10 2016 PERMIT TO DRILL 20 AAC 25.005 � C la.Type of Work: lb.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp ❑ 1 c.Specify if �Tf"is"ropose for: Drill ❑ Lateral 0 Stratigraphic Test ❑ Development-Oil 0• Service- Winj ❑ Single Zone 0 ' Coalbed Gas❑ Gas Hydrates ❑ Redri110 . Reentry❑ Exploratory-Oil ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 • Single Well❑ 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 4 KRU 2S-09A 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 14,171 TVD: 6,344 Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 3062'FNL, 1496'FEL, Sec 17, T10N,R008E,UM" ADL 25603,25589,25590• Kuparuk River Oil Pool ' Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: (ad, 3260'FNL,718'FEL,Sec 17,T10N,ROO8E,UM 2675,2676,2677,2678 8/1/I016 j Di,o/24:46 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2590'FNL,4647'FEL,Sec 9,T10N,R008E,UM • 7573 3900' 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-481,074.22' y-5,929,986.08' Zone-4 , GL Elevation above MSL(ft): 120 . to Same Pool: 1700'f/2S-07 16.Deviated wells: Kickoff depth: 2852 feet • 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 91 degrees ' Downhole: 3292 • Surface: 2659 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5# H-40 Welded 80' 39' 39' 119' 119' pre-driven,cemented to surface 13.5" 10.75" 45.5# L-80 Hydril 563 2783' 39' 39' 2822' 2596' Existing,cemented to surface 9.875" 7.625" 29.7# L-80 Hydril 563 8116' 39' 39' 8155' 6338' 766sx 1st stg,232sx 2nd stg 15.8#G 6.75" 4.5" 12.6# L-80 TXP 6147' 8025' 6325' 14172' 6344' N/A-liner 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 11584 6302 7007 Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" Pre-driven,cemented to surface 120 120 Surface 2822' 10-3/4" Existing,cemented to surface 2822 2596 Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketch❑ Drilling Program 0 Time v.Depth Plot El Shallow Hazard Analysis❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program El 20 AAC 25.050 requirements0 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Haibin Guo @ 907-265-1487 64-74 Email Haibin.GuoaCOP.com Printed Name G.L.�Alvord Title Alaska Drilling Manager Signature /�.l �. ). Phone 265-6120 Date 10(1„,1 L9p ' "_ Commission Use Only 1 Permit to Drill API Number: Permit Approval See cover letter for other a Number: 16 /a$ 50- 103-a o? 19 -01-oo Date: `01 01 I LO requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methan ,gas hydrates,or gas contained in shales: i Other: 8��J fr5, t ti, 3-OC )S/ JSamples req'd: Yes❑ Nog Mud log req'd:Yes❑ No[j f C Z Jr jimeasures: Yes RI No❑ Directional svy req'd:Yes1 No❑ 'ItPvrtvL/ -C-V-&r ( (p rG c f'o r� Spacing exception req'd: Yes❑ Nod Inclination-only svy req'd:Yes❑ No� 1 i2f6` �D(c.Gi.i� eto . Post initial injection MIT req'd:Yes!: No(� / , APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ,D-/3-/ , • roiIDIg, //rt. /Di/0/I( ,A '/ (1/94 Submit Form and Form 10-401(Revised 11/2015) pT iRIrGi Il r Lths from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate • s Application for Permit to Drill,Well 2S-09 Saved:8-Oct-16 Post Office Box 100360 Anchorage,Alaska 99510-0360 s Ed apsPhone(907)263-4180 October 7,2016 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill Well 2S-09A,A Kuparuk A4 Sand Producer Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a permit to re-drill an onshore producer well from the 2S pad. The expected sidetrack date for this well is October 10,2016. It is planned to use rig Doyon 142. / 2S-09A is planned to be a horizontal well in the Kuparuk A4 sand.The well will be sidetracked out of the existing 10- 3/4"surface casing of the parent wellbore 2S-09. The parent wellbore2S-09 failed to drill to TD due to unstable open shale at heel of the production lateral. 2S-09 was plugged back and a cement kick off plug was set up into surface casing. The sidetrack intermediate section will be drilled with 9-7/8"x 11"bit/Under Reamer and run 7-5/8"casing to 8,155'MD /6,339'TVD. It will be landed below the unstable shale. So the production lateral will not be exposed to open shale. The production lateral will be drilled with 6-3/4"bit and run 4-1/2"liner to+/- 14,171'MD/6,344'TVD.The upper completion will be run with 3-1/2"tubing. 2S-09A will be fractured after rig being released. 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 Haibin Guo at 265-1487 (Haibin.Guo@conocophillips.com)or Chip Alvord at 265-6120. Sincerely, Haibin Guo Drilling Engineer • • Application for Permit to Drill Document Kuparuk Well 2S-09AConocesPhiltips s Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 2S-09A Location Summary Requirements of 20 AAC 25.005(c)(2) 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 ideated in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system_for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth: Location at Surface 3062' FNL, 1496'FEL, Sec 17, T1ON,R008E,UM • NGS Coordinates RKB Elevation 159'AMSL Northings: 5,929,986.1' Eastings: 481,074.2' Pad Elevation 120' AMSL Location at Top of 3260' FNL,718' FEL, Sec 17,T1ON,R008E,UM Productive Interval (Kuparuk A4 Sand) NGS Coordinates Measured Depth, RKB: 8,074' Northings: 5,929,786.7'Eastings:481,852.5 Total Vertical Depth, RKB: 6,331' Total Vertical Depth, SS: 6,172' Location at Total Depth 2590' FNL,4647' FEL, Sec 9,T1ON,R008E,UM NGS Coordinates Measured Depth, RKB: 14,172' Northings: 5,935,732.3'Eastings: 483,199.8' Total Vertical Depth, RKB: 6,344' Total Vertical Depth, SS: 6,185' 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 (I)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellhores within 200 feet of any portion of the proposed well; Please see Attachment: Directional Plan And (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(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. i i Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The maximum potential surface pressure (MPSP) while drilling 2S-09A is calculated using an estimated maximum reservoir pressure of 3,292 psi (10.0 ppg, based on offset development wells), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A4 sand at 6,331' TVD (WP10): A Sand Estimated. BHP = 3,292 psi A Sand estimated depth(WP10) = 6,331' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 633 psi (6,331' TVD * 0.10 psi/ft) MPSP =BHP—gas column =2,659 psi (3,292 psi—633psi) (8)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 geopressured strata,lost circulation zones,and zones that have a propensity for differential sticking; See attached 2S-09A Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) 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: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.030f; 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) Size (/b/ft) Grade Conn. (ft) (ft) (ft) Cement Program (in) 16 24 62.5 H-40 Welded 80 Surf 120/120 Existing,cemented to surface 10-3/4 13-1/2 45.5 L-80 H5631i 2,783 Surf 2,822/2,596 Exusting,Cemented to surface Stage 1: 766 sx Class G at 15.8 ppg w/ 9-7/8 Hydril TOC at 6,174 MD 7-5/8 X 29.7 L-80 8,116 Surf 8,155/6,339 Stage 2: 232 sx Class G at 15.8 ppg w/ 11 563 TOC at 4,918 MD 4 1/2 6-3/4 12.6 L-80 TXP 6,147 8,025/6,325 14,172/6,344 Uncemented Liner with Frac Sleeves • 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 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); No diverter will be used. Please reference BOP schematics on file for Doyon 142. 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 Intermediate Production 9-7/8"x 11" Hole 6-3/4" Hole 7-5/8" Casing 4-1/2" Liner LSND FloPro Mud System (WBM) (WBM) Density 9.2- 10.5 10.0-11.0 • PV 10-20 10-20 YP 16-24 16-24 Funnel Viscosity N/A N/A Initial Gel 10- 12 5-8 10 minute Gel 10- 18 5- 12 API Filtrate <6 <6 HTHP Fluid Loss at 160 F < 10 < 10 pH 9.0- 10.0 9.5- 10.0 Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A -Application is not for an exploratory or stratigraphic test well. • • Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A- Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items.except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to attachment for proposed well schematic 1. PU 9-7/8"PDC bit with 11"underreamer on directional drilling assembly,MWD/LWD(Gamma,resistivity). / 2. Kick off 30'below the surface casing shoe in 17.Oppg KO plug. 3. Directionally drill 9-7/8"x 11"intermediate hole TD at+/-8,155' MD/6,339' TVD,wellsite geologist will call intermediate TD. Using MPD to hold near constant BHP of+/-11.5 ppg across HRZ and Kalubik shale. 4. Circulate and condition mud to 10.3ppg. Strip OOH with MPD to minimize swab. Lay down intermediate BHA and rack back 5"DP 5. Run 7-5/8",29.7#L80,Hydril 563 casing and pump cement as per plan. 6. Flush 10-3/4"x 7-5/8"annulus with water,followed by diesel to freeze protect. , 7. PU 4"DP,6-3/4"bit,RSS drilling assembly(Gamma,resistivity,Periscope,and neutron density).RIH and clean out cement to 100' above shoe. Test intermediate casing to 3500 psi for 30 minutes. 8. Drill out shoe track and 20' of new hole. Perform formation integrity test to minimum of 12.5 ppg,maximum of 13.5 ppg EMW. 9. Swap mud to FloPro reservoir drill-in mud system. 10. Directionally drill 6-3/4"hole geosteering through the Kuparuk A4 sand to TD+/-14,171' MD/6,339'TVD as per directional plan. 11. Circulate hole clean. Trip out of hole and lay down production BHA. 12. PU and run 4-1/2", 12.6#liner. The top of liner will be placed at+/-8,005' MD, allowing for 150' of overlap in the 7-5/8"casing. 13. Set liner hanger. Slackoff and set liner top packer. 14. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes,chart results. 15. Flow check well for 30 minutes and POOH 16. Run 3-1/2"upper completion. 17. Nipple down BOPE,nipple up tree and test. 18. Freeze protect well with diesel and install BPV. 19. RDMO. 20. 2S-09A will be fractured after rig being released. I • 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 conunisston 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 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 disposawell (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 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 Cementing program • 2S-09A ConocoPhillips Proposed SideTrack Schematic 1 0/07/201 6 • • 'CAMERON 16"Conductor to—120' 13.5" Surface Hole West Sak Sand:T 1,960'MD/1,853'TVD B 2,748'MD/2,596'TVD Ie. Surface Casing 10-3/4"45.5# L-80 Hydril 563 2,822' MD/2,596' TVD (31° INC) 4,4 Vitia�3 tt�4�t�a 9-7/8" x 11" Intermediate :ridge Hole Plug 2972' MD 2nd Stage TOC: 4918'MD,500'MD above C-37 Stage Collar:5.518'MD �����\\ C-37:5,418'MD/4,886'TVD ', TOG 7007' Growler(Iceberg):5,542'MD/4,986'TVD MD -- Cairn:6,174'MD/5,554'TVD Bermuda:6,427'MD!5,653'TVD HRZ:6,875'MD/6,025'TVD Kalubik:7,187'MD/6,159'TVD 1. Kuparuk C:7,981'MD/6,318'TVD Kuparuk A4:7,504'MD/6,331'TVD Intermediate Casing 7-5/8" 29.7# L-80 Hyd563 Casitr Intermediate Casing 7,247' MD/6,264' TVD (71° INC) 7-5/8" 29.7# L-80 Hyd563 Casing TD:14,171'MD/6,339'TVD 8,155' MD/6,339' TVDO /4N(Production Hole --------411---------------111L 2s.09Awp 1 0 Permit Pack Plan Summary -Sase Permafrost C-37Top Bermuda _ U.Kalubik(base HRZ) t C-dagrovilv-Maiin A4 Target Zone 1.(71--1Vritke? I C-80 , ,‘ Base BkmqiPik(K-1 mkr) 4 • •a• \ \\ I 1 / Ot.IN '1' 1 Top N Sak 1 \ \\ I 1 / , -_-__---- - (1) I \ Top HRZ(K-2 mkr) (0 I i ) A5 - C) - I i IL) t 0-3/4'Surface C1sg, ra - O - I fr4aolW Zit(11-op C4) 0 ,- -Base W Sak 1 - N ' 0 i 1 I i I I I 1 , 1 , , , „ „ r , 0 n , ToCT10 3/4"x 13 1/2 7000 10500 14000 -3 Sand Measured Depth 4 1/2"x6-3/4' o--0° 110 3/4"x 13 1/21 Depth Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doy• 4.11111.-14 /ii) II/ it11117 •:,°,,1 _ ,' Rig: Doyon142 0 00 , „ ,, 0 o ‘I, '50 Pi '05 #I - tab 17-5/8"x 9-7/81 •... / 14 1/2"x 6-3/41 o 9g00 / 0 0/ i 0 1.A44.:-:,,:= 8 1 ' UI co a,% al .„,, __,, •-•lal), I --, __,, -,4 . A I 1 I 1 I 1 4500°91 1 81 1 81,-1 I i i i 8 I -' 0-.1 0 1500 3000300 0 7500S ' o 7100 m 1 0500 0 o 28522852 - 3050 Horizontal Departure 129 3050 - 3240 .. MIME 3240 - 3430 , . . 3430 - 3620 , t 4071 C ' .:.0/1 . .. ' •, ,. 3620 - 3820 9 .. .'-•,. .'-. ... 'hi 60 Rig 9S-Bri 3820 - 4010 czi 300,00Api;, ,),:-. . 4010 - 4200 a ', 60 CO 4200 - 4610 4610 5030 fre$°f :AO,/ .' i 7:. .,'"-.-"„ ."'.:.'\ '.3777'\ -)t-\- 5030 - 5440 8 30- - . ,frei ; : • ,• .--• •, 1 • ; ; : . . 1. ,i : • : • .• .' . • 36Th. . . • 5440 - 5850 270 90 ., 4.;4', :, ., ., %. 5850 - 8280 6260 - 6670 t C.) -J 8670 - 7090 7090 - 7500 0 l' IIIIIIIIIIIIIIIIIIIIIIIH 1#0 : '•..:S.'.....,:''' :,/ 7500 - 8330 3000 4500 6000 7500 9000 10500 12000 240Ify..6920 8330 - 9170 SURVEY PROGRAM ..-- - 040ff ' 9170 - 10000 Surface Location 9. Affritotv izs ol 10000 - 10840 ___ Depth From Depth To Survey/Plan Tool INA 60.00 835.50 2S-09 Srvy 1-SLB NSG+MSHOT(2S-09)GYD-GC-MS Pad Elevation: 120.00 210 /..UP 150 10840 - 11670 858.68 2088.06 2S-09 Srvy 2-SLEI:MWD+GMAMV(LESAIWAK-CAZ-SC 11670 12500 2184.78 2758.43 2S-09 Srvy 3-SLB_MWD+GMAMV(SEO9-AK-CAZ-SC 180 12500 - 1)340 2800.11 2800.11 2S-09 Srvy 4-SLB Inc+Filler(2S-09) INC+TREND CASING DETAILS 2877.83 2852.00 2S-09 Srvy 5-SLB7MWD+GMAMM+913)3-AK-CAZ-SC , 13340 - 14172 2852.00 3202.00 25-09Awp10(Plan 2S-09A) INC+TREND TVD MD Name T M 3202.00 4702.00 2S-09Awp10 Plan 2S-09A MWD 6339.10 8155.49 7-5/8"x 9-7/8" Magnetic Model: BGGM2016 3202.00 8155.49 2S-09Awp10 Plan 2S-09A MWD+IFR-AK-CAZ-SC 6344.10 14171.50 4 1/2"x 6-3/4" Magnetic Model Date: 01-Oct-16 A 8155.49 9655.49 2S-09Awp10 Plan 2S-09A / MWD Magnetic Declination' 17.80° 8155.49 14171.58 2S-09Awp10 Plan 2S-09A MWD+IFR-AK-CAZ-SC To convert a Magnetic Direction to a True Direction,Add 17.80'East SECTION DETAILS - T-3 Sand Sec MD Inc Azi TVD ...N/-S 4-E/-W Dleg TFace VSect Target Annotation 1 2852.00 32.09 178.88 2621.49 -950.45 17.67 0.00 0.00 -913.49 KOP:47100'DLS,150°TF,for 30' 2 2882.00 31.05 180.04 2647.05 -986.16 17.82 4.00 150.00 -928.82 Start 37100'DLS,150°TF,for 80' K-15 Marker 3 2942.00 29.51 181.87 2698.87 -996.40 17.33 3.00 150.00 -957.97 Adjust TF to 120°,for 90' 4 3032.00 28.25 186.82 2777.69 -1039.71 14.06 3.00 120.00-1000.64 Adjust TF to 90°,for 180' 5 3212.00 28.72 198.11 2936.02 -1123.16 -4.44 3.00 90.00-1086.04 Adjust TF to-55.13",for 519.74' -1427.0 6 3731.74 39.58 177.86 3366.92 -1409.00 -37.26 3.00 -55.13 -1370.64 Hold for 374.92' 7 4106.66 39.56 177.86 3655.96 -1647.64 -28.33 0.00 0.00-1598.83 Start 3.57100'DLS,-162.93°TF,for 3389.43' Base Permafrost 8 7496.09 80.50 13.00 6238.00 -752.41 649.47 3.50 -162.93 -558.68 Hold for 484.71' - 1853.0 9 7980.80 80.50 13.00 6318.00 -286.60 757.01 0.00 0.00 -80.91 Start 3 57100'DLS,27.32°TF,for 129.87' 10 8110.87 84.54 15.09 6334.90 -161.72 788.26 3.50 27.32 47.81 Hold for 29.34' Top W Sak 11 8140.01 84.54 15.09 6337.69 -133.53 795.87 0.00 0.00 77.01 Start 3.5°/100'DLS,-32.68°TF,for 15.48' 12 8155.49 85.00 14.80 6339.10 -118.63 799.84 3.50 -32.68 92.42 2S-09 1.Heel 100618 JH Hold for 20' -HypSe W Sak 13 8175.49 85.00 14.80 6340.84 -99.37 804.9) 0.00 0.00 112.35 Start 27100'DLS,-24.1°TF,for 278.49' 10-3/4"Surface Cs 14 8453.97 90.09 12.53 6352.78 170.88 870.63 2.00 -24.10 390.39 Hold for 5717.61' 2921.0 15 14171.58 90.09 12.53 6344.10 5752.32 2110.96 0.00 0.00 6102.68 2S-09 3.Toe 100616 JH TD:14171.58'MD,6344.1'TVD - C-80 Failed AC with 2S-07 and 2S-09 Failed Anti-Collision Mother bore. -4268.0 C-50 -4578.0 C-40 18*.S7 Minor risk 1/200 applied for 2S-07. Growler-AA Minor Risked Minor risk 1/10 applied for 2S-09 motherbore .7-_ON kg rid u d a Base Bermuda -60 :ii1042%srfr argeFgn P.signing this I acknowledge that I have been informed of all risks,checked that the data is correct,ensured it's completeness,and all surrounding wells are assigned to the proper position and I approve the scan and ollision avoidance plan as set out in the audit pack I approve it as the basis for the final well plan and wellsite drawings.I also acknowledge that,unless notified otherwise,all targets have a 100 feet lateral tolerance. Prepared by: Checked by: Accepted by: I Approved by: Vincent Osara Nate Beck Erik Sterk • 03 LC) . ., Northin (Wusftlin) II I Iii �1 1 I I I I I I I II1 1 1g1r. I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I _ tha N 'til----[ - N N - N r - 0 - O N - N r _ . r 10 pa - - O — o a s N Y 1 '� — N 3 N 573NOON I n �\--1,e Q J — t\is f (13 V N N - = o Y y N - N 4 • N N _IY N — N O - r -I N : q., ..;��. „.. 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' "\' O O p0 c0 N \: 0 O O O O O O N LO O LO O In O LO N O CO N CO (ui/�.'S 098) ylde ie3 �n co i1J A anal 0 • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Rig: 2S-09 Plan: 2S-09A Plan: 2S-09Awp10 Report 07 October, 2016 Permit Pack • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Rig:2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonl' Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyon1z Well: Rig:2S-09 North Reference: True Wellbore: Plan:2S-09A Survey Calculation Method: Minimum Curvature Design: 2S-09Awp 10 Database: OAKE D M P2 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 Rig:28-09 Well Position +N/-S usft Northing: usft Latitude: +E/-W usft Easting: usft Longitude: Position Uncertainty usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore Plan:2S-09A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BG G M2016 10/1/2016 17.80 80.84 57,533 Design 2S-09Awp10 Audit Notes: Version: Phase: PLAN Tie On Depth: 2,852.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 39.10 0.00 0.00 15.00 Survey Tool Program Date 10/7/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 60.00 835.50 2S-09 Srvy 1-SLB_NSG+MSHOT(2S-09 GYD-GC-MS Gyrodata gyrocompassing m/s 858.68 2,088.06 2S-09 Srvy 2-SLB_MWD+GMAG(2S-09 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,184.78 2,758.43 2S-09 Srvy 3-SLB_MWD+GMAG(2S-09 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,800.11 2,800.11 2S-09 Srvy 4-SLB_Inc+Filler(2S-09) INC+TREND Inclinometer+known azi trend 2,877.83 2,852.00 2S-09 Srvy 5-SLB-MWD+GMAG(2S-09) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,852.00 3,202.00 2S-09Awp10(Plan:2S-09A) INC+TREND Inclinometer+known azi trend 3,202.00 4,702.00 2S-09Awp10(Plan:2S-09A) MWD MWD-Standard 3,202.00 8,155.49 2S-09Awp10(Plan:2S-09A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,155.49 9,655.49 2S-09Awp10(Plan:2S-09A) MWD MWD-Standard 8,155.49 14,171.58 2S-09Awp10(Plan:2S-09A) 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) (°/100usft) (°) (usft) 2,852.00 32.09 178.88 2,621.49 2,462.39 0.00 0.00 11.74 KOP:4°/100'DLS,150°TF,for 30' 2,882.00 31.05 180.04 2,647.05 2,487.95 4.00 150.00 15.59 Start 3°/100'DLS,150°TF,for 60' 10/7/2016 12:25:19PM Page 2 COMPASS 5000.1 Build 74 • • SchIurnberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Rig:2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(DoyonlL Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonl2 Well: Rig:2S-09 North Reference: True Wellbore: Plan:2S-09A Survey Calculation Method: Minimum Curvature j Design: 2S-09Awp 10 Database: OAKE DM P2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (°) (usft) (usft) (°/100usft) (0) (usft) 2,900.00 30.59 180.58 2,662.51 2,503.41 3.00 150.00 18.44 2,942.00 29.51 181.87 2,698.87 2,539.77 3.00 149.54 25.68 Adjust TF to 120°,for 90' 3,000.00 28.67 185.01 2,749.55 2,590.45 3.00 120.00 36.01 3,032.00 28.25 186.82 2,777.69 2,618.59 3.00 117.25 41.70 Adjust TF to 90°,for 180' 3,100.00 28.31 191.12 2,837.58 2,678.48 3.00 90.00 53.65 3,194.88 28.63 197.06 2,921.00 2,761.90 3.00 86.21 71.00 C-80 3,200.00 28.66 197.37 2,925.49 2,766.39 3.00 80.99 71.00 3,212.00 28.72 198.11 2,936.02 2,776.92 3.00 80.71 71.94 Adjust TF to-55.13°,for 519.74' 3,300.00 30.30 193.82 3,012.61 2,853.51 3.00 -55.13 72.87 3,400.00 32.24 189.42 3,098.09 2,938.99 3.00 -51.39 73.42 3,500.00 34.33 185.49 3,181.69 3,022.59 3.00 -47.63 73.56 3,600.00 36.53 181.97 3,263.18 3,104.08 3.00 -44.34 73.41 3,700.00 38.82 178.80 3,342.33 3,183.23 3.00 -41.47 73.06 3,731.74 39.56 177.86 3,366.92 3,207.82 3.00 -38.96 72.91 Hold for 374.92' 3,800.00 39.56 177.86 3,419.55 3,260.45 0.00 0.00 72.98 3,900.00 39.56 177.86 3,496.64 3,337.54 0.00 0.00 73.07 4,000.00 39.56 177.86 3,573.73 3,414.63 0.00 0.00 73.18 4,100.00 39.56 177.86 3,650.82 3,491.72 0.00 0.00 73.30 4,106.66 39.56 177.86 3,655.96 3,496.86 0.00 0.00 73.31 Start 3.5°/100'DLS,-162.93°TF,for 3389.43' 4,200.00 36.45 176.24 3,729.50 3,570.40 3.50 -162.93 73.08 4,300.00 33.15 174.23 3,811.60 3,652.50 3.50 -161.66 72.66 4,400.00 29.88 171.83 3,896.85 3,737.75 3.50 -160.00 72.04 4,500.00 26.66 168.90 3,984.91 3,825.81 3.50 -157.95 71.09 4,600.00 23.52 165.25 4,075.47 3,916.37 3.50 -155.38 69.62 4,700.00 20.49 160.56 4,168.18 4,009.08 3.50 -152.06 67.30 4,800.00 17.63 154.38 4,262.70 4,103.60 3.50 -147.72 62.55 4,803.47 17.53 154.13 4,266.00 4,106.90 3.50 -141.87 56.26 C-50 4,900.00 15.03 146.02 4,358.67 4,199.57 3.50 -141.64 56.26 5,000.00 12.85 134.60 4,455.74 4,296.64 3.50 -133.85 45.79 5,100.00 11.34 119.46 4,553.54 4,394.44 3.50 -122.76 29.28 5,124.94 11.10 115.14 4,578.00 4,418.90 3.50 -107.95 8.09 C-40 5,200.00 10.78 101.36 4,651.71 4,492.61 3.50 -103.72 8.09 5,300.00 11.31 83.23 4,749.89 4,590.79 3.50 -90.19 17.37 5,400.00 12.81 68.02 4,847.71 4,688.61 3.50 -72.39 35.22 5,418.78 13.17 65.58 4,866.00 4,706.90 3.50 -57.50 47.33 C-37 5,500.00 14.98 56.53 4,944.79 4,785.69 3.50 -55.13 47.33 10/712016 12:25:19PM Page 3 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Rig:2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyon1 V P' Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(DoyonVV Well: Rig:2S-09 North Reference: True Wellbore: Plan:2S-09A Survey Calculation Method: Minimum Curvature Design: 2S-09Awp10 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 5,542.76 16.05 52.61 4,986.00 4,826.90 3.50 -46.34 55.05 Growler-AA 5,600.00 17.57 48.11 5,040.79 4,881.69 3.50 -42.56 55.05 5,700.00 20.43 41.90 5,135.34 4,976.24 3.50 -38.26 60.01 5,800.00 23.46 37.19 5,228.09 5,068.99 3.50 -32.38 63.31 5,900.00 26.60 33.52 5,318.69 5,159.59 3.50 -28.01 65.58 6,000.00 29.81 30.58 5,406.81 5,247.71 3.50 -24.68 67.21 6,100.00 33.08 28.16 5,492.12 5,333.02 3.50 -22.09 68.41 6,174.93 35.55 26.62 5,554.00 5,394.90 3.50 -20.03 69.33 Top Cairn 6,200.00 36.38 26.14 5,574.29 5,415.19 3.50 -18.76 69.33 6,299.96 39.72 24.42 5,653.00 5,493.90 3.50 -18.37 70.05 Top Bermuda 6,300.00 39.72 24.42 5,653.03 5,493.93 3.50 -17.01 70.05 6,400.00 43.08 22.92 5,728.03 5,568.93 3.50 -17.01 70.62 6,427.55 44.00 22.54 5,748.00 5,588.90 3.50 -15.89 71.09 Base Bermuda 6,500.00 46.45 21.60 5,799.03 5,639.93 3.50 -15.61 71.09 6,600.00 49.84 20.42 5,865.74 5,706.64 3.50 -14.95 71.47 6,700.00 53.24 19.35 5,927.93 5,768.83 3.50 -14.16 71.80 6,800.00 56.64 18.37 5,985.37 5,826.27 3.50 -13.50 72.08 6,874.62 59.19 17.69 6,025.00 5,865.90 3.50 -12.94 72.33 Top HRZ(K-2 mkr) 6,900.00 60.06 17.47 6,037.83 5,878.73 3.50 -12.57 72.33 7,000.00 63.48 16.63 6,085.13 5,926.03 3.50 -12.46 72.54 7,100.00 66.90 15.83 6,127.08 5,967.98 3.50 -12.06 72.74 7,186.67 69.88 15.17 6,159.00 5,999.90 3.50 -11.73 72.92 U.Kalubik(base HRZ) 7,200.00 70.33 15.08 6,163.54 6,004.44 3.50 -11.49 72.92 7,300.00 73.76 14.35 6,194.35 6,035.25 3.50 -11.45 73.08 7,400.00 77.20 13.65 6,219.42 6,060.32 3.50 -11.23 73.23 7,496.09 80.50 13.00 6,238.00 6,078.90 3.50 -11.05 73.37 Hold for 484.71'-L.Kalubik(K-1 mkr) 7,500.00 80.50 13.00 6,238.64 6,079.54 0.00 0.00 73.37 7,600.00 80.50 13.00 6,255.15 6,096.05 0.00 0.00 73.41 7,700.00 80.50 13.00 6,271.65 6,112.55 0.00 0.00 73.45 7,800.00 80.50 13.00 6,288.16 6,129.06 0.00 0.00 73.49 7,900.00 80.50 13.00 6,304.66 6,145.56 0.00 0.00 73.54 7,980.80 80.50 13.00 6,318.00 6,158.90 0.00 0.00 73.59 Start 3.5°/100'DLS,27.32°TF,for 129.87 -Kuparuk C(Top C4) 8,000.00 81.10 13.31 6,321.07 6,161.97 3.50 27.32 73.55 8,019.60 81.71 13.63 6,324.00 6,164.90 3.50 27.27 73.32 A5 8,073.57 83.39 14.50 6,331.00 6,171.90 3.50 27.22 73.32 A4 Target Zone 10/7/2016 12:25:19PM Page 4 COMPASS 5000.1 Build 74 • • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Rig:2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(DoyonVV Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonl2 Well: Rig:2S-09 North Reference: True Wellbore: Plan:2S-09A Survey Calculation Method: Minimum Curvature Design: 2S-09Awp10 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 8,100.00 84.21 14.92 6,333.85 6,174.75 3.50 27.11 73.32 8,110.67 84.54 15.09 6,334.90 6,175.80 3.50 27.06 73.29 Hold for 29.34' 8,140.01 84.54 15.09 6,337.69 6,178.59 0.00 0.00 73.31 Start 3.5°/100'DLS,-32.68°TF,for 15.48' 8,155.49 85.00 14.80 6,339.10 6,180.00 3.50 -32.68 73.37 Hold for 20'-7-5/8"x 9-7/8" 8,175.49 85.00 14.80 6,340.84 6,181.74 0.00 0.00 73.38 Start 2°/100'DLS,-24.1°TF,for 278.49' 8,200.00 85.45 14.60 6,342.88 6,183.78 2.00 -24.10 73.42 8,300.00 87.27 13.78 6,349.23 6,190.13 2.00 -24.08 73.60 8,400.00 89.10 12.97 6,352.39 6,193.29 2.00 -24.03 73.80 8,453.97 90.09 12.53 6,352.78 6,193.68 2.00 -24.00 73.92 Hold for 5717.61' 8,500.00 90.09 12.53 6,352.71 6,193.61 0.00 0.00 73.97 8,600.00 90.09 12.53 6,352.56 6,193.46 0.00 0.00 74.09 8,700.00 90.09 12.53 6,352.40 6,193.30 0.00 0.00 74.25 8,800.00 90.09 12.53 6,352.25 6,193.15 0.00 0.00 74.43 8,900.00 90.09 12.53 6,352.10 6,193.00 0.00 0.00 74.65 9,000.00 90.09 12.53 6,351.95 6,192.85 0.00 0.00 74.89 9,100.00 90.09 12.53 6,351.80 6,192.70 0.00 0.00 75.16 9,200.00 90.09 12.53 6,351.64 6,192.54 0.00 0.00 75.45 9,300.00 90.09 12.53 6,351.49 6,192.39 0.00 0.00 75.78 9,400.00 90.09 12.53 6,351.34 6,192.24 0.00 0.00 76.13 9,500.00 90.09 12.53 6,351.19 6,192.09 0.00 0.00 76.50 9,600.00 90.09 12.53 6,351.04 6,191.94 0.00 0.00 76.91 9,700.00 90.09 12.53 6,350.89 6,191.79 0.00 0.00 74.34 9,800.00 90.09 12.53 6,350.73 6,191.63 0.00 0.00 74.41 9,900.00 90.09 12.53 6,350.58 6,191.48 0.00 0.00 74.49 10,000.00 90.09 12.53 6,350.43 6,191.33 0.00 0.00 74.58 10,100.00 90.09 12.53 6,350.28 6,191.18 0.00 0.00 74.66 10,200.00 90.09 12.53 6,350.13 6,191.03 0.00 0.00 74.76 10,300.00 90.09 12.53 6,349.98 6,190.88 0.00 0.00 74.85 10,400.00 90.09 12.53 6,349.82 6,190.72 0.00 0.00 74.96 10,500.00 90.09 12.53 6,349.67 6,190.57 0.00 0.00 75.06 10,600.00 90.09 12.53 6,349.52 6,190.42 0.00 0.00 75.17 10,700.00 90.09 12.53 6,349.37 6,190.27 0.00 0.00 75.29 10,800.00 90.09 12.53 6,349.22 6,190.12 0.00 0.00 75.41 10,900.00 90.09 12.53 6,349.06 6,189.96 0.00 0.00 75.53 11,000.00 90.09 12.53 6,348.91 6,189.81 0.00 0.00 75.66 11,100.00 90.09 12.53 6,348.76 6,189.66 0.00 0.00 75.79 11,200.00 90.09 12.53 6,348.61 6,189.51 0.00 0.00 75.92 11,300.00 90.09 12.53 6,348.46 6,189.36 0.00 0.00 76.06 11,400.00 90.09 12.53 6,348.31 6,189.21 0.00 0.00 76.21 11,500.00 90.09 12.53 6,348.15 6,189.05 0.00 0.00 76.35 10/7/2016 12:25:19PM Page 5 COMPASS 5000.1 Build 74 • • Schlurnberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Rig:2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyon1z Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonl4 Well: Rig:2S-09 North Reference: True Wellbore: Plan:2S-09A Survey Calculation Method: Minimum Curvature Design: 2S-09Awp 10 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (°) (usft) 11,600.00 90.09 12.53 6,348.00 6,188.90 0.00 0.00 76.51 11,700.00 90.09 12.53 6,347.85 6,188.75 0.00 0.00 76.66 11,800.00 90.09 12.53 6,347.70 6,188.60 0.00 0.00 76.82 11,900.00 90.09 12.53 6,347.55 6,188.45 0.00 0.00 76.99 12,000.00 90.09 12.53 6,347.40 6,188.30 0.00 0.00 77.15 12,100.00 90.09 12.53 6,347.24 6,188.14 0.00 0.00 77.32 12,200.00 90.09 12.53 6,347.09 6,187.99 0.00 0.00 77.50 12,300.00 90.09 12.53 6,346.94 6,187.84 0.00 0.00 77.68 12,400.00 90.09 12.53 6,346.79 6,187.69 0.00 0.00 77.86 12,500.00 90.09 12.53 6,346.64 6,187.54 0.00 0.00 78.05 12,600.00 90.09 12.53 6,346.49 6,187.39 0.00 0.00 78.24 12,700.00 90.09 12.53 6,346.33 6,187.23 0.00 0.00 78.44 12,800.00 90.09 12.53 6,346.18 6,187.08 0.00 0.00 78.64 12,900.00 90.09 12.53 6,346.03 6,186.93 0.00 0.00 78.84 13,000.00 90.09 12.53 6,345.88 6,186.78 0.00 0.00 79.04 13,100.00 90.09 12.53 6,345.73 6,186.63 0.00 0.00 79.25 13,200.00 90.09 12.53 6,345.57 6,186.47 0.00 0.00 79.47 13,300.00 90.09 12.53 6,345.42 6,186.32 0.00 0.00 79.69 13,400.00 90.09 12.53 6,345.27 6,186.17 0.00 0.00 79.91 13,500.00 90.09 12.53 6,345.12 6,186.02 0.00 0.00 80.13 13,600.00 90.09 12.53 6,344.97 6,185.87 0.00 0.00 80.36 13,700.00 90.09 12.53 6,344.82 6,185.72 0.00 0.00 80.59 13,800.00 90.09 12.53 6,344.66 6,185.56 0.00 0.00 80.82 13,900.00 90.09 12.53 6,344.51 6,185.41 0.00 0.00 81.06 14,000.00 90.09 12.53 6,344.36 6,185.26 0.00 0.00 81.30 14,100.00 90.09 12.53 6,344.21 6,185.11 0.00 0.00 81.55 14,171.50 90.09 12.53 6,344.10 6,185.00 0.00 0.00 81.73 41/2"x 6-3/4" 14,171.58 90.09 12.53 6,344.10 6,185.00 0.00 0.00 81.73 TD:14171.58'MD,6344.1'TVD 10/7/2016 12:25:19PM Page 6 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Rig:2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(DoyonVV Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(DoyonVV Well: Rig:2S-09 North Reference: True Wellbore: Plan:2S-09A Survey Calculation Method: Minimum Curvature Design: 2S-09Awp10 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C') (') 8,155.49 6,339.10 7-5/8"x 9-7/8" 7-5/8 9-7/8 14,171.50 6,344.10 4 1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 7,186.67 6,159.00 U.Kalubik(base HRZ) 3,194.88 2,921.00 C-80 5,542.76 4,986.00 Growler-AA 5,418.78 4,866.00 C-37 5,124.94 4,578.00 C-40 8,073.57 6,331.00 A4 Target Zone 6,874.62 6,025.00 Top HRZ(K-2 mkr) 7,496.09 6,238.00 L.Kalubik(K-1 mkr) 4,803.47 4,266.00 C-50 7,980.80 6,318.00 Kuparuk C(Top C4) 8,019.60 6,324.00 A5 6,174.93 5,554.00 Top Cairn 6,299.96 5,653.00 Top Bermuda 6,427.55 5,748.00 Base Bermuda Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 2,852.00 2,621.49 -950.45 17.67 KOP:47100'DLS,150°TF,for 30' 2,882.00 2,647.05 -966.16 17.82 Start 37100'DLS,150°TF,for 60' 2,942.00 2,698.87 -996.40 17.33 Adjust TF to 120°,for 90' 3,032.00 2,777.69 -1,039.71 14.08 Adjust TF to 90°,for 180' 3,212.00 2,936.02 -1,123.16 -4.44 Adjust TF to-55.13°,for 519.74' 3,731.74 3,366.92 -1,409.00 -37.26 Hold for 374.92' 4,106.66 3,655.96 -1,647.64 -28.33 Start 3.57100'DLS,-162.93°TF,for 3389.43' 7,496.09 6,238.00 -752.41 649.47 Hold for 484.71' 7,980.80 6,318.00 -286.60 757.01 Start 3.57100'DLS,27.32°TF,for 129.87' 8,110.67 6,334.90 -161.72 788.26 Hold for 29.34' 8,140.01 6,337.69 -133.53 795.87 Start 3.57100'DLS,-32.68°TF,for 15.48' 8,155.49 6,339.10 -118.63 799.84 Hold for 20' 8,175.49 6,340.84 -99.37 804.93 Start 27100'DLS,-24.1°TF,for 278.49' 8,453.97 6,352.78 170.88 870.63 Hold for 5717.61' 14,171.58 6,344.10 5,752.32 2,110.96 TD:14171.58'MD,6344.1'TVD Checked By: Approved By: Date: 10/7/2016 12:25:19PM Page 7 COMPASS 5000.1 Build 74 • 0 • d 0a, Li. 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R m mU 5t) N N Oa U C) 0 N Q F ce m w U 0) 0 U ¢ • • to Zl" October 07 2.16 Ladder View 2S-09Awp10 The Reference Well is along the X-axis. rror Ellipses are the Sum of the Reference and Offset Well Errors Failed Anti-Collision 4 N 300 iiip� II) I 1 — � ----- cV c3 7' /1 ,v , IvvrT3 IVN I CO w 150— � . ; 1 HIIII4t. .✓� 4-- ' N o y ' / re , \U 1 11 I IIIIIIII4;11 0 1 _ I I I I I I I �-�. Equivelant Magnetic Distance 4500 6000 7500 9000 10500 12000 Displayed interval could be less than entire well:Measured Depth2852.00 To 14171.58 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 60.00 835.50 2S-09 Srvy 1 -SLB_NSG+MSHOTcO9K-MS 6339.187155.49 7-5/8"x 9-7/8" 858.68 2088.06 2S-09 Srvy 2-SLB_MWD+GMAG ID9)FR-AK-CAZ-SC 63441k0171.50 4 1/2"x 6-3/4" 2184.78 2758.43 2S-09 Srvy 3-SLB_MWD+GMAG I(ID9)FR-AK-CAZ-SC 2800.11 2800.11 2S-09 Srvy 4-SLBInc+Filler(2S-O+TREND 2877.83 2852.00 2S-09 Srvy 5-SLB-_MWD+GMAG QasvU9 IFR-AK-CAZ-SC 2852.00 3202.00 2S-09Awp10 (Plan: 2S-09A) INC+TREND 3202.00 4702.00 2S-09Awp10 (Plan: 2S-09A) MWD 3202.00 8155.49 2S-09Awp10 (Plan: 2S-09A) MWD+IFR-AK-CAZ-SC 8155.49 9655.49 2S-09Awp10 (Plan: 2S-09A) MWD 8155.4914171.58 2S-09Awp10 (Plan: 2S-09A) MWD+IFR-AK-CAZ-SC 4 N ce c o O m a �I J (A 40 ®.. -- T 4111111111 -wm. c 0 U O 1 c U 0 1 1 - I 1 1 I f r i 1 i I I I I 1111 I I I I I I I 3150 3600 4050 4500 4950 5400 5850 Partial Measured Depth • 11:26, October 07 2C16 2S-09Aw 10 Ladder View pThe Reference Well is along the X-axis. rror Ellipses are the Sum of the Reference and Offset Well Errors Minor Risked 4 N N 300 I -milift► 1 I i _. c 0111/V 0 `m 111 u) ti ( N 150— �' A y U r /I' f N O 1�N (V U 0 1 I I- I I I I 1 I I 1 1 I I I I I I 1 I I I I I 1 1 1 Equivelant Magnetic Distance 4500 6000 7500 9000 10500 12000 Displayed interval could be less than entire well:Measured Depth2852.00 To 14171.58 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 60.00 835.50 2S-09 Srvy 1 -SLB_NSG+MSHOT Q9p-MS 6339.1E0155.49 7-5/8"x 9-7/8" 858.68 2088.06 2S-09 Srvy 2-SLB_MWD+GMAG I D9)FR-AK-CAZ-SC 6344i14)171.50 4 1/2"x 6-3/4" 2184.78 2758.43 2S-09 Srvy 3-SLB_MWD+GMAG f(l1MD )FR-AK-CAZ-SC 2800.11 2800.11 2S-09 Srvy 4-SLBInc+Filler(2S-09¢+TREND 2877.83 2852.00 2S-09 Srvy 5-SLB-_MWD+GMAG (21W1/C18)IFR-AK-CAZ-SC 2852.00 3202.00 2S-09Awp10 (Plan: 2S-09A) INC+TREND 3202.00 4702.00 2S-09Awp10 (Plan: 2S-09A) MWD 3202 00 8155.49 2S-09Awo10 (Plan. 2S-09A) MWD+IFR-AK-CA7-SC N DI C 60 ir /" ............y Co o) N• 30 am..--- C) O - 4) - N U 0 I I 1 I I I I— 1 I 1 1 I I I I I 1 1 I I I I I 1 1 1 1 I I 1 1 3150 3600 4050 4500 4950 5400 5850 Partial Measured Depth • u auoz 2S-09Awp10 M Inc Azi TVD Dleg TFace Target 2852 3050 2852.00 32.09 178.88 2621.49 0.00 0.00 2852.00 To 14171.58 2882.00 31.05 180.04 2647.05 4.00 150.00 3050 3240 2942.00 29.51 181.87 2698.87 3.00 150.00 3240 3430 3032.00 28.25 186.82 2777.69 3.00 120.00 10:22,October 07 2016 3212.00 28.72 198.11 2936.02 3.00 90.00 3430 3620 3731.74 39.56 177.86 3366.92 3.00 -55.13 CASING DETAILS 4106.66 39.56 177.86 3655.96 0.00 0.00 3620 3820 7496.09 80.50 13.00 6238.00 3.50 -162.93 TVD MD Name 7980.80 80.50 13.00 6318.00 0.00 0.00 3820 4010 6339.10 8155.49 7-5/8" x 9-7/8" 8110.67 84.54 15.09 6334.90 3.50 27.32 6344.10 14171.50 4 1/2" x 6-3/4" 4010 4200 8140.01 84.54 15.09 6337.69 0.00 0.00 8155.49 85.00 14.80 6339.10 3.50 -32.68 29-09 1. Heel 100616 JH 4200 4610 8175.49 85.00 14.80 6340.84 0.00 0.00 55Rvzoe m€ 8453.97 90.09 12.53 6352.78 2.00 -24.10 4610 5030 R��aceplA To 5un.�.relaA Tool 14171.58 90.09 12.53 6344.10 0.00 0.00 2S-09 3. Toe 100616 JH 5030 5440 60 00 835 50 2S-09 -0344 Sr,858 68 2088 06 23-09 1 0T- emc WIDOW-Alt-cA2-5C Sr,2184 78 275.43 25 09 3-S. u(+834068m-AR-C82-Sc 23-09200 0(8 an 3-09A 2877 832852 00e _x_50 5440 5850 2202.00 4202.00 255 1.D.TR 0 3202.00 8155.49 25-05Axp10 (elan:25-09A) eMD m 3202.00 8155 49 25-09A�10 (el : 25-09A m01TR-AR-CAL-SC5850 `"`''"_ 6260 8155 49 9655 4909A,10 (elan: 2S-09A) 1,618 8055.491.1,1.58 25-091,10 (elan: 25-09A) e4131.1.R-AR-CA2-3C 6260 6670 6670 7090 7090 7500 Failed Anti-Collision 7500 8330 0/360 8330 9170 a �re�r,'���"'. -, ' ail /. 9170 ��� 10000 30/33 " 4,14 `♦♦��� ♦1 f, 30 10000 10840 �� +� . , �� � . 10840 - 11670 li7► !. k�„„. .` ,. __,=_,.._;-,--_-" ,.� 11670 12500 `a; "",04&%-.1..--.7.4x-t-� i-� .�:-_, . 12500 13340 % -_ -- 13340 14172 • �3 / ' ♦ • �' V.-01-74,44- ♦ .o�svi: o - � x`60-60/ 00 r „oval', i � • . ,> e U ®'�0y\�♦ f. 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Ill(..�11( �' Y� o. a.1`:,..,'.' -90/270 ✓,im...N\\>�� 1Ir,1,a,I i��r0 AIr wIl {.Y ipr -- • 90 e:0'11�nli1/4`\� ��i'lll ,v®�i1jf4rr4 „vI!'r /�I�r t,i % s.'0S0"�°•i . {,y rA��� ®0 < EY r7 iii..♦ 5 ?��i l��1Ci l♦{ • s i ■ ,.IIIII��I1 y,xo 4!"4,1'.40,...--5-s. • i4({{r ' 1; i if ai4 V s• 4' .r . . 1, h' '"'44��11 4, ♦ 0h41{114r•1 ir/ s.y w'r"� 1,4 �• a /, r O0�®'sr / '�'i :'/ 1'{If{�10�♦r1.®t /r s 45►��'6q®���p�r' .+ i ��,;. ,.I\ •Eoe;w My 'r;%j. /;;4111.044.41:...,%:' %4 0+.'•A�4:WItrf. //' \��\�� Al9945 ., '4''" rr,t frf:."4:s,1li41 4v OPIA r ee r 'r. Pi r{{♦ ♦I I � CA •O I.a� 4♦%1 6..�®., p4. •r /1' f.teeGdIy4�fj j r /j/41e, \`O ,-..f �� �•r 9�j jr'• -r. ,�9/I.4 •J ♦�•'.� • e moi%/ �®�1.; �� .1.,‘„,1:‘,.. m i 1 lls�/r r ,,..„.„-: 120/240 tletivi- ��I i"-;"104/4`r: ' 1,M®,RI9t��®`� - Ce`° �!� Isky a�.�rr` '� �011k� ' ol} ''` ;wawa- ���� 120 "\`44e4r400,4401 4 ley q -- 11116alli 1441tkIN---.... 4A°1111 If I(fil;_ i •,,14,44,44404 Iihi itfl/liqq,4 t!, t vivirtire14- . s .VAII‘ 0 pop syr,<f \ tago.„*,„---- Attlidlit. ', ,,,,, t���p �lid��l,p14 Nx_„mil, �. i®® .0. ,.,\\�\� '� A �,�i'°"A - ��®�® - -150/210 �Vik`\���ttiolk�, 42 4,1������0�i�� 150 �� ye`\\�\e_------t- ��� -180/180 U Lu5L 2S-09Awp10 M • Inc Azi TVD Dleg TFace•get 2852 3050 2852.00 32.09 178.88 2621.49 0.00 0.00 2852.00 To 14171.58 2882.00 31.05 180.04 2647.05 4.00 150.00 3050 3240 2942.00 29.51 181.87 2698.87 3.00 150.00 3240 3430 3032.00 28.25 186.82 2777.69 3.00 120.00 11:26,October 07 2016 3212.00 28.72 198.11 2936.02 3.00 90.00 3430 3620 3731.74 39.56 177.86 3366.92 3.00 -55.13 CASING DETAILS 4106.66 39.56 177.86 3655.96 0.00 0.00 3620 3820 7496.09 80.50 13.00 6238.00 3.50 -162.93 3820 TVD MD Name 7980.80 80.50 13.00 6318.00 0.00 0.00 4010 6339.10 6155.99 7-5/8" x 9-7/8" 8110.67 84.54 15.09 6334.90 3.50 27.32 6344.10 14171.50 4 1/2" x 6-3/4" 4010 4200 8140.01 84.54 15.09 6337.69 0.00 0.00 8155.49 85.00 14.80 6339.10 3.50 -32.68 2S-09 1. Heel 100616 JH 4200 4610 8175.49 85.00 14.80 6340.84 0.00 0.00 511,7 pROGRAM 8453.97 90.09 12.53 6352.78 2.00 -24.10 4610 5030 rverie�� Toon 14171.58 90.09 12.53 6344.10 0.00 0.00 25-09 3. Toe 100616 JH 5030 5440 - - e,nc ew�w-zx-uz-SC 5440 - 5850 3202 00 8155 49 25 _0 ° P 092) - x^,- 5850 6260 8155 49 9655 49 25.,2,o 92 6260 - 6670 6670 __--__ 7090 7090 7500 Minor Risked 7500 8330 0/360 8330 - 9170 , 9170 10000 -30/33! � //�,r 210 1.05 30 10000 10840 , ..4�►,� J 10840 11670 'S-09 --`' �.�•,•rP 195 ,. ., 11670 12500 �t��:'�:$':1v‘W113 165 12500 13340 Minor Risked �� .b�✓ � /��� '1%' 165 ' .-„ .I ® t, �l' ,:. 13340 14172 -60/300 // � ,i9•�4A.'4011,4.1 13, 2 60 / / :-' 41,44104$10001 �'iii ,��irl '74 1 2 iy„''*' _ #0061 :7 � R-� t til. 1 ► ;:::.!...___I : , illi . . 0f0 90/270 L I_ .�_ �1�1.414 1611 ,,.r• -90 1 t 1► OfJl //+ Y,. kid \ \\\ \' ®A%,1 tt.0 / ila 1,�.``:I� J/�®ai ���* \ \, --11x04/,' 'ice A„,„:,0460114*,,,,' ,..64 4111,11,10 ' ` 111111 ' 11,400 , ' / z ,,,,,.......,..0;r7...70.1.-,-,„,,4-40 �p****1111%111014,014 fid.;; for? -120/240 la,„. 120 1�k • Q1*„ .411),11,, \\ *.f i /� o,Vt--C - o ..o e.e' 120 \,,A 135 '14, �. ` e 1,`11 cs1�.A+°l p 150 INIFJ 0‘ 4soeo Ili 11,14,v ' �`��l��1♦'441,0 .**V l �\���i///i® dpi.++,s�nh a�1iibig T..;�}i;:i�a�� 1'40 165 �!`����51� '1��/'1f'��rlt�1\$ '' 9 *04 Vit10-0010111010r .‘ 195 •`,-..a1010,•%.0•liiie0'0 0'0 ' L2S-07 `uveae -150/210 210 'e 150 Minor Risked 225 -180/180 Pool Report • • 0 0 0 1 .c rw- aSSSSS c- 1 0 `m z BSoM 0 d VP;ot m 0 U KC.c:CSK a 11;1; ! UUVUU_' P. 44qq i o !ii NN N w oS<S< 9 0 i rmmmmm N 0 fi i O OW c H m 1 meE Q oS w f IN N 88 oN a. OPiff 3 i. CO C "adsoN N O 0 xi9x�12mm �Ni.of of 0.o) s 0 mQoN89 N 1111 Q LO ZNNNc— , 0 H it i Afill"V U) N N of � 0 1 co 1.0 el .. .�_ Cl) MI y 1 ►i� y W N ���� N 01111111 .— co 0 U) ^+ y y \' a N CO Y/ y N N .N. i 1 1 0, pp i CZ N O ^ c� N N to CI. 0 N •� o Q ` O CDL Cl) L- o (Ni CCS o) 10 I O O O N 1 d 0 0 0 0 0 0 O 0ti 0 0 0 00 1.00 o ti Cr) co N- 0 r (ui/44sn 0050) (+)u4aoN/( -)u}nos I • • • • t !, ., i ; .. ., „ ,, ,,,,,.,,,,,,."...... .....„..:.,...„.... , • i' ;:` 1' . I i ./.„ •. :if/ ... 42) • M 4 *; N m • • • • • • • . \ • 9 • l, d . o r."?...' . „ilia S.. ,../ 11N, -� ;®, to N '''' 4111k • • 2S-09A Drilling Hazards Summary 9-7/8"x 11"Hole/7-5/8"Casing Interval Event Risk Level Mitigation Strategy Shale stability High For the unstable HRZ and Kalubik shales with high inclination:drill with highest possible MW without break formation causes losses.Use MPD tripping practices to avoid surging or swabbing. Use MPD technology to keep constant BHP while drilling. 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 Moderate 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 12.0 ppg in Tam formations crossed in intermediate. Hole cleaning Low Use PWD and TAD to monitor hole cleaning.Control the ROP and use the best hole cleaning practice. Stuck pipe Low Good hole cleaning,stabilized BHA,proper mud weight,PWD monitor ECD. Abnormal Reservoir Pressure Low 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 Low Condition mud prior to trips. Monitor ECD's with PWD tool while MW's required drilling across pay interval. 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 Low Good hole cleaning,stabilized BHA,proper mud weight to minimize differential stuck,PWD monitor ECD. Hole swabbing on trips Low Monitor proper hole fill while tripping,good hole cleaning.Backream out to intermediate shoe,then utilize MPD to strip out and eliminate swab. • • 2S-09A 7.625"Intermediate Casing Cement Program Top of slurry is designed to be at 4,918' MD,which is 500'above the C37.Assume 30%excess annular volume. Tail slurry from 8,155'MD to 6,174'MD with 15.8 ppg Class G+additives 7-5/8"x 11" Under reamer to Top of Cement (7,995'—6,174')X 0.3429 ft3/ft X 1.30(30%excess) =812 ft3 7-5/8"x 9-7/8"Shoe to Under reamer (8,155'—7,995')X 0.2148 ft3/ft X 1.30(30%excess) =45 ft3 7-5/8"Shoe Joint (120')X 0.2578 ft3/ft X 1.0(0%excess)=31 ft3 Total Volume=812+45+31=888 ft3=>766 sx of 15.8 ppg Class G @ 1.16 ft3/sk Second Stage from 5,518'-4,918'MD with 15.8 ppg Class G+additives 7-5/8"x 11" Under reamed hole (5,518'—4,918')X 0.3429 ft3/ft X 1.30(30%excess) =268ft3 Total Volume=268 ft3=>232 sx of 15.8 ppg Class G @ 1.16 ft3/sk • I TRANSMITTAL LETTER CHECKLIST WELL NAME: /<1Z�1.. S" QqA— PTD: (00 -/2_ Development Service Exploratory Stratigraphic Test _Non-Conventional FIELD: I POOL: 4,7(ja,44. 7 .I�It4SCUZAR ?\jer 0 '/ 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. 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